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Home My WebLink About206-005 tiOF Ttt, • THE ARE Alaska Oil and Gas � ►�`s� �, ofALASI�:1- Conservation Commission • __= , 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 h: OF Q. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineers AY 2 4 nth ConocoPhillips Alaska, Inc. st° PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-159 Permit to Drill Number: 206-005 Sundry Number: 318-215 Dear Mr. Peirce: Enclosed is the approved application for the 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, Hollis S. French Chair DATED this 23 day of May, 2018. BOMS r Mai 13 1.04R RECEIVED • 0 STATE OF ALASKA MAY 2 2 2O1 ALASKA OIL AND GAS CONSERVATION COMMISSION 5/ �3 1 APPLICATION FOR SUNDRY APPROVALS AOG �: 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE TrtmtE• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development El • 206-005 • 3.Address. Stratigraphic 0 Service ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23297-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1J-159 ' Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25661,ADL 25662 Kuparuk River Field/West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,857' ' 3,642' • 7841 3642 1500psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 77' 20" 108' 108' Surface 2,333' 10 3/4 2,365' 2,207' Production 5,549' 7 5/8 5,575' 3,701' Liner 3,176' 4 1/2 7,842' 3,642' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5567-7810 3695-3642 4.500" L-80 4,194' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER=ZXP LINER TOP PACKER 4200 MD and 3469 ND PACKER=ZXP LINER TOP PACKER 4355 MD and 3508 ND PACKER=HRD ZXP LINER TOP PACKER 4666 MD and 3566 ND SSSV: =NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 ' Service ❑ 14.Estimated Date for 6/20/2018 15.Well Status after proposed work: Commencing Operations: OIL 0 . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr.Wells Engineer Contact Email: John.W.Peirce@cop.com * Contact Phone: (907)265-6471 Authorized Signature: /, ''• Date: Iz1'18 I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ;I$ - 2IG Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: �y 111" Post Initial Injection MIT Req'd? Yes El No IV mr. Spacing Exception Required? Yes ❑ No " Subsequent Form Required: /r, 4 vdotA ►` APPROVED BY Approved by: g&r\____ COMMISSIONER THE COMMISSION Date: S/Z•; is VTZ- /a3IIT A L TLrlSubmit Form and o S Form 10-403 Revised 4/2017 Approved applicatia o o t s rom e date of approval. Attachmen s in Duplicate • KUP PROD 1J-159 C�IM_'";� ; �M Well tes Ma &MD TD V1'(1f Wellbore Field Name Wellbore Status ncl(°) D(MB) Act Btm(IKB) Alaska,1110 500292329700 WEST SAK PROD 93.86 6,310.37 7,857.0 lAtloCaffnwN„p6p Comment H2S(ppm) Date Annotation End Date IKB-Grd(ft) Rig Release Date .°. SSSV:NIPPLE 60 8/11/2015 Last WO: 1/28/2008 31.01 3/13/2006 MULTIPLE LATERALS-1J-159,5/17/2018 6:46:49 AM Last Tag Vertical schemehc(actual) Annotation Depth(ftKB) End Date Last Mod By Last Tag: Irnosbor .W1_, Last Rev Reason HANGER;22.8 - Annotation°� End Date Last Mod By Rev Reason,H2S,PULLED B LAT ISO SLEEVE,GLV C/O 5/20/2016 pproven IMILIIIMIIMIIMIWIIII iCasing Strings t. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread LLL�� CONDUCTOR 20 18.936 31.0 108.0 108.0 62.60 H-40 WELDLD Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) 'Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 31.2 2,364.5 2,206.4 45.50 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) 'Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 75/8 6.875 26.6 5,575.1 3,695.3 29.70 L-80 BTCM -^e^..CONDUCTOR;31.0-108.0- - -/�+r�Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(RKB) °Set Depth(TVD)...WtlLen(I...Grade Top Thread L2 LINER LEM 4 1/2 3.958 4,189.2 4,386.3 3,515.8 12.60 L-80 IBT NIPPLE;515.0 : : Liner Details HEAT TRACE;23.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (int ' 4,189.2 3,465.9 72.86 PBR BAKER 190-47 PBR 5.750 4,200.2 3,469.1' 73.32 PACKER ZXP LINER TOP PACKER 4.950 • SURFACE;31.2-2,384.5 4,208.2 3,471.3 73.66 SBE SEAL BORE EXTENSION 4.750 4,227.5 3,476.6 74.48 XO Bushing 3.958 4,232.6 3,478.0 74.70 HANGER 1 LEM ABOVE HOOK HANGER 3.980 4,245.2 3,481.3 75.23 HANGER 2 LEM BELOW HOOK HANGER 3.980 GAS LIFT;2,559.4 i II 4,341.0 3,505.0 75.66 SEAL ASSY LEM BAKER SEAL ASSEMBLY 3.880 Casing Description OD(in) ID(in) Top(ftKB) Set Depth IRKS) Set Depth(TVD)...WtlLen(I...Grade Top Thread L1 LINER HH LEM 4 1/2 3.958 4,355.1 4,705.5 3,571.1 12.60 L-80 IBT Liner Details - - _ _ Nominal ID Top(RKB) Top(ND)(ftKB) Top Incl Cl Item Des Com (in) 4,355.1 3,508.4 75.80 PACKER ZXP LINER TOP PACKER 4.950 GAS LIFT;4,093.6 -£ 4,372.3 3,512.6 76.38 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 -- 4,391.9 3,517.1 77.04 XO BUSHING CROSSOVER BUSHING 3.910 NIPPLE;4,1372 . 4,550.3 3,547.9 79.90 ABOVE HH LEM ABOVE HOOK HANGER 4.020 4,560.9' 3,549.7 80.16 INSIDE HH LEM INSIDE HOOK HANGER 4.020 GAUGE;4,147.6 �'4►. _ 4,626.4 3,560.0 81.80 NIPPLE CAMCO'DB'NIPPLE 3.562 4,702.3' 3,570.6 81.97 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 - T' Casing Description OD(in) ID(in) 1Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade rTop Thread I- A-SAND LINER 4 1/2 3.958 4,666.1 7,842.1 3,642.2 12.60 L-80 I IBT LOCATOR;4,1935 .'Q' Liner Details - Nominal ID SEAL ASSY;4,194.5 Top(ftKB) Top(ND)(RKB) Top Inol(°) Item Des Com (in) W- 4,666.1 3,565.6 81.92 PACKER "HRD"ZXP Liner Top Packer 5.5"X 7.6" 4.970 # 4,685.1 3,568.2 81.94 NIPPLE "RS"Packoff Seal Nipple 5.5" 4.875 4,688.0' 3,568.6 81.95 HANGER FlexLock Liner Hanger 5.5"X 7.6" 4.853 • 4,697.8 3,570.0 81.96 SBE 190-47 Casing Seal Bore EEL 4.75"ID x 6.25"OD 4.750 D-SAND LINER;4,241.4- ,, 4,717.4 1 3,572.8 1 81.99 IXO BUSHING 1X0 Bushing 3.92"ID,6.02 OD 1 3.920 10,859.6 I' Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING WO 4 1/2 3.958 22.6 4,222.2 3,475.2 12.60 L-80 IBTM Completion Details NTop(TVD) Top Incl Nominal . Top(ftKB) (ftKB) 0) Item Des Corn ID(in) 1 r L2 LINER LEM;4,189.2-4,386.322.6 22.6 0.00 HANGER TUBING HANGER 3.958 -�- 515.0 514.8 5.01 NIPPLE CAMCO'DB'NIPPLE 3.875 4,137.2 3,449.6 70.75 NIPPLE CAMCO DB Nipple 3.812 4,147.6 3,453.0 71.16 GAUGE GUARDIAN GAUGE CARRIER 3.850 - 4,193.8 3,467.2 73.06 LOCATOR LOCATOR 3.880 4,194.5 3,467.4 73.08 SEAL ASSY BAKER GBH-22 PACKER 3.880 B-SAND LINER;4,580.2- 1 11,161.1Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 1 Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 23.0 23.0 0.00 HEAT TRACE HEAT TRACE SET DURING 1/23/2008 WORKOVER 1/24/2008 0.000 II Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shots/ft Top(ftKB) Btm(kKB) (RKB) (ftKB) Zone Date ) Type Com = 5,567.0 5,721.0' 3,695.2 3,697.2 WS A2,1J-159 '2/23/2006 32.0'SLOTS SLOTTED LINER 0.125"x MI 2.5"x32 spf@ 4 Li LINER 1< I Circumferential adjacent HH LEM;4,355.1- rows,3"Centers staggered 47055 • I 18 deg.,3 ft.non-slotted ends 5,845.0 6,091.0 3,694.4 3,688.1 WS A2,1J-159 2/23/2006 32.0 SLOTS 6,399.0 7,810.0 3,681.8 3,642.2•WS A2,1J-159 2/23/2006 32.0 SLOTS Mandrel Inserts St I I aonl N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn PRODUCTION;28.6-5,575.1 1 2,589.4 2,407.6 CAMCO 'KBBG-2- 1 GAS LIFT GLV BK-5 0.156 1,530.0 2/19/2008 SLOTS;5,567.05,721.0I. 1R I 2 4,093.6 3,434.6 CAMCO 'KBG-2- - 1 GAS LIFT DV BK 0.219 0.0 5/19/2016 1R SLOTS;5,645.06,091.0 Notes:General&Safety End Date Annotation SLOTS;6,399.0-7,610.0 5/11/2006 NOTE:MULTI-LATERAL WELL:1J-159(A-SAND),1J-159L1(B-SAND),1J-159L2(D-SAND) A-SAND LINER;4,666.1-7,842.1 . KUP PROD 1J-159 'ConoaoPhillips • Alaska,Inc. ... Cbrw6O6hilltp MULTIPLE LATERALS-1J-159,5/17/2018 6:46'.50 AM Vertical schematic(actual) .0:111 HANGER,22.6 E _,, , Notes:General&Safety .■ I End Date Annotation 2/21/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.OREV 6/7/2013 NOTE:PULLED B LAT ISO SLEEVE -^-A.CONDUCTOR;31.0-108.0- • NIPPLE;515.0 III HEAT TRACE;23.0 SURFACE;31.2-2,364.5 1 ■ GAS LIFT;2,589.4 I II GAS LIFT;4,093.6 II1111 t al NIPPLE;4,137.2 hiii GAUGE;4,147.6 Gr... LOCATOR;4,1936 ; I SEAL ASSY;4,194.5 Y i ! `I DSAND LINER;4,241.4 ,1. 10,858.6 1' 'I I I 1.2 LINER LEM;4,189.2-4,386.3 ( ✓t. .11 rt. 13-SAND LINER;4,580.2- 11,161.1 II- '7..!.- . V L1 LINER HH LEM;4,355.1- 1 I I 4,705.5 ? I II PRODUCTION;28.6-5,575.1 SLOTS;5,567.0-5,721.0 SLOTS;5,845.08,091.0 SLOTS;6,399.0-7,810.0 1 A-SAND LINER;4,666.1-7,842.1 .1 • • • Proposed 1J-154L1 to 1J-159 B Sand MBE Retreatment with RPPG 1J-154 is a West Sak Tri-lateral injector with horizontal laterals in the D, B, and A sands. All 3 laterals contain 4.5", L-80, slotted liners. An MBE occurred 3/3/18 in 1J-154 to offset 1J-159 producer. This is the first MBE in 1J-154. A mainbore IPROF performed on 4/3/18 indicated all injection was going to B lateral. The D lateral was seen crossflowing to B lateral as well, and slight crossflow was seen from A Lat to B Lat. A 1J-154L1 B Lat IPROF of 5/4/18 verified a robust B MBE exists at -8395' MD. This MBE is about half way down the B Lat Liner. 1J-154 is currently configured with an A Lat Plug set, and B Diverter set, and a D Iso-Sly set. Per this procedure, a functional waterflood pattern is to be restored between 1J-154L1 and 1J-159L1 by pumping an RPPG treatment in 1J-154L1 to seal off the B MBE. CT will first deploy a 5' Perf Gun to pert large holes at 6 spf, 60 deg ph, in 4.5" B lateral Liner at 8393 - 8398' RKB over the B MBE at -8395' RKB. This will enable good passage of RPPG slurry through the liner to the B MBE. Due to wellbore volume of -127 bbls to B MBE, CT will be used to pump the RPPG treatment. Pumping down CT allows for monitoring RPPG treatment response development earlier than possible by pumping fullbore. CT also enables placing the RPPG to the MBE faster at any pump rate. Following MBE treatment, 1J-154L1 will be returned to injection to evaluate `B Lat only' performance " for long enough to verify that the B MBE is successfully sealed before normaling up the A and D Lats. Proposed Procedure Coil Tubing: 1) RIH to shoot 5' of 'big hole' add perforations at 8393 - 8398' RKB near the B MBE at -8395' RKB. The perfs are shot over the MBE to provide better passage of RPPG through slotted liner to the MBE. 2) Have 1J-159 producer online and put 1E-105 BOI at -1000 BWPD 12 - 24 hrs before CTU RU on 1J-154. Flow 1J-159 to 1J test separator to avoid CPF1 upset. This establishes flow through MBE between the wells to ensure MBE is open for RPPG, and pushes away gas head from 1J-154 to MBE. Ideally, we want tubing liquid packed for pumping RPPG treatment. RU CT with 2" CT on 1J-154. Request 1J-159 SI when CT is ready to RIH, but keep 1J-154 on injection at -1000 BWPD. RIH with large single down port Nozzle while displacing Diesel FP from CT pumping -50 bbls of 2% KCL Water down CT at -0.5 bpm as injection continues down CT x Tbg annulus. Park Nozzle at Safety above all liner slots at 4405' RKB, and then halt pumping down CT to check WHIP on CT x Tbg. Record starting WHIP on tubing. Any gas head that was in tubing should have been fully displaced from tubing to MBE, so WHIP on tubing should be low to start the RPPG treatment. • S SI SWI to 1J-154 CT x Tbg annulus, and swap to pumping 2% KCL Water from transport down CT x Tbg annulus at minimum rate (-0.4 bpm), to keep CT x Tbg annulus flushed of any potential RPPG stacking up CT backside during RPPG pumping as precaution to prevent stuck CT. Pump short Step Rate Injection Test (SRIT) down CT with 2% KCL Water at 1 bpm, 1.5 bpm, and 2 bpm to record a stable CT treating pressure at each rate. Pick a steady treating rate between 1 to 2 bpm that yields a good starting CT treating pressure somewhere in range of 1000 - 2000 psi. After a steady pump rate is determined, start mixing 2% KCL Water from transport with 1 - 4 mm mesh RPPG at 0.75 ppg concentration (31.5 lbs/bbl) in mixing van to make RPPG slurry on-the-fly while pumping it down CT at established steady rate. Note: CT x Tbg pump rate + CT pump rate = total rate entering MBE, so we will calculate proper RPPG ppg concentration to pump down CT to yield a Net = 0.75 ppg Slurry in the total rate to B MBE. Pump 0.75 ppg RPPG slurry in 2% KCL Water until WHP on CT x Tbg annulus approaches -800 psi. We may pump up to 10 sacks of 'Tail slurry' of Crystal Seal or PolySwell at 0.25 ppg in 2% KCL to leave an easier slurry to FCO in wellbore and to reserve some RPPG stock on hand. Make frequent precautionary PU weight checks, then RBIH to park nozzle at safety at 4405' RKB. When Flush is called, continue simultaneous pumping down CT and CT backside as follows: Down CT: With nozzle parked at 4405' RKB, swap to 5 bbls of 2% KCL Brine Spacer at established steady rate down CT, followed by 1 CT volume (-50 bbls) Diesel down CT at established steady rate down CT, followed by SD pumping down CT, and start POOH to surface. Down CT Backside: Closed end displacement volume of 2" CT to 4405' RKB = 17.1 bbls = voidage created in well when CT is POOH. We need to replace 17.1 bbls during CT Backside pumping, plus need to pump additional 60.6 bbls displacement volume to push RPPG top down 4.5"liner from 4405' RKB to MBE at 8395'RKB. Thus, pump total of 77.7 bbls down CT Backside after CT SD. Proceed with CT Backside pumping as follows: Continue 2% KCL Water pumping at minimum rate (-0.4 bpm) to maintain steady total rate to well (to monitor treating pressure) until CT pumping SD, then increase CT x Tbg rate by rate equal to rate CT was pumping before SD. This maintain total steady rate to well to monitor treating pressure at constant rate. Pump 46.7 bbls of 2% KCL Brine at new increased rate, followed by 31 bbls of Diesel to FP Tubing at new increased rate, followed by SD. This leaves tubing FP to 2000' TVD; 2089' RKB, and puts RPPG slurry fully displaced to the MBE at 8395' RKB. Rate down CT can be reduced to keep WHP < 1200 psi (est Frac pressure), if needed. RD CTU. Wait 48 hours for RPPG particles to crosslink together in MBE before 1J-154L1 is put BOI. Coil Tubing - FCO RPPG (optional, if needed): 3) RIH with jet swirl nozzle to tag RPPG in 1J-154L1. Jet down through slurry Gel with Diesel to as deep as possible while injecting away RPPG and Diesel to MBE &/or formation. POOH. RD CTU. Place 1J-154L1 on injection to evaluate results of B MBE treatment. Evaluate B only' SWI performance and monitor producer 1J-159 performance to verify that the B MBE has been isolated. STATE OF ALASKA , AKA OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations r Fracture Stimulate f Pull Tubing E Operations Shutdown Performed: Suspend E Perforate E Other Stimulate fl Alter Casing im Change Approved Program Plug for Redrill fl Perforate New Pool E Repair Well E Re-enter Susp Well E Other:Crystal Seal MBE TreatmeF 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory E 206-005 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23297-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25661,ADL 25662 KRU 1J-159 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 7857 feet Plugs(measured) None true vertical 3642 feet Junk(measured) None Effective Depth measured 7841 feet Packer(measured) 4200,4355,4666 true vertical 3642 feet (true vertical) 3469,3508, 3566 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108 108 0 0 SURFACE 2333 10.75 2365 2207 0 0 PRODUCTION 5549 7.625 5575 3701 0 0 A-SAND LINER 3176 4.5 7842 3642 0 0 Perforation depth: Measured depth: 5567-7810 RECEIVED True Vertical Depth: 3695-3642 504414E014EJ :,,,W,- r 1f4 fi iFEB 17 2016 AOG Tubing(size,grade,MD,and TVD) 4.5, L-80,4222 MD, 3475 TVD CC Packers&SSSV(type,MD,and ND) PACKERS-ZXP Liner Top Packer @ 4200 MD and 3469 TVD,ZXP Liner Top Packer @4355 MD and 3508 TVD,HRD ZXP Liner Top Packer @ 4666 MD and 3566 ND NIPPLE-CAMCO'DB' NIPPLE @ 515 MD and 515 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 339 - 1290 - 177 Subsequent to operation 517 - 70 - 184 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations FExploratory E Development F Service r Stratigraphic Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas r WDSPL Printed and Electronic Fracture Stimulation Data I GSTOR E WINJ EWAG E GINJ E SUSP E SPLUG fl 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: 315-450 Contact John Peirce(CD 265-6471 Email John.W.Peircee,conocophillios.com Printed Name John Peirce Title Sr. Wells Engineer Signature /1/74-, -- Phone:265-6471 Date 2 i `irForm 10-404 Revised 5/2015 -- fre1-L Z`l fc, Submit Original Only 4- .6 RBDMS L 1 8 2016 s p KUP OD 1J-159 ConocoPhiflips 3' Well Attrib Max AnOMD TD Alaska IIls-- - Wellbore API/UWI Field Name Wellbore Status 'ncl C) MD(ftKB) Act Btm(ftKB) CprrocdPhl8lps'`° 500292329700 WEST SAK PROD 93.86 6,310.37 7857.0 '.-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) \Rig Release Date MULTIPLE LATERALS-1J-156 2/162016 9 52:2I AMSSSV:NIPPLE Last WO: 1/28/2008 31.01 3/13/2006 Vertical schemate(actual) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ---'--- EM - Last Tag. Rev Reason:WELL REVIEW osborl 5/10/2013 - HANGER,22.6 _..�14 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread 1,,, , ,,,CONDUCTOR 20 18.936 31-0 108.0 108.0 62.60 H-40 WELDED L El Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 31.2 2,364.5 2,206.4 45.50 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread • PRODUCTION 7 5/8 6.875 26.6 5,575.1 3,695.3 29.70 L-80 BTCM i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread L2 LINER LEM 41/2 3.958 4,189.2 4,386.3 3,515.8 12.60 L-80 IBT • -^-^-CONDUCTOR;31.0-106.0• Liner Details I Nominal ID NIPPLE;515.0 _ i Top(ftKB) Top(ND)(ftKB) Top Incl C) item Des Com (in) 4,189.2 3,465.9 72.86 PBR BAKER 190-47 PBR 5.750 HEAT TRACE;23.0 4,200.2 3,469.1 73.32 PACKER ZXP LINER TOP PACKER 4.950 4,208.2 3,471.3 73.66 SBE SEAL BORE EXTENSION 4.750 SURFACE;31.2-2,364.5 - 4,227.5 3,476.6 74.48 XO Bushing 3.958 aki 4,232.6 3,478.0 74.70 HANGER 1 LEM ABOVE HOOK HANGER 3.980 NI 4,245.2 3,481.3 75.23 HANGER 2 LEM BELOW HOOK HANGER 3.980 GAS LIFT;2,589.4 4. 4,341.0 3,505.0 75.66 SEAL ASSY LEM BAKER SEAL ASSEMBLY 3.880 Wi Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread I ; L1 LINER HH LEM 41/2 3.958 4,355.1 4,705.5 3,571.1 12.60 L-80 IBT Liner Details Nominal ID ilk Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) 4,355.1 3,508.4 75.80 PACKER ZXP LINER TOP PACKER 4.950 lit 4,372.3 3,512.6 76.38 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 GAS LIFT;4,093.8 MB 4,391.9 3,517.1 77.04 XO BUSHING CROSSOVER BUSHING 3.910 IN 4,550.3 3,547.9 79.90 ABOVE HH LEM ABOVE HOOK HANGER 4.020 NIPPLE;4137.2 4,560.9 3,549.7 80.16 INSIDE HH LEM INSIDE HOOK HANGER 4.020 GAUGE;4,147.6 4,626.4 3,560.0 81.80 NIPPLE CAMCO'DB'NIPPLE 3.562 II 4,702.3 3,570.6 81.97 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread A-SAND LINER 41/2 3.958 4,666.1 7,842.1 3,642.2 12.60 L-80 IBT I Liner Details LOCATOR;4,193.8 :At Nominal ID I' Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Corn (in) SEAL ASSY;4,194.5 _ 4,666.1 3,565.6 81.92 PACKER "HRD"ZXP Liner Top Packer 5.5"X 7.6" 4.970 �; 4,685.1 3,568.2 81.94 NIPPLE "RS"Packoff Seal Nipple 5.5" 4.875 (. 4,688.0 3,568.6 81.95 HANGER FlexLock Liner Hanger 5.5"X 7.6" 4.853 4,697.8 3,570.0 81.96 SBE 190-47 Casing Seal Bore Ext.4.75"ID x 6.25"OD 4.750 11 r 4,717.4 3,572.8 81.99 XO BUSHING XO Bushing 3.92"ID,6.02 OD 3.920 D-SAND LINER;4,241.4- Ii Tubing Strings 10,859.6 If Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..r Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 4 1/2 3.958 22.6 4,222.2 3,475.2 12.60 L-80 IBTM Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Corn (in) 22.6 22.6 0.00 HANGER TUBING HANGER 3.958 _ 515.0 514.8 5.01 NIPPLE CAMCO'DB'NIPPLE 3.875 L2 LINER LEM;4,189.2-4,386.3 ( '= 4,137.2 3,449.6 70.75 NIPPLE CAMCO DB Nipple 3.812 tk 4,147.6 3,453.0 71.16 GAUGE GUARDIAN GAUGE CARRIER 3.850 4,193.8 3,467.2 73.06 LOCATOR LOCATOR ' 3.880 If4,194 5 3,467.4 73.08 SEAL ASSY BAKER GBH-22 PACKER 3.880 !I (j Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) B-SAND LINER;4,560.2- ` Top(ND) Top Incl 11,161.1 III' 'r( Top(ftKB) (ftKB) Cl Des Com Run Date ID(in) IIV I 23.0 23.0 0.00 HEAT HEAT TRACE SET DURING 1/23/2008 1/24/2008 0.000 TRACE WORKOVER Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn 5,567.0 5,721.0 3,695.2 3,697.2 WS A2,1J- 2/23/2006 32.0 SLOTS SLOTTED LINER 0.125" V.7- 159 x2.5"x32 spf @ 4 rx - 1Circumferential adjacent (_,'' rows,3"Centers r staggered 18 deg.,3 ft. L1 LINER HH LEM;4,355.1- non-slotted ends 4,705.5 ) 5,845.0 6,091.0 3,694.4 3,688.1 WS A2,1J- 2/23/2006 32.0 SLOTS 159 6,399.0 7,810.0 3,681.8 3,642.2 WS A2,1J- 2/23/2006 32.0 SLOTS 159 Mandrel Inserts I I St ati PRODUCTION;28.8.5,575.1 ' 1 N Top(ND) Valve Latch Port Size TRO Run SLOTS,5,567 0-5,721.0 Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 2,589.4 2,407.6 CAMCO KBG-2- 1 GAS LIFT GLV BK-5 0.156 1,530.0 2/19/2008 1R 2 4,093.6 3,434.6 CAMCO KBG-2- 1 GAS LIFT OV BK-5 0.250 0.0 2/19/2008 1R SLOTS;5,845 0-6,091.0 Notes:General&Safety SLOTS;6,399.0.7,010.0 End Date Annotation 5/11/2006 NOTE:MULTI-LATERAL WELL:1J-159(A-SAND),1J-159L1(B-SAND),1J-159L2(D-SAND) A-SAND LINER,4,666.1-7,842.1 1J-102L1 WELL EVENTS SUMMARY S DATE SUMMARY 9/2/2015 FCO ice plug from 40'to 75'. Peforate MBE interval in B Lateral from 5,328'to 5,333' RKB with SLB 2 inch Powerflow NSD guns(2006FP-6SPF, EHD 0.45",4.5" PEN). Verified ASF. Next, set a 2.25" ID ISO-Sleeve at leaky CMU @ 4,631' RKB. Well left freeze protected and shut in. Well is now ready for Crystal Seal job Pin holed coil tubing @ 2,315'while POOH no spills.Will cut coil tubing in morning. 9/8/2015 BRUSH n' FLUSH TBG TAG ISO SLEEVE @ 4631' RKB, IN PROGRESS. 9/9/2015 SET 4 1/2 HOLE FINDER I CATCHER SUB ASSEMBLY @ 4631' RKB, PULLED DV @ 4486' RKB, LOADED TBG& IA WITH INHIBITED SEAWATER &DIESEL FREEZE PROTECT, SET DV @ 4486'RKB MIT IA PASS, PULLED HOLE FINDER ASSEMBLY @ 4631' RKB. COMPLETE. 9/17/2015 INJECTIVETY TEST W/SAN PUMPEDIO BBLS@1BPM PUMPED 10 BBLS @ 2BPM PUMPED 80 BBLS @ 3BPM FREEZE PROTECT TBG W/35 BBLS DIESEL JOB COMPLETE 9/18/2015 Pumped fullbore MBE treatment per design placing—290 bbls 3% KCL/4 mil Crystal Seal slurry into formation (3795#of CS). Displaced gel with 80 bbls diesel.Well left shut in. Note: Do not put on injection or bring offset producer online until after 06:00, 9/19. 9/21/2015 Injectivity test,40 bbls dsl down tbg @ lbbl/min pressured up to 200 psi,job complete 10/5/2015 FREEZE PROTECT WELL W/2 BBL METHANOL 100% DOWN F/L FOLLOWED BY 38 BBL DIESEL DOWN TBG JOB COMPLETE 10/8/2015 LOG 24 ARM CALIPER SURVEY FROM 4650'TO SURFACE. LOG CORRELATED TO TUBING DETAIL RECORD DATED 03 OCT 2006. DATA SENT TO ANCHORAGE FOR FURTHER PROCESSING. JOB COMPLETE. • , of rg� �w\� s THE STATE Alaska Oil and Gas °' /t T f /�, S �T /` Conservation Commission z = �_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Op, ALASY'P' Fax 907.276 7542 www.aogcc alaska.gov SCOisiED John Peirce Sr. Wells Engineer ConocoPhillips Alaska, In P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-159 Sundry Number: 315-450 Dear Mr. Peirce: 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, Cathy P oerster Chair DATED this 24 day of July, 2015 Encl. STATE OF ALASKA RECEIVED SKA OIL AND GAS CONSERVATION COMi ,ION JUL 2 3 2015 APPLICATION FOR SUNDRY APPROVALS fiTS7/a1-11 S 20 AAC 25.280 �rA.� (�j'� 1.Type of Request Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r ° ` p_i'aR6n hutdow n j"- Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well rRe-enter Susp Well r Other.Crystal Seal MBE Treatment 2 Operator Name 4 Current Well Class 5 Permit to Drill Number. ConocoPhillips Alaska, Inc. ' Exploratory r Development r"• 206-005 • 3 Address Stratigraphic r Service r 6 API Number P.O. Box 100360,Anchorage,Alaska 99510 50-029-23297-00• 7 If perforating, What 8 Well Name and Number. Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r I KRU 1J-159 • 9 Property Designation(Lease Number): 10 Field/Pool(s) Kuparuk River Field/West Sak Oil Pool 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft) Total Depth TVD(ft)• Effective Depth MD(ft) Effective Depth TVD(ft) Plugs(measured) Junk(measured) 7857 - 3642 . 7841' . 3642' - Casing Length Size MD ND Burst Collapse CONDUCTOR 77 20 108' 108' SURFACE 2333 10.75 2365' 2207' PRODUCTION 5549 7.625 5575' 3701' A-SAND LINER 3176 4 5 7842' 3642' Perforation Depth MD(ft) Perforation Depth TVD(ft) Tubing Size Tubing Grade Tubing MD(ft): slotted liner from 4849-7847 3593'-3642' 4.5 L-80 4222 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) PACKER-ZXP LINER TOP PACKER MD=4200 TVD=3469 PACKER-ZXP LINER TOP PACKER MD=4355 TVD=3508 PACKER-"HRD"ZXP LINER TOP PACKER MD=4666 TVD=3567 NIPPLE-CAMCO'DB'NIPPLE MD=515 TVD=515 12.Attachments: Description Summary of Proposal r 13 Well Class after proposed work Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development • Service r 14 Estimated Date for Commencing Operations 15. Well Status after proposed work 8/1/2015 OIL i• VVINJ r WDSPL r Suspended r 16 Verbal Approval Date GAS r- WAG r GSTOR r SPLUG r Commission Representative GINJ r Op Shutdown r Abandoned r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact John Peirce @ 265-6471 Email John W Peirce@conocophillips corn Printed Name John/Peirce Title Sr.Wells Engineer Signature / 1:4-17__. , -_.. _._-.T_ Phone 265-6471 Date 7/22/i c I y'+ Commission Use Only Sundry Number Conditions of approval Notify Commission so that a representative may witness 316 -y50 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r-- Other.Other. Spacing Exception Required? Yes ❑ No d Subsequent Form Required / 0 — 4 0 4- APPROVED BY Approved by. COMMISSIONER THE COMMISSION Date 7' 2-4--/-r V rL 7../Z3/1 Approved application is valid for 12 months from the date of approval. Submit Form and Form 10-403 Revised 5/2015 1'=� i+��J/I.S a hments in Duplicate ORIGINAL. 0r20//o" RBDMS AUG - 2 2015 KUP 1J-159 • ConocoPhiflips Well Attributes Max Angle&MD TD , A&as#a(fl4 Wellbore APW WI Field Name Well Status Incl(') MD(ftKB) Act Btm(RKB) ti;) 500292329700 WEST SAK PROD 93.86 6,310.37 7,857.0 • Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Well Confg' SSSV:NIPPLE 75 8/14/2012 Last WO: 1/28/2008 31.01 3/13/2006 MULTIPLE LATERALS-iJ-159,5/10/2013 8:46:22 AM Schematic-Actual Annotation Depth)RKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WELL REVIEW osborl 5/10/2013 Casing Strings Casing Description String 0... String ID...Top(5KB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd HANGER,23 CONDUCTOR 20 18.936 31.0 108.0 108.0 62.60 H-40 WELDED �(;. Casing Description String 0... String ID...Top(ftKB) Set Depth(8...Set Depth(ND)...String Wt...String...String Top Thrd - - _ SURFACE 103/4 9.950 31,2 2,364.5 2,206.8 45.50 L-80 BTC - e4`A' ^E r §.5° Casing Description String 0... String ID...Top)RKB) Set Depth(f...Set Depth(ND)...String WL..String...Suing Top Thrd 1111 III PRODUCTION 75/8 6.875 26.6 5,575.1 3,700.8 29.70 L-80 BTCM ` i- Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd L2 LINER LEM 4 1/2 3.958 4,189.2 4,386.3 3,515.5 12.60 L-80 IBT Liner Details Top Depth --- CONDUCTOR,_ )TVD) Top Incl Nomi.,. 31-106 Top(ftKB) (RKB) (°) Item Description Comment ID(in) NIPPLE,515 1,11 4,189.2 3,465.7 72.86 PBR BAKER 190-47 PBR 5.750 1 4,200.2 3,468.6 73.32 PACKER ZXP LINER TOP PACKER 4.950 HEAT TRACE, 23 4,208.2 3,470.7 73.66 SBE SEAL BORE EXTENSION 4.750 I 4,227.5 3,476.3 74.48 XO Bushing 3.958 4,232.6 3,477.8 74.70 HANGER 1 LEM ABOVE HOOK HANGER 3.980 SURFACE, 4,245.2 3,4812 75.23 HANGER 2 LEM BELOW HOOK HANGER 3.980 31-2,364 4,341.0 3,504.9 75.33 SEAL ASSY LEM BAKER SEAL ASSEMBLY 3.880 1 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String String Top Thrd L1 LINER HH LEM 4 1/2 3.958 4,355.1 4,705.5 3,571.2 12.60 L-80 IBT GAS LIFT, 2.5E6 1 Liner Details Top Depth (TVD) Top Incl Noml... Top MKS) (0168) (°) Item Description Comment ID(in) at 4,355.1 3,508.4 75.80 PACKER ZXP LINER TOP PACKER 4.950 IIM 4,372.3 3,512.4 76.38 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 illE 4,391.9 3,516.6 77.04 XO BUSHING CROSSOVER BUSHING 3.910 GAS4,09LIFT,4 4,550.3 3,549.1 81.76 ABOVE HH LEM ABOVE HOOK HANGER 4.020 4,560.9 3,550.6 81.78 INSIDE HH LEM INSIDE HOOK HANGER 4.020 'CZ 4i e-N4,626.4 3,560.0 81.87 NIPPLE CAMCO'DB'NIPPLE 3.562 LOCATOR, 4,702.3 3,570.8 82.45 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 4,194 LI:71 ilriTi E. SEAL ASSY, Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd a,195 EM, A-SAND LINER 4 1/2 3.958 4,666.1 7,842.1 3,642.2 12.60 L-80 IBT U LINER LEM, 4,189-4,386 Liner Details Lt LINER HH LEM, Top Depth 4,355-4,706 (TVD) Top Incl Nomi... PRODUCTION.27A4575 Top(MB) (RKB) PI Item Description Comment ID(in) SLOTS. 4,666.1 3,566.8 83.11 PACKER "HRD"ZXP Liner Top Packer 5.5"X 7.6" 4.970 5,567-5,721 SLOTS, 7N 4,685.1 3,568.8 82.76 NIPPLE "RS"Packoff Seal Nipple 5.5" 4.875 5,845-6.091 TS, T 4,688.0 3,569.1 82.71 HANGER FlexLock Liner Hanger 5,5"X 7,6" 4,853 6,399-7,810 A-SAND 4,697.8 3,570.3 82.53 SBE 190-47 Casing Seal Bore Ext.4.75"ID x 6.25"OD 4.750 LINER,4.00a,e42 4,717.4 3,572.8 82.17 XO BUSHING XO Bushing 3.92"ID,6.02 OD 3.920 TD(1J-159), 7.657TubinD-SAND g Strings LINERTubing Description String 0... String ID...Top(RKB) Set Depth It...Set Depth(TAD)...String Wt...String... String Top Thrd 4,241-1e860TUBING WO 4 1/2 3.958 22.6 4,222.23,474.712.60 L-80 IBTM 111 Completion Details Top Depth (ND) Top Incl Momi... Top)RKB) (ftKB) )°) Rem Description Comment ID(in) 22.6 22.6 -0.09 HANGER TUBING HANGER 3.958 �} 515.0 514.8 5.01 NIPPLE CAMCO'DB'NIPPLE 3.875 4,137.2 3,449.3 70.66 NIPPLE CAMCO DB Nipple 3.812 4,147.6 3,452.9 71.10 GAUGE GUARDIAN GAUGE CARRIER 3.850 4,193,8 3,466,9 73.06 LOCATOR LOCATOR 3.880 4,194.51 3,467.1 73.08 SEAL ASSY BAKER GBH-22 PACKER 3.880 BSAND i ER, h I n Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 4,560.11,161 Top Depth Pr I Il • (ND) Top Incl Top(ftKB) (MB) (°) Description Comment Run Date ID(in) 23.0 23.0 -0.08 HEAT TRACE HEAT TRACE SET DURING 1/23/2008 WORKOVER 1/24/2008 0.000 Perforations&Slots Shot Top(ND) Btm(TVD) Dens - Top(MB)Btm(81KB) (ftKB) (RKB) Zone Date Oh- Type Comment i_, r-`i 5,567.0 5,721.0 3,702.9 3,697.1 WS A2,1J-159 2/23/2006 32.0 SLOTS SLOTTED LINER 0.125"x 2.5"x 32 spf @ 4 Circumferential adjacent r rows,3"Centers staggered 18 deg.,3 ft.non-slotted ends 5,845.0 6,091.0 3,692.0 3,688.0 WS A2,1J-159 2/23/2006 32.0 SLOTS DM 6,399.01 7,810.01 3,681.9{ 3,642.21WSA2,1J-159 12232006 1 32.01SLOTS 1 Notes:General&Safety End Date Annotation l 5/11/2006 NOTE:MULTI-LATERAL WELL:1J-159(A-SAND),1J-159L1(B-SAND),1J-159L2(D-SAND) 2/21/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.OREV L Mandrel Details Top Depth Top Port r , S--, (ND) Mel OD Valve Latch Size TRO Run N...Top(ftKB) (11KB) I") Make Model (In) Seta Type Type (in) (psi) Run Date Com... 1 2,589.4 2,407.1 25.48 CAMCO KBG-2-1R 1 GAS LIFT GLV BK-5 0.156 1,530.0 2/19/2008 1 r 2 4,093.6 3,432.7 68.81 CAMCO KBG-2-1R 1 GAS LIFT OV BK-5 0250 0.0 2/19/2008 1J-102L1 to 1J-159L1 B Sand MBE Treatment Proposal 1J-102 Tri-Lat injector was drilled & completed in 2006 with laterals in West Sak A, B, & D sands. On 3/2/08, a 1J-102 MBE occurred to offset producer 1J-159. A 4/23/08 1J-102 main-bore (PROF saw all PWI entering 1J-102L1. A 2008 1J-102L1 IPROF RIH stuck the BHA in the B Diverter. After lengthy fishing to retrieve all of the fish, a B Iso-Sly was set 9/28/08 (before diagnosing the B MBE location). 1J-102 was on PWI to A& D sands only until 2015. On 6/8/15, a Plug was set at 5081' RKB to isolate the A lat, then a B Diverter and a D Iso-Sly were set 6/9/15. An 6/10/15 IPROF in in 1J-102L1 to 11109' MD found a robust `heel' MBE at -5350' RKB at the first slotted joint below the B LEM. Note, the top of B lat plop & drop liner is -197' out in OH lateral below the B LEM (per 9/22/06 Liner Detail). A fullbore Crystal Seal treatment to seal the B MBE is proposed to return 1 -102L1 to PWI. Procedure: E-line: 1) RIH with 5' perf gun on dual tractors to shoot 6 spf, 60 deg ph large hole perfs at 5328 - 5333' RKB. This perfs the middle of the first 4.5" slotted joint near the MBE at -5350' to allow better CrystalSeal entry through slotted liner to the B MBE. Fire gun. POOH. RD. Coil Tubing: 2) RIH & set 2.25" ID Iso-Sly in CMU Slv at 4631' RKB to isolate leaky CMU Slv for Crystal Seal job. Perform MITIA to verify good Iso-Sly set integrity. Pumping: 3) Fullbore pump -100 bbl Step Rate Inj Test (SRIT) with Seawater to 4 bpm to verify good injectivity. Select a steady treatment rate to hold constant during Crystal Seal treatment to monitor MBE treatment response, and possible Crystal Seal screenout during slurry pumping. After SRIT, continue FB pumping Crystal Seal Slurry stages at constant rate (target 3 - 4 bpm) to the B MBE. Pump all slurry concentrations using only 4 mm mesh Crystal Seal in 3% KCL Water, starting with 0.10 ppg slurry pumped down tubing. Volume of each stage is TBD during pumping based on treating pressure responses noted during pumping. Ramp stages at: 0.10, 0.15, 0.20, to a maximum of 0.25 ppg, or (if needed) swap to pumping Flush if indication of imminent screen out develops during slurry pumping. If screenout development is noted, attempt to pump 80 bbls of Diesel Flush down tubing to displace all Crystal Seal from well to the B MBE. Tubular volume = 81 bbls (surface to MBE). If screenout has not been seen, but it is time to call Flush, pump at least 35 bbls Diesel to FP to 2000' TVD, then SD. RD. Coil Tubing: 4) RIH with 2" OD Jet Swirl Nozzle BHA (to get through 2.25" ID CMU Iso-Sly set in step 2) on either 1.5", 1.75", or 2" OD CT (best CT OD option TBD) to jet through Crystal Seal down to as deep as possible to shear and mechanically break all Crystal Seal remaining in the liner. POOH w/CT. RD. Put 1J-102L1 on PWI to evaluate results of the B MBE treatment for a period long enough to verify that a successful B MBE treatment has been achieved prior to executing step 6 and beyond. 