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206-155
New Plugback Esets 6/27/2024 Well Name API Number PTD Number ESet Number Date 1J-118 PB1 50-029-23337-70-00 206-176 T39063 2-4-2009 1J-118 PB2 50-029-23337-71-00 206-176 T39064 2-4-2009 1J-136L1 PB1 50-029-23331-71-00 206-155 T39065 2-21-2007 1J-136L1 PB2 50-029-23331-72-00 206-155 T39066 2-21-2007 CD2-76 PB1 50-103-20603-70-00 209-098 T39067 1-13-2010 CD2-76 PB2 50-103-20603-71-00 209-098 T39068 1-13-2010 CD4-24 PB1 50-103-20602-70-00 209-097 T39069 3-24-2010 CD4-24 PB2 50-103-20602-71-00 209-097 T39070 3-24-2010 L-203L3 PB1 50-029-23416-70-00 209-112 T39071 9-24-2010 L-203L3 PB2 50-029-23416-71-00 209-112 T39072 9-24-2010 OP03-P05 PB1 50-029-23396-70-00 208-137 T39073 2-23-2009 OP03-P05 PB2 50-029-23396-71-00 208-137 T39074 2-23-2009 1J-136L1 PB1 50-029-23331-71-00 206-155 T39065 2-21-2007 1J-136L1 PB2 50-029-23331-72-00 206-155 T39066 2-21-2007 OF Tit IP • . g ��I y/,'• THE STATE Alaska Oil and Gas ti 0fAT Ac I A Conservation Commission _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS1� Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. scAtiplEU MAR 0 4 Nib P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-136L1 Permit to Drill Number: 206-155 Sundry Number: 316-124 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 :. Foerster Chair /114 DATED this day of February, 2016. RBDMS l,' FEB 2 6 2016 LI • STATE OF ALASKA • RECEIVE • ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 1 7 2016 APPLICATION FOR SUNDRY APPROVALS "75 zy-/jam 20 AAC 25.280 A' C 1.Type of Request: Abandon , Plug Perforations j Fracture Stimulate i Repair Well i Operations Shutdown 3... Suspend E Perforate Other Stimulate - Pull Tubing I...,.,. Change Approved Program 1.— Plug - Plug for Redrill a... Perforate New Pool I......, Re-enter Susp Well I....... Alter Casing F Other: Crystal Seal MBE Treatm: 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory F— Development i 206-155 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic f....... Service '. 50-029-23331-60 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes F– No ri : KRU 1J-136L1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25662, ADL 380058 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): • 17,233' • 3,417' 17233 3417 1400 NONE NONE Casing Length 3417 MD TVD Burst Collapse Structural - Conductor 78' 20" 121' 121' Surface 3,458' 13 3/8 3,501' 2,236' Intermediate 9,043' 9 5/8 9,730' 3,631' D-Sand Liner 7,929' 4 1/2 17,223' 9,661' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9394-17185 . 9394-9664 4.5 L-80 9,057' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER:HRD ZXP Liner Top PackeR 9197=MD,3568=TVD PACKER:ZXP Liner Top Packer 9023=MD,3543=TVD SSSV: Camco DB Nipple 505.5=MD,505.5=TVD - 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory F Stratigraphic i Development i Service :.• 14.Estimated Date for 15.Well Status after proposed work: 3/3/2016 Commencing Operations: OIL I . WINJ F/ ' WDSPL n Suspended 1- 16.Verbal Approval: Date: GAS F-W WAG I__ GSTOR ;— SPLUG F Commission Representative: GINJ I Op Shutdown F. Abandoned E 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John Peirce @ 265-6471 Email John.W.Peirce(a�concocophillips.com Printed Name John Peirce Title Sr.Wells Engineer / ti_y,---- � � – 2r16i1G ^ Signature // .._. , 'done 265-6471 Date / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\ e – \I–ii Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: FEBPost Initial Injection MIT Req'd? Yes ❑ No CT". RBDMS FEB B t 6 2016 Spacing Exception Required? Yes ❑ No LJ Subsequent Form Required: `p—11, _ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Z-Z --0 / 9 •I suomit form ano Form 1 -40 Re) /20 b , MA.. • e .1 i .��• is valid for 12 months from the date of approval. 4/413 4174s. Attachments in Duplicate X94 KUP 10 1J-136L1 COnOCOPhillip5 Well Attribu Max Angle TD Alaska Inc, Wellbore API/UWI Field Name Wellbore Status ncl Cl MD(ftKB) Act Btm(ftKB) Gonocovhlihps 500292333160 WEST SAK INJ - 17233.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date MOTH Laterals-1J-1360,2/16/20162:4152 PM.,, SSSV:NIPPLE Last WO: 44.00 1/3/2007 Vertloal achemago(aolual). Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SET ISO SLEEVE lehallf 12/4/2015 HANGER,37.8 ;I, flit Ili asing Strings CONDUCTOR 34'Insulated; Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt(Len(I...Grade Top Thread -^' 429-121.5 Liner D-Sand 41/2 4.000 9,294.6 17,223.9 9,661.4 11.60 L80 BTC NIPPLE;505.5 tau Liner Details WOW Nominal ID INJECTION;2,211.4 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) nag ow 9,294.6 9,294.6 87.61 SLEEVE 7"Baker"HR"Liner Setting Sleeve(8.3"O.D.x 7. 7.500 Ma 13,027.1 9,696.4 89.61 XO-reducing 5.5"x4.5"CROSSOVER 4.000 17,184.6 9,664.4 94.36 XO-reducing 4.5"x3.5"crossover 2.992 SURFACE;42.9-3,501.0-.. ' SLEEVE-C,8,989.7 lot Perforations&Slots Shot 1 R Dens iiiiam LOCATOR;9,039.4 Top(TVD) Btm(TVD) (shots/ SEAL ASSY;9,040.5 -s '' - Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com INTERMEDIATE,41.4-9,729.7 9,394.0 9,791.0 9,394.0 9,763.5 WS D,1J- 12/28/2006 32.0 SLOTS ALL PERFS IN 0-Send Liner LEM,9,023.1- mk 136L1 WELLBORE:Alternating 9,240.0 solid/slotted pipe- D-Sand Liner HH,9,082.9- 0.125"x2.5"@ 4 9,3468 circumferential adjacent rows,3"centers ri- staggered 18 deg,3'non -slotted ends -11 10,038.0 10,538.0 9,760.3 9,755.5 WS D,1J- 12/28/2006 32.0 SLOTS 136L1 SLOTS;9,394.0x,791.0 _ - 10,785.0 11,284.0 9,750.0 9,733.5 WS D,1J- 12/28/2006 32.0 SLOTS 136L1 11,522.0 12,047.0 9,745.1 9,738.5 WS D,1J- 12/28/2006 32.0 SLOTS - - 136L1 12,289.0 12,824.0 9,738.3 9,700.5 WS D,1J- 12/28/2006 32.0 SLOTS 136L1 SLOTS;10,038.0-10,538.0 13,027.0 13,538.0 9,696.4 9,685.8 WS D,1J- 12/28/2006 32.0 SLOTS 136L1 - 13,795.0 14,181.0 9,675.0 9,672.7 WS D,1J- 12/28/2006 32.0 SLOTS 136L1 14,653.0 15,125.0 9,673.6 9,696.5 WS D,1J- 12/28/2006 32.0 SLOTS _ - 136L1 SLOTS;10785.0-11,284.0 - - 15,425.0 15,769.0 9,684.0 9,678.3 WS D,1J- 12/28/2006 32.0 SLOTS 136L1 16,029.0 16,499.0 9,679.9 9,674.1 WS D,1J- 12/28/2006 32.0 SLOTS - - 136L1 - - 16,756.0 17,185.0 9,672.7 9,664.4 WS D,1J- 12/28/2006 32.0 SLOTS 136L1 Cement Squeezes SLOTS;11,522.0.12,0410 = - Top(TVD) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 10,173.0 10,178.0 9,759.0 9,759.0 GEL SQUEEZE 12/15/201 _ - Notes:General&Safety End Date Annotation 1/1/2007 'NOTE: MULTILATERAL WELL-1J-136(B/C-SANDS),1J-136L1(D-SANDS) SLOTS;12,289.0-12,824.0 _ - 4/17/2010 NOTE:View Schematic w/Alaska Schematic9.0 ' 12/15/2011 NOTE:PROFILE MODIFICATION-PUMPED 1776 LBS(4MM)CRYSTAL SEAL"B"MBE@10175 TEl 1 - SLOTS;13,027.0-13,5380 _p� - b .1 1I- SLOTS;13,795.0-14,181.0-. 1 ? SLOTS 14,653.0-15,125.0 -) - �� _I I SLOTS;15,425.015,769.0 'I l SLOTS,16,029.018,499.0 _. SLOTS;16,756.0-17,185.0 ! )1I Liner D-Sand;9,294.6-17,223.9 - • • 1J-136 to 1J-135 B MBE Retreatment with Crystal Seal Proposal 1J-136 dual-lateral injector with 4-1/2" L-80 tubing was completed December 2006 in West Sak B and D sands, Both laterals have 5-1/2" slotted liners with Constrictors (Swell Packers). A Matrix Bypass Event (MBE) occurred 2/23/10 in 1J-136 B lat to producer 1J-135 B lat. An (PROF of 3/15/11 in 1J-136 showed a B MBE between 10150' - 10680' MD. This interval is mostly covered by a 358' blank liner section. Most PWI appeared to be exiting the liner above this blank. On 12/14/11, 'big hole' perfs were shot at 10173 - 10178' RKB. On 12/15/11, CT pumped 1776 lbs of Crystal Seal (CS) to seal off the B MBE. The B lat was then cleaned out to remove excess CS and restore PWI to both the D & B laterals. This treatment held a few years. On 8/9/15, an (PROF detected a 93% PWI split entering the B lateral. This showed that a B MBE was again becoming evident. PWI continued until a B MBE occurred 9/19/15. A D Iso-Sly was set 11/26/15, and an IPROF was run on 11/27/15 in the B lateral that found a temperature anomaly at—11650' RKB indicating the likely presence of the B MBE location. It is proposed that CT convey a 2" OD x 5' perf gun to shoot perfs in the B lat at 10625' MD (above a B MBE at —10650' RKB). Next, the B MBE would be sealed with Crystal Seal slurry pumped down CT at'-2 bpm to the MBE. After the treatment, 1J-136 will be returned to B sand only PWI to verify that the B MBE has been sealed. After verification that the MBE is sealed, CT will perform an FCO in the B lat and then the D Iso-Sly will be pulled to restore PW(to D lat. 1J-136 Proposed Wellwork Procedure: Coil Tubing: 1. RIH with a 5' OAL x 2" OD Perf gun to shoot 'big hole' perfs, 6 spf, 60 deg ph, in 5.5" slotted liner at 10625- 10630' RKB. POOH. Verify ASF. 2. Verify 1J-135 is shut-in, then RIH with CT Nozzle BHA to 10610' RKB to pump a Crystal Seal Treatment to the B MBE at—10650' RKB. Park nozzle at 10610' RKB and perform a short SRIT pumping Seawater down CT to determine a preferable constant treating rate, then swap to Crystal Seal Slurry consisting of Seawater with 0.25 ppg of 1,2,4 mm mesh Crystal Seal pumped down CT at an established constant rate (-2 bpm expected). Pump Slurry while slowly POOH with CT until achieving —1000 psi WHIP (to bring WHIP near frac pressure), and then go to Flush pumping 15 bbls of Seawater, followed by , Diesel FP to,surface, followed by SD. RD. 3) RIH with Jet Swirl Nozzle to jet through excess Crystal Seal left in the B lateral liner. Perform an FCO jetting Seawater to as deep as possible. POOH & FP with Diesel. RD, 4) Run a post-treatment memory IPROF log in B lateral to verify that the B MBE is sealed. 5) - RIH & pull the D Iso-Sleeve (set 11/26/15)to restore PWI to the D lateral. Return 1J-136 to PWI service to the West Sak B and D sands. JWP 12/29/2015 a ~ Image Project Well History File ever 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 OrganlZi,llg (done) ,~=,a~ iiumiiiiiiuuii Re,~a~~ee~e~ iiuiiuiuuiiuu RE CAN DI TAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ j ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ /s/ Project Proofing III II'III ~I III I I III BY: Maria Date: ~ /s/ Scanning Preparation 1 x 30 = ~o~~ + =TOTAL PAGES ~~ ount does not include cover sheet) BY: _ Maria ~ Date: ~ ~ ~ ls/ Production Scanning Stage 1 Page Count from Scanned File: -~ ~ (Count does include cove heet) Page Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date: ~~ ~ ~ /sl Stage 1 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. III II'I II I II II I I III ReScanned II I II II II I ~ III I I III BY: Maria Date: /s/ Comments about this file: Quality Checked III II!!!