5) RIH with Slim IPROF BHA on CT to pass through 2.25" ID CMU Iso-Sly (set in step 2). Memory log down and up passes to verify if the B MBE is sealed off or still taking PWI. Wait 2 hours and then log a cool back pass. POOH with CT. RD CTU. Return 1J-102L1 to PWI service. If months have passed without obvious indications of a B MBE treatment failure, proceed to normal up the well to resume PWI to all 3 laterals as follows: Coil Tubing: 6) RIH & pull the 2.25" ID Iso-Sly (from leaky CMU Sleeve) at 4631' RKB. 7) RIH & pull the 'D' Iso-Sly set across the D LEM at 4730' RKB to open the D lat to PWI. 8) RIH & pull the 'B' Diverter set in the B LEM at 5047' RKB. 9) RIH & pull Prong and 3.562" Plug set at 5081' to open the A lat to PWI. 10) RIH & set 2.25" ID Iso-Sly in CMU Slv at 4631' RKB to isolate leaky CMU Slv. Perform an MITIA to verify good set integrity of Iso-Sly prior to returning 1J-102 to PWI service. Return 1J-102 to PWI service to all 3 laterals. 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. ~~ ~ - ~ ©~ Well History File Identifier Organizing (done) RE CAN Color Items: ^ Greyscale Items: Two-sided IIIIIlIIIIIIIIIIIII DIGITAL DATA Diskettes, No. ^ Other, No/Type: o R.sU~~eeded iiiuiiii~iiuiiu ^ Poor Quality Originals: ^ Other: NOTES: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY_ ~ Maria) Date: ~' ~~ U ~ /s/ Y r 4 I Project Proofing III IIIIII VIII II III BY: Maria Date: ~ ~ O /s! Scanning Preparation _~ x 30 = Q + ~ =TOTAL PAGES r ~' Q (Count does not include cover sheet) ~n BY: Maria Date: ~ h /s/ 1 Y 1 Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~r~ ~ D ~ lsl ~nn f ' • [~ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned tII II ~I II I I III I I III BY: Maria Date: Comments about this file: o~a,.~~e~k,d iuuiuimuiui 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Re p air w ell r Rug Perforations r Perforate r . Other FF, Pull L1 -LEM Isolation Sleeve Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r (B -sand) Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. r Development p9 Exploratory r • 206 -005 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r • 50 - 029 - 23297 - 7. Property Designation (Lease Number): 8. Well Name and Number: ADL025661; ADL025662 • 1 J - 159 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 7857 • feet Plugs (measured) None true vertical 3642 feet Junk (measured) None Effective Depth measured 7841 feet Packer (measured) 4200 true vertical 3642 feet (true vertical) 3469 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108 108 0 0 SURFACE 2333 18.125 2364 2206 0 0 L2 LINER LEM 197 6.61 4386 3516 0 0 L1 LINER HH LEI 350 8.47 4706 3571 0 0 PRODUCTION 5548 7.625 5575 3695 0 0 A -SAND LINER 3176 6.57 7842 3642' 0 0 Perforation depth: Measured depth: 5567 - 5721; 5845 - 6091; 6399 - 7810 True Vertical Depth: 3703 - 3697; 3692 - 3688; 3682 - 3642 1 4 ve ., , , Tubing (size, grade, MD, and TVD) 4.5, L - 80, 4222 MD, 3475 TVD Packers & SSSV (type, MD, and TVD) PACKER - ZXP LINER TOP PKR @ 4200 MD and 3469 TVD '' "' NIPPLE - CAMCO DB NIPPLE @ 515 MD and 515 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 984 348 434 770 188 Subsequent to operation 1007 341 455 907 196 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 1,7 - Service r Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations _X GSTOR r SPLUG r WIND r WAG r GINJ r S USP r 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: N/A Contact Bob Christensen /Darrell Humphrey Email N1139e.conocophillips.com Printed Name A Robe . Christ nsen Title NSK Production Engineering Specialist Signature / ,'' - Phone: 659 -7535 Date ' i n A , V1 .38 ,ri-r �'� RBDMS JUN 14 20 14 7/ Form 10 -404 Revised 12/2012 Submit Original Only • 1J-159 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/07/13IRIH to 4553' CTMD, latch B lat Isolation sleeve. ..d ` KUP • 1J -159 ConocoPhiIIip5 & Well Attributes Max An • le & MD TD Wellbore API /UWI Field Name Well Status I Inc] (3 MD (ftKB) Act Btm Alaska, Inc. cu, uvr,ps _ 500292329700 WEST SAK PROD 93.86 6,310.37 7,857.0 --. Comment H2S (ppm) Date Annotation End Date KB - Grd (R Rig Release Date ••• SSSV: NIPPLE 75 8/14/2012 Last WO: 1/28/2008 31.01 3/13/2006 Well ConfN MULTIPLE LATERALS-1J-159, 5/10/20138.46.22 AM - Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: WELL REVIEW osborl 5/10/2013 Casin• Strin•s •e now Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt.. String ... String Top Thrd HANGER. 23 111 CONDUCTOR 20 18.936 31.0 108.0 108.0 62.60 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd _ _ - _ - _ - _ _ _ _ SURFACE 103/4 9.950 31.2 2,364.5 2,206.8 45.50 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt.. String ... String Top Thrd I PRODUCTION 75/8 6.875 26.6 5,575.1 3,700.8 29.70 L - 80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd L2 LINER LEM 41/2 3.958 4189.2 4,386.3 3,515.5 12.60 L -80 IBT 1. 7 Liner Details 1 Top Depth CONDUCTOR. (ND) Top Inc! Nom!... 31 -108 h Top (ftKB) (ftKB) (°) Rem Description Comment ID (in) NIPPLE, 515 I lir 4,189.2 3,465.7 72.86 PBR BAKER 190-47 PBR 5.750 4,200.2 3,468.6 ® PACKER ZXP LINER TOP PACKER 4.950 HEAT TRACE. 23 4,208.2 3,470.7 73.66 SBE SEAL BORE EXTENSION 4.750 J I ;. 4,227.5 3,476.3 MEI X0 Bushing - - 3.958 4,232.6 3,477.8 74.70 HANGER 1 LEM ABOVE HOOK HANGER 3.980 SURFACE, • .J 4,245.2 3,481.2 75.23 HANGER 2 LEM BELOW HOOK HANGER 3.980 31 - 2,364 4,341.0 3,504.9 75.33 SEAL ASSY LEM BAKER SEAL ASSEMBLY 3.880 +a Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String .. String Top Thrd L1 LINER HH LEM 4 1/2 3.958 4,355.1 4,705.5 3,5712 12.60 L - IBT GAS LIFT, 2,589 lilt Liner Details Top Depth I (TVD) Top Inc' Nomi... Top )ftKB) (ftKB) (1 ttem Description Comment ID (in) 4,355.1 3,508.4 75.80 PACKER ZXP LINER TOP PACKER 4.950 4,372.3 3,512.4 76.38 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 4,391.9 3,516.6 77.04 X0 BUSHING CROSSOVER BUSHING 3.910 GAS LIFT, 4,550.3 3,549.1 81.76 ABOVE HH LEM ABOVE HOOK HANGER 4.020 4.094 4,560.9 3,550.6 81.78 INSIDE HH LEM INSIDE HOOK HANGER 4.020 NIPPLE, 4,137 4,626.4 3,560.0 81.87 NIPPLE CAMCO'DB' NIPPLE 3.562 SEAL ASSY, Casing Descripton 8 String 0. . . E String ID ... Top ( f1K8 Set ) 3E Se Depth (f Depth (ND) ... String Wt. String ... String Top Thrd 4.195 A - SAND LINER 4 1/2 3.958 4,666.1 7,842.1 3,642.2 12.60 L - 80 IBT L2 LINER LEM, 4 LINE� E 1 Li Liner Details LR M. LEM, Top Depth 4,3554,708 (TVD) Top Inc! Noml... PRODUCTION, i 275,575 Top (ftKB) (ftKB) (°) Item Description Comment ID (in) t SLOTS, 4,666.1 3,566.8 83.11 PACKER "HRD" ZXP Liner Top Packer 5.5" X 7.6" 4.970 5,567$721 t SLOTS. , �` 4,685.1 3,568.8 82.76 NIPPLE "RS" PackoB Seal Nipple 5.5" 4.875 5.845 LLTT, 11 4,688.0 3,569.1 82.71 HANGER FlexLock Liner Hanger 5.5" X 7.6" 4.853 6399 - 7.810 A 4,697.8 3,570.3 82.53 SBE 190 - 47 Casing Seal Bore Ext. 4.75"10 x 6.25" OD 4.750 LINER, D (1J - 1 ,842 4,717.4 3,572.8 82.17 XO BUSHING X0 Bushing 3.92" ID, 6.02 OD 3.920 7857 Tubin• Strin•s D -SAND 4;:t' LINER. Tubing Description String 0... String ID ... 1 Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd 4,241 - 10.860 TUBING WO , 4 1/2 3.958 22.6 4,222.2 3,474.7 12.60 L -80 IBTM ,:- ( rletion Deta _ -_ Top Depth (ND) To p Inc! Nomi... To (ftKB) (ftKB) ( °) Item Descri •lion Comment ID (!n) L 22,6 22.6 -0.09 HANGER TUBING HANGER 3.958 ��i � 515.0 514.8 5.01 NIPPLE CAMCO 'DB' NIPPLE 3.875 4,137.2 3,449.3 70.66 NIPPLE CAMCO DB Nipple 3.812 3.850 4,147.6 3,452.9 71.10 GAUGE GUARDIAN GAUGE CARRIER 4,193.8 3,466.9 73.06 LOCATOR LOCATOR 3.880 4,194.5 3,467.1 73.08 SEAL ASSY BAKER GBH -22 PACKER 3.880 B LIINER, „ Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) 4,560 - 11.161 Top Depth - (ND) Top Intl Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (In) 23.0 23.0 -0.08 HEAT TRACE HEAT TRACE SET DURING 1232008 WORKOVER 1/24/2008 0.000 Perforations & Slots ■ - - -_ - Shot Top )TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (MB) Zone Date ( eh- Type Comment 1 - - _i 5,567.0 5,721.0 3,702.9 3,697.1 WS A2, 1J- 159 2/23/2006 32.0 SLOTS SLOTTED LINER 0.125" x 2.5" x 32 ! spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non - slotted ends 5,845.0 6,091.0 3,692.0 3,688.0 WS A2, 1J- 159 2/23/2006 32.0 SLOTS 6,399.0 7,810.0 3,681.9 3,642.2 WS A2, 1J -159 2/23/2006 32.0 SLOTS Notes: General & Safe End Date Annotation 5/11/2006 2/21/2009 NOTE: MULTI - LATERAL WELL: 1J -159 (A- SAND), 1J -159L1 (B- SAND), 1J -159L2 (D -SAND) NOTE: VIEW SCHEMATIC w /Alaska Schema6c9.OREV Mandrel Deta Top Depth Top Pon - - - -- 5,,, (ND) Intl OD Valve Latch Size TRO Run N ... Top (ftKB) (ftKB) ( °) M ake Model (in) Sery Type Type (in) (psi) Run Date Com... 1 :_.,:_i_ r 1 2,589.4 2,407.1 25.48 CAMCO KBG -2 -1R 1 GAS LIFT GLV BK -5 0.156 1,530.0 2/192008 2 4,093.6 3,432.7 68.81 CAMCO KBG -2 -1R 1 GAS LIFT OV BK -5 0.250 0.0 2/192008 ~ ~ _~ ~~ - ~, .~ ~~. _ ~. ~.. .,ti- ,~~ ~.~ ~. ~ ~rti".. M1~ ~ ~~ ~ ~t xc. ~~ MICROFILMED 6/30/2010 DO .NOT P LAC E ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Mazker.doc ~~ ~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # k ~ ~ >s, ., Log Description N0.4947 Company: Alaska Oil & Gas Cons Gomm Attn: Christine Mahnkein 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/29/08 3S-08C 12066554 MEM PRODUCTION PROFILE ~j - '~' 10/14/08 1 1 1C-26 iC-119 3H-15 1 C-121 3H-18 J-159 iF-10 11978487 11978488 12080445 11978490 12080446 12097431 12080453 SBHP SURVEY ( ~b J INJECTION PROFILE ~ INJECTION PROFILE ~.- -~C/ INJECTION PROFILE INJECTION PROFILE ~ - p PRODUCTION PROFILE '~ INJECTION PROFILE - - f0/15/08 10/16/08 10/16/08 10/17/08 10/17/08 10/13/08 10/27/08 1 1 1 1 1 1 1 1 1 1 1 1 1 1 f C-121 11978490 INJECTION PROFILE f 0/17/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: dab p°s. Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6`h,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klei ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/6/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 1J-101 205-182 6" NA 6" NA 1.28 9/5/2008 1J-102 206-110 7" NA 7" NA 1.70 9/5/2008 1J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1 J-105 207-027 8" NA 8" NA 1.28 9/5/2008 1J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1 J-109 206-050 14" NA 14" NA 8.08 9/5/2008 1J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1J-120 207-045 4" NA 4" NA 2.55 9/5/2008 1J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1J-154 205-035 4" NA 4" NA 4.67 9!6/2008 1 J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1J-159 206-005 20" NA 20" NA 14.87 9/6!2008 1J-160 207-015 20" NA 20" NA 7.23 9/6/2008 1 J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1J-184 206-044 8" NA 8" NA 1.28 9/6/2008 STATE OF ALASKA j~~ 2 3 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERAT10+1~a Oil & Gay ~®ns. Camfnissi0n . _~_ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other / Set L1-tEM Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Isolation Sleeve. Waiver ^ Time Extension ^ (B-sand) Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COr1000PhIIIIpS Alaska, InC. Development ~ Exploratory ^ _ 206-005 3. Address; Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23297-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-159 8. Property Designation: t0. Field/Pool(s): ADL 25661 ~& 25662 ~ Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 785T' feet true vertical 3642` . feet.. Plugs (measured) None Effective Depth measured 7841' ~ feet Junk (measured) true vertical 3642' ~ feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2365' 10-3/4'° 2365' 2207 PRODUCTION 5575' 7-5/8" 5575' 3695' 1 ~~~~~~ ~~G ~ ~ 2~~~ WIN OW 1' 7' 4566' 355 A-Sand Slotted Liner 3175' 4-1 /2" 7841 ` 3642' Perforation depth: Measured depth: 5567-5721 ; 5845'-6091 '; 6399'-7810' true vertical depth: 3694'-3697; 3694'-3689 '; 3682'-3642' bi i T d d d d th " ' ~ ~ ~ ~ ~'°~'~~"~-'~~~ ~ ~-" ng (s ze, gra e, an measure u ep ) 4-1/2 , L-80, 4386.36 M D. ,=. ~: ` Packers &SSSV (type & measured depth) PKR = ZXP Liner Top Pkrs Packer = 4200'; 4666' ~~~ ~ ~. ~ ' ~\ S SSSV= NIP SSSV= 515' 12. Stimulation or cement squeeze summary: ' Intervals treated (measured) ~q Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data -Oil-Bbl Gas-Mcf Water-6b1 Casiri Pressure Tubin Pressure Prior to well operation 804 261 474 94$ 220 Subsequent to operation 773 224 294 861 239' 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run ~ Exploratory ^ Development ~ -. Service Daily Report of Well Operations _X 16. Well Status after work: Oil Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Bob Christensen /Bob Buchholz Printed Name 1 Rpbe hr' tens Title Production Engineering Technician Signature ~ ~ Phone: 265-6471 Date Gj/! V' r Form 10-404 Revised 04/2006 1_~ ~ ~ ~ ~ \- („~ L Submit Original Only • . '(J-959 DESCRfPTIOEV OF WORK COMPLETE© SUMMARY • Page 1 of 2 ~ • Maunder, Thomas E (DOA) From: Gober, Howard [Howard.Gober@conocophillips.com] Sent: Thursday, April 10, 2008 5:19 PM To: Maunder, Thomas E (DOA) Cc: Eggemeyer, Jerome C.; Thomas, Randy L; Cawvey, Von ~~~`.~-~~;;~,~~~, ~~ ~ r`, `~ 3~ ~; , ..~~_: Subject: RE: 1J-159 (206-005) Workover Tom, After our conversation today, I wanted to answer your e-mail concerning 1 J-159 (206-005). i have had conversations with the rig supervisor who was present during this workover, and I am completely confident that this well was under control at all times. in fact we lost 2814 bbls of 8.8 ppg seawater with 6% KCL to the formation during the workover. The rig supervisor stated to me that we pumped triple displacement on ail trips out of the hole. The scope of the workover on 1J-159 was to pull a failed ESP, run the upper LEM and complete the well with a gas lift completion. The ESP failed in April of 2007, and the gauges failed shortly thereafter. The well was on temporary gaslift untif this workover was performed. A shut-in bottom hole pressure survey was run on 5/5/07, and it yielded an equivalent fluid weight of 6.2 ppg. Therefore, we knew that our workover fluid would more than balance the reservoir. When we rigged up on the well, the tubing pressure was 240 psi, and the IA pressure was 480 psi. No packer in the well, just a failed ESP completion. The well was killed by pumping 200 bbls of 8.8 ppg fluid down the IA and 110 bbls of 8.8 ppg fluid down the tubing. Following the BOP test, the well remained dead. The hanger was pulled to the floor, and we attempted to circulate. 300 bbls of fluid was pumped without gaining circulation. This verifies that the reservoir pressure is well below the 8.8 ppg equivalent of the fluid we were using. After the ESP was pulled, we ran a retrievable bridge plug to verify casing integrity. At this point we were able to fill the hole and test the casing. When the plug was released, the well went on a vacuum. The next step was to run the upper LEM. During this operation, we did see oil to surface on the drill pipe side, but it was mainly due to the tight tolerance between the LEM assembly and the casing. We were able to circulate some of the fluid out, but while trying to circulate most of the fluid went to the formation. After setting the LEM, we began pulling out of the hole. At this time it is noted that there was oil on the outside of the pipe as it was pulled out. About the time this comment is made we had Phase 3 weather blow in. The rig team shut in the well and waited on weather. After 32.5 hours, the Phase 3 restrictions were lifted. The crew checked the well pressure - 80 psi tubing and 30 psi casing. Both side bled off easily to 0 psi. The crew began pulling pipe, but it was still oily. Overdisplacing the steel volume was not enough to sweep the oil away. Most likely the fluid we had been pumping during the job was swapping with crude in the laterals bringing oil into the mainbore. The crude on the pipe was making a slick working surface, so the rig supervisar asked me if he could just bullhead it away to get rid of it. I OK'd the operation and we were able to POOH without further issue. The next step was to run the completion. When we started in the hole, we had a similar situation as we did when running the LEM. The water had displaced oil into the main bore. Since we were out of the hole except for the BHA, we just closed the BOP and bullheaded the crude to the perfs with some high viscosity brine. The static losses after this was approx 10 bbls/hr. As we went in the hole with the completion, we stopped 2 more time as a precautionary measure to pump viscosified brine followed by regular KCL water. We were able to finish the weil without any further issues. ConocoPhillips understands that free crude in a well can be a serious matter. That is why we decided to go ahead and bullhead the fluid away. During the operation we did not have a time when the fluid in the hole did not balance or overbalance the reservoir. We do realize that our detail of reporting could be increased. I will be sending out a request to the rig supervisors to inciude more information in the reports that will allow anyone reading them to understand what was happening. I believe this addresses the concerns you expressed in your e-mail below. If you have any questions or require 5/4/2008 Page 2 of 2 ~ • further information, please let me know. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard.Gober@conocophillips.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 28, Z00$ 8:00 AM To: Thomas, Randy L; Eggemeyer, Jerome C, Cc: Jim Regg; Cathy Foerster Subject: 1J-159 (206-005) Workover Randy and Jerome, 1 have reviewed the 404 submitted documenting the work conducted on this well from 1/18/08 -1/27/08. On 1/19/08, the narrative reports "Attempt to fill hole w/ 300 bbls ... never was able to circulate." The next activity reported is POOH. Nothing is mentioned about filling the hole or the fluid level. On 1/21/08 a retrievable packer is run in the hole to test the casing. Filling the hole is specifically mentioned. On 1/22/08 "Circ out crude oil flow back thru DP ..." is reported. On 1/23 and 1I24 various comments are reported about "oily pipe" and "crude oil creating a nuisance/safety hazard". On 1/25, the rams are closed to bullhead crude to the perfs. "Not a well control issues" is also noted. It appears that during this work the hole was not kept full and overbalanced with fluid as required by the regulations ~nd that contrary to someone's assessment, closing the rams and bullheading oil back into the perforations was a welt control issue that should have been reported to the Commission. You are requested to review this matter to provide information as to what actually happened and what decisions were made. Free crude in a wellbore at surface can be a serious matter. A rig fire resulted ~2001 when crude was allowed to be present at the surface while conducting work. The Commission reserves the right to pursue enforcement in this matter. I look forward to your reply by April 4. Call or message with any questions. Tom Maunder, PE AOGCC 5/4/2008 • STATE OF ALASKA ~- RECEIVEC~ MAR 1 0 20Q$ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATI(~~& ~Canmis~t 1. Operations Performed: Abandon ^ Repair Well 0 Plug Perforations ~ Stimulate ^ Other ~ Alter Casing ^ Pull Tubing Q Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Weil Class Before Work: 5. Permit to Drill Number: ConOCOPhillips Alaska, InC. Development ~ F~cploratory ^ 206-005/ ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: , P. O. Box 100360, Anchora e, Alaska 99510 ` 50-029-23297-00 7. KB ev tion (ft): RK ' ~ 9. Well Name and Number: B 28 1J-159 - 8. Property Designation: 10. Field/Pool(s): , ADL 25661 & 25662 ,~ Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 7857' - feet true vertical 3642'' feet Plugs (measured) Effective Depth measured 7841` feet Junk (measured) true vertical 3642'- feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 2337' 10-3/4" 2365' 2207' PRODUCTION 5547' 7-5/8" 5575' 3696' LINER 3176' 4.5" 7842' 3642' Pertoration depth: Measured depth: 5567'-5721', 5845'-6091', 6399'-7810' true vertical depth: 3694'-3697',. 3694'-3689', 3682'-3642' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 4195' MD. Packers & SSSV (type & measured depth) HRD ZxP liner pkr @ 4666' Camco'DB' landing nipple @ 515' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to weil operation 413 1561 55 -- 194 Subsequent to operation 1722 1121 1906 -- 230 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Brett Packer Printed Name Brett Packer Title Ph 265 6845 ~ ~~ Wells Group Engineer 3 l~~ J~ ~ D t ~ ~ Signature `~~~~ _ ~!/ - ~ ~ one: - . a e / Pre ared b Sharon Allsu -Dreke 263-4612 Form 10-404 Revised 04/2006 ~ ,.~~+~ ~[ ~, ~" ,`~~~f ~' ~/~"/O~ f'y !'}~. Submit Original Only • • „ ~t~r~~~~~'~~~~~p~s A~~~~~, ~~+~. KRU 1 J-159 ~on+a~a-Phillips WeAview Web ReportJng Time Log Summary Well Name: 1J-159 Job Type: RECOMPLETION ~~.y~~y . ~ / ; {Iii~~e ~~ ~ \ y/bi7.` ~ \ ., \ \ . ; ;. . ., -;: ~ .•': ~ s Y~~.\~ \ '\.~ •. .:i ~~.\ ... ... \ : _: ._;;.:: :,. \ ~\ :.: ~ ,~ y~\,~' :z ,~+ \ \\\~ {+ ~ .:~, : ~ ~~ . „~~~ ~ v'~!. '~ l1€~~~a~ \\~. , a7~~~~~ ~ , il ..;5 ~ a „~ ../,~'~~ '~. ~ ,~ ~% 01/18/2008 00:00 01:00 1.00 MIRU MOVE RURD P PJSM, R/D prep for rig move. 01:00 03:00 2.00 MIRU MOVE RURD P Move off well # 1J-152. Move over 1J-159. spot & level, berrn up. Accepted rig @ 0300 hrs today, 1 /18/2007. 03:00 07:00 4.00 MIRU MOVE RURD P Roll down tarps, spot tanks, & e ui ment. 07:00 09:00 2.00 MIRU MOVE RURD P RU hardiine to kili tank. Heat up Seawater w/hot oil. 09:00 10:30 1.50 PROD1 RPCOh RURD P PJSM, Pull BPV w/Lubricator. Some trouble linin u tools. 10:30 12:00 1.50 PROD1 RPCO RURD P RU line in cellar, P!T wlair. P/T w/fluid to 2500 si. 12:00 15:00 3.00 PROD1 WELCT KLWL P Blow down hardline, start pumping well kill. IA pressure 480 psi and Tubing press 240 psi. Pumped @ 2 BPM 200 bbls hot seawater down annulus increasing rate to 4 BPM. Switched over and pumped 60 bbis hot seawater down tubing @ same rate. Shut down, check press. Small amount +/- 5 psi. Pumped another 50 bbls down tubing at same rate. Shut in monitor. 15:00 17:00 2.00 PROD1 WELCT KLWL P While monitoring well, changed out ESP spools. Check well for pressure 0 IA/ 0 tubing. RD Circ lines and Blow down lines to kiil tank. 17:00 18:30 1.50 PROD1 WELCT BOPE P Install 4" H-BPV. ND and inspect tree. 18:30 23:30 5.00 PROD1 WELCT BOPE P NU BOPE 23:30 00:00 0.50 PROD1 WELCT BOPE P Function Test and fill stack 01/19/2008 00:00 08:00 8.00 PROD1 WELC BOPE P Continue to BOPE 250/2500 psi 08:00 1530 7.50 PROD1 WELC BOPE T Change out choke valve #2 and retest i 250/2500 si. 15:30 16:30 1.00 PROD1 RPCO OTHR P Puil BPV. Bent T-bar made difficult to ~ line u . 16:30 20:00 3.50 PROD1 RPCOf~ PULD T Attempt to screw in landing jt in hanger, bad thread. Ordered out another landin 't and s ear. 20:00 21:00 1.00 PROD1 FISH PULL T Engage hanger and pull to surface 90k u wt. Break out and la down fish. 21:00 21:30 0.50 IPROD1 RPCOh PULD P Pull and lay down pup jts and e line over sheeve and tie into spool. 01/19/2008 2130 22:30 1.00 PROD1 RPCOh CIRC P Attem t to fill hole w/ 300 bbls 8.8 6% KCL never was able to circulate. 22:30 00:00 1.50 3,618 1,935 PROD1 RPCO RCST P Pooh f/ 3618' to 1935' w/ esp compietion on 4 1/2 12.6# L-80 IBTM, standing back tubing and spooling up ESP cable. 01/20/2008 00:00 05:00 5.00 1,935 73 PROD1 RPCOh RCST P Continue to Pooh w/ 4 1/2 Completion string. Found hole in tubing 1' down from tool jt on 1 st }t above ESP @ 3590.0 +/- 05:00 07:00 2.00 73 0 PROD1 RPCOh PULD P Laid down ESP equipment. Recovered all bands and clamps except 6 stainless steel bands. 07:00 10:00 3.00 PROD1 RPCOti WOEQ T Waiting on slickline for fishing out 6 lost bands. Clean rig floor, strap all e ui ment, or anize i e shed. 10:00 12:00 2.00 PROD1 FISH SLKL T Load new tools (scraper etc) in pipe shed. RU drill pipe equipment, spinners elevators etc while waiting on slickline. 12:00 15:00 3.00 PROD1 FISH SLKL T PJSM. RU slickline. 15:00 20:00 5.00 PROD1 FISH SLKL T RIH with junk basket on slickline fishing for bands. First run retrieved 3 bands, second run retrieved 1 single band, third run 0 bands, 4th run 8-pcs. of inetai, 5th run filled junk bskt w/ 1.5' of scale, 6th run filled junk bskt w/ 2.0' of scale to depth of 4248' slm. RD slick line unit. 20:00 21:30 1.50 0 306 PROD1 RPCOti PULD T PJSM, PU and Rih w/ CSG Scraper Ass . 21:30 00:00 2.50 306 4,052 PROD1 RPCOti PULD T Rih PU Drill from pipe shed to 4052'. u wt 97k dn wt 75k 01/21/2008 00:00 01:00 1.00 4,052 4,240 PROD1 RPCOb PULD T Continue to Rih PU DP f/ 4052' U 4240' 27.0' in on 't # 122 01:00 01:30 0.50 PROD1 RIGMN SVRG P Service rig 01:30 03:00 1.50 4,240 306 PROD1 RPCO TRIP T Pooh f/ 4240' to 306'. 03:00 04:00 1.00 306 0 PROD1 RPCO PULD T Continue to Pooh w/ BHA# 1 and breakdown & La down scra er ass . 04:00 08:00 4.00 0 292 ~PROD1 RPCOh PULD T PJSM, PU BHA#2, 7.625 Baker 08:00 I 12:00 ~ 4.00 I 292 I 4,231 I PROD1 I RPCOhI DHEQ IT I PJSM, set pkr at 3580 ft, fill hole. Test min. All tests successful. No re-tests. 12:00 15:00 3.00 4,231 0 PROD1 RPCOti TRIP T PJSM, release pkr, POH for clean out ass . 15:00 16:00 1.00 PROD1 RPCOh OTHR P Ciean and clear rig floor. Remove tools from 16:OQ 16:30 Q.50 ~PROD1 RPCOti OTHR P RD Spinners and RU Eckies 01/21/2008 16:30 18:30 2.00 0 459 PROD1 RPCOh PULD P MU BHA#3 (clean out assy) RD Eckles and RU S i~ners 18:30 20:00 1.50 459 4,142 PROD1 RPCOh TRIP P Rih f/ 459.0 U 4142.0 20:00 22:30 2.50 4,142 4,392 PROD1 RPCOh FCO P MU Top Drive, fill pipe & wash down f/ 4142' U 4392'. Circ @ 5 bpm @ 2220 si. 105k u wt. 75k dn wt. 22:30 23:00 0.50 4,392 4,360 PROD1 RPCOh TRIP P LD 2 singies and Blow down Top drive 23:00 00:00 1.00 4,360 PROD1 RPCOh OTHR P Load Pipe shed w/ completion e ui ment and re are to Pooh. 01/22l2008 00:00 01:30 1.50 4,360 459 PROD1 RPCO TRIP P Pooh f/ 4360' t/ 459.0 01:30 02:00 0.50 0 PROD1 RPCOh OTHR P RD Spinners and RU Eckles 02:00 03:00 1.00 459 183 PROD1 RPCO PULD P Lay down BHA# 3 03:00 03:30 0.50 PROD1 RPCOti SFTY P PJSM 03:30 04:00 0.50 183 0 PROD1 RPCOh PULD P Continue to lay down BHA# 3 04:00 05:00 1.00 PROD1 RPCO OTHR P Clean and Clear rig floor. Clear Pipe shed 05:00 07:30 2.50 0 208 PROD1 RPCOh PULD P PU and MU BHA# 4 L-2 LEM/MWD assy. Shallow test MWD @ 2bpm @ 340 si. - ood test. 07:30 08:00 0.50 208 208 PROD1 RPCO PULD P C/O handling equip rig floor. 08:00 12:00 4.00 208 3,873 PROD1 RPCO TRIP P Resume RIH 3-1/2 DP to 3873 ft. 12:00 13:30 1.50 3,873 3,873 PROD1 RPCO CIRC P Circ out crude oil flow back thru DP due to ti ht kr / cs tolerance. 13:30 14:00 0.50 3,873 4,200 PROD1 RPCO TRIP P RIH to 4200 ft. 14:00 15:30 1.50 4,200 4,200 PROD1 RPCO CIRC P Bleed / circ crude / gas from annulus. 15:30 16:00 0.50 4,200 4,386 PROD1 RPCOh TRIP P RIH to tag @ 4376' work down U 4386' 16:00 17:30 1.50 4,386 PROD1 RPCO PACK P Wash / re-cip pipe to latch point with LEM. Orient MWD. Multiple attempts due to fill. Latch in, confirm orientation. Unlatch / relatch, confirm depth / orientation. Final depths @ 4386' 1730 19:30 2.00 PROD1 RPCO PACK P Drop ball, pressure up U 1975 psi - set pkr, continue to pressure up to 4,000 si and release settin tool. 19:30 21:00 1.50 PROD1 RPCOh DHEQ P ressure test IA to 2 500 ~ chart for 30 minutes. 21:00 22:00 1.00 PROD1 RPCO OTHR P Remove unneeded equipment from i e shed. 22:00 23:00 1.00 4,189 3,396 PROD1 RPCO OTHR P Pooh laying down dp f/ 4189' ( New to of PBR to 3396' 23:00 00:00 1.00 3,396 PROD1 RPCOh WOEQ T Wait on Pipe Containment equipment to arrive to store oify drill pipe pulled from well. 01/23/2008 00:00 01:30 1.50 3,396 3,396 PROD1 RPCO WOEQ T Waiting on containment for DP laid down - due to oil DP 01:30 00:00 22.50 3,396 3,396 PROD1 RPCOh WOW Phase 3 weather conditions. Monitorin weli 01/24/2008 00:00 09:00 9.00 3,396 3,396 PROD1 RPCOh OTHR NP Clear 1J Pad of snow drifts, making the ri accessible. 09:00 10:00 1.00 3,396 3,396 PROD1 RPCOh OWFF P Phase 3 lifted, PJSM, bieed tbg, 80 to 0 psi, bleed 4-112 X 7-5i8 ann 30 to 0 psi. Observe well while offload pipe shed. 10:00 15:00 5.00 3,396 330 PROD1 RPCO TRIP P PJSM, POH laying dn 4-1/2 DP. 15:00 16:30 1.50 330 330 PROD1 RPCOh CIRC P PJSM, crude oil creating nuisance / mess / safety hazard on rig floor. Butlhead crude to perfs. 4 bpm / 230 si. 16:30 17:00 0.50 330 250 PROD1 RPCO TRIP P Flow check, well stab4e / clean. No crude. resume POH la in dn DP. 17:00 19:00 2.00 250 0 PROD1 RPCO PULD P Flow check at BHA. Lay dn BHA / MWD ass . 19:00 1930 0.50 0 0 PROD1 RPCO OTHR P BOLDS, Pull wear ring 19:30 21:00 1.50 0 0 PROD1 RPCO Clean and clear rig floor. Empty pipe shed of unnecessa e ui ment. 21:00 00:00 3.00 0 0 PROD1 RPCO Load pipe shed with 4 1/2 completion strin and drift tb . 01/25/2008 00:00 00:30 0.50 0 0 PROD1 RPCOh SFTY P Hold PJSM on rigging up Heat trace sheeve and I tech wire sheeve. 00:30 05:00 4.50 0 0 PROD1 RPCO RURD P Continue to load pipe shed w! tbg. Drift and strap. RU heat Trace sheeve and I wire sheeve. S lice I wire. 05:00 07:30 2.50 0 PROD1 RPC06 RCST P PJSM, Commence run 4-1/2 completion. MU seal assy, prep tec wire, " uardian" au e. 0730 08:30 1.00 0 0 PROD1 WELCT CIRC P PJSM, Close rams due to ercolatin crude. Bullhead crude to perfs. NOT a well control issue. 08:30 11:00 2.50 0 0 PROD1 WELCT CIRC P Observe well. Limited success. Pump Hi-Vis seawater to perfs. Note slight press +ncrease. Continue fill. Hole full. Static loss a rox 10 b h. 11:00 12:00 1.00 0 0 PROD1 RPCO PULD P C/O standing valve to positive plug in DB ni le. 12:00 14:00 2.00 0 49 PROD1 RPCOh RURD P Splice remainder tec wire. Test. Test successful. 14:00 19:00 5.00 49 1,885 PROD1 RPCOh RCST P Resume RIH 4-1/2 completion. 19:00 20:30 1.50 PROD1 WELC CIRC P Bullhead 100 bbls hi visc seawater and chase w! 150 bbls KCL @ 4 bpm 50 si. 20:30 00:00 3.50 1,885 2,500 PROD1 RPCO RCST P Test ITec wire and meg heat trace. Continue to Rih w/ 4 1/2 Completion f/ 1885' U 2500' 01l26l2008 00:00 01:00 1.00 1,800 3,614 PROD1 WELC CIRC P PJSM Builhead 100 bbls hi visc seawater and follow w/ 100 bbls seawater (a~ 4 bpm C~ 50 qsi. 01/26/2008 01:00 02:00 1.00 PROD1 RPCO RCST P Continue to Rih w/ 4 1/2 Completion. 02:00 17:00 15.00 PROD1 RPCO RCST P Meg heat trace and test ITec line. Continue to Rih w/ 4 1/2 Com letion. 17:00 19:00 2.00 3,614 4,200 PROD1 RPCOti HOSO P PJSM, sting in SBE with seal assy, note "No Go" stackout. Press annulus 500 psi with reduced press on annular preventer. Strip through annular, note press bleed as seals exit SBE. Pull to floor, discover heat trace line parted. Continue s aceout. 19:00 20:30 1.50 PROD1 RPCOh HOSO P PUI and MU Landing Jt w/ hanger. Install Penetrators and clean up han er, ins ect seals. 20:30 23:00 2.50 PROD1 RPCOh OTHR P Splice Heat Trace and I Tec wire. 23:00 00:00 1.00 PROD1 RPCOb OTHR P Test wires thru Penetrators. 01/27/2008 00:00 04:00 4.00 PROD1 RPCOh OTHR T PJSM, Continue to trouble shoot the I Tec wire splice @ penetrator. Found broken connector @ splice. Re build s lice and tie to enetrator. 04:00 05:00 1.00 PROD1 RPCO HOSO P Land han er and RILDS. Test top and bottom hanger seals @ 5,000 psi - good. Tbg landed w/ bottom of seals @ 4,222', guage @ 4,148', DB 3.812" ID Nipple w/ Positive Plug @ 4,137', GLM w/ SOV @ 4,094', Heat trace started @ 3,000', GLM w/ dummy @ 2,589', and DS 3.875" ID Nipple @ 515'. 05:00 07:00 2.00 PROD1 RPCOh DHEQ P RU to pressure test tbg and csg @ 2,500 psi. Test tbq to 2,500 psi for 15 , min. and bleed back to 1,750 psi. Presure test cs to 2,500 si. Good. Bleed back tbg and shear out SOV @ 2,000 si. 07:00 08:00 1.00 PROD1 RPCO RURD P RD hi-press lines. 