~ III III III 10/6!2005 Well History File Cover Page.doc STATE OF ALASKA ,, KA OIL AND GAS CONSERVATION CO ISSION REP RT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ❑ Repair well fJ Plug Perforations ❑ Perforate ❑ Other p Pull !so sleeve Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑i Change Approved Program ® Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator Name: , 4. Well Class Before Work: 5. Permit to Drill Number: Conoco Phillips Alaska, Inc. Development ❑ Exploratory ❑ " 206 - 155 3. Address: 6. API Number: ��yy P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic ❑ Service 50- 029 - 23331 -60 "`OO 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25662, 380058 1J -136L1 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 17233 feet Plugs (measured) none true vertical 3417 feet Junk (measured) none Effective Depth measured 17233 feet Packer (measured) 0 true vertical 3417' feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 34 78 20 121 121 0 0 SURFACE 3458 18.187 3501 2236 0 0 INTERMEDIATE 9043 9.625 9084 3631 0 0 LINER D -SAND 7929 8.333 17224 3416 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: solid /slotted liner 9394'- 17185' True Vertical Depth: 3527' -3420' RECEIVED Tubing (size, grade, MD, and TVD) 4.5, L -80, 9058 MD, 3505 TVD NOV 2 7 2012 Packers & SSSV (type, MD, and TVD) AOGCC 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 0 0 375 870 696 Subsequent to operation 0 0 820 1818 612 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory ❑ Development ❑ Service 17 Stratigraphic 16. Well Status after work: Oil ❑ Gas ❑ WDSPL r Daily Report of Well Operations X GSTOR ❑ WINJ [ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 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 n1139(caconocophillips.com Printed Name Darrell Humphrey Title NSK Production Engineering Specialist Signature Phone: 659 -7535 Date `� , Z5- ` , RPr- MS NOVr72 i Form 10-404 Revised 12/2012 /l 2 Z /L Submit Original Only 1J -136L1 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/27/12 RIH WITH GS SPEAR AND LATCH D -SAND TYPE I DIVERTER AT 9077' CTMD. POOH, SWAP TO HYD PRS TOOL. RIH AND LATCH DB PRONG AT 9124' CTMD. ON SURFACE WITH PRONG, RIH AND LATCH DB PLUG, ON SURFACE. TURN WELL OVER TO DSO TO PUT ON INJECTION. I I I I I I � � I ( I I I I I ( I • KUP 1J -136L1 ConocoPhillips a Well Attributes Max Angle & MD TD Alaska. Inc Wel'bore API /UWI Field Name Well Status Ind (") MD (ft)(8) Act Btm (ftKB) COnocoprulkps 500292333160 WEST SAK INJ 17,233.0 Comment H2S (ppm) Date Annotation End Date KB - Ord (ft) Rig Release Date -" SSSV: NIPPLE Last WO: 44.00 1/3/2007 Well Confio'. Multiple Laterals - 1J -136L1 9/16/2012 12'.37'.17 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date - - - - -- Last Tag: Rev Reason: SET PLUG & DIVERTER, PULL SLEEVE ninam 9/16/2012 IM.11111.11.111111/1W Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR Liner D - Sand 4 1/2 4.000 9,294.6 17,223.9 9,661.4 11.60 L80 BTC 34 Insulated 43-121 MI Liner Details NIPPLE, 505 ire Top Depth tea (TVD) Top Inc! Nomi... atIOrn INJECTION, miiim SURFACE, Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) • 2' 9,294.6 9,294.6 87.45 SLEEVE 7" Baker "HR" Liner Setting Sleeve (8.3" O.D. x 7. 7.500 eaaars SL EVE 1 . 13,027.1 9,695.6 88.51 XO- reducing 5.5 "x4.5" CROSSOVER 4.000 LOCATOR, 17,184.6 9,664.4 94.29 XO- reducing 4.5 "x3.5" crossover 2.992 9,039 SEAL ASSY, 9,040 Perforations & Slots DIVERTER. 4 • • 1 Shot D -Sande er Top (TVD) Btm (TVD) Dens LEM, { � a' Top(KKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (sh °- Type Comment 9,023 -9,240 HH, f 9,394 9,791 9,394.0 9,762.5 WS D, 1J -136L1 12/28/2006 32.0 SLOTS ALL PERFS IN WELLBORE: D - Sand uner � ��01, Altematngsolid/slottedpipe - I e,0e3 -e.347 0.125 "x2.5" @ 4 circumferential SLOTS. TS. adjacent rows, 3" centers staggered e,3 NTERMEDIATE, 18 deg, 3' non - slotted ends 41 -9,730 • ..... 10,038 10,538 9,760.3 9,755.4 WS D, 1J -136L1 12/28/2006 32.0 SLOTS 10,785 11,284 9,750.0 9,733.5 WS D, 1J -136L1 12/28/2006 32.0 SLOTS 11,522 12,047 9,743.2 9,743.8 WS D, 1J -136L1 12/28/2006 32.0 SLOTS 12,289 12,824 9,737.9 9,700.6 WS D, 1J -136L1 12/28/2006 32.0 SLOTS 13,027 13,538 9,695.6 9,686.2 WS D, 1J -136L1 12/28/2006 32.0 SLOTS 13,795 14,181 9,675.0 9,672.7 WS D, 1J -136L1 12/28/2006 32.0 SLOTS 14,653 15,125 9,674.1 9,696.6 WS D, 1J -136L1 12/28/2006 32.0 SLOTS 15,425 15,769 9,684.0 9,678.3 WS D, 1J -136L1 12/28/2006 32.0 SLOTS 16,029 16,499 9,679.7' 9,674.1 WS D, 1J -136L1 12/28/2006 32.0 SLOTS SLOTS, 10,038 - 10,538 = 16,756 17,185 9,673.0 9,664.4 WS ID, 1J -136L1 12/28/2006 32.0 SLOTS Notes: General & Safety End Date Annotation 1/1/2007 NOTE: MULTILATERAL WELL- 1J -136 (B /C- SANDS), 1J -136L1 (D- SANDS) 4/17/2010 NOTE: View Schematic w/ Alaska Schematic9.0 SLOTS, 10,785 - 11,284 SLOTS, 11,522- 12,047 SLOTS, 12,289- 12,824 SLOTS, 13.027- 13538 SLOTS. 13.795-14.181 SLOTS, 1403- 15,125 SLOTS, - Mandrel Details 15,425- 15,789 T Depth Top Port (TVD) 1861 OD Valve Latch 9160 TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (In) Sery Type Type (in) (psi) Run Date Com... 1 2,211.4 1,906.0 67.11 CAMCO KBMG 1 INJ GLV BK -5 0.188 1,450.0 1/28/2007 SLOTS, 10,029- 16,499 SLOTS. 16,756 - 17,185 Liner D -Sand. 9,295- 17,224 TD (1J- 136L1), 17,233 STATE OF ALASKA ALASK•L AND GAS CONSERVATION COMMIS•N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate r Other Fi Crystal Seal Treatment Alter Casing r Pull Tubing r Perforate New Pool f°' Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 206 - 155 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r °" Service 50- 029 - 23331 -60 - 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25662, 380058 1J-136L1 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 17233 feet Plugs (measured) None true vertical 3417 feet Junk (measured) None Effective Depth measured 17223 feet Packer (measured) none true vertical 3418 feet (true vertucal) none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 113 113 SURFACE 3458 13.375 3501 2196 INTERMEDIATE 9043 9.625 9730 3591 LINER D -SAND 7929 5.5x4.5 17224 3418 Perforation depth: Measured depth: solid /slotted liner from 9394'- 17185' JAN 2012 True Vertical Depth: 3527' -3420' ilBka imi & 6as Cons. Cenvission Tubing (size, grade, MD, and ND) 4.5, L -80, 9058 MD, 3505 TVD •:'!i'`!.'1, ; , Packers & SSSV (type, MD, and ND) NO PACKER IN THIS WELLBORE NO SSSV IN THIS WELLBORE 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 12376 Subsequent to operation 505 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ 17 WAG r GINJ r SUSP r SPLUG r 16. 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: 311 -327 Contact John Peirce Ca 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date ,p / j / j a � RBD S JAN 12 2Q12 (2, /L- A � j /Zy � To l.m 10 -404 Revised 10/2010 Submit Orig Only 1J -136L1 Well Work Summary ..DATE SUMMARY 12/10/11 ATTEMPT TO PULL PRONG ATI/5' MADE SEVERAL ATTEMPTS UNABLIRD LATCH UP. JOB IN PROGRESS. 12/11/11 PULLED PRONG AND PLUG FROM 9126' CTMD. (DB PLUG). JOB IN PROGRESS. 12/12/11 SET TYPE 1 ISO SLEEVE WITH 2.5" ID IN D -LEM AT 9090'. WELL PLACED ON INJECTION FOR XSTAL SEAL TREATMENT. 12/13/11 CLOSE CMD @ 8990' CTMD. MIT IA. (TBG = 145 , IA = 280), (15 MIN T = 137, IA = 297), (30 MIN T = 126, IA = 315.) 12/14/11 PERFORATED LINER AT 10,173 - 10,178 CTMD. PUMPED INJECTION TEST AND EXPERIENCED PARTIAL PLUGING EVENT WHILE PUMPING SEAWATER THROUGH CT. SAW PRESSURE BREAK OVER WHILE POOH. FP CT WHILE POOH. NO SIGNS OF DEBRIS IN BHA. JOB IN PROGRESS. 12/15/11 PUMPED TOTAL OF 1,776 LBS OF 4MM MESH CRYSTAL SEAL TO 'B' SAND MBE AT APPROX 10,175' RKB. SAW A GOOD INDICATION OF APPROCHING SCREENOUT WITH 0.20 PPG CRYSTAL SEAL AT NOZZLE. WENT TO 2% KCL FLUSH PRIOR TO SCREENOUT. FREEZE PROTECTED CT. JOB COMPLETE. KUP 1J -136L1 Conoc 011114ell W Attributes ax Angle & MD TD Alaska kn;. Wellhore APWI Field Name Well Status Inc! ( °) MD (RKB) Act Btm (ftl(8) 500292333160 WESTSAK )NJ 17,233.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' — SSSV: NIPPLE Last WO: 44.00 1/3/2007 Well ConM1p' Multiple Laterals -1J-13611 , 5/15/2011 12'29'18 PM Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod By End Date - -- - - - -- - - - - - - - -- Last Tag: Rev Reason: SET ISO SLEEVE IN D - LEM Imosbor 5/15/2011 - HANGER, 38 Casing Strings !. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR Liner D - Sand 4 1/2 4.000 9,294.6 17223.9 9,661.4 11.60 L80 BTC 3a• Insulated. 3421 4b Liner Details NIPPLE, 505 Top Depth INJECTION, (TVD) Top loci Nomi... 2,211 \ fi Top (1tKB) (IKS) P) Item Description Comment ID (In) SURFACE, 9,294.6 9,294.6 87.45 SLEEVE 7" Baker "HR" Liner Setting Sleeve (8.3" O.D. x 7. 7.500 43 -3,501 SLEEVE -O, 13,027.1 9,695.6 88.51 XO- reducing 5.5 "x4.5 "CROSSOVER 4.000 tow LOCATOR, 17,184.6 9,664.4 94.29 XO- reducing 4.5 "x3.5" crossover 2.992 9, . 039 SEAL A 9 Perforations & Slots ISO SLEEVE, 9,092 Shot D -Send Liner _ _ Top (TVO) Btm (TVD) Dens sr 9.023 -9,240 Top (RKB) Btm (ftKB) (ftKB) (ftKB) Zone Date ("ii. Type Comment D -Send Liner 9,394.0 9,791.0 9,394.0 9,762.5 WS D, 1J -136L1 12/28/2006 32.0 SLOTS ALL PERFS IN WELLBORE: RH, ' Alternating solid/slotted pipe - 9,083 -9,347 :, 0.125 "x2.5" @ 4 circumferential SLOTS, ea ea e .7e1 adjacent rows, 3" centers staggered TERMEDIATE, al 18 deg, 3' non - slotted ends 41 -9,730 '— 10,038.0 10,538.0 9,760.3 9,755.4 WS D, 1J -136L1 12/28/2006 32.0 SLOTS 10,785.0 11,284.0 9,750.0 9,733.5 WS D, 1J -13611 12/28/2006 32.0 SLOTS 11,522.0 12,047.0 9,743.2 9,743.8 WS 0, 1J -136L1 12/28/2006 32.0 SLOTS 12,289.0 12,824.0 9,737.9 9,700.6 WS D, 1J -136L1 12/28/2006 32.0 SLOTS 13,027.0 13,538.0 9,695.6 9,686.2 WS D, 1J -136L1 12/28/2006 32.0 SLOTS 13,795.0 14,181.0 9,675.0 9,672.7 WS D, 1J -136L1 12/28/2006 32.0 SLOTS 14,653.0 15,125.0 9,674.1 9,696.6 WS D, 1J -136L1 12/28/2006 32.0 SLOTS 15,425.0 15,769.0 9,684.0 9,678.3 WS D, 1J -136L1 12/28/2006 32.0 SLOTS SLOTS, 16,029.0 16,499.0 9,679.7 9,674.1 WS D, 1J -136L1 12/28/2006 320 SLOTS 10.038 10,538 16,756.0 17,185.0 9,673.0 9,664.4 WS D, 1J -136L1 12/28/2006 32.0 SLOTS Notes: General & Safety End Date Annotation 1/1/2007 NOTE: MULTILATERAL WELL- 1J -136 (B/C- SANDS), 1J -136L1 (D- SANDS) - 4/17/2010 NOTE: VIEW SCHEMATIC w /Alaska Schemalic9.OREV SLOTS, 10.785 - 11,284 SLOTS. 11,522 - 12,047 -- di SLOTS, 12,289- 12.824 SLTS, 13,027 - 13, SLOTS, 13.795- 14,181 SLOTS. 