08:00 13:00 5.00 PROD1 RPCOh FRZP P RU / test lines. pump 110 bbls corrosion inhibited seawater, follow with 90 bbls diesel, 2 bpm / 1000 psi. Jump annulus to tbg, allow "U" tube to e ualize. 13:00 14:00 1.00 PROD1 RPCOh PULD P PJSM, B/O Idg jt, set BPV. 14:00 17:30 3.50 PROD1 RPCO NUND P PJSM, ND BOPE. 'i 17:30 21:00 3.50 PROD1 RPCOh NUND P Prep / NU temp P&A flange. 21:00 22:30 1.50 PROD1 RPCOI~ DHEQ P Test Temperary P&A Flange @ 2,000 si and hold for 15 minutes. 22:30 23:30 1.00 PROD1 RPCOti OTHR P Continue to wash & clean pits. 23:30 00:00 0.50 PROD1 RPCOh OTHR P Rig down Rockwasher and prepare to move rig to 1J-10. Release rig @ 23:59 hrs on 1-27-08 ~ ~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060050 Well Name/No. KUPARUK RIV U WSAK 1J-159 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23297-00-00 MD 7857 TVD 3642 Completion Date 3/13/2006 REQUIRED INFORMATION Completion Status 1-OIL Current Status 1-OIL UIC N Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/Res, DenslNeu Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name /F2pt 13931 LIS Verification 'H=`D D Lis 13931,/fnduction/Resistivity V D Asc Directional Survey D Asc Directional Survey ~t 13936 LIS Verification ~D D Lis 13936 /l'nductionlResistivity ~~ Spinner I~, ~ Induction/Resistivity o Induction/Resistivit g y C 16118 F~e Notes I~---- - --__--- Well Cores/Samp les Information: Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Scale Media Run No interval Start Stop OH CH Received Comments 2-4 2325 5808 Open 6/8/2006 PB1 2-4 2325 5808 Open 6/8/2006 GR, EWR4, ABI, CNP, SLD, ROP, ACAL, PWD ', P61 j 5541 7857 Open 6/27!2006 I 28 5808 Open 6/27/2006 PB 1 '; 2-5 2325 7857 Open 6/8/2006 2-5 2325 7857 Open 6/8/2006 GR, EWR4, ABI, CNP, SLD, ROP, ACAI, PWD Blu 25 4140 Case 4/10/2008 GLS, Pres, Temp, Gradio, Spin 6-Apr-2008 25 Col 218 7857 Open 4/21/2008 MD, ROP, DGR, EWR, CTN, ALD, ACAL 24-Feb- 2006 25 Col 218 3642 Open 4/21/2008 TVD, ROP, DGR, EWR, CTN, ALD, ACAL 24-Feb- 2006 0 0 Open 4/21 /2008 MD and TVD logs in CGM, EMF and PDS graphics '. Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060050 Well Name/No. KUPARUK RIV U WSAK 1J-159 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23297-00-00 MD 7857 TVD 3642 Completion Date 3/13/2006 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? Y /CN~ Daily History Received? ~~N Chips Received? l~T'R'- Formation Tops ls1~N Analysis Received? Comments: Compliance Reviewed By: Date: y N L ~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO. 4650 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 04/08/08 Well Job # Log Description Date BL Color CD 1A-19 12031469 LEE TOOL PROD PROFILE 03121/08 1 1 F-07 12031470 PROD PROFILE f ~`~ 03/22/08 1 3A-09 11980648 PROD PROFILE f ~4 03/22/08 1 2A-22 11970645 MULTI-FINGER CALIPER 03/20/08 1 1F-15 11970659 INJECTION PROFILE 04/02/08 1 1 C-11 11994642 LDL 04/03/08 1 1 G-09 11996613 INJECTION PROFILE (1= 04/05/08 1 iJ-159 11994646 GLS 04/06/08 1 2W-15 11996615 PRODUCTION PROFILE 04/07/08 1 1 L-08 11996616 PRODUCTION PROFILE L 04/08/08 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ rb • C WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 i April 10, 2008 RE: MWD Formation Evaluation Logs 1J-159+PB1+L1+L1PB1+L1PB2+L2 AK-MW-4150952 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-159+PB1+L1+L1PB1+L1PB2+L2 2" x 5" MD TC Logs: 1 Color Log 5 0-029-23 297-00, 60, 61, 70, 71, 72 2" x 5" TVD TC Logs: 1 Color Log 50-029-23297-00,60,61 Digital Log Images 1 CD Rom 5 0-029-23 297-00, 60, 61, 70, 71, 72 PB1, L1PB1 and L1PB2 have no TVD's. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~' ~~ ~_; ~`~ Date: Signed: ao(o^~vG ~' r~«9 ao~ -ooh '~ t (o t 26 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL .OPERATIONS 1. Operations Performed:. Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~Ct~~L .~ Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ .Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 206-005 / ~' 3. Address: Strati ra hic g p ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23297-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' ~ 1J-159 ~ 8. Property Designation: 10. Field/Pool(s): ADL25661 &.25662 Kuparuk River Field /West Sak Oil Pool ~ 11. Present Well Condition Summary: Total Depth measured 785T ~ feet true vertical 3642' , feet. Plugs (measured) Effective Depth measured 7841' feet Junk (measured) true vertical 3642' feet 4-1/2" Casing Length Size MD TVD Burst Collapse. Structural - - CONDUCTOR 108' 20" 108' 108' SURFACE 2256' 10-3/4" 2365' 2206'. PRODUCTION 5466' 7-5/8" 5575' 3695' WINDOW D-SAN 1' 7" 4247 3481' WINDOW B-SAN 1' T° 4566' 3550' Perforation depth: Measured depth: Liner slots 5567-5721 5845-6091 6399-7810 WS A2 true vertical depth: Liner slots 3694-3697 3694-3689 3682-3642 WS A2 Tubing (size, grade, and measured depth) 4-1 /2" , L-80, 3633' MD. Packers &SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-bbl Casin Pressure Tubin Pressure Prior to well operation 710 ~ 751 41 293 189. Subsequent to operation 737 ~ 1735 90 570 192 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work:. OilO .Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: contact Bob Christensen /Bob Buchholz Printed Name Robert W B u c hholz Title Production Engineering Technician / ~ .Signature ` ``^~2`~y `~~G~~~~ ~~/ / Phone 659-7535 Date //(y/D~ RECEIVED ~u~v 1 2 2007 i sion n (~ !R BFt~ ~t~~ ~ 3 2007 ~ ~ ~ ~ •~2'°7 Form 10-404 Revised 04/2004 ~ K ~ (-~ ~ (\' J,.~ L /C ~'"" Submit Ori ' I J~ IIIJJJ 111 ~~` v ~1 / t /~~J a 1 J-159 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/28/07 .SP stopped producing. Diagnostics determined that there was a ground downhole which wil ~equire a rig workover to replace the rig deployed equipment. 05!07/07 Replaced sheared SOV with DV @ 2577' RKB. 05/11/07 replaced STA #2 with 5/16" orifice valve @ 3172' RKB. Replaced STA #1 DV with .188" ~ORT,TRO=1375 @ 257T RKB. 05/17/07 Well returned to service using gaslift Re: FW: 1J-159 PTD # 206-005 ESP failau-e ~ ~ Subject: Re: FW: 1J-159 PTD # 206-005 ESP failure From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Wed, 23 May 2007 08:23:35 -0800 To: NSK Problem Well Supv <n1617~c~nocophillips.com> Marie, Even if GL when ESP fails is in the permit, I think the AA has some value. There are a lot of things/operations that can be described in the permit as contingencies, but there is value with notice or record of the change. Catch you later, Tom NSK Problem Well Supv wrote, On 5/23/2007 8:06 AM: Tom, Thanks, we'll trash our copies when we receive the returned 10-403s. We've consistently been submitting 10-404s when we change artificial lift methods -such as GL to surface powered jet pump, GL to ESP, etc, so we'll submit a 10-404 with N/A in the sundry box for converting from ESP to GL. The well has been lifting great on GL, our weekly production summary noted the well was producing 1500 BOPD on 5/18 welltest. Yes, I agree that an AA would be a good way to address gas lifting the failed ESPs. It would definitely streamline the paperwork/approval process. I have a note on our to do list to look into submitting an AA for approval to gas lift any of our west sak packerless completions that didn't a gas lift option in the PTD. Have a good time off over the next two weeks! Hopefully we get some sun. Thanks for your assistance. Marie From: Thomas Maunder [mailtoaommaunder@admin.state.ak.us) Sent: Wednesday, May 23, 2007 7:16 AM To: NSK Problem Well Supv Subject: Re: FNV: iJ-159 PTD # 206-005 ESP failure Marie, They are coming back unapproved since using gas lift was described in the permit application. This situation got me wondering if an AA similar to the one for disabling the pilots on injectors might be in order? I will have to check if submitting a 404 might be necessary due to the change in lift method. Notify us according to the AA and submit the 404 changing the lift method. Let me know your thoughts. Tom NSK Problem Well Supv wrote, On 5/22/2007 6:41 PM: Tom, 1 of 4 6/13/2007 7:59 AM Re: FW: 1J-159 PTD # 206-005 ESP failure '~, Have you had a chance to check into what we should do with the 10-403s submitted for 2 yr GL ', approval of 1J-159's failed ESP? Thanks, Marie From: Thomas Maunder [mailtoaom_maunder@admin.state.ak.usl ', Sent: Thursday, May 17, 2007 7:56 AM To: NSK Problem Well Supv '; Subject: Re: FW: 1J-159 PTD # 206-005 ESP failure Marie, I will check. You are probably right. '' Tom NSK Problem Well Supv wrote, On 5/17/2007 7:45 AM: Tom, ', ' Thanks. Just a quick confirmation to double check paperwork requirements. Regarding the 10-403's submitted for gas lift, should we cancel the submission? If we are ok to gas ', lift the failed ESP indefinitely under the PTD, I'm thinking we can toss the 10-403's. We'll be submitting a 10-404 to report a change in the artificial lift method from ESP to gas lift. The ', well was BOL on gas lift 5/16/07. Marie From: Thomas Maunder [mailtoaom_maunder@admin.state.ak.usl ', Sent: Tuesday, May 15, 2007 3:52 PM ', To: NSK Problem Well Supv ', Subject: Re: FW: 1J-159 PTD # 206-005 ESP failure Marie, I discussed this with Commissioner Foerster, your interpretation is correct. The well may be produced on gas lift. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 5/15/2007 11:12 AM: Tom, The west sak engineers noted that gas lift backup was included in the PTD for these wells and were wondering if that would cover approval to gas lift the failed ESP. ', An excerpt of the PTD program for reference: 39. RU and run a 4 1/2" ESP completion with backup gaslift. j 2 of 4 6/13/2007 7:59 AM I Re: FW: 1J-159 PTD # 206-005 ESP failure f. J ', 40. Space out tubing and land tubing in tubinghead. 41. Nipple down BOPS, nipple up tree and test, change over the hole to diesel. ', 42. Set BPV and RDMO Doyon 141. ', 43. Rig up wire line unit. Pull BPV. 44. Circulate out well with diesel through the ESP. 45. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 46. Replace gas lift valves with blank dummy valves. 47. Place well on production with ESP. Marie From: Thomas Maunder [mailtoaom maunder@admin.state.ak.us] ',., Sent: Monday, May 14, 2007 2:20 PM To: NSK Problem Well Supv Subject: Re: FW: 1)-159 PTD # 206-005 ESP failure Marie, I have not seen the sundries yet. I will check to see if they are in-house. Tom '' NSK Problem Well Supv wrote, On 5/14/2007 2:14 PM: Tom, ', Last Monday, Perry Klein, submitted 10-403s to gas lift well 1J-159 (wellbores 1J-159, ', 1 J-159L1, & 1 J-159L2) failed ESP while waiting on a RWO. Has AOGCC received the sundry applications? They may still be in the mail. I understand your work load, especially with the vacancies, so not intending to add any undue '; rush for approval. We'd just like to know as soon as practical once approval is granted for rate optimization. Currently, the well is SI waiting on approval to gas lift. Operations is ready to start gas lifting as soon as commission approval is obtained, and they were wondering about timing. I'll let them know it will be a few weeks at least for paperwork processing. Thanks, Marie McConnell Problem Well Supervisor (907) 659-7224 n 1617(a~conocophillips.com From: NSK Problem Well Supv Sent: Friday, May 04, 2007 9:57 AM To: Thomas Maunder' Cc: NSK West Sak Prod Engr 3 of 4 6/13/2007 7:59 AM Re: FW: 1J-159 PTD # 206-005 ESP failure • Subject: iJ-159 PTD # 206-005 ESP failure Tom, 1 J-159 PTD # 206-005 ESP producers ESP failed 4/28. Centrilift has confirmed that the pump is grounded down hole and will require a RWO to repair /replace. ', Plan forward is to attempt to pull the pump with a coiled tubing unit in preparation to lift via the pump intake manifold. CPAI would like permission to temporarily produce the well on gas lift, not to exceed 30 days. If permission is granted and the test proves the well is economically viable a 10-403 will be submitted requesting permission to produce the well via gas lift until a rig work over is possible. Thanks in advance. Perry Klein Problem Well Supervisor office (907) 659-7224 ', Cell (907) 943-1244 ', ', Pager (907) 659-7000 x909 ', n1617(a~conocophillips.com 4 of 4 6/13/2007 7:59 AM ! ~ ~. a j ~~ x_ ALA5SA OIL A1~TD G.~S COI~TSERQA~`I011T CO1rII~IISSIOI~T Perry Klein Problem Well Supervisor ConocoPhillips Alaska P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-159 Sundry Number: 307-159 Dear Mr. Klein: SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the unapproved Application for Sundry Approval relating to the above referenced well. We are returning your application for Sundry Approval unapproved. Since operating the well is equipped with gas lift if the ESP failed was described in the Application for Permit to Drill this sundry is not needed. DATED thi day of May, 2007 Encl. i 2 6 ~-~ ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 7, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: h E~EI VE® MAY ~ ~ ?001 Alaska Oil & Gas Cons, Commission Anchora~a Enclosed please find 10-403 applications for Sundry Approval for ConocoPhillips Alaska, Inc. well 1J-159 PTD 206-005, 1J-159L1 PTD 206-006, and 1J-159L2 PTD 206007 to produce via gas lift until the failed ESP is replaced. ~' ._._., Please call Marie McConnell or myself if you have any questions. Sincerely, Pe ein Problem Well Supervisor Attachments ~ a~'su~~ ~ RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 1 0 2007 APPLICATION FOR SUNDRY APPROVA~aska oil & Gas Cons. Commission 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 206-005 ~ 3. Address: Stratigraphic ~ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 ` 50-029-23297-00 '~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership chang es: Spacing Exception Required? Y@S ^ NO [/]~ S'Z~ ~ 1J-159 9. Property Designafron: /.}D~ 2S6 B~ ~ 10. KB Elevation (ft): 11. Field/Pool(s): Kuparuk River Unit u ~'~' /_'r'~ RKB 109' Kuparuk River Field /West Sak Oil Pool ~ 12. PRESENT WELL CONDITION SU MARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): PI (measured): Junk (measured): 7857 ~ 3642' Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108 SURFACE 2256' 10-3/4" 23 2207 PRODUCTION 5466' 7-5/8" 75' 3549 _ WINDOW D-SAND 1' 7'y 4247' 3481 WINDOW B-SAND 1' ~~ 566' 3550 Perforation Depth MD (ft): rforation Dep Tubing Size: Tubing Grade: Tubing MD (ft): liner slots 5567-5721 5845-6091 6399-7810 WS A2 er slots 694- 694-3 8 682- 42 WS A2 ~-'!~2" L-$® 3633' Packers and SSSV Type: ckers an SSSV MD (ft) no packer no SSSV S 13. Attachments: Description Summary of Prop I ~ ass after proposed work: Detailed Operations Program ^ BOP etch E oratory ^ Development ^~ Service ^ 15. Estimated Date for 16 el Status after proposed work: Commencing Operations: Oil ^~ ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Dat WAG ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I her the for ng is u and correct to the best of my knowledge. Contact: Perry klein /Marie McConnell rented Name P ry lein Title: Problem Wells supervisor Signature ~ Phone: 659-7224 Date: 05/07/07 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness .~ Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~S S BFI ~iA7 2 3 20D9 Subsequent Form Required: APPROVED BY Approved by: OMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 ~~~? in Duplicate =z/c7 ~y S'.2.e .. m 9 ConocoPhillips Alaska, Inc. West Sak Injection Well 1J-159 (PTD 206005), 1J-159L1 (PTD 206006) & 1J-159L2 (PTD 206007) SUNDRY NOTICE 10-403 VARIANCE REQUEST 05/07/2007 The purpose of this Sundry Notice is for approval to produce tri-lateral West Sak producer 17- 159 via gas lift until the failed ESP is replaced. The well is completed as an ESP (electric submersible pump) producer and does not have a packer. 1J-159 was completed in May, 2006 and produced via ESP unti104/28/07, at which time it was shut-in due to a downhole motor electrical failure. Prior to failure, the ESP had drawn the bottom hole pressure down to 780 psi. A RWO is planned to replace the failed ESP within the next 2 years. The tubing is configured with two gas lift mandrels at 2577' RKB (2396' TVD) and 3172' RKB (2905' TVD). An attempt to place this well on gaslift is desired until the well is worked over and the ESP completion replaced. Due to the deviation coiled tubing will be used to pull the ESP to give the produced fluids a path through the intake ports in the tubing. If the pump can not be pulled then the tubing will be perforated above the ESP. An unloading valve will be installed in the upper gas lift mandrel. The lower gas lift mandrel will not be accessible by slickline and an attempt to pull the dummy valve and replace it with an orifice valve will be made using an electric line tractor tool. Gas lift will be applied in the "standard" configuration; i. e., gas will be injected down the annulus and enter the tubing through the orifice valve or tubing holes. The last production test on 04/26/07 recorded 710 BOPD, 41 BWPD (5%WC), and 751 MSCF of gas. Attached is a wellbore diagram of the well. The following is a summary of the proposed plan: The AOGCC approve this request for a time period not to exceed 24 months from the _ ____ _ approval date; 2. Should a workover not be completed within the approved time period the AOGCC will be contacted for a review and discussion of the plan forward. • r 12-May-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 J-159 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 5,541.32' MD Window /Kickoff Survey: 7,774.17' MD (if applicable) Projected Survey: 7,857.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION 'OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~ ~ Op Si ned a ~ ~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~. u (p -- t9 ©~~- 12-May-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-159 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 28.00' MD Window /Kickoff Survey: 5,751.68' MD (if applicable) Projected Survey: 5,808.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date o~, l k +~..~a G Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ,ZOO-~0> WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-159 PB1, May 31, 2006 AK-MW-4212091 1 LDWG formatted Disc with verification listing. API#: 50-029-23297-70 ~~~3i PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETiJRNING A COPY OF THE TRANSMITTAL LETTER TO TIIE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 1~ D~1~N (1 gT~ri~ Al~ka ~ ~ Gas Oars. CAmmissioi7 Andxfra~e Signed: ~v~ -ors' ~ X393 ~ • • WELL LOG TRANSMITTAL To: State of Alaska May 31, 2006 Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-159, AK-MW-4212091 1 LDWG formatted Disc with verification listing. API#: 50-029-23297-00 l 3 ~ 3 YLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF TIIE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ~~r~chp fag~~ll~~ska 99518 JUN U ~ 2'OOC Date: a~- Oil & Gas on, , ~:s~- Anchcxa~ Signed: C - ~ '~s~_~--- ~U~-U65 ~ t3~3~ ConocoPhillips May 11, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Subject: Well Completion Reports for 1 J-159, 1 J-159L1 and 1 J-159L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 1J-159, 1J-159L1, 1J-159L2. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA ALA KA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT' i4ND` LOG' =`R 1a. Well Status: Oil O Gas Plugged Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development O Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., oraband.: March 13, 2006' 12. Permit to Drill Number: 206-005 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: February 12, 2006 13. API Number: 50-029-23297-00 ' 4a. Location of Well (Governmental Section): Surface: 2035' FSL, 2545' FEL, Sec. 35, T11N, R10E, UM ~ 7. Date TD Reached: February 22, 2006 14. Well Name and Number: 1J-159 At Top Productive Horizon: 86' FSL, 1713' FEL, Sec. 35, T11 N, R10E, UM 8. KB Elevation (ft): 28' RKg 15. Field/Pool(s): Kuparuk River Field Total Depth: 2203' FNL, 1823' FEL, Sec. 2, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 7841' MD / 3642' ND West Sak Oil Pool ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558664 ~ y- 5945847 ~ Zone- 4 10. Total Depth (MD + ND): 7857' MD / 3642' TVD • 16. Property Designation: ADL 25661 & 25662 TPI: x- 559513 y- 5943904 Zone- 4 Total Depth: x- 559424 + - 5941614 ~ Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 8~ 2177 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2365' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 62.58# H-40 28' 108' 28' 108' 42" 233 sx AS 1 10.75" 45.5# L-80 28' 2364' 28' 2207' 13.5" 469 sx Class G, 175 sx Class G 7-5/8" 29.7# L-80 28' 5575' 28' 3696' 9-7/8" 51 sx LiteCRETE 4.5" 12.6# L-80 4666' 7842' 3566' 3642' 6.75" slotted liner 23. Pertorations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 3633' 4666' slotted liner from 4849'-7847', 8174'-10823' MD ` 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production May 5, 2006 Method of Operation (Flowing, gas lift, etc.) ESP oil producer -shares production with 1J-159L1 and 1J-159L2 Date of Test 5/10/2006 Hours Tested 14.5 hours Production for Test Period --> OIL-BBL 2316 GAS-MCF 1072 WATER-BBL 0 CHOKE SIZE 20% GAS-OIL RATIO 506 Flow Tubing press. 32o psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 3659 GAS-MCF 1850 WATER-BBL 1 OIL GRAVITY -API (corr) 19° ' 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ..,, ~~5 ~F~. MAC' ~ 4 200& ~ ~. '' - ~ NONE .~L__~~ •b~ .,. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~~~~~~ ,j ~ ~~, p6 o~~o~NA~ ~f6~~ zs. zs. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-159 West Sak A2 Sand 5560' 3695' ' Base West Sak A2 sand 7856' 3642' . N/A 1 J-159PB1 TD 5808' 3693' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed N Ra Thomas Title: Greater Kuoaruk Area Drilling Team Leader _ S ~~~ ~G5 6 - 6 ~ ~ ~ Date Signature one u { INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval}. Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 • • ConocoPhillips Alaska Operations Summary Report Page 1 of 19 Legal Well Name: 1J-159 Common Well Name: 1 J-159 Spud Date: 2/12/2006 Event Name: ROT -DRILLING Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase Description of Operations 2/11/2006 12:00 - 14:00 ~ 2.00 I MOVE MOB MOVE Disconnect all Electrical lines. Pull Swing arm over, and pin same in 14:00 - 18:00 I 4.001 MOVE 18:00 - 20:30 I 2.501 MOVE 20:30 - 22:00 I 1.501 MOVE 22:00 - 00:00 I 2.001 DRILL 12/12/2006 00:00 - 01:30 1.50 J 01:30 - 03:00 03:00 - 05:15 05:15 - 06:30 06:30 - 07:00 07:00 - 08:00 08:00 - 09:15 09:15 - 09:45 09:45 - 10:30 10:30 - 11:15 I 0.75 DRILL 11:15 - 12:00 0.75 DRILL 12:00 - 13:30 1.501 DRILL 13:30 - 15:00 I 1.501 DRILL 15:00 - 16:30 ~ 1.50 ~ DRILL 16:30 - 00:00 I 7.501 DRILL 12/13/2006 100:00 - 12:00 I 12.001 DRILL place. Continue prep for move. MOVE MOVE PJSM with crew & Peak Truck drivers. Discuss Safety issues and procedure for rig move. Lay matting boards down pulling sub base. Move Pipeshed modules, Rockwasher, Boilers, Motors and Pit Modules from 1J-166. Move Sub base & spot rig on well 1J-159. POSN MOVE Clean up 1 J-166 Well area, spot matting boards for complexes. Move & Spot Boilers, Motors and Pit Modules to rig. POSN MOVE Spot matting boards for for complexes. Move & Spot Pipeshed modules & Rockwasher to rig. Release Peak @ 2200 HRS. RIRD RIGUP Connect all Steam, Hydraulic, Air, & water lines. Connect electrical lines. Work on Rig acceptance checklist. Rig accepted @ 00:01 HRS 2/12/06. NUND RIGUP Install Riser Bell Nipple on_Diveter System, and install 4" Valves on conductor. Derrick. 15 stands. RSRV RIGUP Slip & Cut 60' of Drilling Line. RSRV RIGUP Inspect & Service Top Drive. OTHR RIGUP Pick up 1 Stand of DP. RIH & Pertorm Diverter Function test. Witness of test waived by AOGCC Jeff Jones. Test witnessed by Co. Rep. Simops: Pull BHA equipment to rig floor. PULD RIGUP Pick up 5" HWDP, Drilling jars, and 3 NonMag Flex Drill Collars. Rack in Derrick. SFTY RIGUP Held PJSM with crew & DD's. Discuss safety issues and procedures for picking up BHA, and Spud. RKB to casing Head =22.55' PULD SURFAC Make up 13 1/2" HTC MXC1 bit with 3 x 20's, & 1 x 13 jets (1.00'). 8" Sperry Drill Lobe 4/5 - 5.3 stage (28.69'), 8" WB type Stabilizer (4.42'), 8" Non Mag Float Sub (2.15'), Bottleneck Crossover (2.47'), and 1 stand 5" HWDP (90.83'). CIRC SURFAC Prime mud pumps, and flood conductor. Test surface lines to 3000 PSI. No Leaks. DRLG SURFAC Drill 13 1/2" Surface hole from 90' -130'. Pumps at 450 GPM - 420 PSI. 60 RPM's. 3K torque. ADT = .62 HRS. DRLG SURFAC Continue Drill 13 1/2" Surface hole from 130' -218'. Pumps at 430 GPM - 450 PSI. 60 RPM's. 3K torque. ADT = 1.85 HRS. TRIP SURFAC POOH 2 stands. Blow down Top Drive. PJSM with GYRO crew. RU Gyro Unit. PULD SURFAC Make up MWD assembly, 8" DWD KM8 (26.91'), UBHO sub (3.45'). Orient MWD to motor. MU 1 stand Non Mag Flex Drill Collars (92.91'), and 5" HWDP. Break Circulation. NOTE: STarting JAR HRS = 130.72 DRLG SURFAC Drill 13 1/2" Surface hole from 218' - 615' (397'). Run Gyro survey every 91' for close approach issues & kick off. AST = 1.47 HRS, ADT = 5.04 HRS. Up WT = 74k, SO WT = 74K, ROT WT = 70K. TO on BTM = 3-4k, TO off BTM = 2K. JAR HRS total = 138.85. Pumps @ 480 GPM's - 900 PSI. Rotate @ 60 RPM's. WOB = 10 - 20K. Mud WT = 8.8 PPG Viscosity = 400. YP = 83, Gels = 26 / 59. with Solids @ 4.0 DRLG SURFAC Continue Drill 13 1/2" Surface hole from 615' -1634' (1019'). RD Gyro survey. AST = 4.07 HRS, ADT = 7.45 HRS, ART = 4.00 HRS. Up WT = 98k, SO WT = 90K, ROT WT = 95K. TO on BTM = 4-6k, TO off BTM = 5K. JAR HRS total = 146.58. Pumps @ 550 GPM's - 1750 PSI. Rotate @ 65 RPM's. Max Gas = 54 units. WOB = 30 - 35K. Mud WT = 9.2 1.50 RIGMNT RGRP RIGUP Change out Saver Sub on Top Drive to 4 1/2" IF threads. 2.25 DRILL PULD RIGUP Strap & Pick up 45 joints of 5" DP from pipe shed. Racking back in 1.25 RIGMI 0.50 RIGMI 1.00 DRILL 1.25 DRILL 0.50 DRILL 0.75 DRILL Printed: 4/122006 1:53:21 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 12/13/2006 00:00 - 12:00 12.00 I DRILL DRLG SURFAC 12:00 - 18:45 18:45 - 20:00 20:00 - 21:00 21:00 - 21:30 6.751 DRILL I DRLG I SURFAC 1.251 DRILL ~ CIRC SURFAC 1.001 DRILL (WIPR (SURFAC 0.501 DRILL (WIPR (SURFAC 21:30 - 22:00 22:00 - 00:00 2/14/2006 00:00 - 00:30 00:30 - 01:45 01:45 - 02:30 02:30 - 03:00 03:00 - 03:45 03:45 - 04:00 04:00 - 06:00 06:00 - 10:00 10:00 - 10:30 10:30 - 11:15 11:15 - 12:00 12:00- 12:30 12:30 - 15:30 Page 2 of 19 Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number: Description of Operations PPG Viscosity = 300. YP = 47, Gels = 22 / 38. with Solids @ 6.5 Total AST = 5.54 HRS, ART = 9.04 HRS. Survey @ 1449.84 MD 1411.87 TVD, INC = 25.21 DEG, AZ = 45.28 DEG. Total Bit HRS = 14.58 Continue Drill 13 1/2" Surface hole from 1634' -2370' (736'). Run Gyro survey @.1300' for close appraoch issues.. AST = 1.82 HRS, ADT = 3.7 HRS, ART = 1.89 HRS. Up WT = 110K, SO WT = 97K, ROT WT = 103K. TO on BTM = 5-6k, TO off BTM = 3K. JAR HRS total = 150.29 Pumps @ 700 GPM's - 2100 PSI. Rotate @ 75 RPM's. Max Gas = 54 units. WOB = 20 - 35K. Mud WT = 9.15 PPG Viscosity = 275. YP = 47, Gels = 22 / 38. with Solids @ 6.5. Total AST = 7.36 HRS, ART = 10.93 HRS. Survey @ 2322.58 MD 2169.4 TVD, INC = 28.82 DEG, AZ = 80.98 DEG. Released GYRO Unit @ 1400 HRS. Total Bit HRS = 18.29 Circulate hole clean while reciprocating drill string @ 700 GPM's - 2100 PSI. Attempt to POOH on elevators, observing proper hole fill. Overpull from 5 - 30K. Wipe through spots at 1900' & 1825'. Decision to run back to bottom and pump out of hole, with no rotation. Trip back to bottom @ 2370' on elevators. No issues on TIH. 5 Stands. 0.50 DRILL CIRC SURFAC Circulate btms up @ 700 GPM's - 2100 PSI. 75 RPM's & 4K TO. 2.00 DRILL TRIP SURFAC Pump out of hole, no rotation from 2370' - 1266'. (1104'). Observe no issues, and slight overpull @ 1300'. Pumps @ 500 GPM's - 1200 PSI, to keep from washing out 13 1/2" hole. Observe good cuttings at shakers buf not excessive. 0.50 DRILL TRIP SURFAC Pumped OOH from 1,266' to 1,082' w/ 500 gpm, 1100 psi. 1.25 DRILL TRIP SURFAC POOH from 1,082' to 61'. UD 15 jts HWDP. PUW=90K SOW=85K 0.75 DRILL PULD SURFAC ~ UD 3 jts NMFDCs, UBHO sub, float sub. 0.50 DRILL PULD SURFAC Downloaded MWD. 0.75 DRILL PULD SURFAC UD stab, MWD, motor and flushed same. UD bit and cleared and cleaned rig floor. 0.25 DRILL OTHR SURFAC Made a dummy run to check hanger. 2.00 CASE RURD SURFAC Held PJSM. R/U to run 10 3/4" casing. 4.00 CASE RUNC SURFAC Ran 57 jts 10 3/4" casing to 2,364.47" w/ total 22 bowspring centralizers as follows: Ran 1 centralizer on stop collar 5' above shoe. Ran 2 centralizers one 10' above and one 10' below float collar. One centralizer perjt. #3-#19. One centralizer over collar on jt #56 and #57. 0.50 CASE CIRC SURFAC Circ'd BUs w/ Franks fill-up tool @ 6 bpm, 375 psi. PUW=140K SOW=95K. 0.75 CASE RURD SURFAC R/D Franks fill-up tool, blew down TD, and installed cement head. 0.75 CASE CIRC SURFAC Conditioned mud through cement head. 0.50 CASE CIRC SURFAC Cont'd to circ and cond. mud @ 6 bpm, 400 psi. PUW=145K SOW=95K ~ Held PJSM. 3.00 CEMENT PUMP SURFAC Continue pumped an additional 50 bbls of CW 100 (50 bbls total), Followed by 50 bbls of 10.5 ppg mudpush w/ red dye, dropped btm I ~ plug, began mixing and pumping Arcticset lead slurry, Pumped 375.0 ~ bbls (471 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 6.6 bpm at 275 psi, Followed with 74.1 bbls (169 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.46 yield with add., ave 4.8 bpm at 230 psi, I I i shut down and dropped top plug, Kick plug out with 20 bbls fresh water, ' I i to 15' until 150 bbls cement around shoe then Reciprocated caste ing\10 Printed: 4/12/2006 1:53:21 PM • • ConocoPhillips Alaska Page 3 of 19 Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 2/14/2006 112:30 - 15:30 3.00 CEMENT PUMP SURFAC 15:30 - 16:30 1.00 CEMENT RURD SURFAC 16:30 - 18:00 1.50 WELCTLJ NUND SURFAC 18:00 - 20:00 I 2.001 WELCTLI NUND I SURFAC 20:00 - 23:30 3.50 WELCT NUND SURFAC 23:30 - 00:00 0.50 WELCT NUND SURFAC 2/15/2006 00:00 - 00:45 0.75 WELCT NUND SURFAC 00:45 - 10:45 10.00 WELCT BOPE SURFAC Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006- Rig Release: 3/13/2006 Group: Rig Number. Description of Operations pipe became tight and landed on hanger, Up 135K, Dn 80K..Turn over ~ to rig and displace cement w/ 197 bbls (1967 stks to bump plug) of 9.5 ppg mud, Displaced cement at 7.0 bpm, Initial pump pressure 280 psi, max pressure at 7.0 bpm 320 psi, Observed red dye at shakers after pumping 135 bbls mud, Slowed rate down to 3 bpm @ 280 psi 10 bbls prior to bumping plug, Bumped plug w/ 1100 psi, Held. 10 min, Check floats- OK, CIP @ 1525 hrs 2/14/2006, Had full returns through out job ~~i with 72.1 bbls 10.7 ppg cement to surface, Shoe @ 2,364.47, TVD = '.2,207. Float collar @ 2,279.47. Test Float Equipment. Floats held. Flushed stack and flow line. R/D Schlumberger and pulled landing jt. Nippled down diverter and knife valve, pulled riser, functioned and washed Hydril. Removed Hydril and diverter spool. Cleaned wellhead and installed Vetco Gray 11"wellhead and tested to 5000 psi. Nippled up BOPS, 13 5/8" X 11" adapter spool, attached turnbuckles. P/U 11"wellhead equip. including test plugs, wear rings, and running tools. Finished N/U BOPE. PJSM - Dicuss testing BOP's & Safety Issues. Perform BOP test. As follows:(1) Tested 7.625" rams, HCR choke (2) 3.5"X6" top rams, HCR kill and choke valves, valves 1,12,13,14 (3) Top rams, manual kill, choke valves 9,11, auto IBOP (4) Top rams, manual kill, choke valves 5,8,10, manual IBOP (5) Top rams, manual kill, choke valve 4,6,7 (6) Top rams, manual kill, choke valve 2, 4" TIW valve (7) Top rams, manual kill, choke valve 3, 4" dart valve (8) Top rams, manual kill, HCR choke, 5" TIW valve (9) Top rams, manual kill, 5" dart valve, (10) Annular preventer, manual choke + kill (11) Perform Koomey test. System Pressure = 3000 PSI, Pressure after close = 1900 PSI. First 200 PSI attained in 49 secs, and full pressure attained in 3 min 39 secs. AVG pressure in Nitrogen bottles = 2300 PSI. (12) Blind rams. All test to 250 PSI -low, 3500 PSI High. AOGCC rep, Jeff Jones w~nessed 10:45 - 12:00 I 1.251 WELCTu BOPE I SURFAC 12:00 - 15:15 3.251 WELCTu BOPE SURFAC 15:15 - 19:30 4.25 WELCT BOPE SURFAC 19:30 - 21:30 2.00 WELCTu BOPE SURFAC 21:30 - 00:00 2.501 WELCTu BOPE SURFAC 2/16/2006 ~ 00:00 - 00:30 0.50 WELCT ~ BOPE SURFAC 1 00:30 - 01:00 0.50 ~ DRILL OTHR SURFAC 1 01:00 - 02:30 1.50 RIGMNT RSRV , SURFAC 1 02:30 - 03:00 0.50 DRILL; RIRD ; SURFAC Unable to test Hydril against 5" test joint. Rubber element in need of C/O. R/U to replace element. R/U scaffolding to access BOPS. While R/U scaffolding an incident occured wherein an individual injured a finger. Taken to medic for examination, with scaffolding not fininshed or signed off. Scaffolding crew returned @ 1400 hrs. Work concluded @ 1515 hrs. Changed out Hydril element and installed riser. Retrieved test plug, noted Hydril rubber on plug. Washed rubber off and retrieved plug. Checked seals. R/U 5" test jt and set test plug. Tested annular preventer to 250 /3000 psi. UD 5" test jt and P/U 4" test jt. M/U test plug and RIH. Tested annular preventer to 250 / 3000 psi. Finished testing annular to 250 / 3000 psi against 4" test jt. Performed accumulator test after rebuild of 4-way valve. System Pressure = 3000 PSI, Pressure after close = 1800 PSI. First 200 PSI attained in 35 secs, and full pressure attained in 3 min 079 secs. AVG pressure in Nitrogen bottles = 2300 PSI. Pulled test plug and installed wear ring. Changed out saver sub from 4.5" IF to 4" XT-39. Installed bails and elevators. Printed: 4/12/2006 1:53:21 PM • ~ ConocoPhillips Alaska Page 4 of 19 Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1 J-159 Spud Date: 2/12/2006 Event Name: ROT -DRILLING Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 2/16/2006 103:00 - 08:00 08:00 - 12:00 ~ 12:00 - 14:30 j 14:30 - 16:00 ~ 16:00 - 17:30 17:30 - 20:30 20:30 - 22:00 ~ 22:00 - 00:00 2/17/2006 i 00:00 - 12:00 12:00 - 00:00 2/18/2006 100:00 -06:30 5.00 DRILL 4.00 DRILL 2.50 DRILL PULD SURFAC ~ P/U 150 jts 4" DP and racked back same (50 jts at a time). PULD I SURFAC P/U and M/U BHA#2 including: Bit, Mud Motor, Sub -Float Stabilizer, 6 3!4" DM Collar-MWD, 6 3/4" Gamma/Res/PWD/HCIM. (PULD (SURFAC Held PJSM for nuclear sources. P/U 2 flex DCs, HWDP and jars, 3 stds 5" DP, and ghost reamer, 12 stands 5" DP, XO to 4" DP. Tagged up @ 2268' Circa and S/B 1 std. R/U and tested casing to 3000 psi for 30 mins: ~I Repaired 4-way valve on accumulator (controlled top rams) ,bled air from new lines. Drilled out shoe track w/ 400 gpm, 950 psi, 2-5K WOB, TO=4-6, ROT=95K. Tagged float @ 2,274' and shoe @ 2,360'. Drilled 25' of new hole to 2395' MD 2233' TVD. Swapped mud, R/U and performed LOT to 13.7 EMW w/ 550 psi at surface. R/D and blew down. Garnered SPRs. SPR#1=30stk/180psi, 40stk/230psi SPR#2=30stk/180psi, 40stk/240psi @ 2,395' MD / 2,233' TVD and 9.0 PPG. Drilled from 2,395' to 2,523' MD / 2,344' TVD. ART=0.36 AST=0.43 Jar Hrs=151.08 PUW=112K SOW=82K ROT=95K Continue Directional drill 9 7/8" Intermediate from 2,523' to 3,829' MD / 3,323' TVD. ADT =8.21 hrs ART=2.69 AST=5.52 Total Bit HRS=9.0. Total Jar HRS =159.29 PU WT = 135K, SO WT = 85K, ROT WT =105K: TQ on/off=5-10/5-10K. Pumps- 589 GPM's -1900 PSI. RPMs = 100. WOB = 5-20K. Mud Wt =9.00 PPG, Visc = 57, ECD = 9.59 PPG, Max gas = 62 Units. 1.50 CASE 'MIT SURFAC 1.50 RIGMNT RGRP SURFAC 3.00 CEMEN i DSHO SURFAC 1.50. CEMENT LOT 'SURFAC 2.00 DRILL I DRLG ;INTRMI 12.001 DRILL 12.001 DRILL 6.501 DRILL .DRLG I INTRMI SPR#1=20stk/250psi,30stk/330psi SPR#2=20spm/260psi,30stk/320psi @ 3,736' MD/ 3,265' TVD 9.OMW 'DRLG INTRM1 Continue Directional drill 9 7/8" Intermediate from 3,829' to 4,483' MD / 3,531' TVD. ADT =8.2 hrs ART=4.64 AST=3.56 Total Bit HRS=17.2. Total Jar HRS j -167.49 j PU WT = 135K, SO WT = 81 K, ROT WT =98K. TO on/off=5-9/6-8K. Pumps - 564 GPM's -1925 PSI. RPMs = 100-110. WOB = 15-25K. Mud Wt =9.0+ PPG, Visc = 51, ECD = 9.6 PPG, Max gas =110 Units. Observed drilling through concretions from 4275'-4280', 4297'-4300', 4312'-4314',4320'-4327',4329'-4338', 4390'-4392'. j ~SRR#1=20stk/180psi,30stk/230psi SPR#2=20spm/170psi,30stk/230psi @ 4,390' MD/ 3,516' TVD 9.0 MW DRLG INTRM1 ~ Continue Directional drill 9 7/8" Intermediate from 4,483' to 4,773' MD / ~ 3,576' TVD. ADT =4.72 hrs ART=4.46 AST=0.26 Total Bit HRS=21.92. Total Jar HRS =172.21 PU WT = 135K, SO WT = 75K, ROT WT =95K. TO on/off=6/7K i ;i Pumps - 615 GPM's -2000 PSI. RPMs = 100-110. WOB = 5-35K. Mud j Wt =9.1+ PPG, Visc = 55, ECD = 9.63 PPG, Max gas =174 Units. i ~ Observed drilling through concretions from 4625'-4635'. Printed: 4/1120CHi 1:5:1:11 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 J-159 1 J-159 ROT -DRILLING n1334@ppco.com Doyon 141 Hours Code Code Phase Start: 2/11 /2006 Rig Release:. 3/13/2006 Rig Number: Page 5 of 19 Spud Date: 2/12/2006 End: 3/13/2006 Group: Date From - To 2/18/2006 ~ 00:00 - 06:30 Description of Operations 6.501 DRILL DRLG INTRM1 06:30 - 07:00 0.50 DRILL DEQT INTRM1 07:00 - 07:30 0.50 DRILL CIRC INTRMI 07:30 - 08:45 1.25 DRILL TRIP INTRM1 08:45 - 10:30 1.75 DRILL TRIP INTRM1 10:30 - 1.1:00 0.50 DRILL OBSV INTRM1 11:00 - 12:00 1.00 DRILL TRIP INTRMI 12:00 - 12:30 0.50 DRILL TRIP ,INTRMI 12:30 - 13:00 0.50 DRILL PULD INTRM1 13:00 - 13:15 0.25 DRILL PULD INTRM1 13:15- 13:45 0.50 DRILL PULD INTRMI 13:45 - 14:15 0.50 DRILL PULD INTRM1 14:15 - 14:45 0.50 DRILL PULD INTRMI 14:45 - 15:30 0.75 DRILL PULD INTRM1 15:30 - 16:30 1.00 DRILL PULD INTRM1 16:30 - 17:30 1.00 DRILL PULD INTRMI 17:30 - 18:00 18:00 - 20:30 20:30 - 00:00 12/19/2006. 00:00 - 08:00 0.501 DRILL I PULD I INTRMI 2.501 DRILL (TRIP INTRMI 3.501 DRILL DRLG INTRM1 SPR#1=20stkl180psi,30stk/230psi SPR#2=20spm/170psi,30stk/230psi @ 4,390' MD/ 3,516' TVD 9.O MW MWD failed. Attempt to troubleshoot. Circa BU @ 625 gpm, 2250 psi. POOH from 4,673' to 3.926' MD w/ 40-80 excess drag. POOH from 3.926' to 2,056' MD w/ 500 gpm, 1400 psi. Checked flow, static. Changed over to 5" handling tools. Cont'd to POOH from 2,056' to 1,684'. POOH from 1,684' to 660'. SLM OOH (no correction). Fill Act=49 Calc=38. R/B HWDP and jars. UD 1 jt. NMFDCs. Held PJSM. Removed MWD source. P/U 1 jt. NMFDC, R/B 1 std NMFDC. Downloaded MWD. UD nuclear string w/ DGR, PWD, TM collar M/U BHA #3. Oriented, P/U DGR, PWD, nuclear string, TM collar. Uploaded MWD. P/U 1 std. NMFDCs, UD 1 jt. NMFDCs. SHT MWD w/ 119 spm, 830 psi. Held PJSM. Loaded source fro MWD. P/U 1 jt. NMFDC. TIH w/ HWDP and jars, 5 stds to 657'. TIH from 657' to 4,777'. Washed and reamed to 4,777' w/ 120 spm, 1600 psi, 90 rpm, TO=6-7K Continue Directional drill 9 7/8" Intermediate from 4,473' to 4,990' MD / 3,615' TVD. ADT =1.73 hrs ART=1.22 AST=0.51 Total Bit HRS=23.65. Total Jar HRS =173.94 PU WT = 135K, SO WT = 75K, ROT WT =92K. TO on/off=6-7K/6-7.5K. Pumps - 615 GPM's -2000 PSI. RPMs = 100-110. WOB = 5-35K. Mud Wt =9.1+ PPG, Visc = 55, ECD = 9.71 PPG, Max gas =108 Units. Observed drilling through concretions from 4772'-4776', 4836'-4841', 4849'-4855'. SPR#1=20stk/220psi,30stk/300psi SPR#2=20spm/240psi,30stk/310psi @ 4,948' MD/ 3,612' TVD 9.1+ MW 8.00 DRILL DRLG INTRM1 i Continue Directional drill 9 7/8" Intermediate from 4,990' to 5,580' MD / 3,696' TVD. ADT =6.95 hrs ART=3.13 AST=2.82 Total Bit HRS=24.15. Total Jar HRS =180.89 PU WT = 135K, SO WT = 75K, ROT WT =92K. TO on/off=7/7K. I Pumps - 636 GPM's -2500 PSI. RPMs = 90. WOB = 15-20K. Mud Wt =9.25+ PPG, Visc = 55, ECD = 9.84 PPG, Max gas =108 Units. Observed drilling through concretions from 5072'-5076'. 08:00 - 09:15 09:15 - 12:00 12:00 - 12:30 SPR#1=30stk/270psi,40stk/350psi ~ ~ I SPR#2=30spml280psi,40stk/360psi @ 5,580' MD/ 3,696' TVD 9.1 MW 1.25 DRILL I CIRC ~ INTRMI I Circ'd a hi-vis weighted sweep + 1 BU @ 636 GPM, 2400 psi. Checked, .flow static. 2.75 DRILL TRIP I INTRM1 j Pumped dry job, blew down TD. POOH from 5,511' to 2,988'. 0.50 DRILL TRIP INTRMI I POOH from 2,988' to 2,053'. Changed over to 5" handling tools. Checked flow, static. Printed: 4/7L2UUti 1'.OJ:Z7 rm • • ConocoPhillips Alaska Page 6 of 19 Operations Summary Report Legal Well Name: 1 J-159 Common Well Name: 1J-159 Spud Date: 2/12/2006 Event Name: ROT -DRILLING Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To Phase Description of Operations Hours Code . Code 2/19/2006 12:30 - 13:00 0.50 DRILL TRIP INTRM1 UD 5" DP (45 jts) to 663'. 13:00 - 13:45 0.75 DRILL PULD INTRM1 UD 5 stds HWDP and jars. 13:45 - 14:30 0.75 DRILL PULD INTRMI UD 1 NMFDC. Held PJSM on nuclear sources. UD 2 NMFDCs. 14:30 - 15:00 0.50 DRILL PULD INTRM1 Downloaded MWD. 15:00 - 16:00 1.00 DRILL PULD INTRM1 UD TM, nuclear string w/ DGR, PWD, DM, stab, F/S, motor, and bit. 16:00 - 16:30 0.50 DRILL OTHR INTRMI Cleared and cleaned rig floor. 16:30 - 17:30 1.00 CASE RURD INTRMI R/U to run 7 5/8" casing. 17:30 - 21:15 3.75 CASE RUNC INTRMI Held PJSM. Ran 7 5/8" casing to 2319'. 21:15 - 21:45 0.50 CASE CIRC INTRM1 Circ'd pipe volume @ 3.5 BPM, 350 psi. Staged up as follows: 4.5 BPM, 300 psi; 5.5 BPM, 350 psi; 6.5 BPM, 400 psi. 21:45 - 00:00 2.25 CASE ~ RUNC INTRM1 Cont'd running 7 5/8" casing to 4,312'. 2/20/2006 00:00 - 00:30 0.50 CASE RUNC INTRMI Cont'd to run casing from 4,312' to 5,567'. PUW=190K SOW=90K 00:30 - 01:45 1.25 CASE CIRC INTRMI Circ'd w/ Franks tool staging up to 5 BPM, 450 psi. 01:45 - 02:15 0.50 CASE RURD INTRMI R/D Franks fill up tool, blew down TD. R/U cement head. 02:15 - 04:00 1.75 CEMEN~CIRC INTRM1 Circ'd and cond mud for cement job @ 7 BPM, 450 psi. 04:00 - 06:15 2.25 CEMENT PUMP INTRMI Pumped cement as follows: Fill both Mud pumps & lines with MOBM. Turn Rig over to Dowell lines. Dowell pumped 10 bbls CW 100 at 8.3 ppg at rate of 4.7 bpm @ 168 psi, Pressure tested lines to 4,000 psi, Then pumped 40 add. bbls of CW 100 at rate of 5.0 bpm @ 255 psi. Dropped btm plug then pumped 50 bbls of MudPush at 11.0 ppg at rate of 5.0 bpm @ 420 psi, then pumped 142 bbls, (351sxs - 25% over ~ caliper) of DeepCrete cmt at 12.5 ppg, 2.25 yield with additives, avg 4.9 bpm at 750 psi, Reciprocated pipe with full returns 15' to 20'. Drop top plug and Dowell kicked top plug out with 10 bbls fresh water, @5 BPM 200 PSI. Rig displaced cement with 9.0 ppg OBM, Bumped plug after pumping 244 bbls MOBM (96% pump eff.) 2416 Strokes, avg 6.5 bpm while displacing cmt, Observed lift pressure as cement turned corner. Slowed pump rate to 3 bpm, @ 830 psi prior to bumping. Bumped plug to 1270 psi, ck floats and held. CIP at 0615 hrs, 2-20-2006. Reciprocated pipe 10' to 20' until Mud PUSH at shoe, then recip. 10' ~ until Cmt at shoe, then recip. 10' until 2000 stks looked a little ratty. Landed csg with Shoe @ 5575', Float Collar @ 5486', Calc TOC @ 2226, Had full returns thru out job. Well static after shut down. 5575'. RU and suck out MOBM from inside of 7 5/8" ioint to below well ~ head level. Nipple down BOP stack, and raise for installation of emergency slips. 07:15 - 09:30 2.25 CASE OTHR INTRM1 Set slips with 75K overpull on casing. R/U WACHS pneumatic cutter and cut casing as per Vetco Gray reps. PULD cut off joint. # 129 Cut off length = 36.02'. 06:15 - 07:15 1.00 CEMENTOTHR INTRMI Checked floats, R/D cement head. and blow down all lines. Shoe @ 09:30 - 10:30 ' 1.00 WELCT ~ BOPE ~ INTRMI N/U BOPE and wellhead. 10:30 - 11:00 I 0.50 WELCT BOPE INTRM1 Installed test plug and performed body test on $OPs 250 / 3000 psi for 5 min each. " 11:00 - 12:00 1.00 DRILL ~ LOT INTRM1 ~ annulus. Broke down w/ 7.7 Inject 30 bbls H2O into the 10 7/8" X 7 5/8 I bbls and 860 psi. Final circ press. 710 psi. UD casing tools and i cleared rig floor 12:00 - 13:00 1.00 DRILL ~ RIRD INTRMI ~ Installed bails and 4" elevators. Flushed gas buster w/ H2O also if ld h k fl h d ~ 13:00 - 13:30 j 0.50 DRILL OTHR i INTRMI j . o e man o us e c Installed wear bushing and sim-oped by C/O 6" liners to 5.5" in mud Printed: 4/12/2006 1:53:21 PM • • ConocoPhillips Alaska Page 7 of ~~ Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code 2/20/2006 13:00 - 13:30 0.50 DRILL 13:30 - 14:15 0.75 DRILL 14:15 - 16:30 2.25 DRILL 16:30 - 18:00 1.50 DRILL 18:00 - 19:00 1.00 DRILL 19:00 - 21:30 2.50 DRILL 21:30 - 22:00 0.50 DRILL 22:00 - 23:30 1.50 RIGMNT 23:30 - 00:00 0.50 DRILL 2/21/2006 00:00 - 01:00 ~ 1.00 DRILL 01:00 - 02:00 1.00 DRILL 02:00 - 03:00 1.00 DRILL Sub Phase Code OTHR INTRM1 OTHR INTRM1 PULD INTRMI PULD INTRM1 PULD INTRM1 PULD INTRM1 OTHR INTRMI RSRV i INTRM1 PULD INTRM1 PULD INTRM1 Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number: Description of Operations pumps. Cleaned pits. Loaded pipeshed w/ BHA and DP. P/U 30 stds 4" DP w/ super-sliders. POOH w/ 30 stds 4" DP w/super-sliders and R/B. P/U 7 stds 4" HWDP, POOH and R/B same. P/U 10 stds hybrid DP and R/B same. Cleared and cleaned rig floor. Slipped and cut 58' drill line. Serviced TD and DWs. Sim-opd by flushing 10 7/8" X 7 5/8" annulus w/ 105 bbls H2O @ 2.5 BPM, 780 psi max, 700 psi FCP. P/U BHA tools to rig floor. M/U BHA from bit to TM HOC as follows: Bit, 5" Sperry Drill 6/7 6.0 Stg., Non Mag Float Sub, Non Mag String Stabilizer, 4 3/4" DM Hang Off Collar, 4 3/4" Slimphase 4 w/Gamma/Res, 4 3/4" PWD Collar, 4 3/4" TM Hang Off Collar. PULD INTRM1 Uploaded MWD. PULD INTRM1 P/U NMFDCs, HWDP, jars. Pulse tested MWD, blew down TD. 03:00 - 06:00 I 3.001 DRILL I TRIP I INTRM1 06:00 - 06:30 0.50 DRILL CIRC INTRM1 06:30 - 08:00 1.50 CASE MIT INTRM1 08:00 - 09:30 1.50 CEMENT DSHO INTRM1 09:30 - 10:30 1.00 CEMEN CIRC INTRM1 10:30 - 11:00 0.50 CEMEN LOT INTRM1 11:00 - 12:00 1.00 DRILL DRLH PROD 12:00 - 14:00 2.00 DRILL 14:00 - 19:30 I 5.501 DRILL 19:30 - 00:00 I 4.501 DRILL DRLH PROD !DRLH I PROD Singled in 39 jts 4" DP. P/U XO, Andergauge agitator, shock sub, XO (BHA length 1595') . P/U 12 jts 4" DP. Continued to RIH from 1,969' to 5,585'.. Tagged float equip. Circa 1 BU @ 82 spm, 3200 psi. R/U and tested 7 5/8" casing to 3000 psi for 30 mins. Good test, R/D. Drilled out FC, shoe track, and shoe + 25' of new hole to 5,605' MD w/ 277 gpm, 3400 psi, 100 rpm. PUW=105K SOW=75K ROT=90K. Circa and cond. mud for LOT @ 277 gpm, 3400 psi. RIU and performed LOT to 14.3 psi @ 5,605' MD / 3,695'. R/D equip. Drilled from 5,605' to 5,609' MD / 3,698' TVD. ADT=0.42 AST=0.42 TOon/off=3K ECD=9.81 Jar hrs=0.42 Drilled from 5,609 to 5,810' MD / 3,694' TVD: Exi#ed toy ~-f formation. ADT=1.71 AST=0.64 ART=1.07 Jar hrs=2.31 PUW=105K SOW=70K ROT=85K RPM=90 WOB=3-5K Pump #2=77 spm, 2500 psi. Pulled back to 5,613' MD. Low-sided and drilled from 5,613' to 5,810'. DRLH PROD Drilled from 5,810 to 6,170' MD / 3,689' TVD. AST=3.20 ART=3.05 (Times from 1400 hrs) Total Jar and Bit hrs=8.38 PUW=105K SOW=70K ROT=85K RPM=80-100 WOB=3-10K Pump #1=78 spm, 2600 psi. ECD=10.19 Max Gas= 88 Concretions depths: 5655'-5660', 5696'-5701', 5709'-5710', 5767'-5769', 5795'-5800', 5803'-5810', 5824'-5826', 5852'-5854', 5868'-5870', ~ 5880'-5882', 5890'-5893', 5954'-595T, 5981'-5992',.6004'-6006', ~ 6010'-6018', 6079'-6082' i ~SPR#1=20stk/410psi, 30stk/620psi SPR#=20stk/440psi, 30stk/650psi @ 5,797' MD / 3,676' TVD 8.7 MW. KREVs for tour-10521 2/22/2006. ' 00:00 - 12:00 12.001 DRILL ,DRLH ;PROD ;Drilled from 6,170' to 7,275' MD / 3,652' TVD. Printed: 4/12/2006 1:53:21 PM. • • ConocoPhillips Alaska Page 8 of 19 Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Spud Date: 2/12/2006 Event Name: ROT -DRILLING Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase Description of Operations 2!22!2006 00:00 - 12:00 12.00 DRILL ~ DRLH .PROD ADT=6.23 AST=2.49 ART=3.74 Total Jar and Bit hrs=15.68 ~ PUW=120K SOW=75K ROT=90K RPM=100 WOB=3-5K TOon/off=5K ~ Pump #1=88 spm, 3200 psi. ECD=10.46 Max Gas= 88 SPR#1=20stk/430psi, 30stk/630psi SPR#2=20stk/440psi, 30stk/640psi @ 7,093' MD / 3,659' TVD 8.7+ MW. 12:00 - 17:15 5.25 DRILL I DRLH PROD Drilled from 7,275' to 7,857' MD / 3,642' TVD. Pumped a weighted hi-vis sweep of 35 bbls @ 7,760' and observed a 35% increase in cuttings. ADT=3.65 AST=3.20 ART=0.45 Total Jar and Bit hrs=19.33 PUW=133K SOW=84K ROT=102K RPM=95-110 WOB=3-12K TOon/off=5K/5.5K Pump #1=92 spm, 3825 psi. ECD=10.68 Max Gas=53 KREVs=23400 Concretion depths: 7474-7481', 7520-7541', 7557-7571', 7580-7595', 7600-7609'. 17:15 - 17:30 0.25 DRILL OBSV PROD Garnered SPRs. Checked flow, static. SPR#1=20stk/440psi, 30stk/660psi SPR#2=20stk/460psi, 30stk/670psi @ 7,857' MD / 3,642' TVD 8.7+ MW. 17:30 - 21:00 3.50 DRILL WIPR PROD BROOH from 7,857' to 5,570' w/ 78 spm, 3000 psi, 100 rpm, TO=5K. 21:00 - 21:30 0.50 DRILL CIRC PROD CBU @ work pipe from 5,570° to 5,519' w/ 100 rpm, TO=4K PUW=100K SOW=75K 21:30 - 21:45 0.25 DRILL OBSV PROD Checked flow, static. 21:45 - 23:00 1.25 DRILL WIPR PROD TIH from 5,519' to 7,857. 23:00 - 00:00 1.00 DRILL CIRC PROD Clrc'd hole clean @ 7,857 w/ 92 spm, 3800 psi, TO=5K 2/23/2006 00:00 - 00:30 0.50 DRILL CIRC PROD Circ'd @ 925 spm, 3800 psi. PUW=124K SOW=80K ROT=98K TOoff=5K ECD=10.54 00:30 - 01:15 0:75 DRILL CIRC PROD ~ Displaced well to SFOBM w/ 92 spm, 3800 psi: PUW=144K SOW=87K ROT=105K ECD=10.28 01:15 - 01:30 0.25 DRILL OBSV PROD Garnered SPRs. Blew down TD. Checked flow, static. 01:30 - 05:15 3.75 DRILL TRIP PROD UD 2 jts. POOH from 7,857' to 94'. UD XO, shock sub, Andergauge agitator, and XO. 05:15 - 06:00 0.75 DRILL ~ PULD PROD Downloaded MWD data. 06:00 - 06:30 0.50 DRILL PULD PROD Cont'd to UD BHA including: TM HOC, slimphase 4 w/ DGR and EWR, DM HOC, stab, float sub, motor and bit. 06:30 - 07:00 0.50 DRILL OTHR CMPLTN Cleaned and cleared rig floor. 07:00 - 08:00 1.00 CASE RURD CMPLTN i R/U to run 4.5" liner. Held PJSM. 08:00 - 10:45 2.75 CASE RUNC ~ CMPLTN j RIH w/ 4.5" liner as per detail to 3124'. Ran a total of 41 jts of blank pipe (1265.73') and 59 jts. of slotted pipe (1842.08'). 10:45 - 12:00 1.25 CASE RUNC CMPLTN ~ P/U and M/U seal bore, flexlock liner hanger, RS packoff seal nipple, HRD ZXP liner top packer, and liner running tool to 3,189'. 12:00 - 15:00 3.001 CASE RUNL ~ CMPLTN i TIH w/ liner on DP to 7,857. Pulled up to 7,842'. Checked TO on I supersliders while RIH. PUW=135K SOW=81 K 15:00 - 16:15 1.25 CASE ~ DEQT CMPLTN ~ Drop 1 1/2" ball, Position liner w/shoe @ 7,842.07 & top of liner @ I i 4,666.13', Circ ball down w/ 35 spm and 400 psi. Pressure up to 2500 rnncea: 4i~iuw~o ros:u rm • • ConocoPhillips Alaska Page 9 of 19 Operations Summary Report ~~.~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 J-159 1 J-159 ROT -DRILLING n1334@ppco.com Doyon 141 Date From - To Hours Code Code Phase 2/23/2006. ~ 15:00 - 16:15 ~ 1.25 ~ CASE ~ DEOT j CMPLTN 16:15 - 16:45 0.50 DRILL CIRC CMPLTN 16:45 - 19:00 2.25 DRILL TRIP CMPLTN 19:00 - 19:15 0.25 DRILL PULD CMPLTN 19:15 - 19:45 0.50 DRILL OTHR :CMPLTN 19:45 - 22:00 , 2.25 DRILL PULD PROD2 Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number: Description of Operations PSI to set hanger. Set down 55K to set slips as per BOT rep, continue pressure up to 4200 PSI, to complete setting PKR. Bleed pressure, Rig up and pressure test down annulus to test PKR at 1000 PSI - 5 Minutes. P/U w/ 125K and pulled up 8'. RIH and tagged top of liner @ 4666.13'. Pulled up to 4,595'. Circa 1 BU w/ 80 spm, 1275 psi. Checked flow, static. POOH from 4,595' to 56'. UD running tool Cleaned and cleared rig floor. P/U whipstock BHA as follows:Liner Seals, Locator Sub, Uploader Sub, 3 1/2" HWDP, Blanking Crossover Sub, Bottom Trip Anchor, Shear Disconnect Sub, Drain Sub, Debris Sub, Removable Whipstock, Window Mill,+Lower Mill+Upper Mill, HWDP, Non-Mag Float Sub w/ Spacer, 4 3/4" DM .HOC, 4 3/4" Slimphase 4 w/ DGR & Res, 4 3/4" PWD, 4 3/4" TM HOC 22:00 - 22:45 0.75 DRILL PULD PROD2 Uploaded MWD. 22:45 - 23:00 0.25 DRILL PULD ~ PROD2 P/U and M/U Lub Bumper Sub, Crossover Sub, Hybrid Drill Collars. 23:00 - 00:00 1.00 DRILL TRIP ~ PROD2 RIH from 392' to 1,792' MD. 00:00 - 01:30 1.50 WINDOV~ ITRIP PROD2 01:30 -.02:30 1.00 WINDOV~ fOTHR PROD2 02:30 - 03:00 0.50 WINDOW TRIP PROD2 03:00 - 03:30 0.50 WIND0IN SETW PROD2 03:30 - 04:15 0.751 WIND0INCIRC j PROD2 04:15 - 09:15 I 5.001 WINDOWSTWP I PROD2 09:15 - 10:00 0.751 WINDOVV/STWP I PROD2 10:00 - 10:15 0.251 WINDOWOTHR ; PROD2 10:15 - 12:00 1.75 WINDOV~/T'RIP ' PROD2 12:00 - 12:30 0.50 WINDOWTRIP PROD2 12:30 - 13:45 1.25 WINDOWPULD I PROD2 13:45 - 15:30 I 1.751 DRILL i OTHR I PROD2 15:30 - 16:15 0.75 DRILL OTHR ~ PROD2 16:15 - 17:15 1.00 DRILL ~ PULD ; PROD2 17:15 - 18:15 1.00 DRILL ~ PULD ~ PROD2 18:15 - 18:45 I, 0.50 DRILL 1 PULD PROD2 Tour Note: Freeze protected 10 3/4" X 7 5/8" annulus w/ 85 bbls diesel ICP=1500 psi FCP= 1500 psi @ 1.4 bpm Cont'd to RIH form 1,792' to 3,843' MD. Filled pipe @ 2,559', 3,843'. Made MAD pass from 3,900' to 4,024' MD. Correlation within 1'. Cont'd to RIH from 4,024' to 4,659' MD. Established PUW=120K and SOW=90K prior to setting trip anchor. Orient whipstock @ 11 deg left of high-side and set trip anchor after tagging A Lat ZXP as expected @ 4,666'. Pulled up to 130K to verify trip anchor st. Sheared off bolt w/ 60K downweight. Mill @ 4,565' MD=Top of B Lat window. Held PJSM and displaced well to MOBM @ 70 spm, 1500 psi. Milled window from 4,565' to 4,577'. Milled 20' of gauge hole to total depth of 4,606'. PUW=112K SOW=92K ROT=95K TOonloff=6-7Kl3.5K Pumped 30 bbl weighted hi-vis sweep (observed 50% increase in cuttings) w/ 64 spm, and 100 psi. Rotated through window w/pumps on and 100 rpm. Repeated sliding. PUW=120K SOW=90K Garnered SPR. Flow checked well, static. Pumped dry job. SPR#1=25stks/350psi, 35stks/550psi SPR#2=25stks/370psi, 35stks/530psi @ 4,606' MD/ 3,557' TVD POOH from 4,606' to 1,224' MD. Checked sliders on the way OOH. Cont'd POOH from 1,224' to 290'. UD XO, downloaded MWD. UD MWD, NM FS, 1 jt 3.5" HWDP, upper and lower window mills. Upper mill in gauge. Cleaned and cleared rig floor. Pulled wear bushing, flushed stack, set wear bushing. P/U 2 stds hybrid DP and 2 stds HWDP. Racked back in derrick. M/U BHA #6 as follows: Security PDC bit, Geo-pilot, flexcollar, DM, smart sub, slimpahse 4 w/ DGR and EWR, PWD, TM, NM FS, stab. Uploaded MWD. Cont'd to MU BHA w/ NMFDCs, 2 stds HWDP and jars. SHT MWD w/ 84 spm, 298 gpm, 1350 psi. Printed: 4/12/2006 1:53:21 PM ~ • ConocoPhillips Alaska Page 10 of 19 Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name:. n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 2/24/2006 18:45 - 20:00 ~ 1.25 (DRILL TRIP PROD2 20:00 - 21:00 1.00 21:00 - 21:30 0.50 21:30 - 21:45 l 0.25 21:45 - 22:15 0.50 22:15 - 23:15 1.00 23:15 - 00:00 ~ 0.75 12/25/2006 100:00 - 09:00 9.00 09:00 - 09:30 0.50 09:30 - 10:00 0.50 10:00 - 12:00 2.00 12:00 - 12:45 0.75 12:45 - 13:00 0.25 13:00 - 13:45 0.75 13:45 - 14:15 0.50 14:15 - 15:00 0.75 15:00 - 15:30 0.50 15:30 - 17:00 1.50 17:00 - 18:00 ~ 1.00 18:00 - 19:00 ~ 1.00 19:00 - 19:15 I 0.25 19:15 - 19:45 0.50 19:45 - 20:15 ~ 0.50 20:15 - 20:45 ~ 0.50 Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number: Description of Operations P/U 6 stds DP. TIH to 4,375' MD. RIGMNT RSRV PROD2 Cut and slipped drill line (38'). RIGMNT RSRV PROD2 Serviced TD and inspected saver sub. DRILL TRIP PROD2 Established PUW=95K SOW=76K ROT=85K TO=3.5K w/ 70 spm and 1500 psi. Went through window to 4585' w/ no problems. Reamed to 4,606'. DRILL DRLH PROD2 Drilled from 4,606' to 4,620' MD. DRILL DRLH PROD2 Geo-Pilot not holding toolface. Troubleshot Geo-pilot. Pulled into casing and reset manually. Run back through window to bottom. DRILL DRLH PROD2 Drilled from 4,620' to 4,624' MD / 3,559' TVD. ADT=0.52 PUW=95K SOW=76K ROT=85K TOonloff=4.5K/3.5K Total bit hrs=0.52 Total jar hrs=19.90 DRILL DRLH PROD2 Drilled from 4,624' to 4,987 MD / 3,550' TVD. ADT=6.81 PUW=105K SOW=70K ROT=84K TOon/off=4K/4K ECD=9.61 Mas Gas=51 Total bit hrs=7.33 Total jar hrs=26.71 SPR#1=25stks/280psi, 30stks/430psi SPR#2=25stks/300psi, 30stks/440psi @ 4,966' MD/ 3,551' TVD 8.8 MW DRILL CIRC PROD2 Stop drilling for geology. OuYtop of formation. DRILL CIRC PROD2 CBU @ 91 spm, 2150 psi, ROT=100 TOoff=3K. Geo-Pilot failed. ABI failed which determines highside for toolface referencing. DRILL TRIP PROD2 Checked flow, static. POOH from 4,987' to 4,553' w/ hole taking proper fill. Pumped dry job. Cont'd to POOH to 2,883'. POW=105K SOW=70K DRILL TRIP PROD2 ~ Cont'd to POOH from 2,883' to 91'. VD BHA including: NMFDCs, 2 stds HWDP and jars. DRILL PULD PROD2 Downloaded MWD tool DRILL PULD PROD2 Cont'd to UD BHA including: stab, NM FS, TM, PWD, slimphase 4 w/ DGR and EWR, smart sub, DM, flex collar, geo-pilot, and Security PDC, bit DRILL PULD PROD2 M/U BHA #7 including: Reed Hycalog Bit, 5" Sperry Drill 6/7 6.0 Stg, Non Mag Float Sub, 4 3!4" DM Hang Off Collar, 4 3/4" slimphase 4 w/Gamma/Res, 4 3/4" PWD Collar, 4 3/4" TM Hang Off Collar. DRILL PULD PROD2 Uploaded MWD. DRILL PULD PROD2 P/U 1std NMFDCs, 2jts HWDPw/jars. DRILL TRIP PROD2 TIH inserting Andergauge Agitator and XOs @ 2,598'. TIH from 356' to 4,530' MD. PUW=95K SOW=75K DRILL TRIP PROD2 Oriented to the highside and slid through window w/ 86 spm, 3100 psi. Good pulse on MWD, slid through no problems to 4,675'. Attempted to get good pulse test MWD, no luck. Agitator interfering w/ signal @ this DRILL ~ TRIP PROD2 ~ depth. POOH to 2,524'. UD 2 XOs and Andergauge Agitator w/ shock sub. DRILL ~ DEOT PROD2 Tested MWD w/ 76 spm, 1600 psi. All tests successful DRILL TRIP ~ PROD2 TIH from 2,524' to 4,553'. DRILL TRIP ~ PROD2 ~ Oriented to the highside and slid through windoww! 77 spm, 1900 psi. Good pulse on MWD, slid through no problems to 4,680'. DRILL DRLH PROD2 Drill trough for low-side sidetrack from 4,680' to 4,687. i rnncea: ynu~~~o ~:oo:c i nvi • • ConocoPhillips Alaska Page 11 of 19 Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159. Event Name: ROT - .DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Code 2!25/2006 20:45 - 22:00 1.25 1 DRILL ~ DRLH 22:00 - 00:00 2.00 I DRILL ~ DRLH , Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number: Phase Description of Operations PROD2 Time drilled for low-side sidetrack from 4,687' to 4,710'. PROD2 Drilled from 4,710' to 4,839' MD / 3,555` TVD. ADT=2.17 AST=1.93 ART=0.24 PUW=104K SOW=74K ROT=85K TQon/off=4.5K/5K ECD=9.64 Mas Gas=50 Total bit hrs=2.17 Total jar hrs=28.88 I SPR#1=20stks/280psi, 30stks/440psi SPR#2=20stks/300psi, 30stks/450psi @ 4,839' MD/ 3,555' TVD 8.7+ MW 2/26/2006 ' 00:00 - 01:30 .1.50 DRILL I DRLH PROD2 Drilled from 4,839' to 4,987 MD. Back to measured depth before sidetrack operations began. ADT=0.88 AST=0.62 ART=0.22 A1:30 - 12:00 10.501 DRILL DRLH ~ PROD2 12:00 - 00:00 I 12.001 DRILL !DRLH I PROD2 Drilled from 4,98T to 5;503' MD ! 3,551' TVD. ADT=8.06 AST=2.89 ART=5.17 PUW=104K SOW=70K ROT=82K TQon/off=4K/5K ECD=9.77 Mas Gas=76 Total bit hrs=11.11 Total jar hrs=37.82 Concretion Depths: 4977-4987', 5026-5037', 5045-5056', 5064-5090', 5120-5126', 5144-5148', 5168-5181', 5188-5200', 5203-5204', 5212-5230', 5248-5249',5288-5290', 5306-5320', 5327-5351', 5389-5393', 5400-5401', 5405-5412',5481-5488', 5494-5504'. SPR#1=20stks/280psi, 30stks/440psi SPR#2=20stks/300psi, 30stks/450psi @ 4,839' MD/ 3,555' ND 8.7+ Drilled from 5,503' to 6,508' MD / 3,529' TVD. ADT=8.86 AST=2.57 ART=6.29 PUW=105K SOW=68K ROT=82K TQon/off=5K/5.5K ECD=10.02 Mas Gas=123 Total bit hrs=19.97 Total jar hrs=46.68 Concretion Depths: 5551-5565', 5570-5584', 5587-5589', 5600-5605', 5611-5619', 5754-5760', 5803-5818', 5850-5852', 5983-5995', 6065-6075', 6097-6110', 6113-6115', 6141-6143', 6169-6173', 6268-6284', 6318-6323', 6334-6336', 6350-6353'. SPR#1=20stks/310psi, 30stks/480psi SPR#2=20stks/330psi, 30stks/490psi @ 5,886' MD/ 3,554' TVD 8.7+ 2/27/2006 .100:00 - 0330 3.501 DRILL DRLH PROD2 Drilled from 6,508' to 6,832' MD /.3,520' TVD. ADT=1.86 AST=0.71 ART=1.15 PUW=108K SOW=64 ROT=81 K TQon/off=5K/5K ECD=10.02 Mas Gas=123 03:30 - 04:15 0.75 DRILL ~ REAM PROD2 After looking at logs went out of zone @ 6,740' MD/ 3,526' ND per geos. BROOH from 6,832' to 6,282' MD w/ 88 spm, 310 gpm, 2600 psi, 100 rpm. ~ PUW=108K SOW=64K 04:15 - 05:15 1.00 DRILL DRLH PROD2 Cut trough for sidetrack w/ 88 spm, 310 gpm, 2500 psi. 05:15 - 06:45 1.50 DRILL DRLH PROD2 Time drilled from 6,289' to sidetrack point @ 6,294' MD / 3,541' TVD. 06:45 - 12:00 5.25 DRILL I DRLH ~ PROD2 Drilled from 6,294' to 6,714' MD / 3,540' TVD. ADT=4.78 AST=2.43 ART=2.35 I ' ~ PUW=110K SOW=65K ROT=82K TQon/off=5K/5K ECD=10.25 Mas Gas=84 ~J-1.5~,4~i~~~. ~ ~~`~- ~~s~~- Printed: 4/12/2006 1:53:21 PM • • ConocoPhillips Alaska Page 12 of 19 Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 12/27/2006 106:45 - 12:00 5.251 DRILL DRLH PROD2 12:00 - 12:30 0.50 I DRILL I DRLH I PROD2 12:30 - 00:00 I 11.501 DRILL I DRLH I PROD2 12/28/2006 100:00 - 01:30 01:30 - 01:45 01:45 - 09:00 09:00 - 10:15 10:15 - 12:00 1.501 DRILL DRLH PROD2 0.25 DRILL CIRC PROD2 7.25 DRILL DRLH PROD2 1.251 DRILL I TRIP I PROD2 1.751 DRILL j DRLH PROD2 12:00 - 00:00 12.00 DRILL i DRLH PROD2 3/1/2006 ~ 00:00 - 12:00 12.00 j DRILL ~ DRLH ~ PROD2 12:00 - 17:00 I 5.001 DRILL I DRLH I PROD2 17:00 - 18:00 j 1.001 DRILL ,CIRC PROD2 Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number: Description of Operations I Total bit hrs=26.61 Total jarhrs=53.32 Concretion Depths: 6318-6321', 6334-6336',.6350-6353', 6396-6398', 6489-6492', 6521-6523' SPR#1=20stks/390psi, 30stks/560psi SPR#2=20stks/410psi, 30stks/580psi @ 6,707' MD/ 3,538' ND 8.7+ Drilled from 6,714' to 6,832' MD / 3,536' TVD. ADT=0.73 AST=0.26 ART=0.47 PUW=106K SOW=65K ROT=81 K TOonloff=5K/5.5K Drilled from 6,832' to 7,843' MD ! 3,510' ND. ADT=6.37 AST=0.25 ART=6.12 PUW=105K SOW=62K ROT=81 K TOon/off=5K/5-6K ECD=10.44 Mas Gas=88 Total bit hrs=33.71 Total jar hrs=55.76 Concretion Depths: 7082-7092', 7248-7269', 7716-7721', 7731-7738', 7834-7844' SPR#1=20stks/400psi, 30stks/570psi i SPR#2=20stks/420psi, 30stks/590psi @ 7735' MD/ 3,514' TVD 8.7+ KREVs=8008 Drilled f/ 7843' to 8049' (206') / 3513' TVD, ART= 1.13 hrs, AST= 0.11 hrs, ADT= 1.24 hrs,. Up 110K, Dn 65K, Rot 81 K, Torque On/Off 5K/6K, Concretions @ 7834' to 7844'. Circ for geologist. Drilled f/ 8049' to 8473' (424') / 3519' TVD, ART= 2.4 hrs, AST= 1.94 hrs, ADT= 4.34 hrs, Up 120K, Dn 65K, Rot 85K, Torque On/Off 6K/6K, Concretions @ 8250' to 8258', 8405' to 8410', Ave ECD's 10.7 ppg, Max gas 54 units. POOH w/ 3 stands Hybrid pushPipe to 8204', Pick up & test Andergauge Agitator & shock sub for pressure increase, Had 600 psi @ 250 gpm & 700 psi @ 300 gpm (good test), RIH w/ 3 stands HWDP to 8473'. Drilled f/ 8473' to 8610' (137') / 3523' TVD, ART= 0.52 hrs, AST= 0.17 hrs, ADT= 0.69 hrs, Up 115K, Dn 65K, Rot 84K, Torque On/Off 5K/5K, Ave ECD's 10.7 ppg, Max gas 54 units. Drilled f/ 8610' to 9512' (902') / 3504' TVD, ART= 6.47 hrs, AST= 1.78 hrs, ADT= 8.25 hrs, Up 129K, Dn 75K, Rot 98K, Torque On/Off 7K/6.5K, Ave ECD's 10.8 ppg, Max gas 50 units, Concretions= 8610'-8612', 8622'-8627', 8654'-8664', 8668'-8674', 8680'-8690', 8695'-8700', 8710'-8739', 8745'-8755', 8808'-8809', 8813'-8815', 9009'-9017', 9205'-9212'. Drilled f/ 9,512' to 10,712' (1200') / 3500' TVD, ART= 6.04 hrs, AST= 1.00 hrs, ADT= 7.04 hrs, Up 151 K, Dn 70K, Rot 104K, Torque On/Off 8K/9K, Ave ECD's 11.3 ppg, Max gas 58 units, Concretions= 9553'-9560', 9891'-9899', 9913'-9914', 9945'-9947', 10190'-10198', 10202'-10213', 10230'-10240', 10390'-10397', 10401'-10415', 10424'-10434',10439'-10440', 10488'-10493'. Drilled f/ 10,712' to 11,187' T.D. (475') / 3506' TVD, ART= 2.19 hrs, AST= 1.52 hrs, ADT= 3.71 hrs, WOB 4-12K, 312 gpm @ 3850 psi, Up 158K, Dn 67K, Rot 102K, Torque On/Off 8.5K/8.5K, Ave ECD's 11.22 ppg, Max gas 56 units, Pump Hi-vis sweep on last stand. K-Rev's 51799. Finish pumping Hi-vis weighted sweep out of hole at rate of 312 gpm @ 3900 psi -Had 10% increase of cuttings, ECD's 11.3 ppg, Monitor well - Static. Nrintea: anzizoue i:5s:li rnn i • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 J-159 1 J-159 ROT -DRILLING n1334@ppco.com Doyon 141 Date From - To Hours Code Sub Phase Code 3/1!2006 13/2/2006 18:00 - 00:00 I 6.001 DRILL i WIPR I PROD2 00:00 - 02:45 2.751 DRILL WIPR ~, PROD2 02:45 - 04:00 1.25 DRILL •CIRC PROD2 04:00 - 06:15 2.25 WELCT BOPE PROD2 06:15 - 11:00 4.75 WELCT BOPE PROD2 11:00 - 12:45 I 1.751 WELCTLI BOPE I PROD2 12:45 - 16:15 3.50 DRILL TRIP PROD2 16:15 - 18:45 2.50 DRILL CIRC PROD2 18:45 - 20:00 1.251 DRILL CIRC ~ PROD2 20:00 - 00:00 4.00 DRILL TRIP PROD2 3/3/2006. 00:00 - 02:00 .2.00 DRILL TRIP PROD2 02:00 - 03:00 1.00 DRILL TRIP PROD2 03:00 - 04:00 1.00 DRILL TRIP PROD2 04:00 - 06:45 2 75 WINDOW TRIP CMPLT2 06:45 - 07:15 . 