14 15 r:ff SLOTS, 15 425 -15 769 SLOTS 16 029.16 499 Mandrel Details _ Top Depth Top Port SLOTS, (TVD) Ind OD Valve Latch Gi2e TRO Run 16.758- 77,185 Stn Top (ftKB) (RKB) 1°) Make Model (in) Sery Type Type (In) (psi) Run Date Com... 1 2,211.4 1,906.0 67.11 CAMCO KBMG 1 INJ GLV BK -5 0.188 1,450.0 1/28/2007 Liner 0 -Sand, 9,295 - 17,224 TD (1J- 136L1), 17,233 • • Kam( 'T- I'-) 0 /55 Regg, James B (DOA) From: Gauer, Jenn L [ Jennifer .L.Gauer @conocophillips.com] Sent: Tuesday, January 10, 2012 8:09 AM z- To: Maunder, Thomas E (DOA); Regg, James B (DOA) 1 Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L; CPF1 Prod Engr; Jensen, Marc D Subject: LPP /SSV Defeated for 1J -136 on 01/09/2012 Tom and Jim: The low pressure pilot (LPP) on injector 1J -136 (PTD# 206 -154 ; nd 206 -155 as defeated on 01/09/2012 when the injection pressure fell below 500 PSI while on injection. This pr- sure oss is most likely due to either the failure of a J p injection. p Y recent CrystalSeal job (Matrix Bypass Event Treatment) or the removal of a CrystalSeal plug in the lateral. This injector had previously been returned to service on January 5th, 2012 after being shut in since December 14, 2011. As of 0800 hrs on 01/10/2012 , wellhead injection pressure is 158 psi; injection rate is 607 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure on either well has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. ��rr rz yeucz ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907659. Mobile - 303.248.6641 5) FE 1 • • KE.a 1 -136 Regg, James B (DOA) Fi c.ISu From: CPF1 Prod Engr [n1269 ©conocophillips.com] Sent: Sunday, January 08, 2012 2:50 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L; Jensen, Marc D Subject: LPP /SSV Returned to Service for 1J -136 on 01/07/2012 Tom / Jim, The low pressure pilot (LPP) on injector 1J -136 (PTD# 206 -154 and 206 -155) as returned to service late on 01/07/2012 after the wellhead injection pressure stabilized above the setting of the lo •ressure pilot. Current wellhead pressure is 591 psig; injection rate is 537 bwpd. This pilot had been defeated on 01/06/2012 in accordance with "Administrative Approval No. CO 406B.001." The LPP on injector 1J -176 (PTD# 207 -099) remains defeated; it is currently operating at a wellhead pressure of 463 psi with an injection rate of 1186 bwpd. We will notify you when it is returned to service. Please let me know if you have any questions. David Lagerlef /Dan Bearden CPF1 Production Engineers n 1269(conocophillips.com 659 -7493 pager 659 -7000 765 bitDFEb I, Marc D y, January 05, 2012 4:09 PM coder @alaska.gov'; 'jim.regg @alaska.gov' Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L; CPF1 Prod Engr PP /SSV Defeated for 13-136 on 01/05/2012 Tom and Jim: The low pressure pilot (LPP) on injector 1J -136 (PTD# 206 -154 and 206 -155) was defeated on 01/05/2012 when the injector was returned to service after being shut in since December 14, 2011. As of 1600 hrs on 01/05/2012 , wellhead injection pressure is 390 psi; injection rate is 530 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure on either well has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marc Jensen West Sak Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 907 - 265 -6573 1 marc .d.jensen(c�conocophillips.com, 1 • • (ek 00 6 /s50 Regg, James B (DOA) From: Jensen, Marc D [Marc.D.Jensen @conocophillips.com] Sent: Thursday, January 05, 2012 4:09 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L; CPF1 Prod Engr Subject: LPP /SSV Defeated for 1J -136 on 01/05/2012 Tom and Jim: 1r The low pressure pilot (LPP) on injector 1J -136 (PTD# 206 -154 and was defeated on 01/05/2012 when the injector was returned to service after being shut in since December 14, 201 . As of 1600 hrs on 01/05/2012 , wellhead injection pressure is 390 psi; injection rate is 530 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure on either well has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marc Jensen West Sak Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 907 - 265 -6573 1 marc.d.iensen a()conocophillips.com t DFEB ' 1 . • • suirE ALANKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John Peirce Wells Engineer ConocoPhillips Alaska, Inc. �s k �';: ' ,; t ,r P.O. Box 100360 ..- { Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J -136L1 Sundry Number: 311 -327 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, 1 (>/ Daniel T. Seamount, Jr. Chair DATED thi -C day of October, 2011. Encl. • STATE OF ALASKA 0(1/ ( • �� � ALASKOL AND GAS CONSERVATION COMMISSI 10' C vE ' APPLICATION FOR SUNDRY APPROVAL � � � AA,/;. ► 2011 20 AAC 25.280 4 2. Fl 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r` Repair w ell r ro : t a t m Suspend r Rug Perforations r Perforate r Pull Tubing r" �8 8 "r �" a 1h s on R - enter Sus Well S •'t -41aT r e Operational Shutdown P• r Stimulate Al ter casing r Ot her:Crystar Seai Treatment r� - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory (""" 206 -155 • 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23331 -60 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 changes: Spacing Exception Required? Yes r No p 1J -136L1 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25662; 380058 • 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): 17233 . 3417 • 17223' 3418' Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 113' 113' SURFACE 3458 13.375" 3501' 2196' INTERMEDIATE 9043 9.625 9730' 3591' LINER D -SAND 7929 5.5 "x4.5" 17224' 3418' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): solid /slotted liner from 9394'- 17185' 3527' -3420' 4.5 L - 9058 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) NO PACKER IN THIS LATERAL NO SSSV IN THIS LATERAL 12. Attachments: Description Summary of Proposal j 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory r Development r Service - 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/1/2011 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r • GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Printed Name John f Peirce Title: Wells Engineer Signature - (il.f .�� Phone: 265-6471 Date / D /24l1 1 ide Commission Use Only Sundry Number: �� ' ��� Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: / e — ( JO t / � ��' APPROVED BY / ) � � � r Approved by. f COMMISSIONER THE COMMISSION . Date: I I S , � ( Form 10 -403 Revised 1/2010 z `( tMS OCT 2 • II Submit in Duplicate ORIGIN � f v"' • KUP • 1J -136L1 • r Conoco Phillips ( $ j Well Attributes Max Angle & MD TD 11 AI W Ilbore A PIIU WI Field N II Nell Status Inc! () MD (ftKB) Act Bim (f1103) ' -,...,,,,,,,,,,. L 500292333160 WEST SAK INJ 1 17,233 0 'Comment H2S (ppm) Date !Annotation Entl Date TM-Grd (ft) Rig Release Date 4SSSV NIPPLE I Last WO _ k 44.00 1/312001 i - • Y: PL1A19 1 e1 A @L15i1`,/2111i 1.29: phi_ A notation Depth (ftKB) ' End Date Annotat on Last Mod By End Date Last Tag: I I Rev Reason: SET ISO SLEEVE IN D LEM I Imosbor 5/15/2011 '" • 1 I Casing Strings C asi ng Description String 0... String ID ... Top (ftKB) Set Depth (f . Set Depth (ND) .. Str ng Wt... String .. String Top Thrd CONDUCTOR L D Sand 4 1/2 4.000 ... r op 6 'Set 9 I 9,661 4 !String 11 60 L80 BTC 34 Insulated, i 43-121 ': Liner Details NIPPLE, 505 _ Top Depth ' (ND) Top Ind Nomi... INJECTION, p 2,211 Top (NKB) (ftKB) (') Item Description Comment ID (in) SURFACE, - 9,294.6 9,294.6 87.45 SLEEVE 7" Baker "HR" Liner Setting Sleeve (8.3" O.D. x 7 7.500 43 - 3.501 �rf SLE EVE 13,027.1 9,695.6 88.51 XO- reducing 5.5"x4.5" CROSSOVER 4.000 LOCATOR, i 17,184.6 9,664.4 94.29 XO- reducing 4S "x3.5" crossover 2992 • 9,039 i. y SEAL ASSV, 1, 9 Perforations & Slots w� ISO SLEEVE. __ __ -_ _ - __- Shot D -Sand L ben Top (TVD) Bim (ND) Dens LEM, 's(. Top(ftKB) Btm(itKB) (ftKB) NOM) Zone Date (sh -. Type Comment - Sand Lner ; 9,394.0 9,791.0 9,394.0 9,762.5 WS D, 1J -136L1 12/28/2006 32.0 SLOTS ALL PERFS IN WELLBORE: HH, , _S -- - Alternating solid /slotted pipe - 9,083 - 9,347 -- 0.125 "x2.5" © 4 circumferential SLOTS, 9,394 - 9,791 adjacent rows, 3" centers staggered ERMEDIATE, 18 deg, 3' non - slotted ends 41 - 9,730 10,038.0 10,538.0 9,760.3 9,755.4 WS D, 1J -136L1 12/282006 32.0 SLOTS 1 r 10,785.0 11,284.0 9,750.0 9,733.5 WS D, 1J -136L1 12282006 32.0 SLOTS I I 11,522.0 12,047.0 9,743.2 9,743.8 WS D, 1J -136L1 12282006 32.0 SLOTS i 0 12289.0 12,824.0 9,737.9 9,700.6 WS D, 1J -136L1 12282006 32.0 SLOTS --- 13,027.0 13,538.0 9,695.6 9,686.2 WS D, 1J-136L1 12/28/2006 32.0 SLOTS ;:_:.. 1 1 13,795.0 14,181.0 9,675.0 9,672.7 WS D, 1J -136L1 12282006 32.0 SLOTS '1 1 I 14,653.0 15,125.0 9,674.1 9,696.6 WS D, 1J -136L1 12/28/2006 32.0 SLOTS 7 4' N 1 15,425.0 15,769.0 9,684.0 9,678.3 WS D, 1J -136L1 12282006 32.0 SLOTS sLOrs 1 Y 16,029.0 16,499.0 9,679.7 9,674.1 WS D, 1J -136L1 12/282006 32.0 SLOTS 10,038 SOTS, <_. - II i - ` 16,756.0 17,185.0 9,673.0 9,664 4 WS D, 1J -136L1 12/28/2006 32.0 SLOTS I I - Notes : General & Safety End Date Annotation ... 1 I - 1/1/2007 NOTE: MULTILATERAL WELL - 1J -136 (B /C- SANDS), 1J -136L1 (D- SANDS) ' -. 4/17/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.OREV SLOTS, 1 I , 10,785- 11,284 - 1 1 I 1 i w t f s1Ors, . i 0 11,522 - 12,047 i 1 I sLOrs. 12,289- 12,824 - f I 4' 1 1 .. i i -1 SLOTS. -.... 13,027 - 13,538 _.___ _ I 1 i 1 1 1 I SLOTS, _ -. I 1 ;' 13,795 - 14,181 1 7 - 1 I 1 _" i SLOTS. 14,853- 15,125 i. _....6 I 1 SLOTS, 1 I.... 15,425- 15,769 l "' I l , 1 � SLOTS. • 1 l __ 16,02916,499 - l - I 1 ,.. t L_ 83 T= - *;1 . W ' _ „S- ,Ik . , , • SLOTS. - Top Depth Top Pori ,•: 16,756 - 17,185 Inc! 1 Make Model On) Tye Sery p e O (Psi Stn To • NKB BRIM Run Date Cam... 1 2,211.4 1,906.0 67.11 CAMCO KBMG 1 INJ GLV BK -5 0.188 1,450.0 1/28/2007 Liner D -Sand, _. _. 9,295- 17,224 TD(1J- 136L1), � 17,233 •I • • 1J - 136 to 1J - 135 MBE Treatment A matrix bypass event (MBE) occurred 2/23/10 in 1J -136 with breakthrough to 1J -135 producer. A 3/15/11 IPROF in 1J -136 found a 'heel' MBE in the area between 10150 to 10680' RKB in an interval covered mostly by a 358' section of blank 5.5" liner. Most PWI appears to exiting a slotted liner joint just above the top of this long blank section. Halliburton CrystalSeal is intended for treating injector wells to restore water flood sweep efficiency by remediating direct communication paths through formation to offset producers. CrystalSeal is a water swellable dehydrated crosslinked synthetic polymer gel available in various granular mesh sizes. CrystalSeal swells to 400 times original size by hydrating and absorbing water. Due to swellability of CrystalSeal, it is used to fill highly conductive large voids or channels (MBE's) that dominate acceptance of injection. Procedure: 4 S, Coil Tubing: ry' 1) Pull the isolation Plug from the 1J-136 at 9134' MD to re -open access to the B lateral. " 2) Set a 2.75" min ID Isolation Sleeve in the D LEM at 9100 ' MD to isolate 1 J -136L1 D lateral • 3) RIH with BHA on 2 "coil tubing consisting from bottom to top of 5' OAL x 2" OD TCP Perf Gun, a 2 -1/8" OD closed Circ -Sub, and hydraulic disconnect. Park perf gun to fire 6 spf large hole charges at +/ -10173 - 10178' RKB in a 5.5" slotted liner joint just above the `heel' MBE located behind the 358' blank liner section. Drop a ball to fire the gun, then RIH —5' with coil to spot the Circ -Sub over the perf interval. Drop ball #2 to shift the Circ -Sub open, then proceed to pump a Crystal Seal treatment through the Circ -Sub and perfs to seal off the MBE. Pump as follows: a) Seawater down coil at 2.0 bpm until ready to slurry. Hold 2.0 bpm constant throughout treatment through Flush (step g) to monitor treating pressure change at constant rate. When crew is ready to start mixing Crystal Seal slurry, swap from Seawater to 2% KCI and pump, b) 2% KCI Water with 0.05 ppg CrystalSeal (4 mm mesh, all stages) down coil. Each stage volume is decided during pumping based on treating pressure response seen during the stage. During each stage, check PU weight to ensure Crystal Seal buildup around BHA is not becoming a threat to POOH. When called, swap to subsequent sequential stages as follows: c) 2% KCI Water w /0.10 ppg CrystalSeal down CT, or Flush (step g) should we see screen out. d) 2% KCI Water w /0.15 ppg CrystalSeal down CT, or Flush should we see screen out. e) 2% KCI Water w /0.20 ppg CrystalSeal down CT, or Flush should we see screen out. f) 2% KCI Water w/0.25 ppg CrystalSeal down CT, or Flush should we see screen out. g) If screenout occurs, open CT x Tbg annulus to return tank, and pump 1 CT volume of Seawater Flush to displace Crystal Seal Slurry from coil to the well while POOH. If screenout indication has not been seen prior to Flush, leave CT x Tbg annulus shut -in and pump 1 full CT volume of Seawater Flush to displace Crystal Seal Slurry from coil to MBE while POOH with CT to D LEM, then swap to 73 bbls of Diesel FP down coil, followed by 1 CT volume ( -40 bbls) of Diesel to displace Diesel FP to tubing and FP CT, followed by SD. RD CTU. Wait a minimum of 6 hrs before returning 1J-136 to PWI for post- treatment injectivity evaluation. ~~~ ~ `~ ~: Y ~ ~~ ~~ ~`~ `~ ~' ~~_ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc 3 ~~~ DATA SUBMITTAL COMPLIANCE REPORT 11 /10/2008 Permit to Drill 2061550 Well Name/No. KUPARUK RIV U WSAK 1J-136L1 Operator CONOCOPHILLIPS ALASKA INC MD 17233 TVD 3417 Completion Date 1/3/2007 Completion Status 1-OIL Current Status 1WINJ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr . Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments f---- -- --- --- _--- --... - ---- ------------ --- ---- --- _ ----- ~/ED D Asc Directional Survey ED D Asc Directional Survey ~D D Asc Directional Survey D C Lis 14512 Induction/Resistivity I ~pt 14512 LIS Verification ~4Qpt 14512 LIS Verification ~pt 14512 LIS Verification Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~N Chips Received? YTIV- Analysis ~Y%N Received? 12989 17233 Open 3/27/2007 9072 14426 Open 3!2712007 PB 1 13273 13397 Open 3/27/2007 PB 2 0 0 Open 3/21/2007 Multi LIS Veri's w/ PB's 3451 17233 Open 3/21/2007 LIS Veri, GR, ROP, FET 3451 14426 Open 3/21/2007 PB1 LIS Veri, GR, ROP, FET 3451 13397 Open 3/21/2007 PB2 LIS Veri, GR, ROP, FET Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? `t" N Formation Tops ~ / N API No. 50-029-23331-60-00 Comments: DATA SUBMITTAL COMPLIANCE REPORT 11 /10/2008 Permit to Drill 2061550 Well Name/No. KUPARUK RIV U WSAK 1J-136L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23331-60-00 MD 17233 ND 3417 mpletion Date 1/3/2007 Completion Status 1-OIL Current Status 1WINJ ~~~~~ '1 ,~U.I~C Y Compliance Reviewed By: _______ - _ - _ __ __ ______. _- - _ Date: ~~4~~? _~ • _ __ ~ ~ -~~:~EIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~ ~ 9 2QO7 REPORT OF SUNDRY WELL OPERATIONS ., _ „___ ,,_~,.... 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ~ Other rod to In` yV ~ ~~Og~J~ ~ Alter Casing ^ Pull Tubing. ^ Perforate New Pool ^ . Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name:. 4. Current Well Status: 5. Permit to Drill Number. ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 206-155 / 3. Address: Strati ra hic 9 p ^ Service ~ E ^. 6: API Number:. P. O. Box 100360, Anchorage,. Alaska 99510 50-029-23331-60 7. KB Elevation (ft): 9. Well-Name and Number. RKB 109' 1J-136L1 8. Property Designation: 10. Field/Pool(s):. ADL 25662 & 380058 Kuparuk River Field !West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 17233' feet true Vertical 3417 feet Plugs (measured) Effective Depth measured- 17223 feet Junk (measured) true vertical 3418' feet Casing Length Size MD TVD Burst. Collapse. Structural CONDUCTOR 140' 20" 140' 140' - SURFACE 3392' 10-3/4" 3501' 2196': WINDOW D-SAN 1' 9-5/8" 9085' 3511' INTERMEDIATE 9620' 9-5/8" 9729' 3591' D-SAND LINER 3734' 5-1/2" 13028' 3450': Perforation depth: Measured depth: Alternating slotted liner 9344'-12824', 13067- 17185' true vertical depth: 3527 - 3454', 3450' - 3421' Tubing (size, grade, and measured depth) 4-1l2" , L-80, 9056' MD . Packers &SSSV (type & measured depth) ZXP Liner Top Packer @ 9023' PKR = 3503' SSSV=NIP SSSV= 504' 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 1123 ~ 373 44 1042 326 Subsequent to operation 1948 1608 187 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: Oil^ Gas^ WAG^ GINJ^ WINJ ^~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ~~ ~ _/ contact Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz Title Production Engineering Technician Signature ~:.~ ' Phone 659-7535 Date /~ J / !~ ion a awvnw w~. ~o w~ v tl LUUI~~ '..~ ... Form 10-404 Revised 0412004 ~~ R ~ G I l ~ Submit Original Only' T~'TK IIIJJJ NA L 1J-136L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/08/07 Commenced Water Injection WELL LOG TRANSII~IITTAL To: State of Alaska tilarch 07, ?007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data: 1J-136, PB1, L1, L1 PBl & L1 PB2, AK-'VIW-4725877 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23331-00, 70, 60, 71 & 72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETI7RNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 - , . M ~ ~,,~f Date: ~~; _ ~ ~~ .~,. ~ ;-,-. ~~sf~,a ~~~`~~; - ~ ~" ~ -rte ~~ Signed:' - ~` ~--~~~-..._. ~~~~ l~~/ i~~~rr -- ,~r~j SARAH PALlN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Buchholz Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-136L 1 Sundry Number: 307-075 Dear Mr. Buchholz: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has. been requested. DATED this ~gday of February, 2007 Encl. ~- L;~~' t ~ 5 ~ ~~ • STATE OF ALASKA ~~~ ~Eg 2 7 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAI~~sska Oil & Gas Cans. Commission. 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Chan e a roved ro ram g pp p g ^ Pull Tubing ^ Perforate New Pool ^ Pre-Producer to Re-enter Suspended Well ^ Injector 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ • Exploratory ^ 206-155 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23331-60 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 changes: Spacing Exception Required? YeS ^ NO ^~ 1J-136L1 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25662 & 380058 RKB 109' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17233' ' 341 T • 17223'' ~ 3418' ' Casing Length Size MD TVD Burst Collapse CONDUCTOR 140' 20" 140' 140' SURFACE 3392' 10-3/4" 3501' 2196' WINDOW D-SAND 1' 9-5/8" 9085' 3511' INTERMEDIATE 9620' 9-5/8" 8729' 3591' D-SAND LINER 3734' 5-1/2" 13028' 3450' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Alternating slotted liner 9344'-12824', 13067'- 17185' 3527' - 3454', 3450' - 3421' 4-1 /2" L-80 9056' Packers and SSSV Type: Packers and SSSV MD (ft) tXP Liner Top Packer @ 9023' PKR = 3503' SSSV= NIP SSSV= 504' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: March 25, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ Q - WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz Title: Production Engineering Technician Signature ~ '°~ ,- Phone 659-7535 Date z/Z t~ ~~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -• U Plug Integrity ^ BOP Test ^ Mechanical Integ rity Test ^ Location Clearance ^ '`+ Other: SrC~ .7d1' Q~ l"i C~ J -~ ~~ 1 '~O ~ ~'~Vll E~~a~ Subsequent Form Required: ~o APPROVED BY /J ~~,Q~ Approved by: COMMISSIONER THE COMMISSION ~~ Date: ~1 Form 10-403 Revised 06/2006 ( ~~~ Submit in Dyypplicate • 1J-136L1 • DESCRIPTION SUMMARY OF PROPOSAL i ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Dual-lateral Well 1 J-136L1. Plans are to pre-produce well for 30 days in order to recover Oil based drilling fluids prior to putting the well on injection. Lateral 1 J-136L1 will provide pressure , support for the West Sak D sands. The 13-3/8" Surface casing (3501' and / 2196' tvd) was cemented with 690 sx AS Lite followed by 220 sx DeepCRETE. The 9-5/8" Intermediate casing (9730' and / 3591' tvd) was cemented with 750 sx DeepCRETE. The injection tubing/casing annulus is isolated via the following: Upper D sand ZXP 7'° x 9-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 9023' and / 3503' tvd, Upper B sand HRD ZXP 7" x 9-5/8" Liner Top Packer with 190-47 Casing Sealbore Ext. located @ 9196' and / 3527' tvd. The top of West Sak D sand was found at 9081' and / 3510' tvd. D sand Lateral window top is located @ 9084' and / 3511' tvd. The top of West Sak B sand was found at 9681' and / 3587' tvd. KRU 1J-136L1 CORRECTION ---- FW: 1J-136 D Lateral Tool Failure Sidetracks #1 & #2 Page 1 of 2 • • Maunder, Thomas E (DOA) From: Reilly, Patrick J [Patrick.J.Reilly@conocophillips.com] Sent: Tuesday, February 20, 2007 4:03 PM To: Thomas Maunder Subject: CORRECTION --- FW: 1 J-136 D Lateral Tool Failure Sidetracks #1 & #2 Attachments: Patrick.).Reilly@conocophillips.com.vcf; Patrick.).Reilly@conocophillips.com.vcf Tom, I was finalizing some 1J-136 well paperwork and noticed an error in one of the reported abandoned section values. 1J-136 L1 P62 has a beginning abandoned depth of 12,990' not 12,290'. Please see corrected data below. 12,990' is the number in the daily operations detail. I must have read it wrong when I was drafting the original e-mail. Sorry about the confusion. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907} 265-1535 FAX Patrick.). Reil ly@conocophillips. co_rr~ «Patrick.J.Reilly@conocophillips.com.vcf» -----Original Message----- From: Reilly, Patrick J Sent: Wednesday, December 20, 2006 6:14 PM To: Thomas Maunder' Subject: 1J-136 D Lateral Tool Failure Sidetracks #1 & #2 Tom, We had two tool failure related sidetracks in the last 2 days. The details of the sidetracks are as follows: 1J-136 L1 P61 • Well: 1 J-136 • Rig: Doyon 15 • Date: 12/18/06 • Time: 1930 hrs • Last Casing Window: 9,100 • MD of abandoned section: 1J-136 L1 PB2 • Well: 1 J-136 • Rig: Doyon 15 • Date: 12/20/06 7/3/2007 13,275' - 14,426' CORRECTION ---- FW: 1J-136 D Lateral Tool Failure Sidetracks #1 & #2 Page 2 of 2 • Time: 0200 hrs • Last Casing Window: 9,100 • MD of abandoned section: -^~ 12,390' - 13,398' We are abandoning two crooked hole sections that were caused by malfunctioning rotary steerable tools. We made two low side sidetracks. We are planning to isolate both sidetracks by allowing them to collapse. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J. Reilfy@conocophN_Il.ps.com. «Patrick.J.Reilly@conocophillips.com.vcf» 7/3/2007 Completion report for 1J-136L~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Allsup-Drake, Sharon K [Sharon.K.Allsup-Drake@conocophillips.com] Sent: Tuesday, February 20, 2007 1:17 PM To: Thomas Maunder Cc: Reilly, Patrick J Subject: Completion report for 1J-136L1 Tom - wediscovered recently a correction on the completion report for 1J-136L1. The hole size for the 5.5" x 4.5" should be 8.5" and 6.75". We drilled the 8.5" hole until a point where we had to narrow the hole size to allow a tool to descend easier. This is not a typical occurrence on our development wells which led to our oversight when filling out the completion report. How do you recommend we handle this? I could send over a revised first page. Thanks, Sharon office phone: 263-4612 fax: 265-6224 7/3/2007 I~ ConocoPhillips February 5, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1J-136 and 1J-136L1 Dear Commissioner: Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak wells 1J-136 and 1J-136L1. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, ~..u.~,~ ...... _ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ~~ • STATE OF ALASKA '~~1; ~ ~~~il ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPO`~i~~~~~~~u{ 1a. Well Status: Oil ^ Gas Plugged Abandoned ^ Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1 b. Well Class: Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: January 3, 2007 ~ 12. Permit to Drill Number: 206-155 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudde r, /Z ~` No 6 ~ 13. API Number: 50-029-23331-60 4a. Location of Well (Governmental Section): Surface: 1564' FSL, 2282' FEL, Sec. 35, T11 N, R10E, UM ~ 7. Date TD Reached: ~? 01 December 27, 2006 14. Well Name and Number: 1 J-136L1 At Top Productive Horizon: 374' FNL, 404' FEL, Sec. 11, T10N, R10E, UM 8. KB Elevation (ft): 37' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 2082' FSL, 456' FEL, Sec. 14, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 17223' MD / 3418' TVD West Sak Oil POOI 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558931 J y- 5945378 Zone- 4 10. Total Depth (MD + TVD): 17233' MD / 3417' TVD ~ 16. Property Designation: ADL 25662 & 380058 TPI: x- 560872 y- 5938175 Zone- 4 Total Depth: x- 560892 - 5930072 Zone- 4 11. Depth where SSSV set: landing nipple @ 504' 17. Land Use Permit: ALK 2177 & 4604 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3510' MD 21. Logs Run: w ~ ~/ /1/,~~3s~~ ~ ~/~ GR/Res, Dens/Neu ,,QD 2.7. e7 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 62.58# H-40 37' 113' 37' 113' 42" 375 sx AS 1 13.375" 68# L-80 37' 3501' 37' 2196' 16" 690 sx AS Lite, 22o sx DeepCrete 9-5/8" 40# L-80 37' 9730' 37' 3591' 12.25" 75o sx DeepCRETE 5.5" x 4.5" 15.5# / 11.6# L-80 9082' 17223' 3510' 3418' 8.5" slotted liner 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore slotted liner from 9084'-9343', 9790'-10037', 10537'-10785', 11284'-11522', 12046'-12288', 12824'-13066', 13538'-13795', 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 14181'-14653', 15125'-15382', 15769'-16029', 16498'-16756' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production waiting on facility hook-up Method of Operation (Flowing, gas lift, etc.) Oil Producer -shares production with 1 J-136 Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-o1L RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 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". I~~~ . ~ ~Q ~ ~ ~~Qf i Cu t -,- f u /~iC NONE ,_[_,~.~~r QtE~dFd~l} Form 10-407 Revised 12!2003 CONTINUED ON REVERSE Z .?.6~ ... 2a. 2s. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. It no tests were conducted, state "None". 1 J-136L1 Top West Sak D 9081' 3510' 1J-136L1PB1 TD 14426' 3429' N/A 1 J-136L1 P62 13397' 3452' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Slotted Liner Detail Sheets 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Namer---^~Rand Thoma Title: Greater Kuaaruk Area Drilling Team Leader L `~`~~ ~ - ~~^^ D ` l ~ ~~ 7 Si t t ° gna ure a e ,z,~~ ~ ~..~ 3 r~ 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 r Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 1/23/2007 Time: 13:59:24 Page: 1 ' FieIJ: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-136, True North Site: KuparuklJPad Vertical (TVD)Reference: 1J-136L1:126.6 '14'ell: 1J-136 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-136L1 Survey Calculation Dlcthod: __ _ __ Minimum Curvature llb: Oracle Field: Kuparuk River Unit - North Slope Alaska United States 'i Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) s Datum: Mean Sea Level S Coordinate System: Geoma netic Model: Well Centre I, bggm2006 y g WeII: 1J-136 Slot Name: Well Position: +N/-S -543.14 ft Northing: 5945377.64 ft Latitude: 70 15 40.916 N +E/-W 136.78 ft Easting : 558930.95 ft Longitude: 149 31 25.027 W Position Uncertainty: 0.00 ft ~ Wellpath: 1J-136L1 Drilled From: 1J-136L1PB1 500292333172 Tie-on Depth: 12989.38 ft Current Datum: 1J-136L1: Height 126.60 ft Above System Datum: Mean Sea Level Magnetic Data: 11/17/2006 Declination: 23.72 deg Field Strength: 57613 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 45.50 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 1/23/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft i 120.00 815.00 1J-136P61 gyro (120.00-815.00) CB-GYRO-SS Camera based gyro single shot 848.68 8693.47 1J-136P61 (848.68-8786.52) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8700.00 9072.21 1J-136 (8700.00-17475.72) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ', 9084.00 12989.38 1J-136L1P61 (9084.00-14319.85) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12990.00 17195.25 1J-136L1 (12990.00-17195.25) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD [ncl Azim TVD ft deg deg ft ---- -- 45.50 0.00 0.00 45.50 120.00 0.20 47.82 120.00 171.00 0.14 285.78 171.00 265.00 0.27 139.61 265.00 352.00 2.78 197.00 351.96 450.00 6.34 203.00 449.64 536.00 7.46 210.17 535.02 635.00 9.75 215.20 632.90 735.00 12.62 218.15 730.99 815.00 14.54 214.61 808.75 I~ i 848.68 14.47 210.72 841.36 942.92 13.87 206.23 932.73 1037.30 17.05 197.44 1023.70 ~ 1134.76 21.29 193.44 1115.73 1228.85 25.03 191.05 1202.23 1324.31 29.33 189.97 1287.13 1419.52 33.46 185.70 1368.39 1515.12 36.71 182.56 1446.62 1609.68 42.44 181.81 1519.47 1704.86 45.67 181.69 1587.87 1798.73 49.25 182.85 1651.32 1895.85 53.54 180.56 1711.91 1990.76 56.49 178.87 1766.33 ', 2085.78 62.49 175.78 1814.55 2180.15 65.96 175.41 1855.58 2275.63 70.43 172.88 1891.05 Sys 'f V ll ft -81.10 -6.60 44.40 138.40 225.36 323.04 408.42 506.30 604.39 682.15 714.76 806.13 897.10 989.13 1075.63 1160.53 1241.79 1320.02 1392.87 1461.27 1524.72 1585.31 1639.73 1687.95 1728.98 1764.45 iti~S E/W M1tapN ft ft ft 0 _-- .00 0 _ __ .00 __ 5945377. 64 0 .09 0 .10 5945377. 73 0 .16 0 .10 5945377. 80 0 .03 0 .14 5945377. 67 -2 .15 -0 .35 5945375. 49 -9 .40 -3 .16 5945368. 21 -18 .60 -7 .82 5945358. 98 -31 .01 -15 .88 5945346. 51 -46 .52 -27 .51 5945330. 91 -61 .66 -38 .62 5945315. 68 -68 .76 -43 .17 5945308. 55 -89 .01 -54 .18 5945288. 21 -112 .37 -63 .33 5945264. 79 -143 .23 -71 .73 5945233. 87 -179 .39 -79 .51 5945197. 65 -222 .26 -87 .44 5945154. 73 -271 .37 -94 .08 5945105. 57 -326 .16 -97 .98 5945050. 76 -386 .33 -100 .25 5944990. 57 -452 .47 -102 .27 5944924. 42 -521 .57 -105 .03 5944855. 31 -597 .41 -107 .24 5944779. 47 -675 .15 -106 .83 5944701. 74 -756 .87 -102 .95 5944620. 06 -841 .59 -96 .42 5944535. 40 -929 .74 -87 .35 5944447. 33 MapE _ 't ool ft 558930.95 TIE LINE 558931.05 CB-GYRO-SS 558931.05 CB-GYRO-SS 558931.09 CB-GYRO-SS 558930.62 CB-GYRO-SS 558927.87 CB-GYRO-SS 558923.28 CB-GYRO-SS 558915.31 CB-GYRO-SS 558903.80 CB-GYRO-SS 558892.82 CB-GYRO-SS 558888.32 MWD+IFR-AK-CAZ-SC 558877.48 MWD+IFR-AK-CAZ-SC 558868.51 MWD+IFR-AK-CAZ-SC 558860.35 MWD+IFR-AK-CAZ-SC 558852.85 MWD+IFR-AK-CAZ-SC 558845.26 MWD+IFR-AK-CAZ-SC ~~ 558839.00 MWD+IFR-AK-CAZ-SC 558835.54 MWD+IFR-AK-CAZ-SC 558833.73 MWD+IFR-AK-CAZ-SC 558832.23 MWD+IFR-AK-CAZ-SC 558830.02 MWD+IFR-AK-CAZ-SC 558828.40 MWD+IFR-AK-CAZ-SC 558829.41 MWD+IFR-AK-CAZ-SC 558833.94 MWD+IFR-AK-CAZ-SC 558841.13 MWD+IFR-AK-CAZ-SC 558850.89 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 1!23!2007 __ Timer 13:59:24 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-136, True North Sitr. Kuparuk 1J Pad Vertical (TVD) Reference: 1J-136L1: 126.6 Well: 1J-136 Section(VS)Reference: Well(O.OON,O.OOE,180.OOAzi) Wellpath: 1 J-136L1 Sun~ey Calculation Method: Minimum Curvature Ub: Oraele Survey MD Iuc l Azim TVD Sys TVD N/S ft deg - deg - ft ft ft 2370.17 75 .31 170. 62 1918. 89 1792. 29 -1019 .11 2466.49 77 .31 168. 78 1941. 68 1815. 08 -1111 .18 2562.02 77 .65 165. 14 1962. 40 1835. 80 -1202 .01 2656.89 78 .08 161. 08 1982. 35 1855. 75 -1290 .74 2751.03 77 .04 158. 83 2002. 63 1876. 03 -1377 .10 2847.52 74 .33 155. 61 2026. 49 1899. 89 -1463. 28 2942.22 75 .53 155. 39 2051. 11 1924. 51 -1546. 49 3037.83 74 .33 155. 49 2075. 97 1949. 37 -1630. 46 3133.17 74 .30 156. 45 2101. 75 1975. 15 -1714. 29 3227.45 71 .25 155. 98 2129. 66 2003. 06 -1796. 69 j 3322.39 77 .47 155. 05 2155. 25 2028. 65 -1879. 84 3416.75 76 .91 154. 82 2176. 17 2049. 57 -1963. 19 3466.52 76 .15 154. 70 2187. 76 2061. 16 -2006. 97 3552.93 74 .51 155. 23 2209. 64 2083. 04 -2082 .71 3647.71 75 .21 157. 64 2234. 40 2107. 80 -2166 .56 3742.63 75 .74 157. 42 2258. 21 2131. 61 -2251 .47 3838.51 75 .42 159. 32 2282. 09 2155. 49 -2337 .79 3933.33 75 .40 160. 21 2305. 97 2179. 37 -2423 .88 4027.56 77 .96 161. 69 2327. 68 2201. 08 -2510 .55 4123.78 77 .54 162. 94 2348. 10 2221. 50 -2600 .13 4218.48 76 .69 163. 15 2369. 21 2242. 61 -2688 .43 4314.18 75 .58 163. 58 2392. 15 2265. 55 -2777 .46 4408.86 75 .71 163. 49 2415. 62 2289. 02 -2865 .42 4503.15 76 .55 164. 02 2438. 22 2311. 62 -2953 .30 4600.43 76 .13 164. 36 2461. 20 2334. 60 -3044 .25 4694.51 75 .86 164. 53 2483 .97 2357. 37 -3132 .19 4789.98 74 .97 165. 83 2508. 01 2381. 41 -3221 .51 4885.79 ~ 76 .74 165. 10 2531 .42 2404. 82 -3311 .44 I 4981.19 75 .05 165. 10 2554 .67 2428. 07 -3400 .85 5075 .80 75.79 165. 70 2578 .49 5171 .78 76.40 165. 52 2601 .55 5265 .59 74.53 166. 26 2625 .09 5361 .20 74.24 165. 03 2650 .83 5457 .33 74.26 164. 10 2676 .92 5552 .50 77.11 162. 26 2700 .45 5647 .52 76.07 162. 59 2722 .49 5742 .83 75.16 164. 48 2746. 17 5836 .32 76.20 162. 83 2769. 30 5932 .78 76.49 163. 50 2792. 07 6028 .11 78.25 163. 26 2812. 91 6123 .03 78.56 164. 09 2831 .99 6218 .26 77.83 164. 18 2851 .47 6312 .97 78.26 164. 81 2871 .09 6407 .99 78.39 165. 64 2890 .32 6502 .97 78.14 164. 05 2909 .64 6598 .32 76.41 164. 52 2930 .64 6693 .68 76.48 163. 31 2952 .99 6788 .75 77.51 162. 41 2974 .39 6885 .02 77.09 162. 36 2995 .55 6980 .08 75.74 161. 32 3017 .88 7073 .70 76.06 161. 10 3040 .69 7169 .70 75.37 159. 78 3064 .37 7264 .91 75.32 160. 47 3088 .46 E/W ft -74.36 -57.63 -36.59 -9.64 21.86 58.04 95.96 134.33 171.71 208.02 245.90 284.88 305.52 340.89 377.46 412.58 446.81 478.55 508.47 537.03 563.95 590.55 616.55 642.16 667.91 692.39 716.02 739.34 763.13 !11apN ft 5944358.07 5944266.15 5944175.49 5944086:99 5944000.89 5943914.99 5943832.09 5943748.44 5943664.91 5943582.81 5943499.96 5943416.93 5943373.31 5943297.87 5943214.31 5943129.68 5943043.65 5942957.81 5942871.39 5942782.04 5942693.96 5942605.16 5942517.41 5942429.74 5942339.00 5942251.26 5942162.14 5942072.41 5941983.20 2451. 89 -3489 .45 786. 21 5941894 .78 2474. 95 -3579 .70 809. 37 5941804 .73 2498. 49 -3667 .76 831. 50 5941716 .85 2524. 23 -3756 .96 854. 33 5941627 .84 2550. 32 -3846 .15 878. 96 5941538 .86 2573. 85 -3934 .40 905. 65 5941450 .82 2595. 89 -4022 .51 933 .55 5941362 .94 2619. 57 -4111 .04 959. 72 5941274 .63 2642. 70 -4197 .96 985. 22 5941187 .92 2665. 47 -4287 .68 1012. 36 5941098 .43 2686. 31 -4376 .81 1038. 97 5941009 .51 2705. 39 -4466 .04 1065. 11 5940920 .50 2724. 87 -4555 .71 1090. 59 5940831 .04 2744. 49 -4644 .99 1115. 36 5940741 .96 2763. 72 -4734 .97 1139. 09 5940652 .18 2783. 04 -4824 .73 1163. 40 5940562 .63 2804. 04 -4914 .25 1188. 59 5940473 .31 2826. 39 -5003 .33 1214. 27 5940384 .45 2847. 79 -5091 .84 1241. 57 5940296 .16 2868. 95 -5181 .35 1269 .99 5940206 .88 2891. 28 -5269 .15 1298 .79 5940119 .32 2914. 09 -5355 .11 1328 .04 5940033 .60 2937. 77 -5442 .77 1359 .18 5939946 .20 2961. 