0.50 WINDOW TRIP CMPLT2 07:15 - 08:00 0.75 WINDO ' IRC .CMPLT2 08:00 - 12:30 4.50 CMPLTN CIRC CMPLT2 12:30- 14:30 2.00 CASE RURD CMPLT2 14:30 - 18:15 3.75 CASE PULR CMPLT2 18:15 - 19:30 1.25 CASE ,PULR CMPLT2 19:30 - 21:30 2.00 CASE PULR CMPLT2 21:30 - 22:30 1.00 CASE PULR CMPLT2 22:30 - 00:00 1.50 CASE RUNL CMPLT2 13/4/2006 1010:30 - 02:45 1.25 CMPLTN OTHR i CMPLT2 02:45 - 03:00 I 0.251 CMPLTNI OTHR I CMPLT2 03:00 - 03:45 I 0.75 CMPLTN CIRC I CMPLT2 03:45 - 05:30 ~ 1.75 CMPLTN TRIP ~ CMPLT2 05:30 - 07:45 2.25 CMPLTN PULD ~ CMPLT2 07:45 - 09:30 1.75 ,CMPLTN; PULD ;CMPLT2 Page 13 of 19 Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number: Description of Operations Back ream out of hole at drilling rate 312 gpm @ 3800 to 2850 psi, 90 RPM, 8K Torque, Hole in very good shape but did have mild packing off @8160'&7915'. Back ream out of hole at drilling rate 310 gpm @ 2800 psi, 90 RPM, 6K Torque, Hole in very good shape. Pump 30 bbl Hi-vis weighted sweep, Circ 3 times btm's up at 310 gpm @ 2800 psi, Had 10% Increase in cuttings w/ sweep. Pull 2 stands drill pipe, Pick up Agitator & shock sub- Break down same & crossover subs, Lay same back down, Pick up Baker 7-5/8" Storm packer, RIH & set @ 86' w/ bit @ 4468', Pull wear bushing. Test all BOPE to 250 psi low & 3000 psi high, Good test - No failures, Test all alarms, Test waived by AOGCC Jeff Jones. Set wear bushing, RIH to 86', Release packer, Monitor well -Static, Retrieve & lay down storm packer RIH with no problems to 11,145', Wash to 11,187. Pump 35 bbl Hi-vis weighted sweep, Circ 3 times btm's up at 291 gpm @ 3900 psi, 100 RPM, Torque 8K, Had 10% Increase in cuttings w/ sweep. Change over to 8.7 ppg SFOBM at rate of 295 gpm @ 3850 psi, 100 RPM, Torque 9.5K, Up 165K, Dn 52K, Rot 105K, SPR's, Monitor well. Drop 1-7/8" Rabbit, POOH on elevators with no problem. Monitor well @ 4550', POOH to 82'. Down load MWD tools. Lay down BHA, MWD tools, Motor & Bit. Make up Whipstock retrieving tools, RIH to 4497', Break circ. Hook whipstock on depth @ 4570', Pull same loose w/ 85K over pull, Hole took 10 bbls mud. POOH to 4497, Circ btm's up 220 gpm @ 950 psi, Lost 10 more bbls mud (Total 20 bbls). Monitor well-OK, POOH & Lay down whipstock & tools, Clean rig floor. Rig to run 4-1/2" liner, PJSM w/ all personnel, Bring jewelry & tools to rig floor. Run 4-1/2" liner as per detail & tag crossover on A2 lateral @ 4717'. Pull back to above window @ 4565', Rotate and orient bent joint, RtH & tag A2 lateral liner @ 4717' -Took 4 attempts to work thru window. Continue running 4-1/2" liner (Total 158 jts.) to Hook hanger. Pick up Baker Hook hanger, Sperry-Sun MWD and orient same. RIH w/ 3 stands drill pipe to insure shoe past sidetrack @ 6832', Shallow test MWD -OK, Blow down top drive, Continue RIH to 7267'. Cont RIH with Liner on drillpipe to 11,141'. P/U = 165k, S/O = 70k Orient Hook Hanger & Hook w/ top @ 4560', Pull up and turn 180 degrees, Run past 10', Pull up & Reorient to 1 L, Slack off to 35k on hook, Toolface jumped around to 16 R, Top of hook hanger assembly @ 4560.20' and Shoe @ 11,161.07'. Drop ball and pumped down w/ 3 bpm, 1000 psi. Balf bumped at 415 stks and pressured up to 3000 psi. Released from liner P/U 125K Picked up off bottom and CBU at 4500' with 36 spm, 450 psi. Monitor well: static. POOH. Trip out displacement calc = 36.1 bbls, actual 40.8 bbls. R!U tongs. Break and L/D BHA, slimhole MWD, and Liner running tool. Held PJSM. M/U LEM to 350.5'. Baker seal assembly (3.29'), XO Bent joint 4.5" IBT x STL (43.43'), 4.5" tubing (30.98), Camco D8 nipple (1.49'), 4.5" IBT tubing (31.04'), 4.5" pup (9.84'), LEM assembly Printed: 4/12/2006 1:53:21 PM • • r.~ -~~ ConocoPhllips Alaska Page ~a of ~~ Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1 J-159 Spud Date: 2/12/2006 Event Name: ROT -DRILLING Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 3/4/2006 ~ 07:45 - 09:30 1.75 CMPLTN PULD CMPLT2 (34.83'), 5 jts of 4.5" (153.22'), XO bushing (1.36'), Seal bore receptacle (19.69'), ZXP liner top packer (17.14'). Total tools to stay in hole. 350.5'. 09:30 - 09:45 0.25 CMPLTN RURD CMPLT2 R/D csg equipment. 09:45 - 12:00 2.25 CMPLTN RUNT CMPLT2 RIH with LEM assembly: P/U = 98K, S/O = 80K 12:00 - 13:30 1.50 CMPLTN RUNT CMPLT2 Cont to RIH w/ LEM. Stab into hanger at 4560', P/U 125K, S/O = 95K. Set down with 30K, Pull test LEM to 15K over, Set back down with 30K and picked up to neutral weight. Drop ball and chase with 3 bpm @ 500 psi, 330 stks. Pressure up to 4000 psi. S/O with 30K. Pressure test 2XP to 1000 psi f/ 5 min- OK. P/U with overpull of 5K. Set back down and tagged liner top. Blow down top drive and kill line. 13:30 - 16:30 3.00 CMPLTN PULD CMPLT2 POOH with running tools and UD. 16:30 - 18:30 2.00 WINDO PULD PROD3 Clear and clean rig floor. MU whipstock assembly. 18:30 - 19:15 0.75 WINDO ULD PROD3 Upload MWD. 19:15 - 22:00 2.75 WINDO ULD PROD3 PU XO, 3 stands hybrid DP, and shallow test MWD. RIH to 3878'. 22:00 - 22:30 0.50 WINDOV 'ITRIP PROD3 MAD pass from 3888' to 4006' @ 350' HR. 22:30 - 23:30 1.00 WINDOW SETW PROD3 Cont to RIH to 4355'. Set 22K on Baker trip anchor. PU 10K over and confirm trip anchor release. PU to 42K to shear off of whipstock. PU before 115K & SO 87K. After 107K & SOK. Whipstock set at 17 degree left high side. 23:30 -00:00 0.50 WINDOV ~/CIRC PROD3 Displace well from SFOBM to drilling MOBM. 3/5/2006 00:00 - 00:15 0.25 WINDOW CIRC PROD3 Cont to displace over from SFOBM to MOBM. Pump @ 310 gpm & 2100 psi. 00:15 - 05:00 4.75 WINDOW SCML PROD3 Mill out window from 4246' to 4258'. Drill 5' of gauged hole to 4274'. ~~ ~ SPR @ 4274' / 3488' TVD. pump #1:20 spm= 230psi 30 spm = 310 psi pump #2: 20 spm= 230psi 30 spm = 350 psi 05:00 - 06:00 1.00 WINDOW SCML PROD3 Work mills through window @ 60 rpm, 78 spm, 275 gpm, 1750 psi. Pumped 30 bbl hi vis sweeps @ 4255' & 4274'. Able to slide through window with no pump problems. 06:00 - 07:45 1.75 WINDOW TRIP PROD3 Monitor well: static. Pump dry job. POOH to 96'. Trip out actual fill 38.3 bbls, Calc 32.85 bbls. 07:45 - 09:00 1.25 WINDOW PULD PROD3 LD BHA: XO, Bumper sub, down load MWD. Mill in gauge. Clean Rig floor. PUII wear pushing, flush stack, install wear bushing. 09:00 - 13:30 4.50 DRILL PULD PROD3 PU BHA #9 including: Bit, motor, NMFS, DM HOC, MWD, PWD, TM HOC, Flex DC, HWDP & Jars. Upload MWD. RIH to 2685' and PU agitator. ; 13:30 - 16:00 2.50 DRILL ~ TRIP PROD3 Continue to RIH to 4209'. Fill pipe. PJSM. Cut and slip 65' of drilling line. 16:00 - 17:00 1.00 DRILL TRIP PROD3 Calibrate depth. Inspect Saver sub. Establish circulation and go through window. 17:00 - 20:15 3.25 DRILL i DRLH PROD3 Drilled from 4,24T to 4,486' MD / 3,505' TVD. 20:15 - 21:00 0.75 DRILL ! DRLH PROD3 Trouble getting detection from MWD due to agitator interference. Adjusted pump rate down from 330 gpm to 250 gpm and regained detection. 21:00 - 00:00 3.00 DRILL DRLH PROD3 i Continued to drill from 4486' to 4766' MD / 3506' TVD. ADT=1.38 hrs. AST= 1.38 hrs Jar hrs=90.28 ~ I i ' PUW=100K SOW=74K ROT=82K TOon/off=4/4K ~ Max Gas=46 Units Max ECD=9.64 3/6/2006 ~ 00:00 - 12:00 12.00 ; DRILL DRLH i PROD3 I Drilled from 4,766' to 5,607 MD / 3481' TVD. ADT=6.76 hrs. AST= 1.64 hrs ART= 5.12 hrs Jar hrs=97.04 j ~~ ~ I ; PUW=103K SOW=71 K ROT=82K TOon/off=4/5K Printed: 4/12/2006 1:53:21 PM • • ConocoPhillips Alaska Page 15 of ~g Operations Summary Report Legal Well. Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase Spud Date: 2/12!2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number:. Description of Operations 3/6/2006 j 00:00 - 12:00 I 12.00 j DRILL ;DRLH PROD3 12:00 - 00:00 12.00 j DRILL j DRLH ; PROD3 3/7/2006 100:00 - 12:00 I 12.001 DRILL ;DRLH I PROD3 12:00 - 00:00 12.00 j DRILL !DRLH j PROD3 13/8/2006 100:00 - 12:00 I 12.001 DRILL I DRLH I PROD3 12:00 - 20:15 ! 8.25 DRILL !DRLH PROD3 Max Gas=52 Units Max ECD=10.01 SPR@ 4895'MD / 3502' TVD, #1@ 20spm/370 psi, 30spm/590 psi #2@ 20spm/410 psi, 30spm/620 psi Concretion depths = 4857'-4859', 4867'-4870', 4919'-4925', 4947'-4948', 5013'-5015', 5020'-5024', 5034-5037', 5048'-5050', 5054'-5057', 5081'-5088', 5134'-5160', 5420'-5424', 5447'-5450' Drilled from 5,607' to 7,101' MD / 3461' ND. ADT=10.41 hrs. AST= 2.48 hrs ART= 7.93 hrs Jar hrs=107.45 PUW=11 OK SOW=65K ROT=85K TQon/off = 5-6/5-6K Max Gas=136 Units Max ECD=10.48 SPR@ 6074'MD / 3478' TVD, #1 @ 30spm/670 psi, 40spm/930 psi #2@ 30spm/710 psi, 40spm/970 psi Concretion depths =5607'-5608, 5650'-5651', 5667'-5670', 5700'-5702', 5720'-5722', 5793'-5799', 5900'-5902', 5930'-5931', 6015'-6019', 6566'-6569', 6593'-6597' Drilled from 7,101' to 8,167' MD / 3458' TVD. ADT=8.07 hrs. AST= 1.25 hrs ART= 6.82 hrs Jar hrs=115.52 PUW=122K SOW=54K ROT=80K TQon/off = 5/5K Max Gas=137 Units Max ECD=10.65 SPR@ 7101'MD / 3461' TVD, #1 @ 20spm/480 psi, 30spm710 psi #2@ 20spm/480 psi, 30spm/720 psi Concretion depths =7473'/7476', 7585'/7586', 7727'/7731' Drilled from 8,167' to 9437' MD / 3458' ND. ADT=8.67 hrs. AST= 2.15 hrs ART= 6.52 hrs Jar hrs=124.92 PUW=118K SOW=54K ROT=85K TQon/off = 7/6K Max Gas=107 Units Max ECD=11.34 SPR@ 8502"MD / 3473' TVD, #1@ 30spm/800 psi, 40spm/1080 psi #2@ 30spm/850 psi, 40spm/1140 psi Concretion depths =7800'/7802', 8093'/8101', 8129'/8140', 8596'!8601', 9418/9425" Drilled from 8,167 to 10372' MD / 3455' TVD ADT=8.37 hrs. AST= 1.5 hrs ART= 8.22 hrs Jar hrs=133.29 PUW=130K SOW=55K ROT=85K TQon/off = 8/7K Max Gas=88 Units Max ECD=11.27 SPR@ 10112' MD /3424' ND, #1 @ 20spm/660 psi, 30spm/820 psi #2@ 20spm/640 psi, 30spm/840 psi Concretion depths =9984'/9989', 9993'/9998', 10008'/10012', 10030'/10037`, 10110'/11115', 10120'/10125', 10136'/10138', 10188'/10192', 10249'/10261', 10268'/10285', 10296'/10300', 10304'/10306', 10316'/10319' Drilled from 10372' MD to TD @ 10884' MD / 3424' TVD. ADT=5.42 hrs. AST= 1.66 hrs ART=3.59 hrs Jar hrs=138.71 PUW=140K SOW=60K ROT=103K TQon/off = 8/7K Printed: 4/12/2006 1:53:21 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 J-159 Common WeII Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 3/8/2006 ~ 12:00 - 20:15 ~ 8.25 ~ DRILL ~ DRLH ~ PROD3 20:15 - 00:00 3/9/2006 00:00 - 05:45 05:45 - 06:30 06:30 - 10:30 10:30 - 12:00 12:00 - 13:00 13:00 - 20:15 20:15 - 21:15 21:15 - 22:00 22:00 - 00:00 3/10/2006 00:00 -.00:45 00:45 - 02:15 02:15 - 02:45 02:45 - 03:30 03:30 - 06:15 06:15 - 07:45 07:45 - 08:30 08:30 - 09:30 09:30 - 12:00 i 12:00 - 16:30 I 16:30 - 17:30 17:30 - 20:15 3.75 ~ DRILL ;REAM PROD3 5.751 DRILL I REAM I PROD3 Start: 2/11/2006 Rig Release: 3/13/2006 Rig Number: Page 16 of 19 ~ Spud Date: 2/12/2006 End: 3/13/2006 Group: Description of Operations Units Max ECD=11.23 Concretion depths =10370'/10415', 10424'/10426', 10471'/10474', 10488'/10513', 10715'/10730', 10795'/10805' Circ clear BHA for 10 mins. Pump up survey. BROOH @ 90 rpm, TO 7K, 294-300 gpm, 4000/3500 psi. Cont BROOH from 9159' to 4246' MD. Orinet High side and pull thru window (no problems). PU = 97k, SO = 80k, Rot = 86k, TQ = 4k 0.75 DRILL. CIRC PROD3 Pump 35 BBI weighted High Vis sweep @ 4209'. Circ SS x 1 bottoms up @ 86 spm, 300 gpm, 3100 psi, Rot @ 60 rpm. 4.00 DRILL TRIP PROD3 Orient High side, monitor well, RIH and check condition of 'Super-Sliders' on TIH. RIH to 10,808' MD and Wash and Ream from 10,808' to 10,884' MD. 1.50 DRILL ,CIRC ~ PROD3 Circ Hole Clean @ 10,884' MD. 78 spm, 275 gpm, 3900 psi, 100 rpm, Off Bttm TO = 7k Trip OUT Actual Fill = 80.6 Bbls (46.3 Bbls Calc) Trip IN Actual Gain = 42 Bbls (40.81 Bbl Calc) 1.00 DRILL CIRC PROD3 Displace well to SFOBM @ 80 spm and 3800 psi ... observe well. 7.25 DRILL TRIP PROD3 POOH w/ BHA #9 ... monitor T&D every 5 stands in open hole and I every 10 stands in cased hole. 1.00 DRILL PULD PROD3 LD BHA #9 0.75 DRILL SURV PROD3 Down Load MWD 2.00 DRILL PULD ~ PROD3 Continue LD BHA #9 ... Clean Rig Floor K-Revs = 20,067 0.75 WINDOW PULD CMPLT3 MU BHA - MU retriving hook, 1 jt 3.5" HWDP, float sub, bumper sub, jars, XO, 2 stds Hybrid DCs.(total 261.60") 1.50 WINDOW TRIP CMPLT3 ~ RIH to 4,214" -Break Circu, 4 BPM @ 600 PSI -Wash down to 4,259' - Pull back up to 4,235' -Put 1.5 rounds turn in string - Up wt 125K - Dn wt 97k. 0.50 WINDOW TRIP CMPLT3 i Engage hook slot @ 4,252' -apply 75k over pull -Trip jar and pulled trip anchor free. Pull up to 4,232' MD 0.75 WINDOV~ /CIRC CMPLT3 CBU @ 4,232' - PR 4 BPM, 600 psi 2.75 WINDOV~ ITRIP CMPLT3 Monitor well -Static- POOH to 261' 1.50 WINDOW PULD CMPLT3 PJSM - L/D BHA, Whipstock and Trip Anchor assy 0.75 WINDOW PULD CMPLT3 - Clean rig floor -Remove all tools from rig floor 1.00 CASE ! RURD CMPLT3 P/U csg equip from beaver slide - PU slim hole MWD tools - RU 4.5" i csg tools. 2.50 CASE PULR CMPLT3 ~ RIH w/ 4.5" D Sand Liner - 50 jts (2,200') Trip IN Actual Gain = 34 BBLs (Galt = 32.78 BBLs) Trip OUT Actual Fill = 41 BBLs (Galt = 35.18 BBLs) 4.50 CASE i PULR CMPLT3 ~ RIH w/ 4.5" D Sand Liner to 4,391' MD -Tag up - LD 2 jts of tubing and ! ~ pull to 4,240' and turn pipe -attempt stab @ window3 times with same ~ i procedure then continue RIH w/ Liner 1.00 CASE PULR CMPLT3 ! PU Liner running tool and Slim Hole MWD - MU same and Orient -Rig Down Casing Tools. 2.75 ~ CASE j RUNL CMPLT3 I RIH w/ Liner on DP -Shallow test MWD on first stand -Continue RIH w! Printed: 4/12/2006 1:53:21 PM • • ConocoPhillips Alaska Page 17 of 19 Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Spud Date: 2/12/2006 Event Name: ROT -DRILLING Start: 2/11/2006 End:. 3/13/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 3/10!2006 17:30 - 20:15 I 2.751 CASE ~ RUNL I CMPLT3 DP to 10,785' Liner Depth 20:15 - 21:30 1.251 CASE RUNL CMPLT3 21:30 - 00:00 I 2.50 CMPLTN TRIP 'CMPLT3 3/11/2006 , 00:00 - 01:45 1.75 ~ CMPLTN TRIP CMPLT3 01:45 - 02:15 I 0.50 I CMPLTNI PULD I CMPLT3 02:15 - 03:00 0.75 CMPLTN PULD CMPLT3 03:00 - 03:45 0.75 CMPLTN PULD CMPLT3 03:45 - 05:15 1.50 RIGMNT RSRV CMPLT3 05:15 - 10:30 5.25 CMPLTN PULL CMPLT3 10:30 - 12:00 1.50 CMPLTN PULL CMPLT3 12:00 - 15:15 3.25 CMPLTN PULL CMPLT3 15:15 - 17:30 2.25 CMPLTN RURD CMPLT3 17:30 - 22:30 5.00 I CMPLTNI TRIP I CMPLT3 13/12/2006 22:30 - 00:00 1.50 CMPLTN TRIP CMPLT3 00:00 - 01:00 1.00 CMPLTN TRIP CMPLT3 00:00 - 01:00 1.00 CMPLTN TRIP CMPLT3 01:00 - 01:30 0.50 CMPLTN RURD CMPLT3 01:00 - 01:30 0.50 CMPLTN OTHR CMPLT3 01:30 - 02:00 0.50 CMPLTN RURD CMPLT3 01:30 - 02:00 0.50 CMPLTN PULD CMPLT3 02:00 - 06:30 4.50 CMPLTN RUNT CMPLT3 02:00 - 06:30 I 4.501 CMPLTNI RUNT !CMPLT3 06:30 - 07:00 ' 0.50 CMPLTN SLIN CMPLT3 06:30 - 07:00 0.50 CMPLTN SLIN CMPLT3 07:00 - 10:00 3.00 CMPLTN SLIN CMPLT3 07:00 - 10:00 10:00 - 10:30 10:00 - 10:30 10:30 - 12:00 ~ 3.00 0.50 0.50 1.50 CMPLTN CMPLTN CMPLTN CMPLTNI SLIN ~ SLIN SLIN RUNT I CMPLT3 CMPLT3 CMPLT3 CMPLT3 10:30 - 12:00 I 1.501 CMPLTNI RUNT CMPLT3 12:00 - 15:00 3.00 I CMPLTNI RUNT I CMPLT3 PU = 150k, SO = 57k Break Circ @ 35 SPM & 940 psi -Orient High Side and Tag up with 25k Wt -Pull Back up and turn 180? -Pass Thru window 10' - PU and Re-Orient High Side - Re-Tag with 25k -Drop ball and chase @ 3 BPM for 300 strokes -slow to 1.5 BPM and set ball @ 370 strokes -Pressure up to 3,000 psi to actuate hydraulic set hanger- PU Wt now 125k - Attempt to blow ball seat with 4,000 psi - RU test pump and shear ball 4,350 psi -Rig down and Blow down. PJSM -Stand Back Hybrid and HWDP - PU 4 stands Sliders from Derrick and POOH removing Super Sliders (WWT Rep Present) PJSM - Con't POOH std bk 4" DP -Removing WWT supersliders from DP - 90 total. The SS's will be shipped to Anchorage to be serviced by WWT. Clean rig floor - UD all tools from rig floor - UD WWT super sliders for shipping -Wash rig floor Make Service breaks and UD Baker liner running tool & slim hole MWD Clear rig floor - UD Baker liner tool out beaver slid and all csg runnig tools, tongs, slips, bowl, ect, PJSM -Slip & Cut drill line (59') and service rig top drive. PJSM - UD 207 jts (69 stds) 4" DP from derrick thru/ mouse hole. Con't UD 9 stds Hybrid DCs (1 jt HWDP + 2 - 43/4" Sprial DC) Con't UD 3 stds Hybrid DCs ii 9 stds of HWDP push pipe. UD Mouse hole -Clear and pick up rig floor - Pull tbg running tools to rig floor RIH open ended w! completion tbg picking up singles from pipe shed 111 jts) 37 stds POOH w/ completion tbg string and std bk in derrick. Cont POOH and std bk 4.5" tbg in derrick - (Total 37 stds in derrick) PJSM - Con't POOH std bk 4-1/2" Tbg string -Rack back 32 stands PU test jt and pull wear bushing - LD same PU Test Jt, Pull Wear ring, LD Same PJSM - PU and RU ESP Tools + Eqipment, clamps, hands tools. PU & RU ESP Tools & Equipment PJSM - PU/MU Motor centralizer,A well pump guage, Motor 418 HP, Tandem seal section, screen intake, 2 jts 4.5" SCC tbg, Discharge sub, 3 jts 4.5" SCC. Total 234.37 PJSM, PU & MU Motor Centralizer, Pump Guage, Tandem Seal Section, Screen Intake, 2 jts 4.5" Tbg, Discharge Sub, 3 more jts 4.5" Tbg w/ cable clamps RU Slick line unit to run ESP pump. RU Slickline Unit Run pump on slick line, set packoff and test to 1000 psi / 10 min, run and set pump lock. Wireline Pump Assy, Pack-off Assy, and Tbg Stop RD Slick line unit. RD Slickline Unit Cont to run 4.5" 12.6# L80 IBTM completion tbg. Ran total 17 jts, 1 GLM -Run cannon clamp every other connection. Cont RIH w! 4.5" Tbg from derrick (17 jts, 1 GLM & clamps every other connection) Cont to run 4.5" 12.6# L80 IBTM completion tbg. With total 47 jts, 2 Printed: 4/12/2006 1:53:21 PM ConocoPhillips Alaska Page 18 of 19 Operations Summary Report Legal Well Name: 1J-159 Common W ell Name: 1 J-159 Event Nam e: ROT -D RILLIN G Contractor Name: n1334@ ppco.co m Rig Name: Doyon 1 41 Date From - To Hours Code Sub Phase Code 3/12/2006 12:00 - 15:00 3.00 CMPLTN RUNT CMPLT3 12:00 - 15:00 3.00 CMPLTN RUNT CMPLT3 15:00 - 18:00 3.00 CMPLTN TRIP CMPLT3 15:00 - 18:00 ~ 3.00 CMPLTN TRIP CMPLT3 18:00 - 19:15 ~ 1.25 CMPLTN TRIP CMPLT3 18:00 - 19:15 1.25 CMPLTN TRIP CMPLT3 19:15 - 22:00 2.75 CMPLTN TRIP CMPLT3 19:15 - 22:00 2.75 CMPLTN DEOT CMPLT3 22:00 - 00:00 2.00 CMPLTN RUNT CMPLT3 22:00 - 00:00 2.00 CMPLTN RUNT CMPLT3 3/13/2006 00:00 - 05:00 5.00 CMPLTN RUNT ~ CMPLT3 05:00 - 06:30 1.50 CMPLTN RUNT CMPLT3 06:30 - 08:45 2.25 CMPLTN RURD CMPLT3 ~ 08:45 - 09:15 0.50 CMPLTN DEOT CMPLT3 09:15 - 10:00 0.75 CMPLTN RURD ~ CMPLT3 10:00 - 11:30 1.50 CMPLTN NUND CMPLT3 11:30 - 12:00 0.50 CMPLTN DEQT CMPLT3 12:00 - 13:30 1.50 CMPLTN NUND CMPLT3 13:30 - 14:30 1.00 CMPLTN SEAT CMPLT3 14:30 - 15:30 1.00 CMPLTN FRZP CMPLT3 15:30 - 15:45 i 0.25 ~ ~ CMPLTNi I FRZP j CMPLT3 Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number: Description of Operations GLM in hole -Run cannon clamp every other connection. -Control cable would not megger. Double checked meter and coil - NO Test. 'RIH w/ 4.5" Tbg from derrick w/.ESP clamps every other jt -Gas Lift w/ 2k Shearon top of jt #32 -Test line every 10 stands ... Make it to 1595.5' MD - 47 jts In Hole -ESP line did not test POOH checking for bad spot in control power cable. Pulled back to GLM #1 w/ 2K shear 1121' -Had smashed spots at each end of mandrel. Megger line and could still not get a reading. POOH standing Tbg back and testing ESP line - 1,121' -GLM w/ 2k Shear -line smashed in 2 places (@ top and bottom of concintric offset of GLM) Cut line -Test from truck to rig floor -Good ... Test down hole no good Con't to POOH GLM #2 - 525' -Cable smashed at top and bottom of i mandrel just like #1. Motor cable had been. installed in the wrong place running along the GLM outside almost directly across from the concentric shoulder. Cont POOH to bottom of ('Dummy') GLM @.525' -Cable smashed in 2 ,places again (on top and on bottom of GLM) Test line to Motor -Good -Make splice on Motor control line. ~ ""*NOTE"" Had to cut out 728' of Motor control cable. Will have to have two splices at top of hole. #1 -Splice on more cable #2 Splice on penitrator lead. Test Line down hole -Good Splice ESP cable -Test same -Good RIH w14.5" completion string from derrick -ESP cable clamps every other jt - 2K shear GLM @ 1,121'. RIH w/ 4.5" Completion String from derrick -ESP cable clamps every other jt - 2k Shear GLM @ 1,121' Con't RIH w/ 4.5" ESP completion from derrick. Cannon clamp every otherjoint. Test cable every 1000' PU tbg hanger on full jt tbg, Orient hanger, MU landing joint Splice control cable to penetrator lead. Install penetrator and hookup to cable. Plug into penetrator and test cable. All test "OK" Land hanger - RILDS and torque to spec -Test upper and lower hanger seals to 5000 psi f/ 10 min "OK" (@ landing PU wt 133K - Dn wt 125K ) ND BOP stack and set back on stump. Test ESP Cable "OK" NU Vetco /Gray Production Tree Testing tree void to 5000K psi -Test tree to 5000K psi -Test ECP cable "OK" Scaffold up around tree -Pull 2 way check -Rig up to Freeze protect well. We will pump 186 bbls diesel down the annulus and taking returns thru the tbg to the willis choke. PR Max 4 BPM. Start pumping 4 BPM = 600 psi and finish pumping 4 BPM 1050 psi. Pumped 186 bbls diesel. ~ Tbg psi 170 , IA 400, OA 0 Scaffold up around tree -Pull 2 way check -Rig up to Freeze protect well. We will pump 186 bbls diesel down the annulus and taking returns j thru the tbg to the willis choke. PR Max 4 BPM. Printed: 4/12/2006 1:53:21 PM • • ConocoPhillips Alaska Page 1 ~ of ~ Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Spud Date: 2/12/2006 Event Name: ROT -DRILLING Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13!2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Code Phase Description of Operations 3/13/2006 15:45 - 17:00 1.25 CMPLTN ~ FRZP CMPLT3 I Freeze protect well thru pump intake @ 3633' - Start pumping 4 BPM = 1600 psi and finish pumping 4 BPM 1050 psi. Pumped 186 bbls diesel. ~ Shut In well. Tbg Pressure 200, IA 400, OA 0 18:00 - 20:00 2.00 CMPLTN RURD CMPLT3 Install flow line hyd actuator valve. Install BPV w/ Lubricator 20:00 - 21:00 1.00 CMPLTN ~ RURD CMPLT3 ASRC RD scaffold -Pick up and clean cellar -Secure Well ""'Release Rig 2100 hrs 3/13/2006 Printed: 4/12/2006 1:53:21 PM i Halliburton Company,. Global Report C~unp:ui}~: ConoroPhillipsAlasha Inc_ I~auc: 4/11i200o link: 15:1204 Pa~c: L I~ielil: Kuparuk River Unit (~u-urdim~tclAI~~) kc Cercnce: Well: 1J-159. True North ~itc: Kuparuk 1J Pad ~crtical (f~l)) Itcfc rcucc: 1J-159: 109-0 ~~'cll: 1J-159 ticc~iuu I~~ti) licferc uec Well (0.OON,O-OOE,O OUAzil ~'.'ellp:uh: 1J-159 ~un~c~~ ('alculation 1lctliud: Minimum Curvatu re Ilh: Oracle Survey: Start Date: Company: Engineer: Tool: Tied-to: Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 192 7 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Kuparuk 1 J Pad Site Position:. Northing: 5945919.64 ft Latitude: 70 15 46.258 N From: Map Easting: 558789.95 ft Longitude: 149 31 29.007 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergen ce: 0.45 deg Well: 1J-159 Slot Name: Well Position: +N/-S -71.86 ft Northing: 5945846.80 ft + Latitude: 70 15 45.551 N +E/-W -126.82 ft Easting : 558663.71 ft Longitude: 149 31 32.697 W Position Uncertainty: 0.00 ft Wellpath: 1J-159 Drilled From: 1J-159PB1 500292329700 Tie-on Depth: 5541.32 ft Current Datum: 1J-159: Height 109.00 ft Above System D atum: Mean Sea Level Magnetic Data: 2/9/2005 Declination: 24.57 deg Field Strength: 57557 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 4/11/2006 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 50.00 717.00 1J-159PB1 gyro (50.00-717.00) CB-GYRO-SS Camera based gyro single shot 749.61 1403.57 1J-159 (717-1449) (749.61 -1403 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1449.80 1549.80 1 J-159P61 gyro(1449-1549) (144 CB-GYRO-SS Camera based gyro single shot 1619.68 5541.32 1J-159 (1619 .68-5751.68) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5620.00 7774.17 1J-159 (5620 .00-7774.17) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ~t~) InCI _~ll nl ~ ~ 1) SA S 1 ~ 11 ~~~ I~.r ~~' 'tla ~)~ CIA fit, ~ OUP ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945846.80 558663.71 TIE LINE 50.00 0.36 208.13 50.00 -59.00 -0.06 -0.03 5945846.74 558663.68 CB-GYRO-SS 100.00 0.32 197.19 100.00 -9.00 -0.33 -0.15 5945846.47 558663.56 CB-GYRO-SS 200.00 0.32 216.08 200.00 91.00 -0.83 -0.39 5945845.97 558663.32 CB-GYRO-SS 264.00 0.65 197.76 264.00 155.00 -1.32 -0.61 5945845.48 558663.11 CB-GYRO-SS 355.00. 0.37 95.03 354.99 245.99 -1.83 -0.48 5945844.96 558663.25 CB-GYRO-SS 444.00 2.89 49.19 443.95 334.95 -0.39 1.51 5945846.42 558665.22 CB-GYRO-SS 534.00 5.58 38.99 533.70 424.70 4.49 5.98 5945851.34 558669.65 CB-GYRO-SS 626.00 8.98 35.44 624.94 515.94 13.82 12.96 5945860.72 558676.56 CB-GYRO-SS 717.00 13.78 33.39 714.13 605.13 28.67 23.05 5945875.64 558686.53 CB-GYRO-SS i 749.61 14.47 29.58 745.75 636.75 35.45 27.20 5945882.46 558690.63 MWD+IFR-AK-CAZ-SC 842.05 16.42 27.05 834.85 725.85 57.13 38.84 5945904.23 558702.10 MWD+IFR-AK-CAZ-SC 934.49 16.12 24.17 923.59 814.59 80.48 50.04 5945927.66 558713.11 MWD+IFR-AK-CAZ-SC 978.89 15.93 26.88 966.27 857.27 91.54 55.32 5945938.76 558718.31 MWD+IFR-AK-CAZ-SC 1025.72. 15.66 29.47 1011.33 902.33 102.77 61.33 5945950.04 558724.23 MWD+IFR-AK-CAZ-SC • Halliburton Compan~ Global Report ('nmp:un~: ConocoPhi'IipsAlaska Inc. Ilailc: 4/11!2000 l~inm: 15.1X4 I'a~c: _' Iirl~l: Kuparuk River Unit Cu-unlinaitclA1~:) Kcfcrencc: Well: 1J-159. True North ~ifc: Kuperuk iJ P2d ~~crlical(11~D) Iicfcrcncc: 1J-159. 109.0 ~~cll: iJ-159 ~cciiim(VSI l2cfcrcncc: Well (O OON,0-GOE,O OOAzi) '.'~~'elipa~h: 1J-159 ~ur~e~ ('alculatfun ~lcthud: MinimumCurvature 11 h: Oracle ~unc~ III) Inrl ~ziw I~'11 ~~s Ill) V'S I~:r~1' ~L~hA ~Ia~iF. i~~xil ft deg deg ft ft ft ft ft a _ 1063.68 15.73 30.50 1047.87 938.87 111.67 66.46 5945958.97 558729.30.. MWD+IFR-AK-CAZ-SC 1124.97 15.49. 33.39 1106.90 997.90 125.66 75.18 5945973.03 558737.91 MWD+IFR-AK-CAZ-SC 1217.44 16.35 39.14 1195.83 1086.83 146.07 90.20 5945993.55 558752.76 MWD+IFR-AK-CAZ-SC 1309.86 20.27 41.59 1283.56 1174.56 168.14 109.04 5946015.77 558771.43 MWD+IFR-AK-CAZ-SC 1403.57 25.11 44.48 1369.99 1260.99 194.48 133.76 5946042.30 558795.94 MWD+IFR-AK-CAZ-SC 1449.80 25.72 48.64 1411.75 1302.75 208.11 148.17 5946056.04 558810.24 CB-GYRO-SS 1499.80 26.89 50.63 1456.57 1347.57 222.45 165.05 5946070.51 558827.01 CB-GYRO-SS 1549.80 26.01 51.60 1501.34 1392.34 236.43 182.39 5946084.62 558844.23 CB-GYRO-SS 1619.68 26.54 49.51 1564.00 1455.00 256.09 206.27 5946104.46 558867.96 MWD+IFR-AK-CAZ-SC 1680.87 29.46 51.24 1618.02 1509.02 274.39 228.40 5946122.93 558889.95 MWD+IFR-AK-CAZ-SC 1772.82 30.78 54.80 1697.56 1588.56 302.11 265.26 5946150.94 558926.59 MWD+IFR-AK-CAZ-SC 1866.42 30.99 55.49 1777.89 1668.89 329.57 304.69 5946178.70 558965.80 MWD+IFR-AK-CAZ-SC 1959.63 32.44 57.34 1857.18 1748.18 356.66 345.52 5946206.10 559006.40 MWD+IFR-AK-CAZ-SC 2050.50 31.68 64.11 1934.22 1825.22 380.24 387.51 5946230.01 559048.21 MWD+IFR-AK-CAZ-SC 2144.19 30.77 69.13 2014.35 1905.35 399.52 432.05 5946249.64 559092.59 MWD+IFR-AK-CAZ-SC 2236.02 29.86 73.73 2093.63 1984.63 414.30 475.95 5946264.75 559136.37 MWD+IFR-AK-CAZ-SC 2300.28 28.53 78.34 2149.73 2040.73 421.88 506.34 5946272.57 559166.70 MWD+IFR-AK-CAZ-SC 2322.58 28.21 80.61 21fi9.36 2060.36 423.82 516.76 5946274.59 559177.10 MWD+IFR-AK-CAZ-SC 2422.10 27.18 88:20 2257.50 2148.50 428.37 562.70 .5946279.50 559223.00 MWD+IFR-AK-CAZ-SC 2479.77 25.89 92.10 2309.10 2200.10 428.32 588.45 5946279.65 559248.75 MWD+IFR-AK-CAZ-SC 2572:77 26.16 98.98 2392.69 2283.69 424.38 629.00 5946276.02 559289.32 MWD+IFR-AK-CAZ-SC 2668.69 26.35 108.60 2478.75 2369.75 414.28 670.08 5946266.25 559330.47 MWD+IFR-AK-CAZ-SC 2761.93 27.37 119.14 2561.98 2452.98 397.24 708.43 5946249.50 559368.96 MWD+IFR-AK-CAZ-SC 2852.14 28.67 128.27 2641.65 2532.65 373.72 743.55 5946226.27 559404.25 MWD+IFR-AK-CAZ-SC 2947.41 32.19 138.44 2723.84 2614.84 340.55 778.36 5946193.37 559439.32 MWD+IFR-AK-CAZ-SC 3041.26 35.21 147.66 2801.96 2692.96 298.95 809.45 5946152.01 559470.73 MWD+IFR-AK-CAZ-SC 3134.05 38.69 155.81 2876.15 2767.15 249.84 835.66 5946103.12 559497.32 MWD+IFR-AK-CAZ-SC 3227.21 44.67 164.51 2945.75 2836.75 191.62 856.38 5946045.07 559518.49 MWD+IFR-AK-CAZ-SC 3320.49 51.09 171.09 3008.32 2899.32 124.06 870.78 5945977.63 559533.41 MWD+IFR-AK-CAZ-SC 3414.92 52.58 175.27 3066.69 2957.69 50.37 879.56 5945904.02 559542.77 MWD+IFR-AK-CAZ-SC 3507.84 52.22 175.12 3123.38 3014.38 -22.99 885.73 5945830.71 559549.51 MWD+IFR-AK-CAZ-SC 3601.74 51.76 175.40 3181.20 3072:20 -96.72 891.85 5945757.04 559556.20 MWD+IFR-AK-CAZ-SC 3695.29 51.60 174.04 3239.21 3130.21 -169.80 898.60 5945684.02 559563.52 MWD+IFR-AK-CAZ-SC 3789.71 55.75 .174.70 3295:13 3186.13 -245.49 906.05 5945608.40 559571.56 MWD+IFR-AK-CAZ-SC 3882.32 60.01 172.71 3344.36 3235.36 -323.43 914.68 5945530.54 559580.79 MWD+IFR-AK-CAZ-SC 3977.16 64.36 175.95 3388.62 3279.62 -406.87 922.91 5945447.18 559589.68 MWD+IFR-AK-CAZ-SC 4071.75 68.20 177.90 3426.66 3317.66 -493.32 927.54 5945360.77 559594.97 MWD+IFR-AK-CAZ-SC 4165.31 71.85 179.96 3458.62 3349.62 -581.22 929.16 5945272.90 559597.28 MWD+IFR-AK-CAZ-SC 4257.98 75.77 184.29 3484.47 3375.47 -670.11 925.83 5945183.99 559594.64 MWD+IFR-AK-CAZ-SC 4350.48 75.65 184.46 3507.30 3398.30 -759.48 918.99. 5945094.57. 559588.50 MWD+IFR-AK-CAZ-SC 4443.58 78.77 184.05 3527.91 3418.91 -850.01 912.26 5945004.00 559582.47 MWD+IFR-AK-CAZ-SC 4534.51 79.50 182.66 3545.05 3436.05 -939.16 907.03 5944914.83 559577.94. MWD+IFR-AK-CAZ-SC 4629.08 81.87 185.36 3560.36 3451.36 -1032.23 900.50 5944821.71 559572.14 MWD+IFR-AK-CAZ-SC 4726.40 82.00 184.89 3574.01 3465.01 -1128.21 891:89 5944725.68 559564.28 MWD+IFR-AK-CAZ-SC 4814.31 80.38 184.26 3587.47 3478.47 -1214.80 884.96 5944639.05 559558.02. MWD+IFR-AK-CAZ-SC 4907.68 81.05 183.38 3602.54 3493.54 -1306.74 878.82 5944547.07 559552.60 MWD+IFR-AK-CAZ-SC 4999.99 79.68 183.57 3617.99 3508.99 -1397.58. 873.31 5944456.20 559547.79 MWD+IFR-AK-CAZ-SC 5092.87 77.20 182.53 3636.60 3527.60 -1488.44 868.46 5944365.32 559543.66 MWD+IFR-AK-CAZ-SC ~ 5187.25 78.66 183.16 3656.33 3547.33 -1580.61 863.88 5944273.12 559539.79 MWD+IFR-AK-CAZ-SC 5280.93 80.23 183.86 3673.49 3564.49 -1672.53 858.24 5944181.17. 559534.87 MWD+IFR-AK-CAZ-SC i 5374.21 83.85 185.33 3686.41 3577.41 -1764.60 850.84 5944089.05 559528.19 MWD+IFR-AK-CAZ-SC 5467.64 89.04 185.13 3692.20 3583.20 -1857.43 842.34 5943996.17 559520.41 MWD+IFR-AK-CAZ-SC 5541.32 87.57 184.81 3694.38 3585.38 -1930.80 835.96 5943922.76 559514.61 MWD+IFR-AK-CAZ-SC i Halliburton Company. Global Report (~nmpan~: ConocoPhillipsAlaska Inc. Uarc : ~'11i2006 Iinm: 15:1204 I'a~~e: 3 F~icld: Kuparuk River U nit Cn-u rdinatc(~1~:1 Kc fcrcncr. Well: 1J-159. True North tine: Kuparuk lJ Pad ~~crd e:~l fll~lll Kcfe rcnce: 1J- 159: 109-0 ~~cll: 1J-159 ~cctii m 1~~1 ILcferc ncr. Well (0-OON O.OUE O OOA~iI 11'cllpath: 1J-159 tiun evCailculatiun 1ti~tho~l: Min imum Curv2tu re Uh: Oracle Sure cc ~lll Intl ~zini ll U tit's lVI) \;~ 1::1~ ~lapA ~lapl~: ~fniil ft dey deg ft ft ft ft ft ft 5620.00 91.91 187.01 3694.74 3585.74 -2009.03 827.86 5943844.47 559507.12 MWD+IFR-AK-CAZ-SC 5658.20 86.92 186.41 3695.13 3586.13 -2046.96 823.40 5943806.52 559502.95 MWD+IFR-AK-CAZ-SC 5751.64 90.50 188.11 3697.23 3588.23 -2139.61 811.59 5943713.79 559491.87 MWD+IFR-AK-CAZ-SC 5844.78 93.03 189.91 3694.36 3585.36 -2231.54 797.02 5943621.75 559478.01 MWD+IFR-AK-CAZ-SC 5937.99 91.05 188.18 3691.04 3582.04 -2323.53 782.38 5943529.66 559464.09 MWD+IFR-AK-CAZ-SC 6031.55 91.49 184.78 3688:97 3579.97 -2416.45 771.82 5943436.67 559454.26 MWD+IFR-AK-CAZ-SC 6125.21 89.39 184.15 3688.25 3579.25 -2509.82 764.53 5943343.25 559447.70 MWD+IFR-AK-CAZ-SC 6172.25 89.14 183.54 3688.85 3579.85 -2556.75 761.38 5943296.30 559444.91 MWD+IFR-AK-CAZ-SC 6217.41 88.90 183.52 3689.63 3580.63 -2601.82 758.60 5943251.22 559442.48 MWD+IFR-AK-CAZ-SC 6310.37 93.86 184.81 3687.39 3578.39 -2694.47 751.85 5943158.52 559436.46 MWD+IFR-AK-CAZ-SC 6403.95 93.28 183.21 3681.56 3572.56 -2787.64 745.32 5943065.32 559430.65 MWD+IFR-AK-CAZ-SC 6497.24 91.12 184.27 3677.98 3568.98 -2880.66 739.24 5942972.27 559425.30 MWD+IFR-AK-CAZ-SC 6590.68 92.10 182.70 3675.36 3566.36 -2973.88 733.56 5942879.01 559420.35 MWD+IFR-AK-CAZ-SC 6682.50 91.49 185.77 3672.48 3563.48 -3065.40 726.78 5942787.45 559414.28 MWD+IFR-AK-CAZ-SC 6772.57 91.13 186.04 3670.42 3561.42 -3154.96 717.52 5942697.82 559405.72 MWD+IFR-AK-CAZ-SC 6864.00 92.44 183.18 3667.57 3558.57 -3246.04 710.17 5942606.70 559399.08 MWD+IFR-AK-CAZ-SC 6955.14 92.91 180.53 3663.32 3554.32 -3337.03 707.23 5942515.70 559396.84 MWD+IFR-AK-CAZ-SC 7046.89 91.42 177.58 3659.85 3550.85 -3428.69 708.74 5942424.07 559399.07 MWD+IFR-AK-CAZ-SC 7136.40 92.29 178.28 3656.95 3547.95 -3518.09 711.97 5942334.70 559403.00 MWD+IFR-AK-CAZ-SC 7228.22 91.92 177.10 3653.58 3544.58 -3609.77 715.67 5942243.06 559407.41 MWD+IFR-AK-CAZ-SC 7320.38 90.31 178.37 3651.79 3542.79 -3701.84 719.31 5942151.03 559411.77 MWD+IFR-AK-CAZ-SC 7410.69 93.37 180.48 3648.89 3539.89 -3792.08 720.22 5942060.81 559413.38 MWD+IFR-AK-CAZ-SC 7500.56 92.29 179.25 3644.45 3535.45 -3881.84 720.43 5941971.07 559414.29 MWD+IFR-AK-CAZ-SC 7591.50 90.25 177.63 3642.43 3533.43 -3972.71 722.91 5941880.22 559417.47 MWD+IFR-AK-CAZ-SC 7682.62 89.88 177.32 3642.33 3533.33 -4063.74 726.92 5941789.23 559422.20 MWD+IFR-AK-CAZ-SC 7774.17 90.13 180.87 3642.32 3533.32 -4155.27 728.37 5941697.73 .559424.35 MWD+IFR-AK-CAZ-SC 7857.00 90.13 180.87 3642.13. 