86 -5529 .39 1390 .49 5939859 .83 nIApE. TDOI ft - -- 558864.57 __ __- MWD+IFR-AK-CAZ-SC 558882.03 MWD+IFR-AK-CAZ-SC 558903.77 MWD+IFR-AK-CAZ-SC 558931.41 MWD+IFR-AK-CAZ-SC 558963.58 MWD+IFR-AK-CAZ-SC 559000.43 MWD+IFR-AK-CAZ-SC 559039.00 MWD+IFR-AK-CAZ-SC I 559078.02 MWD+IFR-AK-CAZ-SC 559116.05 MWD+IFR-AK-CAZ-SC 559153.00 MWD+IFR-AK-CAZ-SC 559191.53 MWD+IFR-AK-CAZ-SC 559231.16 MWD+IFR-AK-CAZ-SC 559252.14 MWD+IFR-AK-CAZ-SC 559288.10 MWD+IFR-AK-CAZ-SC 559325.32 MWD+IFR-AK-CAZ-SC 559361.10 MWD+IFR-AK-CAZ-SC 559396.00 MWD+IFR-AK-CAZ-SC 559428.41 MWD+IFR-AK-CAZ-SC 559459.00 MWD+IFR-AK-CAZ-SC 559488.26 MWD+IFR-AK-CAZ-SC 559515.87 MWD+IFR-AK-CAZ-SC 559543.16 MWD+IFR-AK-CAZ-SC 559569.84 MWD+IFR-AK-CAZ-SC 559596.14 MWD+IFR-AK-CAZ-SC 559622.60 MWD+IFR-AK-CAZ-SC 559647.76 MWD+IFR-AK-CAZ-SC 559672.09 MWD+IFR-AK-CAZ-SC 559696.11 MWD+IFR-AK-CAZ-SC 559720.60 MWD+IFR-AK-CAZ-SC 559744.37 MWD+IFR-AK-CAZ-SC 559768.22 MWD+IFR-AK-CAZ-SC 559791.05 MWD+IFR-AK-CAZ-SC 559814.57 MWD+IFR-AK-CAZ-SC 559839.89 MWD+IFR-AK-CAZ-SC 559867.27 MWD+IFR-AK-CAZ-SC 559895.86 MWD+IFR-AK-CAZ-SC 559922.72 MWD+IFR-AK-CAZ-SC 559948.89 MWD+IFR-AK-CAZ-SG 559976.74 MWD+IFR-AK-CAZ-SC 560004.04 MWD+IFR-AK-CAZ-SC 560030.87 MWD+IFR-AK-CAZ-SC 560057.05 MWD+IFR-AK-CAZ-SC 560082.51 MWD+IFR-AK-CAZ-SC 560106:94 MWD+IFR-AK-CAZ-SC 560131.95 MWD+IFR-AK-CAZ-SC 560157.84 MWD+IFR-AK-CAZ-SC 560184.22 MWD+IFR-AK-CAZ-SC 560212.21 MWD+IFR-AK-CAZ-SC 560241.33 MWD+IFR-AK-CAZ-SC 560270.81 MWD+IFR-AK-CAZ-SC 560300.72 MWD+IFR-AK-CAZ-SC 560332.55 MWD+IFR-AK-CAZ-SC 560364.54 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska lnc. Date: 1/23/2007 Time: 13:59:24 Page: 3 .Field: Kuparuk River Unit Co-ordiuate(NE) Reference: Well: 1J-136, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-136L1: 126.6 Well: 1J-136 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-136L1 Survey Calculation Method: Minimum Curvature Db: Oracle - ___ SUrvly 111D Incl Azim TVD Sys TVD N/S E/tiV ]1iapN MapE Tool '~, ft deg deg ft ft ft ft ft ft 7360. 01 75. 91 160. 13 3112 .09 2985. 49 -5616 .12 1421. 55 5939773. 35 560396. 26 MWD+IFR-AK-CAZ-SC 7455. 22 75. 95 159. 52 3135 .24 3008. 64 -5702 .81 1453. 40 5939686. 93 560428. 79 MWD+IFR-AK-CAZ-SC 7548. 91 75. 50 160. 57 3158 .34 3031. 74 -5788 .15 1484. 39 5939601. 84 560460. 44 MWD+IFR-AK-CAZ-SC 7645. 28 75. 37 160. 94 3182 .57 3055. 97 -5876 .21 1515. 13 5939514. 03 560491. 87 MWD+IFR-AK-CAZ-SC 7738. 81 74. 66 160. 16 3206 .76 3080. 16 -5961 .40 1545. 21 5939429. 08 560522. 62 MWD+IFR-AK-CAZ-SC 7835. 65 73. 99 161. 81 3232 .92 3106. 32 -6049 .55 1575. 59 5939341. 19 560553. 68 MWD+IFR-AK-CAZ-SC 7930. 56 74. 02 161. 73 3259 .08 3132 .48 -6136 .21 1604. 13 5939254. 76 560582. 90 MWD+IFR-AK-CAZ-SC j 8025. 73 77. 06 160. 74 3282 .84 3156 .24 -6223 .45 1633. 78 5939167. 76 560613. 22 MWD+IFR-AK-CAZ-SC 8119. 36 76. 89 161. 17 3303 .94 3177 .34 -6309 .68 1663. 55 5939081. 78 560643. 66 MWD+IFR-AK-CAZ-SC 8216. 42 75. 28 162. 91 3327 .28 3200 .68 -6399 .29 1692. 60 5938992. 41 560673. 41 MWD+IFR-AK-CAZ-SC 8312. 10 76. 06 162. 35 3350. 96 3224. 36 -6487 .76 1720. 28 5938904. 16 560701. 78 MWD+IFR-AK-CAZ-SC 8407. 06 74. 58 162. 16 3375 .03 3248. 43 -6575 .25 1748. 27 5938816. 90 560730. 45 MWD+IFR-AK-CAZ-SC 8502. 36 76. 41 162. 53 3398 .90 3272. 30 -6663 .16 1776. 25 5938729. 22 560759. 12 MWD+IFR-AK-CAZ-SC 8598. 36 75. 80 162. 40 3421 .95 3295. 35 -6752 .02 1804. 33 5938640. 59 560787. 89 MWD+IFR-AK-CAZ-SC 8693. 47 76. 14 165. 01 3445 .01 3318. 41 -6840 .58 1830. 21 5938552. 25 560814. 46 MWD+IFR-AK-CAZ-SC 8700. 00 76. 25 165. 25 3446 .57 3319. 97 -6846 .71 1831. 84 5938546. 13 560816. 14 MWD+IFR-AK-CAZ-SC 8787. 00 77. 74 169. 13 3466 .15 3339 .55 -6929 .35 1850. 62 5938463. 65 560835. 56 MWD+IFR-AK-CAZ-SC 8882. 71 82. 01 171. 81 3482 .98 3356 .38 -7022 .24 1866. 20 5938370. 89 560851. 87 MWD+IFR-AK-CAZ-SC 8976. 03 81. 74 174. 42 3496 .17 3369 .57 -7113 .95 1877. 28 5938279. 28 560863. 66 MWD+IFR-AK-CAZ-SC 9072. 21 82. 69 176. 94 3509 .20 3382 .60 -7208 .97 1884. 45 5938184. 33 560871. 58 MWD+IFR-AK-CAZ-SC 9084. 00 82. 46 177. 12 3510 .72 3384 .12 -7220 .64 1885. 06 5938172. 66 560872. 27 MWD+IFR-AK-CAZ-SC 9182. 98 87. 16 178. 50 3519 .67 3393 .07 -7319 .11 1888. 82 5938074. 23 560876. 80 MWD+IFR-AK-CAZ-SC 9278. 32 87. 33 179. 82 3524 .26 3397 .66 -7414 .33 1890 .22 5937979. 04 560878. 95 MWD+IFR-AK-CAZ-SC 9373. 19 88. 94 181. 14 3527 .34 3400 .74 -7509 .14 1889 .42 5937884. 23 560878. 89 MWD+IFR-AK-CAZ-SC 9467. 44 90. 73 182. 26 3527 .62 3401 .02 -7603 .35 1886 .63 5937790. 02 560876. 83 MWD+IFR-AK-CAZ-SC 9566. 53 91. 79 181. 00 3525 .44 3398 .84 -7702 .37 1883 .81 5937690. 99 560874. 79 MWD+IFR-AK-CAZ-SC 9661. 20 92. 77 182. 37 3521 .67 3395 .07 -7796 .92 1881 .03 5937596. 43 560872. 75 MWD+IFR-AK-CAZ-SC 9756. 28 92. 02 181. 58 3517 .70 3391 .10 -7891 .86 1877 .75 5937501. 48 560870. 22 MWD+IFR-AK-CAZ-SC 9851. 03 90. 35 180 .26 3515 .74 3389 .14 -7986 .57 1876 .23 7406. 593 76 . 560869 44 MWD IFR-AK-CAZ-SC 9946. 21 90. 91 179 .07 3514 .69 3388 .09 -8081 .74 1876 .79 5937311. 61 560870. 74 MWD+IFR-AK-CAZ-SC i 10041. 31 90. 60 179. 66 3513 .44 3386 .84 -8176 .83 1877 .84 5937216. 54 560872. 54 MWD+IFR-AK-CAZ-SC 10136. 91 90. 48 180. 87 3512 .54 3385 .94 -8272 .42 1877. 40 5937120. 96 560872. 85 MWD+IFR-AK-CAZ-SC 10230. 65 90. 60 181. 06 3511 .65 3385 .05 -8366 .14 1875. 82 5937027. 24 560872. 00 MWD+IFR-AK-CAZ-SC 10326. 60 91. 10 180. 30 3510 .23 3383 .63 -8462 .07 1874. 68 5936931. 31 560871. 61 MWD+IFR-AK-CAZ-SC 10421. 58 91. 04 180. 88 3508 .46 3381 .86 -8557 .03 1873. 70 5936836. 36 560871. 38 MWD+IFR-AK-CAZ-SC 10515. 61 88. 99 181. 04 3508 .43 3381 .83 -8651 .04 1872. 13 5936742. 34 560870. 54 MWD+IFR-AK-CAZ-SC 10609. 39 91. 10 183. 37 3508 .36 3381 .76 -8744 .74 1868 .52 5936648. 63 560867. 66 MWD+IFR-AK-CAZ-SC ~~ 10703. 46 91. 90 184. 70 3505 .90 3379 .30 -8838 .54 1861 .91 5936554. 79 560861. 78 MWD+IFR-AK-CAZ-SC 10799. 57 91. 96 181. 23 3502 .66 3376 .06 -8934 .46 1856 .94 5936458. 85 560857. 57 MWD+IFR-AK-CAZ-SC 10895. 47 91. 34 176. 63 3499 .90 3373 .30 -9030 .27 1858 .73 5936363. 06 560860. 11 MWD+IFR-AK-CAZ-SC 10991. 15 93. 51 176. 09 3495 .85 3369 .25 -9125 .67 1864 .80 5936267. 72 560866. 92 MWD+IFR-AK-CAZ-SC 11086. 57 92. 64 176. 54 3490 .73 3364 .13 -9220 .75 1870 .92 5936172. 70 560873. 79 MWD+IFR-AK-CAZ-SC 11181. 19 91. 28 177. 34 3487 .49 3360 .89 -9315 .18 1875 .97 5936078. 32 560879. 57 MWD+IFR-AK-CAZ-SC 11276. 28 89. 80 175. 84 3486 .60 3360 .00 -9410 .09 1881 .62 5935983. 46 560885. 97 MWD+IFR-AK-CAZ-SC 11372. 32 86. 83 177 .61 3489 .42 3362 .82 -9505 .92 1887 .11 5935887. 69 560892. 20 MWD+IFR-AK-CAZ-SC 11467. 59 86. 40 177 .75 3495 .05 3368 .45 -9600 .94 1890 .96 5935792. 71 560896. 80 MWD+IFR-AK-CAZ-SC 11562. 18 86. 90 180 .11 3500 .57 3373 .97 -9695 .35 1892 .72 5935698. 33 560899. 30 MWD+IFR-AK-CAZ-SC 11652. 29 93. 26 183 .12 3500 .45 3373 .85 -9785 .37 1890 .18 5935608. 30 .560897. 47 MWD+IFR-AK-CAZ-SC i 11752. 76 92. 08 182 .29 3495 .77 3369 .17 -9885 .61 1885 .45 5935508. 03 560893. 51 MWD+IFR-AK-CAZ-SC 11846. 80 90. 41 182 .51 3493 .72 3367 .12 -9979 .55 1881 .51 5935414. 08 560890. 31 MWD+IFR-AK-CAZ-SC 11943. 01 91. 41 181 .32 3492 .20 3365 .60 -10075 .69 1878 .29 5935317. 93 560887. 85 MWD+IFR-AK-CAZ-SC 12038. 43 89. 30 177 .66 3491 .60 3365 .00 -10171 .08 1879 .14 5935222. 55 560889. 45 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report i Company: ConocoPhillips Alaska InC. llate: 1/23/2007 Time: 13:59:24 Pale: S Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-136, True North Site: Kuparuk 1J Pad Vertical (TVD) ticfcrence: 1J-136L1: 126.6 Well: 1J-136 Secfion (VS) Keference: Well (O.OON,O.OOE,180.OOAzi) N'ellpath: 1 J-136L1 Survey CaMulation Dtethod: Minimum Curvature Db: Oracle __ _ __ __ Survcy MD Incl Azim TVD Sys TVD !~/S El1V MapN VIapE Tool ft deg deg ft ft ft ft ft ft 12132.52 91.41 177.98 3491.02 3364.42 -10265.09 1882.72 5935128.58 560893.76 MWD+IFR-AK-CAZ-SC 12228.40 88.50 176.25 3491.10 3364.50 -10360.84 1887.55 5935032.88 560899.33 MWD+IFR-AK-CAZ-SC ~~ 12322.96 92.15 177.57 3490.56 3363.96 -10455.24 1892.64 5934938.53 560905.17 MWD+IFR-AK-CAZ-SC i 12418.40 93.88 178.67 3485.54 3358.94 -10550.49 1895.77 5934843.32 560909.04 MWD+IFR-AK-CAZ-SC 12513.54 95.24 181.15 3477.98 3351.38 -10645.32 1895.92 5934748.50 560909.93 MWD+IFR-AK-CAZ-SC 12608.47 94.87 181.77 3469.61 3343.01 -10739.85 1893.51 5934653.97 560908.26 MWD+IFR-AK-CAZ-SC 12703.38 94.44 180.28 3461.91 3335.31 -10834.43 1891.82 5934559.39 560907.31 MWD+IFR-AK-CAZ-SC 12799.20 93.63 180.36 3455.17 3328.57 -10930.01 1891.29 5934463.81 560907.53 MWD+IFR-AK-CAZ-SC 12894.96 91.65 180.48 3450.76 3324.16 -11025.66 1890.59 5934368.17 560907.57 MWD+IFR-AK-CAZ-SC 12989.38 89.98 178.56 3449.41 3322.81 -11120.06 1891.38 5934273.79 560909.10 MWD+IFR-AK-CAZ-SC 12990.00 89.98 178.56 3449.41 3322.81 -11120.68 1891.39 5934273.17 560909.13 MWD+lFR-AK-CAZ-SC I 13082.38 89.05 181.38 3450.19 3323.59 -11213.05 1891.44 5934180.81 560909.90 MWD+IFR-AK-CAZ-SC 13178.10 89.99 181.70 3451.00 3324.40 -11308.73 1888.87 5934085.13 560908.07 MWD+IFR-AK-CAZ-SC 13271.60 91.78 185.74 3449.55 3322.95 -11402.00 1882.81 5933991.82 560902.74 MWD+IFR-AK-CAZ-SC ~I 13318.95 89.20 184.35 3449.15 3322.55 -11449.16 1878.64 5933944.64 560898.95 MWD+IFR-AK-CAZ-SC 13418.27 94.93 181.40 3445.57 3318.97 -11548.23 1873.66 5933845.53 560894.74 MWD+IFR-AK-CAZ-SC 13516.73 91.85 179.67 3439.75 3313.15 -11646.50 1872.75 5933747.27 560894.60 MWD+IFR-AK-CAZ-SC 13617.40 92.91 175.91 3435.57 3308.97 -11746.99 1876.62 5933646.82 560899.26 MWD+IFR-AK-CAZ-SC 13666.95 93.02 174.96 3433.00 3306.40 -11796.32 1880.56 5933597.53 560903.58 MWD+IFR-AK-CAZ-SC 13715.54 92.40 174.82 3430.70 3304.10 -11844.66 1884.88 5933549.23 560908.28 MWD+IFR-AK-CAZ-SC ~~ 13765.01 91.65 174.82 3428.96 3302.36 -11893.90 1889.35 5933500.03 560913.13 MWD+IFR-AK-CAZ-SC 13814.78 91.11 174.01 3427.76 3301.16 -11943.42 1894.19 5933450.56 560918.36 MWD+IFR-AK-CAZ-SC 13913.56 89.81 173.45 3426.97 3300.37 -12041.60 1904.98 5933352.47 560929.92 MWD+IFR-AK-CAZ-SC 13963.87 88.82 172.17 3427.57 3300.97 -12091.51 1911.27 5933302.62 560936.60 MWD+IFR-AK-CAZ-SC 14012.11 88.33 172.10 3428.77 3302.17 -12139.28 1917.87 5933254.91 560943.57 MWD+IFR-AK-CAZ-SC 14111.07 91.92 175.19 3428.55 3301.95 -12237.60 1928.82 5933156.68 560955.29 MWD+IFR-AK-CAZ-SC 14210.04 92.61 174.78 3424.64 3298.04 -12336.12 1937.47 5933058.25 560964.71 MWD+IFR-AK-CAZ-SC 14308.84 90.72 174.86 3421.77 3295.17 -12434.47 1946.39 5932959.98 560974.39 MWD+IFR-AK-CAZ-SC 14408.52 88.57 175.22 3422.39 3295.79 -12533.77 1955.00 5932860.76 560983.78 MWD+IFR-AK-CAZ-SC !~ 14507.29 88.87 175.30 3424.59 3297.99 -12632.17 1963.16 5932762.43 560992.71 MWD+IFR-AK-CAZ-SC ~~ 14605.79 89.33 174.58 3426.14 3299.54 -12730.28 1971.85 5932664.41 561002.17 MWD+IFR-AK-CAZ-SC 14704.48 88.87 173.93 3427.69 3301.09 -12828.46 1981.73 5932566.32 561012.81 MWD+IFR-AK-CAZ-SC 14803.62 87.65 173.57 3430.70 3304.10 -12926.96 1992.51 5932467.91 561024.37 MWD+IFR-AK-CAZ-SC 14849.99 86.78 172.69 3432.95 3306.35 -12972.94 1998.05 5932421.98 561030.27 MWD+IFR-AK-CAZ-SC 14901.36 85.93 173.61 3436.22 3309.62 -13023.84 2004.17 5932371.13 561036.78 MWD+IFR-AK-CAZ-SC 14943.15 85.43 174.41 3439.37 3312.77 -13065.28 2008.52 5932329.73 561041.45 MWD+IFR-AK-CAZ-SC 15000.99 85.29 174.01 3444.05 3317.45 -13122.64 2014.33 5932272.42 561047.72 MWD+IFR-AK-CAZ-SC 15043.34 85.86 171.22 3447.31 3320.71 -13164.51 2019.76 5932230.60 561053.47 MWD+IFR-AK-CAZ-SC 15097.46 89.44 170.61 3449.53 3322.93 -13217.90 2028.30 5932177.29 561062.42 MWD+IFR-AK-CAZ-SC i 15198.49 91.54 171.84 3448.67 3322.07 -13317.73 2043.71 5932077.59 561078.61 MWD+IFR-AK-CAZ-SC 15297.11 92.47 171.60 3445.22 3318.62 -13415.26 2057.90 5931980.18 561093.57 MWD+IFR-AK-CAZ-SC 15347.16 93.53 172.92 3442.60 3316.00 -13464.79 2064.63 5931930.71 561100.69 MWD+IFR-AK-CAZ-SC 15396.40 94.31 174.07 3439.23 3312.63 -13513.60 2070.20 5931881.96 561106.63 MWD+IFR-AK-CAZ-SC 15445.87 93.83 173.11 3435.72 3309.12 -13562.63 2075.71 5931832.97 561112.53 MWD+IFR-AK-CAZ-SC 15477.68 93.56 172.84 3433.67 3307.07 -13594.14 2079.59 5931801.50 561116.65 MWD+IFR-AK-CAZ-SC 15577.97 87.57 174.04 3432.68 3306.08 -13693.72 2091.04 5931702.02 561128.88 MWD+IFR-AK-CAZ-SC 15673.12 90.85 179.38 3434.00 3307.40 -13788.66 2096.50 5931607.14 561135.08 MWD+IFR-AK-CAZ-SC ~ 15764.85 92.08 184.58 3431.65 3305.05 -13880.27 2093.33 5931515.51 561132.63 MWD+IFR-AK-CAZ-SC 15862.33 89.48 183.24 3430.32 3303.72 -13977.50 2086.69 5931418.24 561126.75 MWD+IFR-AK-CAZ-SC 15957.39 89.05 182.09 3431.54 3304.94 -14072.45 2082.27 5931323.27 561123.07 MWD+IFR-AK-CAZ-SC ~ 16052.17 88.25 184.17 3433.77 3307.17 -14167.06 2077.09 5931228.63 561118.64 MWD+IFR-AK-CAZ-SC 16147.83 90.11 185.53 3435.14 3308.54 -14262.36 2069.01 5931133.28 561111.30 MWD+IFR-AK-CAZ-SC 16243.40 91.28 188.03 3433.98 3307.38 -14357.24 2057.73 5931038.32 561100.76 MWD+IFR-AK-CAZ-SC 4 • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. llate: 1!23/2007 Time: 13:58'24 Page: 5 ', Field: Kuparuk River Unit Co-or dinate(NE) Reference: WeII: 1 J-136, Tru e North ', Site: Kuparuk 1J Pad ~'crtical(T~'D) Re ference: 1J-136L1: 126.6 Well: 1J-136 Sectio n (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-136L1 Survey Calculation Method: Minimum Curvat ure Db: Oracle -- Sun°cv ~tD [ncl Azim TVD SysTVD N/S EIW MapN NiapE - --_ Tool ft deg deg ft ft ft ft ft ft __-- 16338.53 91.77 190.73 3431.45 3304.85 -14451.06 2042.23 5930944.39 561086.00 ,I MWD+IFR-AK-CAZ-SC 16434.28 91.52 193.83 3428.70 3302.10 -14544.57 2021.87 5930850.74 561066.38 MWD+IFR-AK-CAZ-SC I I 16528.80 90.84 196.33 3426.76 3300.16 -14635.81 1997.29 5930759.32 561042.52 MWD+IFR-AK-CAZ-SC 16623.93 90.53 196.24 3425.62 3299.02 -14727.11 1970.62 5930667.81 561016.56 MWD+IFR-AK-CAZ-SC 16719.58 87.69 196.34 3427.10 3300.50 -14818.90 1943.79 5930575.83 560990.46 MWD+IFR-AK-CAZ-SC 16813.75 87.45 194.18 3431.10 3304.50 -14909.66 1919.03 5930484.88 560966.41 MWD+IFR-AK-CAZ-SC 16908.07 89.24 192.09 3433.82 3307.22 -15001.47 1897.61 5930392.92 560945.71 MWD+IFR-AK-CAZ-SC 17003.30 92.08 191.57 3432.72 3306.12 -15094.66 1878.09 5930299.59 560926.92 MWD+IFR-AK-CAZ-SC I 17098.72 94.31 189.44 3427.41 3300.81 -15188.32 1860.72 5930205.80 560910.29 MWD+IFR-AK-CAZ-SC 17195.25 94.37 187.56 3420.10 3293.50 -15283.52 1846.49 5930110.51 560896.81 MWD+IFR-AK-CAZ-SC 17233.00 94.37 187.56 3417.22. 3290.62 -15320.83 1841.54 5930073.16 560892.15 PROJECTED to TD • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. llate:1/23/2007 Time: 13:43:00 Page: l Field: Kuparuk River Unit Co-ordinate(NE) Reference: WeII: 1J-136, Tr ue North Site: Kuparuk 1J Pad Vertical (1'VD) Reference: 1J-136L1PB1:1 26.6 Well: 1J-136 Section (VS) Reference: Well (O.OON,O.OOE;180.OOAzi) Wellpath: 1 J-136L1 P61 Survey Calculation Ntethod: Minimum Curva ture Db: Oracle -. Field: Kuparuk River Unit - - North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 ~ Well: 1 J-136 Slot Name: ~ Well Position: +N/-S -543.14 ft Northing: 5945377.64 ft Latitude: 70 15 40.916 N +E/-W 136.78 ft Easting : 558930.95 ft Longitude: 149 31 25.027 W ~ Position Uncertainty: 0.00 ft I Wellpath: 1 J-136L1 PB1 Drilled From: 1 J-136 j 500292333100 Tie-on Depth: 9072.21 ft j Current Datum: 1J-136L1 P61: Height 126.60 ft Above System Datum: Mean Sea Level Magnetic Data: 11/17/2006 Declination: 23.72 deg ~ Field Strength: 57613 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 45.50 0.00 0.00 180.00 ', Survey Program for Definitive Wellpath Date: 1/23/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 120.00 815.00 1J-136PB1 gyro (120.00-815.00) CB-GYRO-SS Camera based gyro single shot 848.68 8693.47 1J-136P61 (848.68-8786.52) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 8700.00 9072.21 1J-136 (8700.00-17475.72) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9084.00 14319.85 1J-136L1P61 (9084. 00-14319.85) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey t~ID Incl Azim TVI) tics TVD N/S E/W MapN A1apE Tool ft deg deg ft ft ft ft _ -- ft' ft _ 45.50 0.00 0.00 45.50 -81.10 0.00 0.00 5945377.64 558930.95 TIE LINE 120.00 0.20 47.82 120.00 -6.60 0.09 0.10 5945377.73 558931.05 CB-GYRO-SS 171.00 0.14 285.78 171.00 44.40 0.16 0.10 5945377.80 558931.05 CB-GYRO-SS 265.00 0.27 139.61 265.00 138.40 0.03 0.14 5945377.67 558931.09 CB-GYRO-SS 352.00 2.78 197.00 351.96 225.36 -2.15 -0.35 5945375.49 558930.62 CB-GYRO-SS 450.00 6.34 203.00 449.64 323.04 -9.40 -3.16 5945368.21 558927.87 CB-GYRO-SS 536.00 7.46 210.17 535.02 408.42 -18.60 -7.82 5945358.98 558923.28 CB-GYRO-SS 635.00 9.75 215.20 632.90 506.30 -31.01 -15.88 5945346.51 558915.31 CB-GYRO-SS 735.00 12.62 218.15 730.99 604.39 -46.52 -27.51 5945330.91 558903.80 CB-GYRO-SS 815.00 14.54 214.61 808.75 682.15 -61.66 -38.62 5945315.68 558892.82 CB-GYRO-SS 848.68 14.47 210.72 841.36 714.76 -68.76 -43.17 5945308.55 558888.32 MWD+IFR-AK-CAZ-SC 942.92 13.87 206.23 932.73 806.13 -89.01 -54.18 5945288.21 558877.48 MWD+IFR-AK-CAZ-SC 1037.30 17.05 197.44 1023.70 897.10 -112.37 -63.33 5945264.79 558868.51 MWD+IFR-AK-CAZ-SC 1134.76 21.29 193.44 1115.73 989.13 -143.23 -71.73 5945233.87 558860.35 MWD+IFR-AK-CAZ-SC ~ 1228.85 25.03 191.05 1202.23 1075.63 -179.39 -79.51 5945197.65 558852.85 MWD+IFR-AK-CAZ-SC 1324.31 29.33 189.97 1287.13 1160.53 -222.26 -87.44 5945154.73 558845.26 MWD+IFR-AK-CAZ-SC 1419.52 33.46 185.70 1368.39 1241.79 -271.37 -94.08 5945105.57 558839.00 MWD+IFR-AK-CAZ-SC 1515.12 36.71 182.56 1446.62 1320.02 -326.16 -97.98 5945050.76 558835.54 MWD+IFR-AK-CAZ-SC 1609.68 42.44 181.81 1519.47 1392.87 -386.33 -100.25 5944990.57 558833.73 MWD+IFR-AK-CAZ-SC 1704.86 45.67 181.69 1587.87 1461.27 -452.47 -102.27 5944924.42 558832.23 MWD+IFR-AK-CAZ-SC 1798.73 49.25 182.85 1651.32 1524.72 -521.57 -105.03 5944855.31 558830.02 MWD+IFR-AK-CAZ-SC 1895.85 53.54 180.56 1711.91 1585.31 -597.41 -107.24 5944779.47 558828.40 MWD+IFR-AK-CAZ-SC 1990.76 56.49 178.87 1766.33 1639.73 -675.15 -106.83 5944701.74 558829.41 MWD+IFR-AK-CAZ-SC 2085.78 62.49 175.78 1814.55 1687.95 -756.87 -102.95 5944620.06 558833.94 MWD+IFR-AK-CAZ-SC i '~ 2180.15 65.96 175.41 1855.58 1728.98 -841.59 -96.42 5944535.40 558841.13 MWD+IFR-AK-CAZ-SC 2275.63 70.43 172.88 1891.05 1764.45 -929.74 -87.35 5944447.33 558850.89 MWD+IFR-AK-CAZ-SC ~ 2370.17 75.31 170.62 1918.89 1792.29 -1019.11 -74.36 5944358.07 558864.57 MWD+IFR-AK-CAZ-SC ' Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. bate: 1/23/2007 Time: 13:43:00 Nag_e: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: WeII: 1 J-136, True North Site: Kuparuk 1J Pad Vertical (TVD)Referencc: 1J-136L1PB1' 126.6 Well: 1J-136 Section(VS)Reference: Well (O.OON,O,OOE,180.OOAzi) Wellpath: 1J-136L1P61 Survey Calculation Method: Minimum Curvature Db: Oracle __ Survey 111D [ncl azim TVD Sys TVD N/S ElV1' D1apN 111apE Tool ft deg deg ft ft ft ft ft ft 2466.49 77.31 168.78 1941.68 1815.08 -1111.18 -57.63 5944266.15 558882.03 MWD+IFR-AK-CAZ-SC '~ 2562.02 77.65 165.14 1962.40 1835.80 -1202.01 -36.59 5944175.49 558903.77 MWD+IFR-AK-CAZ-SC 2656.89 78.08 161.08 1982.35 1855.75 -1290.74 -9.64 5944086.99 558931.41 MWD+IFR-AK-CAZ-SC 2751.03 77.04 158.83 2002.63 1876.03 -1377.10 21.86 5944000.89 558963.58 MWD+IFR-AK-CAZ-SC 2847.52 74.33 155.61 2026.49 1899.89 -1463.28 58.04 5943914.99 559000.43 MWD+IFR-AK-CAZ-SC 2942.22 75.53 155.39 2051.11 1924.51 -1546.49 95.96 5943832.09 559039.00 MWD+IFR-AK-CAZ-SC 3037.83 74.33 155.49 2075.97 1949.37 -1630.46 134.33 5943748.44 559078.02 MWD+IFR-AK-CAZ-SC 3133.17 74.30 156.45 2101.75 1975.15 -1714.29 171.71 5943664.91 559116.05 MWD+IFR-AK-CAZ-SC 3227.45 71.25 155.98 2129.66 2003.06 -1796.69 208.02 5943582.81 559153.00 MWD+IFR-AK-CAZ-SC 3322.39 77.47 155.05 2155.25 2028.65 -1879.84 245.90 5943499.96 559191.53 MWD+IFR-AK-CAZ-SC ! 3416.75 76.91 154.82 2176.17 2049.57 -1963.19 284.88 5943416.93 559231.16 MWD+IFR-AK-CAZ-SC 3466.52 76.15 154.70 2187.76 2061.16 -2006.97 305.52 5943373.31 559252.14 MWD+IFR-AK-CAZ-SC 3552.93 74.51 155.23 2209.64 2083.04 -2082.71 340.89 5943297.87 559288.10 MWD+IFR-AK-CAZ-SC 3647.71 75.21 157.64 2234.40 2107.80 -2166.56 377.46 5943214.31 559325.32 MWD+IFR-AK-CAZ-SC 3742.63 75.74 157.42 2258.21 2131.61 -2251.47 412.58 5943129.68 559361.10 MWD+IFR-AK-CAZ-SC 3838.51 75.42 159.32 2282.09 2155.49 -2337.79 446.81 5943043.65 559396.00 MWD+IFR-AK-CAZ-SC 3933.33 75.40 160.21 2305.97 2179.37 -2423.88 478.55 5942957.81 559428.41 MWD+IFR-AK-CAZ-SC 4027.56 77.96 161.69 2327.68 2201.08 -2510.55 508.47 5942871.39 559459.00 MWD+IFR-AK-CAZ-SC 4123.78 77.54 162.94 2348.10 2221.50 -2600.13 537.03 5942782.04 559488.26 MWD+IFR-AK-CAZ-SC 4218.48 76.69 163.15 2369.21 2242.61 -2688.43 563.95 5942693.96 559515.87 MWD+IFR-AK-CAZ-SC 4314.18 75.58 163.58 2392.15 2265.55 -2777.46 590.55 5942605.16 559543.16 MWD+IFR-AK-CAZ-SC 4408.86 75.71 163.49 2415.62 2289.02 -2865.42 616.55 5942517.41 559569.84 MWD+IFR-AK-CAZ-SC 4503.15 76.55 164.02 2438.22 2311.62 -2953.30 642.16 5942429.74 559596.14 MWD+IFR-AK-CAZ-SC 4600.43 76.13 164.36 2461.20 2334.60 -3044.25 667.91 5942339.00 559622.60 MWD+IFR-AK-CAZ-SC II 4694.51 75.86 164.53 2483.97 2357.37 -3132.19 692.39 5942251.26 559647.76 MWD+IFR-AK-CAZ-SC 4789.98 74.97 165.83 2508.01 2381.41 -3221.51 716.02 5942162.14 559672.09 MWD+IFR-AK-CAZ-SC 4885.79 76.74 165.10 2531.42 2404.82 -3311.44 739.34 5942072.41 559696.11 MWD+IFR-AK-CAZ-SC 4981.19 75.05 165.10 2554.67 2428.07 -3400.85 763.13 5941983.20 559720.60 MWD+IFR-AK-CAZ-SC 5075.80 75.79 165.70 2578.49 2451.89 -3489.45 786.21 5941894.78 559744.37 MWD+IFR-AK-CAZ-SC 5171.78 76.40 165.52 2601.55 2474.95 -3579.70 809.37 5941804.73 559768.22 MWD+IFR-AK-CAZ-SC j 5265.59 74.53 166.26 2625.09 2498.49 -3667.76 831.50 5941716.85 559791.05 MWD+IFR-AK-CAZ-SC 5361.20 74.24 165.03 2650.83 2524.23 -3756.96 854.33 5941627.84 559814.57 MWD+IFR-AK-CAZ-SC 5457.33 74.26 164.10 2676.92 2550.32 -3846.15 878.96 5941538.86 559839.89 MWD+IFR-AK-CAZ-SC 5552.50 77.11 162.26 2700.45 2573.85 -3934.40 905.65 5941450.82 559867.27 MWD+IFR-AK-CAZ-SC 5647.52 76.07 162.59 2722.49 2595.89 -4022.51 933.55 5941362.94 559895.86 MWD+IFR-AK-CAZ-SC 5742.83 75.16 164.48 2746.17 2619.57 -4111.04 959.72 5941274.63 .559922.72 MWD+IFR-AK-CAZ-SC ~i 5836.32 76.20 162.83 2769.30 2642.70 -4197.96 985.22 5941187.92 559948.89 MWD+IFR-AK-CAZ-SC 5932.78 76.49 163.50 2792.07 2665.47 -4287.68 1012.36 5941098.43 559976.74 MWD+IFR-AK-CAZ-SC 6028.11 78.25 163.26 2812.91 2686.31 -4376.81 1038.97 5941009.51 560004.04 MWD+IFR-AK-CAZ-SC 6123.03 78.56 164.09 2831.99 2705.39 -4466.04 1065.11 5940920.50 560030.87 MWD+IFR-AK-CAZ-SC 6218.26 