3533.13 -4238.09 727.11 5941614.91 ~ 559423.74 ~ PROJECTED to TD Halliburton Company Global Report ('nmlrtnc: ConocoPhiipsAaska nc. I)atc: 4/1tl2006 lime: 10:4721 I'a;;r. 1 Field: Kuparuk River Unit (~~~-~u~linatelAI:) Re fcrencr. Weli: 1J-159, True North bite: Kuparuk 1J Pad Fertical (I 4U) Kei'e rcnce: 1J-159P81 109-0 ~~cll: 1J-159 tiectiun I~~,~IRefere ncc: Well i0.00N.0-OOE O COAzi) 1ellpath: 1J-159PE1 ~ur~c~ CalculationMethnd: Minimum Curvatur e Ub: Oracle Survey: - Start Date: -- Company: Engineer: Tool: Tied-to: Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 192 7 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Kuparuk 1J Pad Site Position: Northing: 5945919.64 ft Latitude: 70 15 46.258 N From: Map Easting: 558789.95 ft Longitude: 149 31 29.007 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergen ce: 0.45 deg Well: 1 J-159 Slot Name: Well Position: +N/-S -71.86 ft Northing: 5945846.80 ft Latitude: 70 15 45.551 N +E/-W -126.82 ft Easting : 558663.71 ft Longitude: 149 31 32.697 W Position Uncertainty: 0.00 ft Wellpath: 1J-159PB1 Drilled From: Well Ref. Point 500292329770 Tie-on Depth: 28.00 ft Current Datum: 1 J-159PB1: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 2/9/2006 Declination: 24.19 deg Field Strength: 57564 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 4/11/2006 Validated: No Version: 2 ~ Actual From To Survey Toolcode Tool Name ft ft 50.00 717.00 1 J-159P61 gyro (50.00-717.00) CB-GYRO-SS Camera based gyro single shot 749.64 1403.57 1J-159 (717-1449) (749.61 -1403 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1449.80 1549.80 1J-159PB1 gyro(1449-1549) (144 CB-GYRO-SS Camera based gyro single shot 1619.68 5751.68 1J-159 (1619 .68-5751.68) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey -- - ~11) lucl liim llD 5~ ~ ~Il~l) \;S 1~:,'~~ ~lnhA ~lapl% fnnl ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945846.80 558663.71 TIE LINE I 50.00 0.36 208.13 50.00 -59.00 -0.06 -0.03 5945846.74 558663.68 CB-GYRO-SS ~ 100.00 0.32 197.19 100.00 -9.00 -0.33 -0.15 5945846.47 558663.56 CB-GYRO-SS 200.00 0.32 216.08 200.00 91.00 -0.83 -0.39 5945845.97 558663.32 CB-GYRO-SS 264.00 0.65 197.76 264.00 155.00 -1.32 -0.61 5945845.48. 558663.11 CB-GYRO-SS 355.00 0.37 95.03 354.99 245.99 -1.83 -0.48 5945844.96 558663.25 CB-GYRO-SS 444.00 2.89 49.19 443.95 334.95 -0.39 .1.51 5945846.42 558665.22 CB-GYRO-SS 534.00 5.58 38.99 533.70 424.70 4.49 5.98 5945851.34 558669.65 CB-GYRO-SS 626.00 8.98 35.44 624.94 515.94 13.82 12.96. 5945860.72 558676.56 CB-GYRO-SS 717.00 13.78 33.39 714.13 605.13 28.67 23.05 5945875.64 558686.53 CB-GYRO-SS 749.61 14.47 29.58 745.75 636.75 35.45 27.20 5945882.46 558690.63 MWD+IFR-AK-CAZ-SC i 842:05 16.42 27.05 834.85 725.85 57.13 38.84 5945904.23 558702.10 MWD+IFR-AK-CAZ-SC ~ ~ 934.49 16.12 24.17 923.59 814.59 80.48 50.04 5945927.66 558713.11 MWD+IFR-AK-CAZ-SC 978.89 15.93 26.88 966.27 857.27 91.54 55.32 5945938:76 558718.31 MWD+IFR-AK-CAZ-SC 1025.72 15.66 29.47 . 1011.33 .902.33 102.77 61.33 5945950.04 558724.23 MWD+IFR-AK-CAZ-SC ~ 1063.68 15.73 30.50 1047.87 938.87 111.67 66.46 5945958.97 .558729.30 MWD+IFR-AK-CAZ-SC ~ Halliburton Company, Global Report (~ump;3n~: ConocoPhillips Alaska Inc. I~iclil: Kuparuk River U nit 1ilc: Kuparuk 1J Pad ~~cll: 1 J-159 1~'clllrith: 1 J- 150P61 Su ncc ~lll lucl ~ciw ft deg deg 1124.97 15.49 33.39 1217.44 16.35 39.14 1309.86 20.27 41.59 1403.57 .25.11 44.48 1449.80 1499.80 1549.80 1619.68 1680.87 1772.82 1866.42 1959.63 2050.50 2144.19 2236.02 2300.28 2322.58 2422.10 - 2479:77 2572.77 2668.69 2761.93 2852.14 2947.41 3041.26 3134.05 3227.21 3320.49 3414.92 3507.84 3601.74 3695.29 3789.71 3882.32 3977.16 4071.75 4165.31 4257.98 4350.48 4443.58 4534.51 as2s.os 4726.40 4814.31 4907.68 4999.99 5092.87 5187.25 5280.93 5374.21 5467.64 5541.32 5657.27 25.72 48.64 26.89 50.63 26.01 51.60 26.54 49.51 29.46 51.24 30.78 54.80 30.99 55.49 32.44 57.34 31.68 64.11 30.77 69.13 29.86 73.73 28.53 78.34 28.21 80.61 27.18 88.20 25.89 92.10 26.16 98.98 26.35 108.60 27.37 119.14 28.67 128.27 32.19 138.44 35.21 147.66 38.69 155.81 44.67 164.51 51.09 171.09 52.58 175.27 52.22 175.12 51.76 175.40 51.60 174.04 55.75 174.70 60.01 172.71 64.36 175.95 68.20 177.90 71.85 179.96 75.77 184.29 75.65 184.46 78.77 184.05 79.50 182.66 81.87 185.36 82.00 184.89 80.38 184.26 81.05 183.38 79.68 183.57 77.20 182.53 78.66 183.16 80.23 183.86 83.85 185.33 89.04 185.13 87.57 184.81 93.96 188.05 I):1f C: 4/11/2006 fimc: 10:4721 Pa,c _ ('u-ur~linstclAl:) Kc~cr-cncc: We_ 1J-159, True North ~'cr kcal ITS [)) Rcfcrcocr. 1 J-159PB1 109.0 tiectiuu f~S) Reference: Well (0-OON,Q OOEO OOAzi) ~nn~c~~ (,alcufalion ~lcthuil: Minimum Curvature Uh: Oraele lll) ties ll U \;,~ ft ft ft 1106 .90 . 997.90 125.66 1195:83 1086.83 146.07 1283 .56 1174.56 168.14 1369 .99 1260.99 194.48 1411 .75 1302.75 208.11 1456 .57 1347.57 222.45 1501 .34 1392.34 236.43 1564 .00 1455.00 256.09 1618 .02 1509.02 274.39 1697 .56 1588.56 302.11 1777 .89 1668.89 329.57 1857 .18 1748.18 356.66 1934 .22 1825.22 380.24 2014 .35 1905.35 399.52 2093 .63 1984.63 414.30 2149 .73 2040.73 421.88 2169 .36 2060.36 423.82 2257 .50 2148.50 428.37 2309. 10 2200.10 428.32 2392. 69 2283.69 424.38 2478. 75 2369.75 414.28 2561. 98 2452.98 397.24 2641. 65 2532.65 373.72 2723. 84 2614.84 340.55 2801. 96 2692.96 298.95 2876. 15 2767.15 249.84 2945. 75 2836.75 191.62 3008. 32 2899.32 124.06 3066. 69 2957.69 50.37 3123.38 3014.38 -22.99 3181.20 3072.20 -96.72 3239.21 3130.21 -169.80 3295.13 3186.13 -245.49 3344.36 3235.36 -323.43 3388.62 3279.62 -406.87 3426.66 3317.66 -493.32 3458.62 3349.62 -581.22 3484.47 3375.47 -670.11 3507.30 3398.30 -759.48 3527.91 3418.91 -850.01 3545.05 3436.05 -939.16 3560.36 3451.36 -1032.23 3574.01 3465.01 -1128.21 3587.47 3478.47 -1214.80 3602.54 3493.54 -1306.74 3617.99 3508.99 -1397.58 3636.60 3527.60 -1488.44 3656.33 3547.33 -1580.61 3673.49 3564.49 -1672.53 3686.41 3577.41 -1764.60 3692.20 3583.20 -1857.43 3694.38 3585.38 -1930.80 3692.83 3583.83 -2045.93 1:-11 ~1:+hA ~lahl: I'iml ft ft ft 75.18. 5945973.03 558737.91 MWD+IFR-AK-CAZ-SC 90.20 5945993.55 558752.76 MWD+IFR-AK-CAZ-SC 109.04 5946015.77 558771.43 MWD+IFR-AK-CAZ-SC 133.76 5946042.30 .558795.94 MWD+IFR-AK-CAZ-SC 148:17 5946056.04 558810.24 CB-GYRO-SS 165.05 5946070.51 558827.01 CB-GYRO-SS 182.39 5946084.62 558844.23 CB-GYRO-SS 206.27 5946104.46 558867.96 MWD+IFR-AK-CAZ-SC 228.40 5946122.93 558889.95 MWD+IFR-AK-CAZ-SC 265.26 5946150.94 558926.59 MWD+IFR-AK-CAZ-SC 304.69 5946178.70 558965.80 MWD+IFR-AK-CAZ-SC 345.52 5946206.10 559006.40 MWD+IFR-AK-CAZ-SC 387.51 5946230.01 559048.21 MWD+IFR-AK-CAZ-SC 432.05 5946249:64 559092.59 MWD+IFR-AK-CAZ-SC 475.95 5946264.75 559136.37 MWD+IFR-AK-CAZ-SC 506.34 5946272.57 559166.70 MWD+IFR-AK-CAZ-SC 516.76 5946274.59 559177.10 MWD+IFR-AK-CAZ-SC 562.70 5946279.50 559223.00 MWD+IFR-AK-CAZ-SC 588.45 5946279.65 559248.75 MWD+IFR-AK-CAZ-SC 629.00 5946276.02 559289.32 MWD+IFR-AK-CAZ-SC 670.08 .5946266.25 559330.47 MWD+IFR-AK-CAZ-SC 708.43 5946249.50 559368.96 MWD+IFR-AK-CAZ-SC 743.55 5946226.27 559404.25 MWD+IFR-AK-CAZ-SC 778.36 5946193.37 559439.32 MWD+IFR-AK-CAZ-SC 809.45 5946152.01 559470.73 MWD+IFR-AK-CAZ-SC 835.66 5946103.12 559497.32 MWD+IFR-AK-CAZ-SC 856.38 5946045.07 559518.49 MWD+IFR-AK-CAZ-SC 870.78. 5945977.63 559533.41. MWD+IFR-AK-CAZ-SC 879.56 5945904.02 559542.77 MWD+IFR-AK-CAZ-SC 885.73 5945830.71 559549.51 MWD+IFR-AK-CAZ-SC 891.85 5945757.04 559556.20 MWD+IFR-AK-CAZ-SC 898.60 5945684.02 559563.52 MWD+IFR-AK-CAZ-SC 906.05 5945608.40 .559571.56 MWD+IFR-AK-CAZ-SC 914.68 5945530.54 559580.79 MWD+IFR-AK-CAZ-SC 922.91 5945447.18 559589.68 MWD+IFR-AK-CAZ-SC 927.54 5945360.77 559594.97 MWD+IFR-AK-CAZ-SC 929.16 5945272.90 559597.28 MWD+IFR-AK-CAZ-SC 925.83 5945183.99 559594.64 MWD+IFR-AK-CAZ-SC 918.99 5945094.57 559588.50 MWD+IFR-AK-CAZ-SC 912.26 5945004.00 559582.47 MWD+IFR-AK-CAZ-SC 907.03 5944914.83 559577.94 MWD+IFR-AK-CAZ-SC 900.50 5944821.71 559572.14 MWD+IFR-AK-CAZ-SC 891.89 5944725.68 559564.28 MWD+IFR-AK-CAZ-SC 884.96 5944639.05 559558.02 MWD+IFR-AK-CAZ-SC 878.82 5944547.07 559552.60 . .MWD+IFR-AK-CAZ-SC 873.31 5944456.20 559547.79 MWD+IFR-AK-CAZ-SC 868.46 5944365.32 559543.66 MWD+IFR-AK-CAZ-SC 863.88 5944273.12 559539.79 MWD+IFR-AK-CAZ-SC 858.24 5944181.17 559534.87 MWD+IFR-AK-CAZ-SC 850.84 5944089.05 559528.19 MWD+IFR-AK-CAZ-SC 842.34 5943996:17 559520.41 MWD+IFR-AK-CAZ-SC 835.96 5943922.76 559514.61 MWD+IFR-AK-CAZ-SC 822.99 5943807.54 559502.53 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report ('~uupau~: CcnucoPhrliipsAlaska Inc. 11atr: di11i200o Fiinc: 10'.4721 P.~~,c: 3 Field: Kuparuk River U nit (~~~-urdinarcl~l:) 12cf~rcncr. Well: 1J-159. True North tiire: Kuparek 1J Pad ~'crticaal (I~~[)) Ilcfcrcncc: 1J-159PB1~ 109.0 ~~cll: 1J-159 ~rctiun 1~~~1 llcferencr. Well i0.OON.QOOEO OOAzi) ~1'cllpath: 1J-15gPBl ~unc} lalculslion ~lcthod: Minit~~,ur~ CUNatU2 Ub: Oracle ~uncc X111 Intl lziui l~D S~~I~D V"ti I~.'ll' 11:~pA ~IapH: l~niil ft deg deg ft ft ft ft ft ft 5751.68 88.36 187.22 3690.92 3581.92 -2139.45 810.45 5943713.94 f 559490.73 MWD+IFR-AK-CAZ-SC W 5808.00 88.36 187.22 3692.54 3583.54 -2195.30 803.38 5943658.04 559484.09 PROJECTED to TD L /~ o ~/ N_ r O ~ L y o~ a 4r .A ~ Y I ~ N O ? ~ ~ C :T fl. p ~ ~ ~ ~ p '~ o Yac~ ~ ~ ~ _p~n ~w ~r ~ ~ ~ \t w ~`.. ~ `° ~~. '°~ ~,. '~*s M ` ~ ~ ~~ t--~ `. ~ ty O `~ a p ~ c; G G O ~ _ - ~ ~ c~ r ~ /~ W o i V1 4 N G J ~~ '~ J ~ ~ 1~ N ~ Jl o _,, _ ~~ J -_ --.___ ! ~ 4 ~~~1 J ~ ~r i '` 0 a 0 d 4 4 C] r7 0 v o iN 4 [V 4 P 4 0 Z Re: 1J-159 19T Geological Sidetrack Notifica Subject: Rc: 1J-159 197' Geological Sidetrack Notifiication From: Thomas iVla~mder atom ~~~aundcr~~iad~nin.stat~.ak.us> Datez Thu, ? ; [~ cb 20Ci6 07.15:22 -09(10 °Co: "Rcillti~, Patrick J" Patrick.J.Reill_y(uconocophillips.corn = CC: Steti~e Da~~ies <ste~-e davies(ci%admin.state.ak.us~ Hi Pat, • ~~, - CQO ~ Got your voice message as well. This notice should be sufficient. The "lost" section should have PB 1 added to the name as usual. Call or message with any questions. Tom Maunder, PE AOGCC Reilly, Patrick J wrote, On 2/22/2006 5:21 PM: Tom, The details of the sidetrack are as follows: • Well: 1J-159 • Rig: 141 • Date: 2/21 /06 • Time: 1400 hrs • MD Intermediate Casing: 5,575' • MD of abandoned section: 5,613' - 5,810' We exited the top of the formation after building more aggressively than planned. We made a low side sidetrack. We are planning to isolate the sidetrack with blank liner and constrictors to prevent any shale inflow. Please let me know if you need any additional information. Thanks. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.Reilly(a~conocophillips.com «Patrick.J.Reilly a~7conocophillips.com.vcf» 1 of 1 2/23/2006 7:46 AM 4 ~ ~ ~ ` ~~ ~~,~~ ~~ ~ °~ ~ j ~ ,~ FRANK H. MURKOWSK/, GOVERNOR ~~~~ ~~r+ ~~ OI~ ~ e]r~~ ,~ 333 W. 7TM AVENUE, SUITE 100 COI~TSFiR~A~l`IOI1T COMZtII55I0AT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River, 1J-159 ConocoPhillips Alaska, Inc. Permit No: 206-005 Surface Location: 2036' FSL, 2545' FEL, Sec. 35, T 11 N, R 10E, UM Bottomhole Location: 2184' FNL, 1837' FEL, Sec. 2, TlON, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. 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. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager) . Sincerely, G'~`~i~''` +' ~f Daniel T. Seamount Jr. ~ Commissioner J1tiN~A.'~'~ DATED thisZ~J day of r~eTffh, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips ~ Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com January 16, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ~c~f~ SAN Y 8 200 '0~$6 -~ ram Re: Applications for Permit to Drill, West Sak Producer, 1J-159, iJ-159 L1, 1J-159 L2 Dear Commissioners: ,~ ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore producer well, a trilateral horizontal well in the West Sak "A2", ~~B"and °D" sands. The main bore of the well will be designated iJ- 159, and the lateral bores of the well will be designated 1J-159L1 and 1J-159L2. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1J-159 is February 9, 2006. If you have any questions or require any further information, please contact Pat Reilly at 265-6048. Sincerely, ~~~ ~ Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 `~EGEIVED ,,~~~ JAN 1 8 20t~E~ ~~vska 0~ & Gaa Cons C~iss~Qn Anchoraa~ 1 a. Type of Work: Drill Q Redrill 1 b. Current Well Class: Exploratory Development Oil / Multiple Zone ^ Re-entry ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone ^/ 2. Operator Name: 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1J-159 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 7857' ' TVD: 3641' Kuparuk River Field 4a. Location of Well (Governmental Se ion): b `~ 7. Property Designation: `~ g<v fJ ~• ~~ ~ ~ Surface;283'S' FSL, 2545' FEL, Sec. 35, T11 N, R10E, UM ~ ADL 25661 & 25662 West Sak Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 109' FSL, 1709' FEL, Sec. 35, T11 N, R10E, UM ~ ALK 471 & 2177 2/9/2006 Total Depth: 9. Acres in Property: 14. Distance to 2184' FNL, 1837' FEL, Sec. 2, T10N, R10E, UM 2560 Nearest Property: 8723' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to ,Nearest' Surface: x- 558664 y- 5945847 Zone- 4 (Height above GL): 28' RKB feet Well within. Pool: WSP 11 , 176' @ 4007' 16. Deviated wells: Kickoff depth: 500 ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.os5) Maximum Hole Angle: 92° deg Downhole: 1665 psig " Surface: 1257 psig '" 18. Casing Program ifi ti S Setting Depth Quantity of Cement Si ca ons pec B T tt f k ze om op o . or sac c. s Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' ' 108' • 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 2364' 28' 28' 2392' 2207' ' 470 sx ASLite, 170 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 5528' 28' 28' 5556' ~ 3698' 350 sx DeepCRETE 6.75" 4.5" 12.6# L-80 IBTM 2301' 5556' 3698' 7857' ~ 3641' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ff): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch / Drilling Program / Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~~ ~ Phone l G s" ~ $3U Date t~ 1 b/ab a d h n All u D ke Commission Use Only Permit to Drilt API Number: Permit Approval See cover letter 7 ~ Number: !._L./~ "" r~d .j y~ 50- (~x~•' ~ ~`/ ~~+U~ Date: ' . ~ a, for other requirements Conditions of approval Samples required Yes ^ No ~ Mud log required Yes ^ No Hydrogen sulfide measures Yes No ~` Directional survey required Yes ~ No ^ Other: 7~~id S`~ ~©~ "~ES~' CAS ~~~~ - ^-r . ,, . APPROVED BY a ~ ~ i ~ THE COMMISSION Date: ' Approved by: *- Form 10-401 Revised 06/2004 ` (~ ~.,,~ , ~~ i }~ ~ ], ~ Submit in Duplicate • ~ation for Permit to Drill, Well 1J-159 Revision No.O Saved: 13-Jan-06 Permit It -West Sak Well #1J-159 Application for Permit to Dri// Document well value Table of Contents 1. Well Name ................................................................................................................. 2 Re uirements of 20 AAC 25.005 ............................ 2 q (fl ........................................................................... 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................•--•-••----................-•--•-•----•--•-•--..................................... 3 3.Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) •-• ...................................................................•---........................ 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) ......................................................................•-•-•-•--................... 4 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) •---• ..................................................................•-•-•-•--................... 4 Sun`ace Hole. Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (LSND) ............................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) A/8/D sand laterals ........................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ..............................................•--•-•----•-•-•---•-•--............................. 5 10. Seismic Analysis .........................................................................................:........... 5 Requirements of 20 AAC 25.005 (c)(10).........e ...................................................................................... 5 11. Seabed Condition Analysis ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 1J-159 PERMIT IT Page 1 of 8 Printed: 13-Jan-O6 ORIGINAL • ~ation for Permit to Drill, Well 1J-159 Revision No.O Saved: 16-Jan-06 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) .............e.................................................................................. 6 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 Requirements of 20 AAC 25.005 (c) (14) ................................................................................................ 8 15. Attachments ............................................................................................................. 8 Aftachment 1 Directional Plan ............................................................................................................... 8 Aftachment 2 Drilling Hazards Summary .............................................................................................. 8 Aftachment 3 Cement Loads and CemCADE Summary ....................................................................... 8 Aftachment 4 BOP Configuration .......................................................................................................... 8 Aftachment 5 Schematic ........................................................................................................................ 8 1. Well Name Requirements of 20 AAC 25.005 (i) Each well-must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 2t1 AAC 25.040(6). For a well with mu/tip0e wel/branches, each branch must similarly be identified by a .unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1]-159. ,_--- 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the fotiowing items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at tota/depth, referenced to governmental section /roes. (S) the coordinates of the proposed location of the well at the surr`ace, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the Natianai Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 2,036' FSL, 2,545' FEL, Section 35, T11N R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109.0' AMSL Northings: 5,945,846 Eastings: 558,663 Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak "A2" Sand 109' FSL, 1,709' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB.' S, 556 Northings: 5,943,927 Eastings: 559,517 Total t/ertica/De th RKB.' 3,698 Total ~ertica/ De th, SS.' 3,589 Location at Total De th 2,184' FNL, 1,837' FEL Section 2, T10N, R10E ASPZone 4 NAD 27 Coordinates MeaSl/red De th, RKB: 7,857 Northings: 5,954,721 Eastings; 559,285 Total ~ertica/De th, RKB.• 3,641 ' Total vertical De th SS.' 3 532 1J-159 PERMIT IT Page 2 of 8 ®ry f /~ ~ ~ A ~ Printed: 16-Jan-O6 ~ation for Permit to Drill, Well 1J-159 Revision No.O Saved: 13-Jan-06 and (D) other information required by 20AAC25.050(b); Requirements of 20 AAC 25.050(b) If a we!/ is to be intentionally deviated, the application for a Permit to 13ri// (Form 10-401) must (I) include a plat, drawn to a suitable scale, showing the path of the proposed wel/bore, including a!1 adjacent wellbores within 200 feet ofany portion of the proposed we/!; Please see Attachment 1: Directional Plan and (2) for al! wel/s within 200 feet of the proposed wellbore (A) /ist the names of the operators of those we/Is, to the extent that those names are known ar discoverable in pub/ic records, and show that each named operator has been furnished a copy of the application by certr`fied mai/; or (B) state that the app/icant is the on/y affecfed owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An app/ication for a Permit to Dril/ must be accompanied by each of the following items, except for an item a/ready on Erie with the commission and identified in the app/ication; (3) a diagram and description of the b/owout prevention equipment (Bt)PE) as required by 20 AAC25.035, 20 A,4C 25.036, or 20 AAC 2s.037, as applicab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) wiN be utilized to drill and complete the well. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams iii the middle. cavity, and 7-5/8" rams in the lowermost cavity. See attached diagram entitled °Doyon 141 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). Immediately prior to running the intermediate string of 7-5/8" casing, a test plug will be set below the lowermost rams, and those rams will be closed and tested to 3,000 psi on a 7-5/8" OD. ~ ASS ,L~000 ~ ~ 4. Drilling Hazards Information P.~ - ~Q~ - ~,`r~c) r~ ~(~..vt~ Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to ©ril/ must be accompanied by each of the following items, except for an item already on fie with the commission and identified in the app/ication; (4) information on dri//ing hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW ' (equivalent mud weight). These pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak A2 sand formation is 1,281 psi, calculated thusly: MPSP =(3,699 ft TVD)(0.45 - 0.11 psi/ft) =1,257 psi (8) data on potentia/gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole prob/ems such as abnormal/y geo pressured strata, /ost circa/anon zones, and zones that have a propensity for dih`erentia/sticking; Please. see Attachment 2: Drilling Hazards Summary. 1J-159 PERMIT /T Page 3 of 8 Printed: 13-Jan-06 ORIGINAL • ~ation for Permit to Drill, Well 1J-159 Revision No.O Saved: 16-Jan-06 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the fat/owing items, except for an item already on file with the commission and identified in the application; (5) a description of the procedure for conducting formatian integrity tests, as required under 20 AAC25.030(t); 7-5/8" intermediate casing will be landed at the top of the West Sak A2 sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/ication far a Permit to Dri// must be accompanied by each of the fo/lowing items, except for an item already an fi/e with the commission and identified in the application; (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description ofany slofted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summa .~ "~ Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 20 x 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE BTC Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 special 2,181 28 / 28 2,392 /2,207 470 sx ASLite Lead, drift 170 sx DeepCRETE Tail Cement Top planned @ 7-5/8 9-7/8 29.7 L-80 BTCM 5,462 28 / 28 5,556 / 3,698 2,976' MD / 2,497' TVD. Cemented w/ 350 sx Dee CRETE 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 6,026 5,556 / 3,698 7,857 / 3,641 Slotted- no cement I Lateral(iJ-159) 4-1/2 6-3/4" B Sand 12.6 L-80 IBTM 7,113 4,588/ 3,548 11,205 / 3,474 Slotted- no cement slotted Lateral (1J-159 Ll) 4-1/2 6-3/4" D Sand 12.6 L-80 IBTM 7,521 4,285/ 3,482 10,900 / 3,399 Slotted- no cement Slotted Lateral (1J-159 L2) 7. Diverter System Information Requirements of 20 AAC 25:005(c)(7) An app/ication for a Permit to Dri/I must be accompanied by each of the fo/%wmg items, except far an item already on die with the commission and identified in the appication: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2),• f A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1J-159. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application far a Permit to Drr"l1 must be accompanied by each of the following items, except far an item already on file with the commission and identified in the application: (8) a drilling fluidprogram, including a diagram and description of the do/ling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 1J-159 PERMIT IT Page 4 of 8 ®~ ~ ~ ~ ~ ~ Printed: 16-Jan-O6 V [fl r • Surface Hole Mud Program (extended bentonite) ~ation for Permit to Drill, Well 1J-159 Revision No.O Saved: 13-Jan-06 Spud to Base of Permafrost Base of Permafrost to 10-3/4" Casin Point Initial Value Final Value Initial Value Final Value Density (ppg) 8.9 9.2 ' 9.5 9.6 Funnel viscosity 150 250 200 300 seconds Yield Point 50 70 30 50 cP Plastic Viscostiy 20 45 15 20 Ib/100 s pH 8.5 9.0 8.5 9.0 API Filtrate NC 8 0 5 0 7 0 cc / 30 min . . . *9.6 ppg if hydrates are encountered ' Intermediate Hole Mud Program (LSND) 10-3/4"Cs Shoe to 7-5/8"Cs Point Value Density (ppgJ 9.0 - 9.1 Funnel Viscosity 45 - 60 seconds Plastic Viscostiy Ib/100 s 12 - 18 Yield Point cP 26 - 35 API Filtrate cc / 30 min 4 - 6 Chlorides (mg/1) <500 pH 9.0 - 9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) A/B/D sand laterals Value Densit pp 8.6 ' Plastic Viscostiy 15 - 25 Ib/100 s Yield Point 18 - 28 cP HTHP Fluid loss (ml/30 min @ 200psi & <4.0 150° Oil /Water Ratio 70 / 30 Electrical Stability >600 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the fol/owing items, except for an item already on fr/e with the commission and identified in the app/ication: (9) for an exploratory or stratigraphic test wel% a tabulation setting out the depths ofpredicted abnorma//y geo pressured strata as required by 20 AAC25. t133(>?; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Hermit to Drill must be accompanied by each of the fo/%wing items, except for an item already on fi/e with the commission and identified in the application: (i0) for an exp/oratory or stratigraphic test we/% a seismic refraction or reflection analysis as required by 2Q AAC 25, D61(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 1J-159 PERMIT IT Page 5 of 8 Printed: 13-Jan-06 • ~ation for Permit to Drill, Well 1J-159 Revision No.O Saved: 16-Jan-06 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (IIJ for a we/l drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis ofseabed conditions as required by 20 AAC 25.06i(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Dri// must be accompanied by each of the following items, except for an item already on fi/e with the commission and identified in the application: (12) evidence showing that the requirements of20AAC25.025 ~6onding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. ' Install landing ring on conductor. 2. Move in /rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 13-1/2" hole to casing point at +/- 2,392' MD / 2,207' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 9-7/8" bit and 6-1/4"drilling assembly, with MWD, LWD & PWD.~ RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8" casing point at 5,556 MD / 3,698' TVD, the prognosed top of the A2 sand. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud to 2,719' MD / 2,498' TVD. (500' MD above top Ugnu C). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 7-5/8" packoff and test to 5000 psi. 11. Flush 10-3/4" x 7-5/8"annulus with water, followed by diesel. 12. PU 6-3/4" PDC Bit and 4-3/4"drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. (expected ECD's in 6-3/4" lateral modeled to be less than 12.0 ppg). 14. Directionally drill 6-3/4" hole to TD at +/- 7,857' MD / 3,641' TVD as per directional plan. 1J-159 PERMIT IT Page 6 of 8 Printed: 16-Jan-O6 ~~~~~~ I • ~ation for Permit to Drill, Well 1J-159 Revision No.O Saved: 13-Jan-06 15. POOH, back reaming out of lateral to 7-5/8" shoe. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 16. Run USIT log for cement bond if the well is an injector. 17. PU and run 4-1/2" slotted liner. ~ ~~~~ ~~-~`~ 18. Land liner, set liner hanger @ +/- 4,678' MD. POOH. Y\ Note: Remaining operations are covered under the 1J-159L1 Application for Permit to Drill, and are provided here for information only. 19. Run and set Baker WindowMaster whipstock system, at window point of 4,588' MD / 3,548' TVD, the top of the B sand. 20. Mill 6-3/4" window. POOH. 21. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 22. Drill to TD of B sand lateral at 11,205' MD / 3,474' TVD, as per directional plan. 23. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 24. RIH with whipstock retrieval tool. Retrieve whipstock and POOH 25. PU and run 4-1/2" slotted liner. 26. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 27. Release hanger running tool. POOH. 28. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. Note: Remaining operations are covered under the 1J-159L2 Application for Permit to Drill, and. are provided here for information only. 29. Run and set Baker WindowMaster whipstock system, at window point of 4,285' MD / 3,482' TVD, the top of the D sand. 30. Mill 6-3/4" window. POOH. 31. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 32. Drill to TD of D sand lateral at 10,900' MD / 3,399' TVD, as per directional plan. 33. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 34. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 35. PU and run 4-1/2" slotted liner. 36. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 37. Release hanger running tool. 38. POOH and lay down drill pipe. 39. RU and run a 4 1/2" ESP completion with backup gaslift. 40. Space out tubing and land tubing in tubinghead. 41. Nipple down BOPE, nipple up tree and test, change over the hole to diesel. 42. Set BPV and RDMO Doyon 141. 1J-159 PERMIT IT Page 7 of 8 Printed: 13-Jan-O6 ORIGINAL • 43. Rig up wire line unit. PuII BPV. 44. Circulate out well with diesel through the ESP. ~ation for Permit to Drill, Well 1J-159 Revision No.0 Saved: 13-Jan-06 45. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 46. Replace gas lift valves with blank dummy valves. 47. Place well on production with ESP. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c) (14) An app/ication for a Permit to Dri// must be accompanied by each of the following items, except for an item already on fi/e with the commission and identified in the application; (14J a general description of how the operator p/ans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the we/f.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on iJ Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska. may in the future. request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary Attachment 4 BOP Configuration Attachment 5 Schematic 1J-159 PERMIT IT Page 8 of 8 a ~ ~ ~ ~ ~ ~ ~ Printed: 13-Jan-06 • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-159 Plan: 1J-159 (wp06) Proposal Report 14 December, 2005 HA~..L1f3tJRTON s ~rr~ r~11~r~~ ~rwri~+~s OR161NAL ~U10¢¢'¢ p i .~SmgCYYYYmpY IOUOCQ (~W yrn (qy ~~ ~ N~ : O N# C G C M m m m m d m ~ y~ P V tC O OD J ~ ~ N 0 ~MOI NI•. ae~~r~Nmr NN a k- mWm01 a1010m mOD~tD<~O h fA ya: - yN ~ ~ M ~ f 0 ~ M \\ ~' d ~ O NOiOtity Y9NppO OlmiO •m{tO 1 d O~s Oem'/N Ymf tnC CmDNn{{IG 9D OIN(f J Q ~Nr Zr1~d' M t0 p r \4 ~' ~ ~ F ~ n, ~r NNM MMMQ V O tNN O F W p M L •' :\' i / } rn C F p pPOM VO1~ ~ r2 p r '~ : :: ~ :1: ~ Z yNm rmm ~'O+MNr0~1~ Q yNMMp~ oyy Mn~ n~~ ~ ~ L NtG 10 .'~ 2' : 01 '7 :;~ 7 p y ~,}N a~mOmO NM f. O~ NN MMMMtH ~tOMmm ? 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G 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M M (O d) ~ ~ OD N V N. h N O M M M (O M O) M ui a ~i a 'n#', Continue Buil @ 3.5i100ft , 1695ft MD, 1629ft ND Project: Kuparuk River Unit _ - - -- _ Site: Kuparuk 1J Pad Continue Build/Turn @ 5/100ft , 1994ft MD, 1873ft ND; Well: Plan 1J-159 900 Wellbore: 1J-159 (Sail @ 31°Inc & 43.7°Azi : 1545ft MD, 1500ft NDI Plan: 1J-159 (wp06) 10 314" CSG @ 2392ft MD, 2207ft NDI 600 - ti ..- "" ^ f~.- o Begin Pump Tangent @ 49° Inc : 3434ft MD, 3067ft ND o 5 300 Continue Build/Turn @ 3.5/100ft , 1067ft MD, 1061ft NDI ° ~ - 0 -~----- ~ Continue Build @ 3/100ft , 900ft MD, 898Tt TV ~ __ - -: 171° ,.--'"~ ' j End Pump Tangent - Build/Turn @ 5/100ft , 3641ft MD, 3203ft ND' -300 I Sail @ 77° Inc _ 4236ft MD, 3471ft ND J KOP @ SOOft MD, SOOft ND -Build @ 2.5°/100ft~i - 180° _ -600 - -- ...-. ~ . ~~ ~- ~ ~ -~~~--~~~~~~--~-~ ---iContinue Turn @ 1°It00ft , 4286ft MD, 3482ft ND', ~ 9D0 ~- ConotoPhillips : 1J-159 Tt-D to{, !wp06~ - _ -~ - -- ---- ---- -----------.. - ahlska _ --- -- - Sail @ 77° Inc : 4481ft MD, 3526ft ND (Continue Build @ 3.5/100ft , 4503ft MD, 3531ft NDI -1200 184° -1500 Build @ 3.5°/100ft to 86° lint - 5307ft MD, 3673ft N ._ - ~ - _ Sail @ 80° Inc : 4588ft MD, 3548ft ND -1800 w O Build @ 4°l100ft to 92° Zinc - 5499ft MD, 3695ft ND o - -'------... ~ - v @ J C.. ,-. Sail 86° Inc : 5479ft MD, 3694ft ND ~ -2100 L r _.. _. _... ~~ ~~ Z 187° L -2400 p v7 185° ~ ~~ ~ -1 ss T2 !w pne~ --__ -2700 Continue GeoSteer in Upper Lobe of A2, 5673ft MD, 3698ft ND -- CASING DETAILS t ' -3000 No ND MD Name Size 1 2207.00 2392.47 10 3/4" 10-3/4 ~ I 2 3697.99 5556.00 7 5!8" 7-5/8 ~ -3300 3 3641.00 7856.73 4 1/2" 4-1/2 !~ I w~,u~, 1` -3600 -3900 1.1- ^ ~9 T4-Toe ~wp06~ T ..... - -4200 M ... ......... ~ L- - -~~~ -- ~-- -' ' "' - BHL @ 7857ft MD, 3641ft ND Magnetic North: 24.29° i -4500 Magnetic Field ~ Strength: 57561.6nT Dip Angle: 80.76° 4 1/2" Date: 10/31 /2005 Model. BGGM2005 HALLIBURTON -4800 Sperry Drilling Services ~~ -1500 -1200 -900 -600 -300 0 300 600 900 1200 1500 1800 2100 2400 2700 s~(-)~ast(+ (600 ftlin) ~,JRiVl~vp ~i-- Project: Kuparuk River l Site: Kuparuk 1J Pad Well: Plan 1J-159 Wellbore: 1J-159 Plan: 1J-159 (wp06) LEGEND -~- Plan 1J-159, 1J-159 L1, 1J-159 L1 (wp06) VO -~ Plan 1J-159, 1J-159 L2, 1J-159 L2 (wp06) VO -B- 1J-159 (wp06) ELLBORE TARGET DETAILS {MAP CO-ORDINAT Name ND NDSS +N/S +E/ W Northing Easting Shape Fault 135 -4999.00 -5108 -4192.39 962.53 5941662.44 559658.78 Polygon Fault 35 -4999.00 -5108 -5661.63 1103.71 5940194.48 559811.39 Polygon Fault 49 - 27' DTS -4999.00 -5108 -2778.81 843.17 5943074.91 559528.42 Polygon Fault 50 X999.00 -5108 -3468.03 1759.40 5942392.91 560449.90 Polygon Fault 51 X999.00 -5108 -7879.47 664.59 5937973,50 559389.60 Polygon Fault 75 -4999.00 -5108 -9277.74 687.35 5936575.59 559423.25 Polygon 1J-159 T1-D top (wp06)3482.00 3373 -678.08 923.12 5945176.00 559592.00 Point 1J-159 T4-Toe (wp06) 3641.00 3532 -4219.88 712.51 5941633.00 559409.00 Point 1J-159 T3 (wp06) 3649.00 3540 X952.88 716.59 5941900.00 559411.00 Point 1J-159 T2 (wp06) 3674.00 3565 -2852.93 740.16 5943000.00 559426.00 Point SECTION DETAILS Sec MD Inc Azi ND NDss +N/-S +E/-W Northing Easting DLeg TFace VSec Target 1 28.00 0.000 0.00 28.00 -81 0.00 0.00 5945846.80 558663.71 0.00 0.000 0.00 2 500.00 0.000 0.00 500.00 391 0.00 0.00 5945846.80 558663.71 0.00 0.000 0.00 3 900.00 10.000 30.00 897.97 788.97 30.15 17.41 5945877.09 558680.88 2.50 30.000 ,30.15 4 1066.67 15.000 30.00 1060.64 951.64 61.38 35.44 5945908.45 558698.67 3.00 0.000 -61.38 5 1545.18 30.979 43.69 1500.00 1391 205.09 152.29 5946053.05 558814.39 3.50 25.000 -205.09 6 1695.18 30.979 43.69 1628.60 1519.6 260.92 205.62 5946109.29 558867.27 0.00 0.000 -260.92 7 1993.68 39.000 55.44 1873.24 1764.24 370.06 336.40 5946219.43 558997.19 3.50 45.000 X70.06 8 3434.34 49.004 170.52 3067.14 2958.14 47.26 871.68 5945900.85 559534.91 5.00134.058 -47.26 9 3640.98 49.004 170.52 3202.70 3093.7 -106.57 897.36 5945747.23 559561.79 0.00 0.000 106.57 10 4235.81 77.000 182.00 3470.75 3361.75 X29.39 924.82 5945224.70 559593.32 5.00 23.004 629.39 11 4285.81 77.000 182.00 3482.00 3373 -678.08 923.12 5945176.00 559592.00 0.00 0.000 678.08 1J-159 T1-D top (wp06) 12 4480.68 77.000 184.00 3525.84 3416.84 -867.69 913.19 5944986.34 559583.54 1.00 90.225 867.69 13 4502.68 77.000 184.00 3530.79 3421.79 -889.07 911.69 5944964.95 559582.21 0.00 0.000 889.07 14 4588.39 80.000 184.00 3547.88 3438.88 -972.85 905.83 5944881.13 559577.01 3.50 360.000 972.85 15 5307.39 80.000 184.00 3672.73 3563.73 -1679.20 856.44 5944174.48 559533.12 0.00 0.000 1679.20 16 5478.82 86.000 184.00 3693.61 3584.61 -1848.86 844.58 5944004.75 559522.58 3.50 0.000 1848.86 17 5498.82 86.000 184.00 3695.01 3586.01 -1868.76 843.19 5943984.84 559521.35 0.00 0.000 1868.76 18 5673.47 92.185 187.25 3697.77 3588.77 -2042.43 826.08 5943811.06 559505.59 4.00 27.750 2042.43 19 5938.40 92.185 187.25 3687.67 3578.67 -2305.06 792.67 5943548.21 559474.24 0.00 0.000 2305.06 20 5988.96 91.386 185.39 3686.09 3577.09 -2355.28 787.11 5943497.95 559469.07 4.00-113.251 2355.28 21 6488.96 91.386 185.39 3674.00 3565 -2852.93 740.16 5943000.00 559426.00 0.00 0.000 2852.93 1J-159 T2 (wp06) 22 6637.75 91.295 180.93 3670.52 3561.52 -3001.41 731.97 5942851.47 559418.97 3.00 -91.111 3001.41 23 7589.59 91.295 180.93 3649.00 3540 -3952.88 716.59 5941900.00 559411.00 0.00 0.000 3952.88 1J-159 T3 (wp06) 24 7604.10 91.728 180.87 3648.62 3539.62 -3967.39 716.36 5941885.49 559410.89 3.00 -6.840 3967.39 25 7856.74 91.728 180.87 3641.00 3532 -4219.88 712.51 5941633.00 559409.00 0.00 0.000 4219.88 1J-159 T4-Toe w 06 ANNOTATIONS ND NDss MD Annotation 28.01 -80.99 28.01 SHL @ 2036ft FSL $ 2545ft FEL -Sec 35 - T11 N - R10E ~ 500.01 391.01 500.01 KOP @ 500ft MD, 500ft ND -Build @ 2.5°/100ft 897.98 788.98 900.01 Continue Build @ 3l100ft , 900ft MD, 898ft ND 1060.65 951.65 1066.68 Continue BuildlTurn @ 3.5/100ft , 1067ft MD, 1061ft ND 1500.01 1391.01 1545.19 Sail @ 31°Inc &43.7°Azi : 1545ft MD, 1500ft ND 1628.62 1519.62 1695.19 Continue Build/Turn @ 3.5/100ft , 1695ft MD, 1629ft ND 1873.24 1764.24 1993.69 Continue Build(furn @ 5/100ft , 1994ft MD, 1873ft ND 2207.00 2098 2392.47 10 3/4" CSG @ 2392ft MD, 2207ft ND - 2484ft FSL & 2009ft FEL -Sec 35 - T11 N - R10E 3067.15 2958.15 3434.35 Begin Pump Tangent @ 49° Inc : 3434ft MD, 3067ft ND 3202.70 3093.7 3640.99 End Pump Tangent - Build/Turn @ 5/100ft , 3641ft MD, 3203ft ND 3470.76 3361.76 4235.82 Sail @ 77° Irtc : 4236ft MD, 3471ft ND 3482.00 3373 4285.82 Continue Turn @ 1 °/100ft , 4286ft MD, 3482ft ND 3525.84 3416.84 4480.69 Sail @ 77° Inc : 4481ft MD, 3526ft ND 3530.79 3421.79 4502.69 Continue Build @ 3.5/100ft , 4503ft MD, 3531ft ND 3547.88 3438.88 4588.40 Sail @ 80° Inc : 4588ft MD, 3548ft ND 3672.73 3563.73 5307.40 Build @ 3.5°/100ft to 86° lint - 5307ft MD, 3673ft ND 3693.61 3584.61 5478.83 Sail @ 86° Inc : 5479ft MD, 3694ft ND 3695.01 3586.01 5498.83 Build @ 4°/100fE to 92° lint - 5499ft MD, 3695ft ND 3697.99 3588.99 5556.00 75/8" CSG @ 5556ft MD, 3698ft ND -109ft FSL & 1709ft FEL -Sec 35 - T11 N - R10E 3697.77 3588.77 5673.48 Continue GeoSteer in Upper Lobe of A2, 5673ft MD, 3698ft ND 3641.00 3532 7856.73 BHL @ 7857ft MD, 3641ft ND : 2184ft FNL & 1837ft FEL -Sec 2 - T10N - R10E " ti-` ~ Hailiburton Energy Services ~t~~OP~11~jt ~ HALLlBURTON Planning Report -Geographic f~ask~ S~~ $rtlling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-159 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True , Well: Plan 1J-159 Survey Calculation Method: Minimum Curvature Wellbore: 1J-159 Design: 1J-159 (wp06) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zane 04 Using geodetic scale factor Well Plan 1J-159 Well Position +W-S 0.00 ft Northing: 5,945,846.80 ft ' Latitude: 70° 15' 45.551" N +E/-W 0.00 ft Easting: 558,663.71 ft ~ Longitude: 149° 31' 32.697" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft :Ilbore 1J-159 agnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 10/31/2005 24290 80.764 57,562 Design 1J-159 (wp06) Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (n) (°) 28.00 0.00 0.00 180.00 12/14/2005 4:08:16PM Page 2 of 8 COMPASS 2003.11 Build 48 r!~L • • Halliburton Energy Services ~C)Ctt3CO~hl~llp5 Planning Report -Geographic Aiaaka Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparukj Project: Kuparuk River Unit Site: Kuparuk 1J Pad WeII: Plan 1J-159 Wellbore: 1 J-159 Design: 1J-159 (wp06) fHALLIfEtUATC7N Sperry Drilling Servites Local Co-ordinate Reference: Well Plan 1J-159 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +Nl-S +E(-W Rate Rate Rate TFO (ft) (°} {°) (ft) (ft) (ft) (°l100ft) (°/100ft) (°/10pft} (°) 28.00 0.000 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.000 500.00 0.000 0.00 500.00 0.00 0.00 0.00 0.00 0.00 0.000 900.00 10.000 30.00 897.97 30.15 17.41 2.50 2.50 0.00 30.000 1,066.67 15.000 30.00 1,060.64 61.38 35.44 3.00 3.00 0.00 0.000 1,545.18 30.979 43.69 1,500.00 205.09 152.29 3.50 3.34 2.86 25.000 1,695.18 30.979 43.69 1,628.60 260.92 205.62 0.00 0.00 0.00 0.000 1,993.68 39.000 55.44 1,873.24 370.06 336.40 3.50 2.69 3.94 45.000 3,434.34 49.004 170.52 3,067.14 47.26 871.68 5.00 0.69 7.99 134.058 3,640.98 49.004 170.52 3,202.70 -106.57 897.36 0.00 0.00 0.00 0.000 4,235.81 77.000 182.00 3,470.75 -629.39 924.82 5.00 4.71 1.93 23.004 4,285.81 77.000 182.00 3,482.00 -678.08 923.12 0.00 0.00 0.00 0.000 4,480.68 77.000 184.00 3,525.84 -867.69 913.19 1.00 0.00 1.03 90.225 4,502.68 77.000 184.00 3,530.79 -889.07 911.69 0.00 0.00 0.00 0.000 4,588.39 80.000 184.00 3,547.88 -972.85 905.83 3.50 3.50 0.00 360.000 5,307.39 80.000 184.00 3,672.73 -1,679.20 856.44 0.00 0.00 0.00 0.000 5,478.82 86.000 184.00 3,693.61 -1,848.86 844.58 3.50 3.50 0.00 0.000 5,498.82 86.000 184.00 3,695.01 -1,868.76 843.19 0.00 0.00 0.00 0.000 5,673.47 92.185 187.25 3,697.77 -2,042.43 826.08 4.00 3.54 1.86 27.750 5,938.40 92.185 187.25 3,687.67 -2,305.06 792.67 0.00 0.00 0.00 0.000 5,988.96 91.386 185.39 3,686.09 -2,355.28 787.11 4.00 -1.58 -3.68 -113.251 6,488.96 91.386 185.39 3,674.00 -2,852.93 740.16 0.00 0.00 0.00 0.000 6,637.75 91.295 180.93 3,670.52 -3,001.41 731.97 3.00 -0.06 -3.00 -91.111 7,589.59 91.295 180.93 3,649.00 -3,952.88 716.59 0.00 0.00 0.00 0.000 7,604.10 91.728 180.87 3,648.62 -3,967.39 716.36 3.00 2.98 -0.36 -6.840 7,856.74 91.728 180.87 3,641.00 -4,219.88 712.51 0.00 0.00 0.00 0.000 12/14!2005 4:08:16PM Page 3 of 8 COMPASS 2003.99 Build 48 r-` ~ Hailiburton Ener Services Ct~rtc~4Phi1li 5 gy p Planning Report -Geographic Al~sk~ Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-159 Survey Calculation Method: Wellbore: 1J-159 Design: 1J-159 (wp06j HALLIBUWTC'!N Sperr}f Drilling Services Well Plan 1J-159 Planning RKB @ 109.OOft {Doyon 141 (28+81)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minirnum Curvature Planned Survey 1J-159 (wp06) Map Map MD Inclination Azimuth TVD SSTVD +W.S +EI-W Northing Easting DLS£V Vert Section (ft) (°) (°) eft) (ft) (ft) (ft) eft) (ft) (°/10Uft) (ft) 28.00 0.000 0.00 28.00 -81.00 0.00 0.00 5,945,846.80 558,663.71 0.00 0.00 SHL @ 2036ft FSL 8 2 545ft FEL -Sec 35 - T11N - 810E ~ 100.00 0.000 0.00 100.00 -9.00 0.00 0.00 5,945,846.80 558,663.71 0.00 0.00 200.00 0.000 0.00 200.00 91.00 0.00 0.00 5,945,846.80 558,663.71 0.00 0.00 300.00 0.000 0.00 300.00 191.00 0.00 0.00 5,945,846.80 558,663.71 0.00 0.00 400.00 0.000 0.00 400.00 291.00 0.00 0.00 5,945,846.80 558,663.71 0.00 0.00 500.00 0.000 0.00 500.00 391.00 0.00 0.00 5,945,846.80 558,663.71 0.00 0.00 KOP @ 500ft MD, 500ft TVD -Build @ 2.5°l100ft 600.00 2.500 30.00 599.97 490.97 1.89 1.09 5,945,848.70 558,664.79 2.50 -1.89 700.00 5.000 30.00 699.75 590.75 7.55 4.36 5,945,854.39 558,668.01 2.50 -7.55 800.00 7.500 30.00 799.14 690.14 16.98 9.80 5,945,863.85 558,673.38 2.50 -16.98 900.00 10.000 30.00 897.97 788.97 30.15 17.41 5,945,877.09 558,680.88 2.50 -30.15 Continue B uild @ 3l100ft , 900ft M D, 898ft TVD 1,000.00 13.000 30.00 995.95 886.95 47.42 27.38 5,945,894.42 558,690.71 3.00 -47.42 1,066.67 15.000 30.00 1,060.64 951.64 61.38 35.44 5,945,908.45 558,698.67 3.00 -61.38 Continue BuildlTurn @ 3.5/100ft , 1067ft MD, 106 1ft TVD 1,100.00 16.065 31.78 1,092.75 983.75 69.04 40.03 5,945,916.14 558,703.19 3.50 -69.04 1,200.00 19.328 35.96 1,188.01 1,079.01 94.20 57.04 5,945,941.44 558,720.01 3.50 -94.20 1,300.00 22.660 38.96 1,281.36 1,172.36 122.59 78.88 5,945,969.98 558,741.62 3.50 -122.59 1,400.00 26.033 41.23 1,372.46 1,263.46 154.08 105.46 5,946,001.68 558,767.96 3.50 -154.08 1,500.00 29.435 43.00 1,460.96 1,351.96 188.56 136.69 5,946,036.40 558,798.92 3.50 -188.56 1,545.18 30.979 43.69 1,500.00 1,391.00 205.09 152.29 5,946,053.05 558,814.39 3.50 -205.09 Sail @ 31°inc 843.7°Azi : 1545ft MD, 15008 TVD 1,584.83 30.979 43.69 1,534.00 1,425.00 219.85 166.39 5,946,067.92 558,828.37 0.00 -219.85 Permafrost 1,600.00 30.979 43.69 1,547.00 1,438.00 225.50 171.79 5,946,073.61 558,833.72 0.00 -225.50 1,695.18 30.979 43.69 1,628.60 1,519.60 260.92 205.62 5,946,109.29 558,867.27 0.00 -260.92 Continue Buildfrurn @ 3.5/1008 , 1695ft MD, 1629ft TVD 1,700.00 31.098 43.92 1,632.74 1,523.74 262.72 207.34 5,946,111.10 558,868.98 3.50 -262.72 1,716.69 31.515 44.70 1,647.00 1,538.00 268.92 213.40 5,946,117.35 558,874.99 3.50 -268.92 T3 1,800.00 33.663 48.37 1,717.19 1,608.19 299.74 245.98 5,946,148.42 558,907.33 3.50 -299.74 1,900.00 36.367 52.24 1,799.10 1,690.10 336.32 290.15 5,946,185.34 558,95121 3.50 -336.32 1,993.68 39.000 55.44 1,873.24 1,764.24 370.06 336.40 5,946,219.43 558,997.19 3.50 -370.06 Continue B uild/Turn @ 5/100ft , 1994ft MD,1873ft TVD 2,000.00 38.781 55.80 1,878.15 1,769.15 372.30 339.68 5,946,221.70 559,000.44 4.99 -372.30 2,077.92 36.178 60.57 1,940.00 1,831.00 397.32 379.91 5,946,247.03 559,040.47 5.00 -397.32 K15 2,100.00 35.477 62.03 1,957.90 1,848.90 403.53 391.24 5,946,253.32 559,051.76 5.00 -403.53 2,200.00 32.547 69.28 2,040.82 1,931.82 426.67 442.06 5,946,276.86 559,102.39 5.00 =426.67 2,300.00 30.102 77.68 2,126.28 2,017.28 441.54 491.75 5,946,292.12 559,151.96 5.00 -441.54 2,392.47 28.382 86.48 2,207.00 2,098.00 447.84 536.37 5,946,298.77 559,196.52 5.00 -447.84 10 3f4" CSG @ 2392ft M D, 2207ft TVD - 2484ft FSL 8 2009ft FEL -Sec 35 - T11 N - 810E - T3+550 -10 3/4" 2,400.00 28.268 87.23 2,213.63 2,104.63 448.04 539.93 5,946,298.99 559,200.09 4.99 -448.04 12/14/2005 4:08:16PM Page 4 of 8 ORIGINAL COMPASS 2003.118ui1d 48 ~ r' Halliburton Ener Services 9Y HALLIBtJRTI'~N ~~~~~~~ '~ Planning Report -Geographic :~iaska S~Serr}t flrilling Servlc®s Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-159 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-159 Survey Calculation Method: Minimum Curvature Wellbore: 1J-159 Design: 1J-159 (wp06) Planned Survey 1J-159 (wp06) Map Map MD Inclination Azimuth TVD SSTVD +NI-S +E!-W Northing Easting DLSEV Vert Section ~ftl (°) (°) (ft1 (ft) eft) (ft) eft) (ft) (°1100ft) eft) 2,500.00 27.172 97.73 2,302.20 2,193.20 446.11 586.24 5,946,297.42 559,246.40 5.00 -446.11 2,600.00 26.903 108.73 2,391.33 2,282.33 435.76 630.32 5,946,287.42 559,290.56 5.00 -435.76 2,700.00 27.487 119.61 2,480.33 2,371.33 .417.08 671.84 5,946,269.06 559,332.21 5.00 -417.08 2,800.00 28.871 129.80 2,568.53 2,459.53 390.21 710.47 5,946,242.49 559,371.05 5.00 -390.21 2,900.00 30.948 138.93 2,655.25 2,546.25 355.35 745.93 5,946,207.91 559,406.78 5.00 -355.35 3,000.00 33.588 146.90 2,739.84 2,630.84 312.76 777.95 5,946,165.58 559,439.13 5.00 -312.76 3,100.00 36.669 153.75 2,821.64 2,712.64 262.78 806.29 5,946,115.83 559,467.85 5.00 -262.78 3,200.00 40.088 159.63 2,900.05 2,791.05 205.78 830.72 5,946,059.02 559,492.72 5.00 -205.78 3,219.64 40.793 160.69 2,915.00 2,806.00 193.79 835.04 5,946,047.08 559,497.13 5.00 -193.79 Ugnu C 3,300.00 43.765 164.71 2,974.46 2,865.46 142.19 851.06 5,945,995.60 559,513.55 5.00 -142.19 3,400.00 47.637 169.13 3,044.30 2,935.30 72.51 867.16 5,945,926.05 559,530.19 5.00 -72.51 3,434.34 49.004 170.52 3,067.14 2,958.14 47.26 871.68 5,945,900.85 559,534.91 5.00 -47.26 Begin Pump Tangent @ 49° Inc : 3434ft M D, 30 67ft TVD 3,500.00 49.004 170.52 3,11021 3,001.21 -1.62 879.84 5,945,852.04 559,543.45 0.00 1.62 3,560.65 49.004 170.52 3,150.00 3,041.00 -46.77 887.38 5,945,806.95 559,551.34 0.00 46.77 Ugnu B 3,600.00 49.004 170.52 3,175.81 3,066.81 -76.06 892.27 5,945,777.70 559,556.46 0.00 76.06 3,640.98 49.004 170.52 3,202.70 3,093.70 -106.57 897.36 5,945,747.23 559,561.79 0.00 106.57 End Pump Tangent - BuildlTurn @ 5/100ft , 3641ft MD, 3203ft TVD 3,670.82 50.380 171.28 3,222.00 3,113.00 -129.04 900.96 5,945,724.79 559,565.56 5.00 129.04 Ugnu A 3,700.00 51.729 171.99 3,240.34 3,131.34 -151.49 904.26 5,945,702.37 559,569.03 5.00 151.49 3,800.00 56.385 174.24 3,299.03 3,190.03 -231.84 913.91 5,945,622.10 559,579.31 5.00 231.84 3,893.99 60.795 176.15 3,348.00 3,239.00 -311.75 920.59 5,945,542.26 559,586.61 5.00 311.75 K13 3,900.00 61.077 176.27 3,350.92 3,241.92 -317.00 920.94 5,945,537.02 559,587.00 4.99 317.00 4,000.00 65.797 178.11 3,395.63 3,286.63 -406.31 925.29 5,945,447.75 559,592.05 5.00 406.31 4,100.00 70.538 179.82. 3,432.81 3,323.81 -499.09 926.94 5,945,354.99 559,594.42 5.00 499.09 4,200.00 75.293 181.44 3,462.18 3,353.18 -594.64 925.87 5,945,259.45 559,594.09 5.00 594.64 4,235.81 77.000 182.00 3,470.75 3,361.75 -629.39 924.82 5,945,224.70 559,593.32 5.00 629.39 Sail @ 77° I nc : 4236ft MD, 3471ft TVD 4,285.81 77.000 182.00 3,482.00 3,373.00 -678.08 923.12 5,945,176.00 559,592.00 0.00 678.08 Continue Turn @ 1°/100ft , 4286ft MD, 3482ft TVD -West Sak D -1J-759 T1-D top (wp06) 4,300.00 76.999 182.15 3,485.19 3,376.19 -691.90 922.62 5,945,162.18 559,591.61 1.00 691.90 4,400.00 76.998 183.17 3,507.69 3,398.69 -789.23 918.10 5,945,064.82 559,587.85 1.00 789.23 4,472.50 77.000 183.92 3,524.00 3,415.00 -859.73 913.74 5,944,994.30 559,584.03 1.00 859.73 West Sak C 4,480.68 77.000 184.00 3,525.84 3,416.84 -867.69 913.19 5,944,986.34 559,583.54 1.00 867,69 Sail @ 77° I nc : 4481ft MD, 3526ft TVD 4,500.00 77.000 184.00 3,530.19 3,421.19 -886.46 911.87 5,944,967.55 559,582.37 0.00 886.46 4,502.68 77.000 184.00 3,530.79 3,421.79 -889.07 911.69 5,944,964.95 559,582.21 0.00 889.07 Continue B uild @ 3.5/100ft , 4503ft MD, 3531ft TVD 12/14/2005 4:08:16PM Page 5 of 8 COMPASS 2003.11 Build 48 `!l q k. ~~~~ ~' ~ Halliburton Ener Services r ~~r>~~coPhill~ ~ gy Iws+-u..[elu~r~n~~ Planning Report -Geographic Alaska .Sperry DrillitYg Ssrvices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-159 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-159 Survey Calculation Method: Minimum Curvature Wel Ibore: 1 J-159 Design: 1J-159 (wp06) Planned Survey 1J-159 (wp06) Map Map MD Inclination Azimuth TVD SSTVD +W-S +E/-W Northing Easting DLSEV Vert Section lft) (°) (°) (ft) (ft) 1ft) 1ft1 (ft) (ft) (°/100ft) (ft) 4,588.39 80.000 184.00 3,547.88 3,438.88 -972.85 905.83 5,944,881.13 559,577.01 3.50 972.85 Sail @ 80° Inc : 4588ft MD, 3548ft ND 4,600.00 80.000 184.00 3,549.89 3,440.89 -984.25 905.04 5,944,869.73 559,576.30 0.00 984.25 4,600.62 80.000 184.00 3,550.00 3,441.00 -984.86 904.99 5,944,869.11 559,576.26 0.00 984.86 West Sak B 4,700.00 80.000 184.00 3,567.26 3,458.26 -1,082.49 898.17 5,944,771.44 559,570.20 0.00 1,082.49 4,800.00 80.000 184.00 3,584.62 3,475.62 -1,180.73 891.30 5,944,673.16 559,564.09 0.00 1,180.73 4,819.45 80.000 184.00 3,588.00 3,479.00 -1,199.84 889.96 5,944,654.04 559,562.91 0.00 1,199.84 West Sak A4 4,900.00 80.000 184.00 3,601.99 3,492.99 -1,278.97 884.43 5,944,574.88 559,557.99 0.00 1,278.97 5,000.00 80.000 184.00 3,619.35 3,510.35 -1,377.21 877.56 5,944,476.60 559,551.89 0.00 1,377.21 5,038.29 80.000 184.00 3,626.00 3,517.00 -1,414.83 874.93 5,944,438.97 559,549.55 0.00 1,414.83 West Sak A3 5,100.00 80.000 184.00 3,636.72 3,527.72 -1,475.45 870.69 5,944,378.32 559,545.78 0.00 1,475.45 5,200.00 80.000 184.00 3,654.08 3,545.08 -1,573.70 863.82 5,944,280.03 559,539.68 0.00 1,573.70 5,300.00 80.000 184.00 3,671.45 3,562.45 -1,671.94 856.95 5,944,181.75 559,533.58 0.00 1,671.94 5,307.39 80.000 184.00 3,672.73 3,563.73 -1,679.20 856.44 5,944,174.48 559,533.12 0.00 1,679.20 Build @ 3.5°/100ft to 86° line - 5307ft MD, 3673ft ND 5,400.00 83.240 184.00 3,686.22 3,577.22 -1,770.58 850.05 5,944,083.06 559,527.45 3.50 1,770.58 5,478.82 86.000 184.00 3,693.61 3,584.61 -1,848.86 844.58 5,944,004.75 559,522.58 3.50 1,848.86 Sail @ 86° Inc : 5479ft MD, 3694ftND 5,498.82 86.000 184.00 3,695.01 3,586.01 -1,868.76 843.19 5,943,984.84 559,521.35 0.00 1,868.76 Build @ 4°/100ft to 92° lint - 5499ft M D, 3695ft TVD 5,500.00 86.041 184.02 3,695.09 3,586.09 -1,869.93 843.10 5,943,983.67 559,521.27 3.93 1,869.93 5,556.00 88.025 185.07 3,697.99 3,588.99 -1,925.68 838.67 5,943,927.90 559,517.28 4.00 1,925.68 7 518" CSG @ 5556ft M D, 3698ft ND -109ft FSL & 1709ft FEL -Sec 35 - T11 N - R10E -West Sak A2 - 7 518" 5,600.00 89.582 185.88 3,698.91 3,589.91 -1,969.47 834.48 5,943,884.08 559,513.42 4.00 1,969.47 5,673.47 92.185 187.25 3,697.77 3,588.77 -2,042.43 826.08 5,943,811.06 559,505.59 4.00 2,042.43 Continue GeoSteer in Upper Lobe of A2, 5673ft MD, 3698ft ND 5,700.00 92.185 187.25 3,696.76 3,587.76 -2,068.74 822.73 5,943,784.73 559,502.45 0.00 2,068.74 5,800.00 92.185 187.25 3,692.95 3,583.95 -2,167.87 810.12 5,943,685.52 559,490.62 0.00 2,167.87 5,900.00 92.185 187.25 3,689.13 3,580.13 -2,266.99 797.52 5,943,586.31 559,478.79 0.00 2,266.99 5,938.40 92.185 187.25 3,687.67 3,578.67 -2,305.06 792.67 5,943,548.21 559,474.24 0.00 2,305.06 5,988.96 91.386 185.39 3,686.09 3,577.09 -2,355.28 787.11 5,943,497.95 559,469.07 4.00 2,355.28 6,000.00 91.386 185.39 3,685.83 3,576.83 -2,366.27 786.08 5,943,486.95 559,468.12 0.00 2,366.27 6,100.00 91.386 185.39 3,683.41 3,574.41 -2,465.80 776.68 5,943,387.36 559,459.51 0.00 2,465:80 6,200.00 91.386 185.39 3,680.99 3,571.99 -2,565.33 767.29 5,943,287.77 559,450.89 0.00 2,565.33 6,300.00 91.386 185.39 3,678.57 3,569.57 -2,664.86 757.90 5,943,188.18 559,442.28 0.00 2,664.86 6,400.00 91.386 185.39 3,676.15 3,567.15 -2,764.39 748.51 5,943,088.59 559,433.66 0.00 2,764.39 6,488.96 91.386 185.39 3,674.00 3,565.00 -2,852.93 740.16 5,943,000.00 559,426.00 0.00 2,852.93 1J-159 T2 (wp06) 6,500.00 91.380 185.06 3,673.73 3,564.73 -2,863.92 739.15 5,942,989.00 559,425.08 2.99 2,863.92 6,600.00 91.319 182.06 3,671.38 3,562.38 -2,963.69 732.95 5,942,889.20 559,419.65 3.00 2,963.69 6,637.75 91.295 180.93 3,670.52 3,561.52 -3,001.41 731.97 5,942,851.47 559,418.97 3.00 3,001.41 6,700.00 91.295 180.93 3,669.11 3,560.11 -3,063.64 730.96 5,942,789.24 559,418.44 0.00 3,063.64 12/14/2005 4:08:16PM Page 6 of 8 COMPASS 2003.11 Build 48 e21~INa~ ~' ~ Halliburton Ener Services ~~toPhttii ~ 9Y Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-159 Wellbore: 1 J-159 Design: 1J-159 (wp06) Local Co-ordinate Reference: Well Plan 1J-159 HALLIBUF~iTCYN 5)~[ry Detllling Services TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 1J-159 (wp06) Map Map MD Inclination Azimuth TVD SSTVD +N!-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 6,800.00 91.295 180.93 3,666.85 3,557.85 -3,163.60 729.34 5,942,689.28 559,417.61 0.00 3,163.60 6,900.00 91.295 180.93 3,664.59 3,555.59 -3,263.56 727.73 5,942,589.32 559,416.77 0.00 3,263.56 7,000.00 91.295 180.93 3,662.33 3,553.33 -3,363.52 726.11 5,942,489.36 559,415.93 0.00 3,363.52 7,100.00 91.295 180.93 3,660.07 3,551.07 -3,463.49 724.50 5,942,389.40 559,415.10 0.00 3,463.49 7,200.00 91.295 180.93 3,657.81 3,548.81 -3,563.45 722.88 5,942,289.43 559,414.26 0.00 3,563.45 7,300.00 91.295 180.93 3,655.55 3,546.55 -3,663.41 721.27 5,942,189.47 559,413.42 0.00 3,663.41 7,400.00 91.295 180.93 3,653.29 3,544.29 -3,763.37 719.65 5,942,089.51 559,412.59 0.00 3,763.37 7,500.00 91.295 180.93 3,651.03 3,542.03 -3,863.33 718.03 5,941,989.55 559,411.75 0.00 3,863.33 7,589.59 91.295 180.93 3,649.00 3,540.00 -3,952.88 716.59 5,941,900.00 559,411.00 0.00 3,952.88 1J-159 T3 (wp06) 7,600.00 91.606 180.89 3,648.74 3,539.74 -3,963.29 716.42 5,941,889.59 559,410.92 3.00 3,963.29 7,604.10 91.728 180.87 3,648.62 3,539.62 -3,967.39 716.36 5,941,885.49 559,410.89 3.00 3,967.39 7,700.00 91.728 180.87 3,645.73 3,536.73 -4,063.24 714.90 5,941,789.65 559,410.17 0.00 4,063.24 7,800.00 91.728 180.87 3,642.71 3,533.71 -4,163.18 713.37 5,941,689.71 559,409.42 0.00 4,163.18 7,856.74 91.728 180.87 3,641.00 3,532.00 -4,219.88 712.51 5,941,633.00 559,409.00 0.00 4,219.88 . SHL @ 7857ft MD, 364 1ft TVD : 2184ft FNL & 1837ft FEL -Sec 2 - T10N - R10E - 41/2" -1J-159 T4-Tce (wp06) Geologic Targets 1J- 159 TVD Tar get Name +N/-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,482.00 1J-159 T 1-D top (wp06) -678.08 923.12 5,945,176.00 559,592.00 - Point 3,649.00 1J-159 T3 (wp06) -3,952.88 716.59 5,941,900.00 559,411.00 - Point 3,674.00 1J-159 T2 (wp06) -2,852.93 740.16 5,943,000.00 559,426.00 - Pant 3,641.00 1J-159 T4-Toe (wp06) -4,219.88 712.51 5,941,633.00 559,409.00 - Point Prognosed Casing Points Measured Depth (ft) 2,392.47 5,556.00 7,856.73 Vertical Casing Hole Depth Diameter Diameter 2, 207.00 10-3/4 13-112 3,697.99 7-518 9-7/8 3,641.00 4-1/2 6-314 12/14/2005 4:08:16PM Page 7 of 8 COMPASS 2003.11 Buitd 48 ~~~~~~~ r•' ~ Halliburton Ener Services ~~r~dP~tllli ~ 9Y HALLII3U~tTGh1. - Planning Report -Geographic A1~5ka Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-159 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft {Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft {Doyon 141 {28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-159 Survey Calculation Method: Minimum Curvature Wellbore: 1J-159 Design: 1J-159 (wp06) Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +W-E +E/-W (ft) (°) (°) (ft) (ft) (ft) Name 1,584.83 30.98 43.69 1,534.00 219.85 166.39 Permafrost 1,716.69 31.52 44.70 1,647.00 268.92 213.40 T3 2,077.92 36.18 60.57 1,940.00 397.32 379.91 K15 2,392.47 28.38 86.48 2,207.00 447.84 536.37 T3+550 3,219.64 40.79 160.69 2,915.00 193.79 835.04 Ugnu G 3,560.65 49.00 170.52 3,150.00 -46.77 887.38 Ugnu B 3,670.82 50.38 171.28 3,222.00 -129.04 900.96 Ugnu A 3,893.99 60.79 176.15 3,348.00 -311.75 920.59 K13 4,285.81 77.00 182.00 3,482.00 -678.08 923,12 West Sak D 4,472.50 77.00 183.92 3,524.00 -859.73 913.74 West Sak C 4,600.62 80.00 184.00 3,550.00 -984.86 904,99 West Sak B 4,819.45 80.00 184.00 3,588.00 -1,199.84 889.96 West Sak A4 5,038.29 80.00 184.00 3,626.00 -1,414.83 874.93 West Sak A3 5,556.00 88.02 185.07 3,697.99 -1,925.68 838.67 West Sak A2 12/94/2005 4:08:16PM Page 8 of 8 COMPASS 2003, J 9 Build 48 ~,~ ~~ • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-159 Anticollision Summary 14 December, 2005 • i~rry ~r~1~~ng rv~~ ORIGINAL ~Clf'~C?CCI~'~"'l1~~1 ~ Alasl<<a Company: ConocoPhillips Alask a (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Welt: Plan 1J-159 Well Ertor: O.OOft Reference Wellbore 1J-159 Reference Design: 1J-159 (wp06) Halliburton Energy Services Anticoliision Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: t4AL~.IBURTON Sperry Drilling 5ervl~es Well Plan 1 J-159 Planning RKB @ 109.OOft (Doyon 141 (28+81)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Reference Datum Reference 1J-159(wp06) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referen Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 982.87ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma iurvey Tool Program Date 12/14/2005 From To (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 800.00 1J-159 (wp06) (1J-159} CB-GYRO-SS Camera based gyro single shot 800.00 7,856.74 1J-159 (wp06) (1J-159) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min cenVe to center distance or covergent pant, SF -min separation factor, ES -min ellipse separation 12/14/2005 4:39:26PM Page 2 of 5 COMPASS 2003.11 Bu>7d 48 ORIGINAL llafe: 2005-12-14700:00:00 \'alldafed: 4'es \'erei°n: ~ From Uepth Te Smtiry~Plan Tuol 28.00 800.00 1J-159 (ap06) (B-G11t0-SS 800.0[1 7856.7) I.1-159 (np06) \1\\D+I}1LAli-CAZSC Plan 1J-157 270 Plan 1J-156- Plan 1J-160 Plan 1J-101 1 J-164 Plan 1 = rom Colour To MD 28 250 250 500 500 750 WSP-15 ' 1aD , Plan 1J-112 Kuparuk Prelim 7so 1000 loon 1250 WSP-20 Plan 1J-166~~ .WSP-02 1250 1500 1500 1750 1750 2000 Travelling Cylinder Azimuth (TFO+AZI) [° ~ vs Centre to Centre Separation [75 ft/in] 2000 2250 2250 2500 2500 2750 2750 3000 3000 3250 3250 3500 REFERENCE INFORMATION 3500 4000 Coordinate (N/E) Reference: Well Plan iJ-159, True North 4000 5000 Vertical (ND) Reference: Planning RKB @ 109.ODh (Doyon 141 (28+g1)) 5000 6000 Section (VS) Reference: Slot - (O.OON, O.ODE) 6000 7000 Measured Depth Reference: Planning RKB @ 109.00(1 (Doyon 141 (28+81)) Calculation Method: Minimum Curvature 7000 8000 NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-159 ANTI-COLLISION SETTINGS Ground Level: 81.00 Interpolation Method: MD Interval: 50Statlons +NI-S +E/-W Northing Easting Lafittude Longitude Slat iJ-759 Depth Range From: 28.00 To 7858.74 0.00 0.00 5945648.80 558863.71 70°15'45.557N 149°3f'32.697W Maximum Range:982.87 Reference: Plan: 1J-159 (wp06) 240 330 30 Plan 1J-158. ~ 25 / _~~~ 2 107 300 ~ -'-~ 60 1 I-03 Plan 1J-109 - 27n _ _!, Plan 1J-111 90 Plan 1J-160 ConocoPhi7lips Alaska (Kuparuk) Drilling & Wells West Sak Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based ~~ 90 z1o 1so 30 _ _ _ 180 - - - -WSP-1 S Travelling C~•linder Azimuth (TFOrAZI) [°] Vs Centre to Centre Separation X15 ft/in] SECTION DETAILS Sec MD Inc Azi ND +N!-S +E/-W DLeg TFace VSec Target 1 28.00 0.000 0.00 28.00 0.00 0.00 0.00 0.000 0.00 2 500.00 0.000 0.00 500.00 0.00 0.00 0.00 0.000 0.00 3 900.0010.000 30.00 897.97 30.15 17.41 2.50 30.000 -30.15 4 1066.6715.OD0 30.001060.64 61.38 35.44 3.00 0.000 -61.38 5 1545.1630.979 43.69 1500.00 205.09 152.29 3.50 25.000 -205.09 6 1695.1830.979 43.691628.60 260.92 205.62 0.00 0.000 -260.92 7 1993.6839.000 55.44 1873.24 370.06 336.40 3.50 45.000 -370.06 8 3434.3449.004 170.52 3067.14 47.26 871.68 5.00134.058 -47.26 9 3640.9849.004 170.52 3202.70 -106.57 897.36 0.00 0.000 106.57 10 4235.8177.000 162.00 3470.75 -629.39 924.62 5.00 23.004 629.39 11 4285.8177.000 182.00 3482.00 -678.08 923.12 0.00 0.000 678.08 1J-159 T1-D top (wp06) 124480.6677.000 184.00 3525.84 -867.69 913.19 1.00 90.225 867.69 134502.6877.000 164.00 3530.79 -869.07 911.69 0.00 0.000 689.07 144588.3980.000 184.00 3547.88 -972.85 905.63 3.50360.000 972.85 155307.3980.000 184.00 3672.73-1679.20 856.44 0.00 0.000 1679.20 16 5478.8286.000 184.00 3693.61 -1848.86 844.56 3.50 0.000 1848.86 17 5498.8286.000 164.00 3695.01 -1868.76 643.19 0.00 0.000 1668.76 185673.4792.185 187.25 3697.77.2042.43 626.08 4.00 27.750 2042.43 19 5938.4092.185 187.25 3687.67.2305.06 792.67 0.00 0.000 2305.06 205988.9691.386 185.39 3686.09-2355.28 787.11 4.00113.251 2355.28 21 6488.9691.386 185.39 3674.00-2652.93 740.16 0.00 0.000 2852.93 1J-159 T2 (wp06) 226637.7591.295 180.93 3670.52.3001.41 731.97 3.00.91.111 3001.41 23 7589.5991.295 180.93 3649.00.3952.88 716.59 0.00 0.000 3952.88 1J-159 T3 (wp06) 247604.1091.728 180.87 3648.62-3967.39 716.36 3.00 -fi.840 3967.39 257856.7491.728 180.87 3641.00-4219.88 712.51 0.00 0.000 4219.88 1J-159 T4-Toe(wp06) Plan 1J-152 T 1J-09 ~C)1"1iJ~C~p~"ll~ ~x ~J5 P.lalk~i • Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-159 Well Error: O.OOft Reference Wellbore 1J-159 Reference Design: 1J-159(wp06) Halliburton Energy Services HALLIBU~tTt7N Anticollision Report ~°~~ ~~~~~°°~-~--~~~~ ~~L~~'rY Clr~i~rg 5eev3c+~~ Local Co-ordinate Reference: Well Plan 1J-159 TVD Reference: Planning RKB @ 109.OOft(Doyon 141 (28+81)) M D Reference: Planning RKB @ 109.OOft (Doyon 141 {28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM 2003.11 Single User Db Offset TVD Reference: Reference Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellbore -Design {ft) (ft) (ft) (ft) Kuparuk 1J Pad 1J-03 - 1J-03 - 1J-03 142.88 150.00 146.03 2.52 143.51 Pass -Major Risk 1J-09 - 1J-09 - 1J-09 293.93 300.00 120.50 5.37 115.13 Pass -Major Risk 1J-10 - 1J-10 - 1J-10 544.08 550.00 39.47 10.07 29.39 Pass -Major Risk 1J-154 - 1J-154 - 1J-154 Rig 758.64 750.00 105.78 16.49 89.29 Pass -Major Risk 1J-154 - 1J-154 L1 - 1J-154 L1 758.64 750.00 105.78 16.49 89.29 Pass -Major Risk 1J-154 - 1J-154 L2 - 1J-154 L2 758.64 750.00 105.78 16.49 8929 Pass -Major Risk 1J-164 - 1J-164 - 1J-164 Rig 1,312.54 1,350.00 86.75 25.46 61.30 Pass -Major Risk 1J-164 - 1J-164 L1 - 1J-164 L1 1,312.54 1,350.00 86.75 25.46 61.30 Pass -Major Risk 1J-164 - 1J-164 L2 - 1J-164 L2 28.00 28.00 119.59 1.01 118.58 Pass -Major Risk 1J-168 - 1J-168 - 1J-168 Rig 399.85 400.00 201.56 8.66 192.90 Pass -Major Risk 1J-168 - 1J-168 L1 - 1J-168 L1 Rig 399.85 400.00 201.57 8.66 192.91 Pass -Major Risk 1J-168 - 1J-168 L2 - 1J-168 L2 399.85 400.00 201.57 8.66 192.91 Pass -Major Risk 1J-168 - 1J-168 L2 P61 - 1J-168 l2 PB1 Rig 399.85 400.00 201.57 8.66 192.91 Pass -Major Risk Plan 1J-101 -Plan 1J-101 - 1J-101 Rig 1,598.48 1,550.00 79.49 31.56 47.94 Pass -Major Risk Plan 1J-102 - 1J-102 -1J-102 (wp03) 1,560.04 1,450.00 194.86 28.94 165.92 Pass -Major Risk Plan 1J-102 - 1J-102 L1 - 1J-102 L1 (wp03) 1,560.04 1,450.00 194.86 28.85 166.00 Pass -Major Risk Plan 1J-102 - 1J-102 L2 - 1J-102 L2 (wp03) 1,560.04 1,450.00 194.86 28.85 166.00 Pass -Major Risk Plan 1J-103 -Plan 1J-103 - 1J-103 (wp01) BHI 777.33 750.00 222.82 16.44 206.38 Pass -Major Risk Plan 1J-105 -Plan 1J-105 - 1J-105 (wp01) BHI 450.99 450.00 189.56 9.55 180.01 Pass -Major Risk Plan 1J-107 -Plan 1J-107 - 1J-107 (wp01) BHI 350.99 350.00 167.20 7.33 159.87 Pass -Major Risk Plan 1J-109 - 1J-109 L1 (N Gullwing) - 1J-109 L1 (~ 287.99 300.00 147.81 6.38 141.44 Pass -Major Risk Plan 1J-109 -Plan 1J-109 - 1J-109 (wp03) (S Gully, 287.99 300.00 147.81 6.38 141.44 Pass -Major Risk Plan 1J-111 -Plan 1J-111 - 1J-111 (wp01) 350.99 350.00 148.15 7.02 141.13 Pass -Major Risk Plan 1J-112 Kuparuk Prelim - 1J-12 E Lateral - 1J-1 1,142.37 1,150.00 134.08 23.25 110.83 Pass -Major Risk Plan 1J-112 Kuparuk Prelim - 1J-12 Pilot - 1J-12 Pil 1,142.37 1,150.00 134.08 23.25 110.83 Pass -Major Risk Plan 1J-112 Kuparuk Prelim -Plan 1J-12 W Lateral 1,142.37 1,150.00 134.08 23.25 110.83 Pass -Major Risk Plan 1J-115 -Plan 1J-115 -1J-115 (wp01) 551.63 550.00 177.37 10.99 166.38 Pass -Major Risk Plan 1J-118 -Plan 1J-118 -Plan 1J-118 (wp01) 450.99 450.00 217.05 8.99 208.06 Pass -Major Risk Plan 1J-120 -Plan 1J-120 - 1J-120 (wp01) 450.99 450.00 248.25 8.98 239.27 Pass -Major Risk Plan 1J-127 -Plan 1J-127 - 1J-127 (wp01) 2,876.95 2,850.00 215.40 57.23 158.17 Pass -Major Risk Plan 1J-137 - 1J-137 -1J-137 (wp03) 350.99 350.00 559.55 7.38 552.17 Pass -Major Risk Plan 1J-137 - 1J-137 L1 - 1J-137 L1 (wp03) 350.99 350.00 559.55 7.38 552.17 Pass -Major Risk Plan 1J-150 {Ugnu Disposal) -Plan 1J-UgnuDispos 350.99 350.00 200.84 6.75 194.09 Pass -Major Risk Plan 1J-152 - 1J-152 - 1J-152 (wp04) 349.99 350.00 160.85 7.58 153.27 Pass -Major Risk Plan 1J-152 - 1J-152 L1 - 1J-152 L1 (wp04) 349.99 350.00 160.85 7.58 153.27 Pass -Major Risk Plan 1J-152 - 1J-152 L2 - 1J-152 L2 {wp04) 349.99 350.00 160.85 7.58 153.27 Pass -Major Risk Plan 1J-156 -Plan 1J-156 - 1J-156 (wp02) 550.26 550.00 62.39 13.16 49.23 Pass -Major Risk Plan 1J-158 - 1J-158 - 1J-158 (wp2A) BHI 300.99 300.00 20.41 5.86 14.54 Pass -Major Risk Plan 1J-159 - 1J-159 L1 - 1J-159 L1 (wp06) 4,600.00 4,600.00 0.19 1.58 -1.39 FAIL - No Errors Plan 1J-159 - 1J-159 L2 - 1J-159 L2 (wp06) 4,299.98 4,299.98 0.27 1.57 -1.30 FAIL - No Errors Plan 1J-160 -Plan 1J-160 - 1J-160 (wp01) BHI 399.73 400.00 19.60 8.66 10.94 Pass -Major Risk Plan 1J-162 - 1J-162 - 1J-162 {wp03.1-North Heel) 499.52 500.00 77.88 10.72 67.16 Pass -Major Risk Plan 1J-162 -1J-162 L1 - 1J-162 L1 (wp3.1) 499.52 500.00 77.88 10.62 67.26 Pass -Major Risk Plan 1J-162 -1J-162 L2 - 1J-162 L2 (wp3.1) 499.52 500.00 77.88 10.62 67.26 Pass -Major Risk Plan 1J-166 - 1J-166 - 1J-166 {wp07) 547.59 550.00 160.29 11.88 148.40 Pass -Major Risk Plan 1J-166 -1J-166 L1 - 1J-166 L1 (wp07) 547.59 550.00 160.29 11.88 148.40 Pass -Major Risk Plan 1J-166 - 1J-166 L2 - 1J-166 L2 (wp07) 547.59 550.00 160.29 11.88 148.40 Pass -Major Risk Plan 1J-170 -Plan 1J-170 - 1J-170 (wp02) 449.89 450.00 241.37 10.97 230.40 Pass -Major Risk WSP-02 -WSP-02 -WSP-02 1,309.65 1,300.00 134.23 26.81 107.42 Pass -Major Risk WSP-03 -WSP-03 -WSP-03 1,163.94 1,150.00 176.34 27.92 148.42 Pass -Major Risk WSP-04 -WSP-04 -WSP-04 991.15 1,000.00 210.63 20.62 190.01 Pass -Major Risk WSP-05 -WSP-05 -WSP-05 881.89 900.00 259.44 24.01 235.44 Pass -Major Risk WSP-09 -WSP-09 -WSP-09 3,983.93 3 500.00 237.20 92.47 144.73 Pass - Major Risk CC -Min centre to center distance or covergent pant, SF -min separation factor, ES -min ellipse separation 12114/2005 4:39:26PM Page 4 of 5 COMPASS 2003.11 Budd 48 ORIGINAL Haiiiburton Energy Services '~~~~~~~~~~ Anticollision Repast Al~tsk~ Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-159 Well Error: O.OOft Reference Wellbore 1J-159 Reference Design: 1J-159 (wp06) Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TYD Reference: HALLIBURTON __ _.,-~ Sperry brillir~g S~etviiCe~ Well Plan 1 J-159 Planning RKB @ 109.OOft (Doyon 141 (28+81)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Reference Datum Summary Site Name Offset Well - Wellbore -Design Kuparuk 1J Pad WSP-11 -WSP-11 -WSP-11 WSP-13 -WSP-13 -WSP-13 WSP-15 -WSP-15 -WSP-15 WSP-1S -WSP-1S -WSP-1S WSP-20 -WSP-20 -WSP-20 Reference Offset Centre to Measured Measured Centre Depth Depth Distance (ft) (ft) (ft) 4,006.94 3,500.00 176.38 4,472.71 3,600.00 268.81 1,412.42 1,400.00 76.39 1,477.88 1,450.00 24.13 600.00 600.00 128.48 No-Go Allowable Distance Deviation Warning (ft) from Plan (ft) 95.29 81.09 Pass -Major Risk 101.39 167.43 Pass -Major Risk 32.18 44.21 Pass -Major Risk 1.01 23.12 Pass -Minor 1/10 14.96 113.51 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 92/14/2005 4:39.~26PM Page 5 of 5 COMPASS 2003.11 Bind 48 ORIGINAL 1J-159 ~illin Hazards momma (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 9-7/8" Oaen Hole / 7-5/8" Casino Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud wei ht Abnormal Reservoir Low BOP training and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates mud rheolo ,LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo ,LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling. (use of trip sheets , um in out, backreamin 1J-159 Drilling Hazards Summary 1/16/2006 9:07 AM • CemCADE Preliminary Job Design 10 3/4" Surface Casing ~eliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client:. ConocoPhillips Alaska, Inc. Revision Date: 1/9/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Sulfiace Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,591' MD (1,539' TVD) Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 1,635' MD. Lead Slurry Minimum pump time: 200 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.3644 ft3/ft x (80') x 1.00 (no excess) = 109.2 ft3 0.3637 ft3/ft x (1591' - 80') x 3.50 (250% excess) = 1923.4 ft3 0.3637 ft3/ft x (1635' - 1591') x 1.35 (35% excess) = 21.6 ft3 109.2 ft3 + 1923.4 ft3+ 21.6 ft3 = 2054.2 ft3 2054.2 ft3 / 4.45 ft3/sk = 461.6 sks Round up to 470 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 150 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.3637 ft3/ft x (2385' - 1635') x 1.35 (35% excess) = 368.2 ft3 0.5400 ft3/ft x 80' (Shoe Joint) _ 43.2 ft3 368.2 ft3 + 43.2 ft3 = 411.4 ft3 411.4 ft3/ 2.47 ft3/sk = 166.6 sks Round up to 170 sks BHST = 47°F, Estimated BHCT = 64°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbll (mini < Top of Tail at 1,635' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 2,385' MD (2,200' TVD) Mark of Schlumberger CW100 5.0 10.0 20 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL 7.0 365.9 52.3 85.6 DeepCRETE 6.0 73.3 12.2 97.8 Drop top plug 0.0 0.0 5.0 102.8 Water 5.0 20.0 4.0 106.8 Switch to rig 0.0 0.0 5.0 111.8 Mud 7.0 192.7 27.5 139.3 Slow & bump plug 3.0 9.0 3.0 142.3 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 17-21, TY ? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. OR161NAL ~ • CemCADE Preliminary Job Design 7-5/8" Intermediate Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 1/12/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com Previous Csg. ' < 10 3/4", 45.5# casing at 2,385' MD < Top of Tail at 2,719' MD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 5,556' MD (3,697' TVD) Schlamberger Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above top hydrocarbon bearing zone - (2837' MD annular length). Tail Slurrv Minimum thickening time: 170 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.2148 ft3/ft x 2837' x 1.25 (25% excess) = 761.7 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 761.7 ft3 + 20.6 ft3 = 782.3 ft3 782.3 ft3/ 2.25 ft3/sk = 347.7 sks Round up to 350 sks BHST = 87°F, Estimated BHCT = 74°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 50.0 10.0 35.0 DeepCRETE 5.0 139.3 27.9 62.9 Drop top plug 0.0 0.0 5.0 67.9 Water 5.0 20.0 4.0 71.9 Switch to rig 0.0 0.0 5.0 76.9 Mud 6.0 222.4 37.1 114.0 Slow & bump plug 3.0 9.0 3.0 117.0 MUD REMOVAL Recommended Mud Properties: 8.9 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH* II, Pv ? 19-22, TY ? 22-29 Centralizers: Recommend 1 '/ per joint across West Sak zones and 1 per joint across Ugnu zones to asist in efficient mud removal OR161NAL Drill String Valves To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Annular ~ To be tested to 250 psi and 1,500 psi at initial installation and every 14 days thereafter. 13-5 Double Ram Upper Rams: 3-'/z' to 6" variables To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Lower Rams: Blind To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Choke and Kill Line Valves < To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Single Ram v Rams to fit Intermediate Casing: 7-5/8" or 9-5/8" ~- To be tested to 250 psi and 3,000 psi only before running casing. ~ Wellhead Valves tested to 3,000 psi upon assembly ..~ Doyon ~ 4~ West Sak 3 kSl 13-5 BOP 3K Sheet 1 of ~ ~onOCOPh[ip~s BOP Configuration prepared by Steve B//12004 AIaSI{a OR161dAL Tubing String 4-112" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift Camco 4.112" X 1" KBMG, Gas Recombination Camco 4.1/2" X 1" KBMG 10.314" 66# Casing Shoe, set @ 2392' MD, 2207' TVD Bottom of Motor Centralizer Centralift 418 HP KMHFER 2610 / 98 D-sand Window at 4285' MD, 3482'TVD Casing Sealbore Receptacle .- 4.75"ID 4-112" X 7-518" Model 'B' HOOK Hancer Seal Bore 3.68" ID 4-112" 12.6# T 4-112" 12.6# LAO Slotted Liner Every Joint ~ 3-112" Bent Joint 1 ~ 3-112" Guide Shoe 4.112" Liner Shoe, 12.6#, L-80 IBTM Set @ 10901' MD, 3399' TVD 4-112" X 7-5/8" Model 'B' HOOK Hanger 5-112" X 7-518" ZXP Liner Top Packer with Hold Downs Assembly .~--- 5-112" X 7-516" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID - Tubing Swivel, 4-1/2" - Orienting Profile Automatic Alignment of LEM - Positive Latching Collet Indicates Correct Location ~ Seal Bore for Lateral Isolation - 3.68" ID ~ Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID Conoc Phillips West Sak 7-5/8" Producer 1 J-159 Tri-Lateral Completion 'D' Sand Lateral Lateral Entry Module(LEM) Orienting Profile B-sand Window 'g' Sand Lateral at 4586' MD, 3548' TVD 4-112" 12.6# L-80 Slotted As Planned Baker Oil Tools Late ral Entr~Module (LEMI With Diverters and Isolation lateral Access Diverter Lateral isolation Diverter GS Running Tool Stnng Installetl Installetl (3.00" Lateral Drifl) (2.50" ID Mainbore Drill) 'GS' Profile for Coil Connector yy rRUnning/Retrieving ~( ~ (1.00' Length) t I! I ~ Snap lNSnap Out / Positive Locating ti i.a~6ack Pressure Valve ~ Collet ( (1.80' Length) ; ~i ' i ; Lateral Isolation ~~ i .~ Flow•Thru Swivel '' 'I Ij heals (1.23'Length) ,\ ~ 4--:I fLMeral Diverter Mytlraulic Ramp ~ l ti / M i bore I 50' Length) ( _ ~ so on a n a Diverter Sleeve GS Spear ~.50' Length) ~ - Lateral Isolation ~- ~ Seals ', 8.85 ft Approx. GAL- ~ '~ ~ 'Jars may be r¢quNetl in highly deviatetl 18.3' Diverter Length 16.5' Sleeve Length - or tleep applications (8' approx lengt h). LI Eery Jo t 3-112" Bent Joint r 3-112" Guide Shoe --=ara~.J.~ - 4-112" Liner Shoe, 12.6#, L-80 IBTM Set @ 11205' MD, 3472' TVD 3.562" DB Nipple 5.112" X 7-518" ZXP '~ Liner Top Packer with Hold Downs 5-112" X 7-518" Flex Lock Liner Hanger I Packer Assembly at Liner Hange / +!- 4700' MD Casing Sealbore Receptacle, 4.75 1~ ®Baker Hughes 2005. This tlocumanl may nol be reproducatl or dleldbuled, In whole or In pert, In awYjpra by any means etectronle or mechanical, Including photocopying, recording, or by any Information storage and Mrleval syatsm now known or heraeflar Invanlad, wlthoul wratsn parrnisalon from Baksr Hughes Inc. Seal Assembly 4.75" Seal OD 3.a7s"ID '~' SanA llnrlulatinn I ateral 4-1 /2" 12.6# L-80 Slotted Liner Every Joint 4-t12"Eccentric / ,Guide Shoe Eauioment Saecifications 4-112" X 7-5I8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter; 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 4-112" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation sleeve: 2.50" \ateral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve: +l- 3.89" Diverter and Sleeve Length: +/- 18.5' 4.112" Casing Shoe, 12.6#, L-80 Set @ 7857' MD, 3641' TVD Shoe, Set at 2006 Wast Bek'1-518" Trl-lateral Completion -Protlueer ONe: Ornwn By Rwklon NO.: January t6, 2005 Merc D. Kuck 1 No.: Ol: • • • • ~ ~ ~ ~ N ~ v~ T .= S T N (~\\) ~=o ~ s V ~ \ji '~ N ,. Q ~ J ~ ~ i ~. N ~ . \. /~ o W ~ 'S ~'. ~ a ~ o rv o ~ l 1 0 ( ^~ ~..J ~ A `J a ~ i r ~ ~ ti Q' [~- ~ Q. .a [~- w ~ . Y ~ ~~ ~ ~ ~' ~ ~ ~ d (/) Q ~~ ~ (n o ~ ~ ~ Z .-a rn a m L Y ,~ ~~ ~ ~~ + J J Y ti = ro LJ"I Q= Q ~ ~ ~ ~ Yapo c7 ~L= .a Z ch a L U G ,,. ~p~mp rWZ-LLp o~ m'~ S QZO~U °W ~ c o E o' J 2 O ~- o ~ cnUQ~Q ao ~dU w • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~ ~~~ ~=~ ~ ~~` Development Service Exploratory Stratigraphic Test Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) 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 / infect 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 SAMPLE in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 1/05/06 C:\jody\transmittal_checklist ~ i ^^ : ~,: : m o , o: t: , : a~ °- ° ° . - ; , a~ ~ ~: , ~ ~ ~ o>: c ~ c : ~ °~ °: 3 O °: a -~: g. ~: ~ : ~ V!' ~: O as a N' N. c C~ ~ rn v; O a ~ c o ' t v, ~ ~ ~, c. n ~, co a ~ O 3 o. ° . ~ m. o' a C E O f6' c: Oy a o tn, o O oS a N ~ ~ N ~' ' 7 f6 ° rn m: ~: ; o T 4 4 Q: , ,~: io ~ O(O: Q O: 00: ~, a O ~ O. i O: ~ 'O , ~: C I o ° 3. ~ m. °° m: O coo ~: , - , Q. -°~ (d Q ~ 07 3, o: N o a. p ~ 'T t T ~: v. ~: ~ ~: o: -o, a a~: v: n ~ rn = °, m ~, o c : , ~: : a m: ~ io ~: ~ a c. 'T w: ~: : I _: ~, 3: i~ ~ Y c o o, `: ~ ~ a, ~ Z: U, ~ ~ ° N ~ u w a~ ° c: c. ~: ~: ~: > o m ~ ° ~ C , : , Q O ~ O, a O, ~: ~, ~C, ~ ~ ~ ~ ~~ N O . ~ N: ~ ~ O ~: o a o Z ~ ~ ° ~ , ~, o: o~ ~, : ~: ~ r: o~ a ~ ~: -o, v i v ~ ~ ~: ~: ~ ~, , O ~, ~, y: N: $ a i; ~ o: v; ?, a i ~ a N O ~: N: ~: ~: a ~ O: N: U, O: ~, y. ~, C N ~ Z ~' ~. 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O: O, ~ o` a u ~ ' ' ' ~ «° .N ~, a~: ~ a~: a~: c, o: D U c a, -~: ~, ~, ~, ~, v~, _, O, O, n., a; U ~: Q, a; Q, U, cn, U, U, U, U. ~C, _, Q: _, ~; m, m, U; , ~ , ~ , ~' o., ~; cn, cn, U W n ~ ~ ~ r ~~ ~~ _ N N _ M M M M M ~ ~ -_. N - M~ ~ M ~ W O ~ ~ . . . N N N N N N N N M M M M M U __ ._ .- __._ ._ ____ _ , _ , _ ~ U O o O 0 O ~ 0 O ~• C C N N N U ~ W y ~ ~ ~ ~ C O ~- _ I ~ O ~ OO N N O a ~ `~ ~ _ ~ ~ ~ ° ..~ N N C d ' ~ 01 c7 E O o ( W a a w ~ ~ Q o U ~ a ¢ a • • 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 Tending information, information of this nature is accumulated at the end of the rile under APPENDIX. No special effort has been made to chronologically organize this category of information. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed May 31 10:06:14 2006 Reel Header Service name ......... ....LISTPE Date ................ .....06/05/31 Origin .............. .....STS Reel Name ........... .....UNKNOWN Continuation Number. .....01 Previous Reel Name.. .....UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name ........ .....LISTPE Date ................ .....06/05/31 Origin .............. .....STS Tape Name ........... .....UNKNOWN Continuation Number. .....01 Previous Tape Name.. .....UNKNOWN Comments ............ .....STS LIS Writing Library Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW0004212091 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD ao~~ ~ ~393t Scientific Technical Services Scientific Technical Services 1J-159 PB1 500292329770 ConocoPhillips Alaska, Inc. Sperry Drilling Services 31-MAY-06 MWD RUN 3 MWD RUN 4 MW0004212091 MW0004212091 P. ORTH P. ORTH D. GLADDEN D. GLADDEN 35 11N l0E 2035 2545 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2365.0 2ND STRING 6.750 7.875 5574.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD) 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE • • PRESENTED. 4. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 2,3 ALSO INCLUDED COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTIC CALIPER (ACAL). MWD RUN 4 ALSO INCLUDED AT-BIT INCLINATION (ABI) . 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-4 REPRESENT WELL 1J-159 PB1 WITH API#: 50-029-23297-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5808'MD/3693'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE LITHOLOGY, ACAL-DERIVED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. ACAL = ACOUSTIC CALIPER. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (9.875" BIT) MUD WEIGHT: 9.0-9.2 PPG MUD SALINITY: 150-300 PPM CHLORIDES FORMATION WATER SALINITY: 11000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/31 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD • • Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2325.5 5744.0 NPHI 2345.0 5484.0 FONT 2345.0 5484.0 NCNT 2345.0 5484.0 DRHO 2345.0 5497.5 PEF 2345.0 5497.5 RPM 2345.0 5751.0 RPS 2345.0 5751.0 FET 2345.0 5751.0 RPX 2345.0 5751.0 RPD 2345.0 5751.0 RHOB 2345.0 5497.5 ROP 2370.5 5808.0 GALA 2371.5 5487.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2325.5 4773.0 3 4773.0 5580.0 4 5580.0 5808.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GALA MWD INCH 4 1 68 4 2 FONT MWD CNTS 4 1 68 8 3 NCNT MWD CNTS 4 1 68 12 4 RHOB MWD G/CM 4 1 68 16 5 DRHO MWD G/CM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPX MWD OHMM 4 1 68 36 10 FET MWD HOUR 4 1 68 40 11 GR MWD API 4 1 68 44 12 PEF MWD BARN 4 1 68 48 13 ROP MWD FT/H 4 1 68 52 14 NPHI MWD PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2325.5 5808 4066.75 6966 2325.5 5808 GALA MWD INCH 8.87 12.76 10.1583 5986 2371.5 5487 FONT MWD CNTS 443 3635 784.181 6279 2345 5484 NCNT MWD CNTS 102867 181631 122677 6279 2345 5484 RHOB MWD G/CM 1.299 2.88 2.13747 6306 2345 5497.5 DRHO MWD G/CM -0.886 0.601 0.0915966 6306 2345 5497.5 RPD MWD OHMM 0.64 2000 34.7307 6813 2345 5751 RPM MWD OHMM 0.06 2000 21.0037 6813 2345 5751 RPS MWD OHMM 0.54 1652.4 12.656 6813 2345 5751 RPX MWD OHMM 0.42 1652.42 11.6598 6813 2345 5751 FET MWD HOUR 0.19 113.21 2.69504 6813 2345 5751 GR MWD API 19.79 120.37 71.5088 6838 2325.5 5744 PEF MWD BARN 0.01 10.09 2.00298 6306 2345 5497.5 ROP MWD FT/H 0.09 481.14 159.228 6876 2370.5 5808 NPHI MWD PU-S 2.95 83.67 35.522 6279 2345 5484 First Reading For Entire File..........2325.5 Last Reading For Entire File...........5808 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/31 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .......... ...STSLIB.002 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...06/05/31 Maximum Physical Record..65535 File Type ............. ...LO Previous File Name.... ...STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit r un in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2325.5 4727 .0 PEF 2345.0 4692 .5 FET 2345.0 4719 .0 RPX 2345.0 4719 .0 NPHI 2345.0 4679 .0 DRHO 2345.0 4692 .5 FCNT 2345.0 4679 .0 NCNT 2345.0 4679 .0 RHOB 2345.0 4692 .5 RPD 2345.0 4719 .0 RPM 2345.0 4719 .0 RPS 2345.0 4719 .0 ROP 2370.5 4773 .0 GALA 2371.5 4682 .0 LOG HEADER DATA DATE LOGGED: 18-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4773.0 TOP LOG INTERVAL (FT) 2370.0 BOTTOM LOG INTERVAL (FT) 4773.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 25.9 MAXIMUM ANGLE: 81.9 • TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 157645 CTN COMP THERMAL NEUTRON 1844674407370955 ALD Azimuth. Litho-Den 186328 ACAL Acoustic Caliper 727422 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....DOwn Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 9.875 2365.0 Fresh Water Gel 9.00 51.0 8.9 250 5.0 2.900 65.0 1.950 100.0 3.000 65.0 5.000 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD020 INCH 4 1 68 4 2 FCNT MWD020 CNTS 4 1 68 8 3 NCNT MWD020 CNTS 4 1 68 12 4 RHOB MWD020 G/CM 4 1 68 16 5 DRHO MWD020 G/CM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 RPM MWD020 OHMM 4 1 68 28 8 RPS MWD020 OHMM 4 1 68 32 9 RPX MWD020 OHMM 4 1 68 36 10 FET MWD020 HOUR 4 1 68 40 11 GR MWD020 API 4 1 68 44 12 PEF MWD020 BARN 4 1 68 48 13 ROP MWD020 FT/H 4 1 68 52 14 NPHI MWD020 PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2325.5 4773 3549.25 4896 2325.5 4773 GALA MWD020 INCH 8.87 12.76 10.1435 4376 2371.5 4682 FCNT MWD020 CNTS 443 3635 755.409 4669 2345 4679 NCNT MWD020 CNTS 102867 1 81631 119916 4669 2345 4679 RHOB MWD020 G/CM 1.299 2.88 2.12692 4696 2345 4692.5 i • DRHO MWD020 G/CM -0.886 0.601 0.10985 4696 2345 4692.5 RPD MWD020 OHMM 0.64 2000 29.357 4749 2345 4719 RPM MWD020 OHMM 0.77 1749.02 15.5537 4749 2345 4719 RPS MWD020 OHMM 0.54 1136.14 13.529 4749 2345 4719 RPX MWD020 OHMM 0.42 1440.52 12.3938 4749 2345 4719 FET MWD020 HOUR 0.19 113.21 2.03744 4749 2345 4719 GR MWD020 API 19.79 117.61 66.5542 4804 2325.5 4727 PEF MWD020 BARN 0.01 10.09 2.00743 4696 2345 4692.5 ROP MWD020 FT/H 0.09 481.14 171.719 4806 2370.5 4773 NPHI MWD020 PU-S 2.95 83.67 36.2224 4669 2345 4679 First Reading For Entire File..........2325.5 Last Reading For Entire File...........4773 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/31 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/31 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 4679.5 5484.0 NCNT 4679.5 5484.0 FCNT 4679.5 5484.0 GALA 4682.5 5487.0 DRHO 4693.0 5497.5 RHOB 4693.0 5497.5 PEF 4693.0 5497.5 RPX 4719.5 5526.5 RPM 4719.5 5526.5 RPD 4719.5 5526.5 FET 4719.5 5526.5 RPS 4719.5 5526.5 GR 4727.5 5534.0 ROP 4773.5 5580.0 LOG HEADER DATA DATE LOGGED: 19-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5580.0 TOP LOG INTERVAL (FT) 4773.0 BOTTOM LOG INTERVAL (FT) 5580.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.2 MAXIMUM ANGLE: 89.0 • TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 157655 EWR4 ELECTROMAG. RESIS. 4 145654 CTN COMP THERMAL NEUTRON 1844674407370955 ALD Azimuth. Litho-Den 10507541 ACAL Acoustic Caliper 728187 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type..... 0 Logging Direction ................. DOwn Optical log depth units........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 9.875 2365.0 Fresh Water Gel 9.00 51.0 8.9 250 5.0 3.000 65.0 2.020 105.8 3.500 65.0 3.250 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GALA MWD030 INCH 4 1 68 4 2 FCNT MWD030 CNTS 4 1 68 8 3 NCNT MWD030 CNTS 4 1 68 12 4 RHOB MWD030 G/CM 4 1 68 16 5 DRHO MWD030 G/CM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 RPM MWD030 OHMM 4 1 68 28 8 RPS MWD030 OHMM 4 1 68 32 9 RPX MWD030 OHMM 4 1 68 36 10 FET MWD030 HOUR 4 1 68 40 11 GR MWD030 API 4 1 68 44 12 PEF MWD030 BARN 4 1 68 48 13 ROP MWD030 FT/H 4 1 68 52 14 NPHI MWD030 PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4679.5 5580 5129.75 1802 4679.5 5580 GALA MWD030 INCH 8.87 11.68 10.1984 1610 4682.5 5487 FCNT MWD030 CNTS 660 1289 867.62 1610 4679.5 5484 NCNT MWD030 CNTS 115930 145871 130684 1610 4679.5 5484 RHOB MWD030 G/CM 1.67 2.56 2.16824 1610 4693 5497.5 DRHO MWD030 G/CM -0.073 0.258 0.0383565 1610 4693 5497.5 RPD MWD030 OHMM 4.67 23.88 10.6298 1615 4719.5 5526.5 RPM MWD030 OHMM 4 27.38 9.78394 1615 4719.5 5526.5 RPS MWD030 OHMM 3.61 1652.4 10.5164 1615 4719.5 5526.5 RPX MWD030 OHMM 3.33 1652.42 9.99108 1615 4719.5 5526.5 FET MWD030 HOUR 0.29 14.96 1.72794 1615 4719.5 5526.5 GR MWD030 API 52.57 109.03 83.9579 1614 4727.5 5534 PEF MWD030 BARN 1 4.54 1.99002 1610 4693 5497.5 ROP MWD030 FT/H 0.62 240.09 126.368 1614 4773.5 5580 NPHI MWD030 PU-S 19.54 43.99 33.4906 1610 4679.5 5484 First Reading For Entire File..........4679.5 Last Reading For Entire File...........5580 File Trailer Service name .......... ...STSLIB.003 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...06/05/31 Maximum Physical Recor d..65535 File Type ............. ...LO Next File Name........ ...STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/31 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 5527.0 5751.0 RPX 5527.0 5751.0 RPD 5527.0 5751.0 FET 5527.0 5751.0 RPS 5527.0 5751.0 GR 5534.5 5744.0 ROP 5580.5 5808.0 LOG HEADER DATA DATE LOGGED: 21-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5808.0 TOP LOG INTERVAL (FT) 5580.0 BOTTOM LOG INTERVAL (FT) 5808.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.4 MAXIMUM ANGLE: 94.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 EWR4 Electromag Resis. 4 162742 S v BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value .......................-999 Depth Units ....................... Datum Specification Block sub-type...0 6.750 5574.0 Mineral Oil Base 8.85 96.0 .0 37000 3.0 000 .0 000 90.0 000 .0 000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5527 5808 5667.5 563 5527 5808 RPD MWD040 OHMM 1.33 2000 178.255 449 5527 5751 RPM MWD040 OHMM 0.06 2000 119.004 449 5527 5751 RPS MWD040 OHMM 4.89 47.25 11.1184 449 5527 5751 RPX MWD040 OHMM 0.5 22.93 9.89855 449 5527 5751 FET MWD040 HOUR 0.32 52.09 13.1289 449 5527 5751 GR MWD040 API 29.98 120.37 80.3391 420 5534.5 5744 ROP MWD040 FT/H 7.54 444.78 143.896 456 5580.5 5808 First Reading For Entire File..........5527 Last Reading For Entire File...........5808 File Trailer Service name............ Service Sub Level Name.. Version Number.......... Date of Generation...... Maximum Physical Record. .STSLIB.004 .1.0.0 .06/05/31 .65535 • • File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/05/31 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN. Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/05/31 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ~0~-005 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue May 30 12:19:46 2006 Reel Header Service name ........ .....LISTPE Date ................ .....06/05/30 Origin .............. .....STS Reel Name ........... .....UNKNOWN Continuation Number. .....01 Previous Reel Name.. .....UNKNOWN Comments ............ .....STS LIS Writing Library Tape Header Service name ........ .....LISTPE Date ................ .....06/05/30 Origin .............. .....STS Tape Name ............ ....UNKNOWN Continuation Number. .....01 Previous Tape Name.. .....UNKNOWN Comments ............. ....STS LIS Writing Library Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW0004212091 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: D. GLADDEN MWD RUN 5 JOB NUMBER: MW0004212091 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Scientific Technical Services Scientific Technical Services 1J-159 500292329700 ConocoPhillips Alaska, Inc. Sperry Drilling Services 30-MAY-06 MWD RUN 3 MWD RUN 4 MW0004212091 MW0004212091 P. ORTH P. ORTH D. GLADDEN D. GLADDEN 35 11N l0E 2035 2545 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2365.0 2ND STRING 6.750 7.875 5574.0 3RD STRING PRODUCTION STRING REMARKS: ~ t3°~~~ 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE • • NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-159 PB1 WELLBORE AT 5620'MD/3695'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 2,3 ALSO INCLUDED COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTIC CALIPER (ACAL) MWD RUNS 4,5 ALSO INCLUDED AT-BIT INCLINATION (ABI) POROSITY DATA ARE PRESENTED FOR THE 1J-159 PB1 WELLBORE ONLY. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-5 REPRESENT WELL 1J-159 WITH API#: 50-029-23297-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7857'MD/3642'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2325.5 7792.5 RPD 2345.0 7800.0 RPS 2345.0 7800.0 RPM 2345.0 7800.0 FET 2345.0 7800.0 RPX 2345.0 7800.0 ROP 2370.5 7857.0 # • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 4 MWD 5 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2325.5 4773.0 4773.0 5580.0 5580.0 5620.0 5620.5 7857.0 Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....DOwn Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2325.5 7857 5091.25 11064 2325.5 7857 RPD MWD OHMM 0.64 2000 29.0449 10911 2345 7800 RPM MWD OHMM 0.06 2000 20.0046 10911 2345 7800 RPS MWD OHMM 0.54 1652.4 14.474 10911 2345 7800 RPX MWD OHMM 0.42 1652.42 13.6633 10911 2345 7800 FET MWD HOUR 0.19 113.21 1.93316 10911 2345 7800 GR MWD API 19.79 117.61 70.4452 10935 2325.5 7792.5 ROP MWD FT/H 0.09 559.78 167.825 10974 2370.5 7857 First Reading For Entire File..........2325.5 Last Reading For Entire File...........7857 File Trailer Service name ........... ..STSLIB.001 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..06/05/30 Maximum Physical Record ..65535 File Type .............. ..LO Next File Name......... ..STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 Maximum Physical Record..65535 • File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2325.5 4727.0 RPD 2345.0 4719.0 RPM 2345.0 4719.0 RPX 2345.0 4719.0 RPS 2345.0 4719.0 FET 2345.0 4719.0 ROP 2370.5 4773.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined 18-FEB-06 Insite 68.18 Memory 4773.0 2370.0 4773.0 25.9 81.9 TOOL NUMBER 216265 157645 9.875 2365.0 Fresh water Gel 9.00 51.0 8.9 250 5.0 2.900 65.0 1.950 100.0 3.000 65.0 5.000 65.0 • Frame Spacing .. .......... ... ......60 .lIN Max frames per record .... ... ......Undefined Absent value ... .......... ... ......-999 Depth Units .... .......... ... ...... Datum Specifica tion Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2325.5 4773 3549.25 4896 2325.5 4773 RPD MWD020 OHMM 0.64 2000 29.357 4749 2345 4719 RPM MWD020 OHMM 0.77 1749.02 15.5537 4749 2345 4719 RPS MWD020 OHMM 0.54 1136.14 13.529 4749 2345 4719 RPX MWD020 OHMM 0.42 1440.52 12.3938 4749 2345 4719 FET MWD020 HOUR 0.19 113.21 2.03744 4749 2345 4719 GR MWD020 API 19.79 117.61 66.5542 4804 2325.5 4727 ROP MWD020 FT/H 0.09 481.14 171.719 4806 2370.5 4773 First Reading For Entire File..........2325.5 Last Reading For Entire File...........4773 File Trailer Service name ........... ..STSLIB.002 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..06/05/30 Maximum Physical Record ..65535 File Type .............. ..LO Next File Name......... ..STSLIB.003 Physical EOF File Header Service name ........... ..STSLIB.003 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..06/05/30 Maximum Physical Record ..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 4719.5 5526.5 FET 4719.5 5526.5 RPM 4719.5 5526.5 RPD 4719.5 5526.5 RPS 4719.5 5526.5 GR 4727.5 5534.0 ROP 4773.5 5580.0 LOG HEADER DATA • • DATE LOGGED: 19-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5580.0 TOP LOG INTERVAL (FT) 4773.0 BOTTOM LOG INTERVAL (FT) 5580.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.2 MAXIMUM ANGLE: 89.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 157655 EWR4 ELECTROMAG. RESIS. 4 145654 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2365.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 51.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3) 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.000 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.020 105.8 MUD FILTRATE AT MT: 3.500 65.0 MUD CAKE AT MT: 3.250 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4719.5 5580 5149.75 1722 4719.5 5580 RPD MWD030 OHMM 4.67 23.88 10.6298 1615 4719.5 5526.5 RPM MWD030 OHMM 4 27.38 9.78394 1615 4719.5 5526.5 RPS MWD030 OHMM 3.61 1652.4 10.5164 1615 4719.5 5526.5 RPX MWD030 OHMM 3.33 1652.42 9.99108 1615 4719.5 5526.5 FET MWD030 HOUR 0.29 14.96 1.72794 1615 4719.5 5526.5 GR MWD030 API 52.57 109.03 83.9579 1614 4727.5 5534 ROP MWD030 FT/H 0.62 240.09 126.368 1614 4773.5 5580 First Reading For Entire File..........4719.5 Last Reading For Entire File...........5580 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name........... Service Sub Level Name. Version Number......... Date of Generation..... Maximum Physical Record File Type .............. Previous File Name..... Comment Record FILE HEADER .STSLIB.009 .1.0.0 .06/05/30 .65535 .LO .STSLIB.003 FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 5527.0 5620.0 FET 5527.0 5620.0 RPM 5527.0 5620.0 RPX 5527.0 5620.0 RPD 5527.0 5620.0 GR 5534.5 5620.0 ROP 5580.5 5620.0 LOG HEADER DATA DATE LOGGED: 21-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5620.0 TOP LOG INTERVAL (FT) 5580.0 BOTTOM LOG INTERVAL (FT) 5620.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.4 MAXIMUM ANGLE: 94.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 EWR4 Electromag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5574.0 • BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 • Mineral Oil Base 8.85 96.0 .0 37000 3.0 000 .0 000 90.0 000 .0 000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5527 5620 5573.5 187 5527 5620 RPD MWD040 OHMM 1.33 2000 411.753 187 5527 5620 RPM MWD040 OHMM 0.06 2000 272.482 187 5527 5620 RPS MWD040 OHMM 6.83 47.25 15.3849 187 5527 5620 RPX MWD040 OHMM 0.5 22.93 13.0418 187 5527 5620 FET MWD040 HOUR 0.63 52.09 30.6214 187 5527 5620 GR MWD040 API 29.98 77.87 58.6291 172 5534.5 5620 ROP MWD040 FT/H 7.54 444.78 131.478 80 5580.5 5620 First Reading For Entire File..........5527 Last Reading For Entire File.......:...5620 File Trailer Service name .......... ...STSLIB.004 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...06/05/30 Maximum Physical Record..65535 File Type ............. ...LO Next File Name........ ...STSLIB.005 Physical EOF e • File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 5620.5 7800.0 ROP 5620.5 7857.0 RPX 5620.5 7800.0 RPS 5620.5 7800.0 RPD 5620.5 7800.0 GR 5620.5 7792.5 FET 5620.5 7800.0 LOG HEADER DATA DATE LOGGED: 22-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7857.0 TOP LOG INTERVAL (FT) 5620.0 BOTTOM LOG INTERVAL (FT) 7857.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.1 MAXIMUM ANGLE: 93.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 EWR4 Electromag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5574.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil B ase MUD DENSITY (LB/G) 8.50 MUD VISCOSITY (S) 73.0 MUD PH: .0 MUD CHLORIDES (PPM): 35500 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 118 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • • Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type..... 0 Logging Direction ................. Down Optical log depth units........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type ...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO50 OHMM 4 1 68 4 2 RPM MWDO50 OHMM 4 1 68 8 3 RPS MWDO50 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWDO50 HOUR 4 1 68 20 6 GR MWDO50 API 4 1 68 24 7 ROP MWDO50 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5620.5 7857 6738.75 4474 5620.5 7857 RPD MWDO50 OHMM 8.04 36.07 19.1118 4360 5620.5 7800 RPM MWDO50 OHMM 6.77 35.36 17.8098 4360 5620.5 7800 RPS MWDO50 OHMM 6.1 36.69 16.9302 4360 5620.5 7800 RPX MWDO50 OHMM 5.8 40.95 16.4329 4360 5620.5 7800 FET MWDO50 HOUR 0.19 4.62 0.665147 4360 5620.5 7800 GR MWDO50 API 37.67 102.06 70.1956 4345 5620.5 7792.5 ROP MWDO50 FT/H 0.24 559.78 179.247 4474 5620.5 7857 First Reading For Entire File..........5620.5 Last Reading For Entire File...........7857 File Trailer Service name........... Service Sub Level Name. Version Number......... Date of Generation..... Maximum Physical Record File Type .............. Next File Name......... Physical EOF .STSLIB.005 ..1.0.0 ,.06/05/30 ..65535 .LO .STSLIB.006 Tape Trailer Service name .............LISTPE Date .....................06/05/30 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/05/30 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF • • Physical EOF End Of LIS File