77.83 164.18 2851.47 2724.87 -4555.71 1090.59 5940831.04 560057.05 MWD+IFR-AK-CAZ-SC ~ 6312.97 78.26 164.81 2871.09 2744.49 -4644.99 1115.36 5940741.96 560082.51 MWD+IFR-AK-CAZ-SC 6407.99 78.39 165.64 2890.32 2763.72 -4734.97 1139.09 5940652.18 560106.94 MWD+IFR-AK-CAZ-SC I ', 6502.97 78.14 164.05 2909.64 2783.04 -4824.73 1163.40 5940562.63 560131.95 MWD+IFR-AK-CAZ-SC 6598.32 76.41 164.52 2930.64 2804.04 -4914.25 1188.59 5940473.31 560157.84 MWD+IFR-AK-CAZ-SC 6693.68 76.48 163.31 2952.99 2826.39 -5003.33 1214.27 5940384.45 560184.22 MWD+IFR-AK-CAZ-SC 6788.75 77.51 162.41 2974.39 2847.79 -5091.84 1241.57 5940296.16 560212.21 MWD+IFR-AK-CAZ-SC 6885.02 77.09 162.36 2995.55 2868.95 -5181.35 1269.99 5940206.88 560241.33 MWD+IFR-AK-CAZ-SC 6980.08 75.74 161.32 3017.88 2891.28 -5269.15 1298.79 5940119.32 560270.81 MWD+IFR-AK-CAZ-SC 7073.70 76.06 161.10 3040.69 2914.09 -5355.11 1328.04 5940033.60 560300.72 MWD+IFR-AK-CAZ-SC 7169.70 75.37 159.78 3064.37 2937.77 -5442.77 1359.18 5939946.20 560332.55 MWD+IFR-AK-CAZ-SC 7264.91 75.32 160.47 3088.46 2961.86 -5529.39 1390.49 5939859.83 560364.54 MWD+IFR-AK-CAZ-SC 7360.01 75.91 160.13 3112.09 2985.49 -5616.12 1421.55 5939773.35 560396.26 MWD+IFR-AK-CAZ-SC ~ • Halliburton Company Survey Report __ Company: ConocoPhillips Alaska Inc. Field:.. Kuparuk River Unit Site: Kuparuk 1J Pad Well: 1 J-136 ~Yellpath:' 1J-136L1P61 Survev _ _ -_ ___ 111D Incl Azim "CVD Sys TVD N1S ft deg deg ft ft ft 7455.22 75.95 159.52 31 7548.91 75.50 160.57 31 7645.28 75.37 160.94 31 i 7738.81 74.66 160.16 32 7835.65 73.99 161.81 32 7930.56 74.02 161.73 32 8025.73 77.06 160.74 32 8119.36 76.89 161.17 33 8216.42 75.28 162.91 33 8312.10 76.06 162.35 33 8407.06 74.58 162.16 33 8502.36 76.41 162.53 33 8598.36 75.80 162.40 34 '~ 8693.47 76.14 165.01 34 8700.00 76.25 165.25 3 8787.00 77.74 169.13 34 8882.71 82.01 171.81 34 8976.03 81.74 174.42 34 9072.21 82.69 176.94 35 9084.00 82.46 177.12 35 9182.98 87.16 178.50 35 9278.32 87.33 179.82 35 9373.19 88.94 181.14 35 9467.44 90.73 182.26 35 9566.53 91.79 181.00 35 9661.20 92.77 182.37 35 9756.28 92.02 181.58 35 9851.03 90.35 180.26 35 9946.21 90.91 179.07 35 10041.31 90.60 179.66 35 10136.91 90.48 180.87 35 10230.65 90.60 181.06 35 10326.60 91.10 180.30 35 10421.58 91.04 180.88 35 10515.61 88.99 181.04 35 10609.39 91.10 183.37 35 10703.46 91.90 184.70 35 10799.57 91.96 181.23 35 10895.47 91.34 176.63 34 10991.15 93.51 176.09 34 ' 11086.57 92.64 176.54 34 ~ 11181.19 91.28 177.34 34 11276.28 89.80 175.84 34 11372.32 86.83 177.61 34 11467.59 86.40 177.75 34 11562.18 86.90 180.11 35 11652.29 93.26 183.12 35 11752.76 92.08 182.29 34 11846.80 90.41 182.51 34 i 11943.01 91.41 181.32 34 12038.43 89.30 177.66 34 i, 12132.52 91.41 177.98 34 35.24 58.34 82.57 06.76 32.92 59.08 82.84 03.94 27.28 50.96 75.03 98.90 21.95 45.01 446.57 66.15 82.98 96.17 09.20 10.72 19.67 24.26 27.34 27.62 25.44 21.67 17.70 15.74 14.69 13.44 12.54 11.65 10.23 08.46 08.43 08.36 05.90 02.66 99.90 95.85 90.73 87.49 86.60 89.42 95.05 00.57 00.45 95.77 93.72 92.20 91.60 91.02 Date: 1 /23/2007 Time: 13:43:00 Pag_ c: 3 Co-ordinate(NE) Reference: Well: 1J-136, True North Vertical (TVD) Reference: 1 J-136L1 PB1; 126.6 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Survev Calculation Method: P~linimum Curvature Db: Oracle E/N' ft 3008.64 -5702.81 3031.74 -5788.15 3055.97 -5876.21 3080.16 -5961.40 3106.32 -6049.55 3132.48 -6136.21 3156.24 -6223.45 3177.34 -6309.68 3200.68 -6399.29 3224.36 -6487.76 3248.43 -6575.25 3272.30 -6663.16 3295.35 -6752.02 3318.41 -6840.58 3319.97 -6846.71 3339.55 -6929.35 3356.38 -7022.24 3369.57 -7113.95 3382.60 -7208.97 3384.12 -7220.64 3393.07 -7319.11 3397.66 -7414.33 3400.74 -7509.14 3401.02 -7603.35 3398.84 -7702.37 3395.07 -7796.92 3391.10 -7891.86 3389.14 -7986.57 3388.09 -8081.74 3386.84 -8176.83 3385.94 -8272.42 3385.05 -8366.14 3383.63 -8462.07 3381.86 -8557.03 3381.83 -8651.04 3381.76 -8744.74 3379.30 -8838.54 3376.06 -8934.46 3373.30 -9030.27 3369.25 -9125.67 3364.13 -9220.75 3360.89 -9315.18 3360.00 -9410.09 3362.82 -9505.92 3368.45 -9600.94 3373.97 -9695.35 3373.85 -9785.37 3369.17 -9885.61 3367.12 -9979.55 3365.60 -10075.69 3365.00 -10171.08 3364.42 -10265.09 1453.40 1484:39 1515.13 1545.21 1575.59 1604.13 1633.78 1663.55 1692.60 1720.28 1748.27 1776.25 1804.33 1830.21 1831.84 1850.62 1866.20 1877.28 1884.45 1885.06 1888.82 1890.22 1889.42 1886.63 1883.81 1881.03 1877.75 1876.23 1876.79 1877.84 1877.40 1875.82 1874.68 1873.70 1872.13 1868.52 1861.91 1856.94 1858.73 1864.80 1870.92 1875.97 1881.62 1887.11 1890.96 1892.72 1890.18 1885.45 1881.51 1878.29 1879.14 1882.72 MapN n 5939686.93 5939601.84 5939514.03 5939429.08 5939341.19 5939254.76 5939167.76 5939081.78 5938992.41 5938904.16 5938816.90 5938729.22 5938640.59 5938552.25 5938546.13 5938463.65 5938370.89 5938279.28 5938184.33 5938172.66 5938074.23 5937979.04 5937884.23 5937790.02 5937690.99 5937596.43 5937501.48 5937406.76 5937311.61 5937216.54 5937120.96 5937027.24 5936931.31 5936836.36 5936742.34 5936648.63 5936554.79 5936458.85 5936363.06 5936267.72 5936172.70 5936078.32 5935983.46 5935887.69 5935792.71 5935698.33 5935608.30 5935508.03 5935414.08 5935317.93 5935222.55 5935128.58 MapE Tool ft ' 560428.79 MWD+IFR-AK-CAZ-SC 560460.44 MWD+IFR-AK-CAZ-SC 560491.87 MWD+IFR-AK-CAZ-SC 560522.62 MWD+IFR-AK-CAZ-SC i 560553.68 MWD+IFR-AK-CAZ-SC 560582.90 MWD+IFR-AK-CAZ-SC 560613.22 MWD+IFR-AK-CAZ-SC 560643.66 MWD+IFR-AK-CAZ-SC 560673.41 MWD+IFR-AK-CAZ-SC 560701.78 MWD+IFR-AK-CAZ-SC 560730.45 MWD+IFR-AK-CAZ-SC 560759.12 MWD+IFR-AK-CAZ-SC 560787.89 MWD+IFR-AK-CAZ-SC 560814.46 MWD+IFR-AK-CAZ-SC 560816.14 MWD+IFR-AK-CAZ-SC j 560835.56 MWD+IFR-AK-CAZ-SC ', 560851.87 MWD+IFR-AK-CAZ-SC i 560863.66 MWD+IFR-AK-CAZ-SC 560871.58 MWD+IFR-AK-CAZ-SC 560872.27 MWD+IFR-AK-CAZ-SC 560876.80 MWD+IFR-AK-CAZ-SC 560878.95 MWD+IFR-AK-CAZ-SC 560878.89 MWD+IFR-AK-CAZ-SC 560876.83 MWD+IFR-AK-CAZ-SC 560874.79 MWD+IFR-AK-CAZ-SC i 560872.75 MWD+IFR-AK-CAZ-SC ; 560870.22 MWD+IFR-AK-CAZ-SC 560869.44 MWD+IFR-AK-CAZ-SC 560870.74 MWD+IFR-AK-CAZ-SC 560872.54 MWD+IFR-AK-CAZ-SC 560872.85 MWD+IFR-AK-CAZ-SC 560872.00 MWD+IFR-AK-CAZ-SC 560871.61 MWD+IFR-AK-CAZ-SC 560871.38 MWD+IFR-AK-CAZ-SC 560870.54 MWD+IFR-AK-CAZ-SC 560867.66 MWD+IFR-AK-CAZ-SC 560861.78 MWD+IFR-AK-CAZ-SC 560857.57 MWD+IFR-AK-CAZ-SC 560860.11 MWD+IFR-AK-CAZ-SC 560866.92 MWD+IFR-AK-CAZ-SC 560873.79 MWD+IFR-AK-CAZ-SC 560879.57 MWD+IFR-AK-CAZ-SC i 560885.97 MWD+IFR-AK-CAZ-SC ~ 560892.20 MWD+IFR-AK-CAZ-SC 560896.80 MWD+IFR-AK-CAZ-SC 560899.30 MWD+IFR-AK-CAZ-SC 560897.47 MWD+IFR-AK-CAZ-SC 560893.51 MWD+IFR-AK-CAZ-SC 560890.31 MWD+IFR-AK-CAZ-SC 560887.85 MWD+IFR-AK-CAZ-SC 560889.45 MWD+IFR-AK-CAZ-SC 560893.76 MWD+IFR-AK-CAZ-SC • • Halliburton Company Survey Report - __ ___ Company: ConocoPhillips Alaska Inc. Date: 1/23/2007 Time: 13:43:00 Pate: 4 Field: Kuparuk River Unif Co-ordinate(NE) Reference: Well: 1J-136, True North Site: Kuparuk 1J Pad Vertical (1'VD) Reference: iJ-136L1P61:126.6 Well: 1J-136 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-136L1PB1 Survey Cakulafion Alethod: Minimum Curvature nn: Oracle Sun~ev MD Incl Azim TVD Sys TVD NIS E/W DIapN MapE .fool ft deg deg ft ft ft ft ft ft 12228.40 88.50 176.25 3491.10 3364.50 -10360.84 1887.55 5935032.88 560899.33 MWD+IFR-AK-CAZ-SC 12322.96 92.15 177.57 3490.56 3363.96 -10455.24 1892.64 5934938.53 560905.17 MWD+IFR-AK-CAZ-SC !~ 12418.40 93.88 178.67 3485.54 3358.94 -10550.49 1895.77 5934843.32 560909.04 MWD+IFR-AK-CAZ-SC 12513.54 95.24 181.15 3477.98 3351.38 -10645.32 1895.92 5934748.50 560909.93 MWD+IFR-AK-CAZ-SC 12608.47 94.87 181.77 3469.61 3343.01 -10739.85 1893.51 5934653.97 560908.26 MWD+IFR-AK-CAZ-SC ~~ 12703.38 94.44 180.28 3461.91 3335.31 -10834.43 1891.82 5934559.39 560907,31 MWD+IFR-AK-CAZ-SC 12799.20 93.63 180.36 3455.17 3328.57 -10930.01 1891.29 5934463.81 560907.53 MWD+IFR-AK-CAZ-SC 12894.96 91.65 180.48 3450.76 3324.16 -11025.66 1890.59 5934368.17 560907.57 MWD+IFR-AK-CAZ-SC 12989.38 89.98 178.56 3449.41 3322.81 -11120.06 1891.38 5934273.79 560909.10 MWD+tFR-AK-CAZ-SC 13083.48 90.48 179.19 3449.03 3322.43 -11214.14 1893.22 5934179.73 560911.69 MWD+IFR-AK-CAZ-SC 13178.71 90.17 181.11 3448.49 3321.89 -11309.36 1892.98 5934084.52 560912.18 MWD+IFR-AK-CAZ-SC 13273.60 90.17 181.58 3448.21 3321.61 -11404.23 1890.75 5933989.65 560910.70 MWD+IFR-AK-CAZ-SC 13368.85 90.91 183.39 3447.32 3320.72 -11499.38 1886.62 5933894.48 560907.32 MWD+IFR-AK-CAZ-SC 13463.98 90.66 183.32 3446.01 3319.41 -11594.34 1881.05 5933799.49 560902.49 MWD+IFR-AK-CAZ-SC 13559.24 91.59 184.24 3444.14 3317.54 -11689.37 1874.77 5933704.42 560896.96 MWD+IFR-AK-CAZ-SC 13654.76 92.09 185.01 3441.07 3314.47 -11784.53 1867.08 5933609.21 560890.01 MWD+IFR-AK-CAZ-SC ~ i 13749.59 90.74 185.96 3438.73 3312.13 -11878.89 1858.01 5933514.79 560881.68 MWD+IFR-AK-CAZ-SC 13843.31 91.48 187.28 3436.92 3310.32 -11971.97 1847.21 5933421.64 560871.61 MWD+IFR-AK-CAZ-SC 13938.77 90.73 189.45 3435.08 3308.48 -12066.39 1833.33 5933327.13 560858.47 MWD+IFR-AK-CAZ-SC ~, i 14033.80 90.74 189.18 3433.86 3307.26 -12160.16 1817.95 5933233.25 560843.82 MWD+IFR-AK-CAZ-SC !, 14129.56 91.11 188.07 3432.31 3305.71 -12254.82 1803.59 5933138.49 560830.21 MWD+IFR-AK-CAZ-SC ~ 14223.80 90.86 188.98 3430.69 3304.09 -12348.00 1789.62 5933045.20 560816.97 MWD+IFR-AK-CAZ-SC 14319.85 90.43 189.95 3429.61 3303.01 -12442.74 1773.83 5932950.36 560801.92 MWD+IFR-AK-CAZ-SC 14426.00 90.43 189.95 3428.81 3302.21 -12547.29 1755.49 5932845.68 560784.40 PROJECTED to TD • • Halliburton Company Survey Report Cun~pany: ConocoPhillips Alaska Inc. llate: 1/23/2007 Time: 13:53:18 __ Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-136, Tr ueNorth Site: KuparuklJPad Vertical (l`VD)Re ference: 1J-136L1PB2: 1 26.6 Well: 1J-136 Section (VS)Refer ence:'' Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-136L1P62 _ __ Survey Calculation Method: Minimum Curva ture Db: Oracle __ __ 'r Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-136 Slot Name: Well Position: +N/-S -543.14 ft Northing: 594537 7.64 ft Latitude: 70 15 40.916 N +E/-W 136.78 ft Easti ng : 55893 0.95 ft Longitude: 149 31 25.027 W Position Uncertainty: 0.00 ft Wellpath: 1 J-136L1 P62 Drilled From: 1 J-136L1 P61 500292333171 Tie-on Depth: 13273.60 ft Current Datum: 1 J-136L1 P62: Height 126.60 ft Above System Datum: Mean Sea Level i Magnetic Data: 11/17/2006 Declination: 23.72 deg Field Strength: 57613 nT Mag Dip Angl e: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 45.50 0.00 0.00 180.00 Survey Program for Definitive Wellpath ' Date: 1/23/2007 Validated: No Version: 2 ! Actual From To Survey Toolcode Tool Name ft ft 120.00 815.00 1J-136PB1 gyro (120.00-815.00) CB-GYRO-SS Camera based gyro single shot 848.68 8693.47 1J-136PB1 (848.68- 8786.52) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 8700.00 9072.21 1J-136 (8700.00-17475.72) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 9084.00 13273.60 1J-136L1 P61 (9084 .00-14319.85) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 13275.00 13367.83 1J-136L1 P62 (1327 5.00-13367.83 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C ~ Survey __ _ - D1D Incl Azim 7~VD .Sys TVD Y/S Ei~~ {titapN D1apE foul ft deg deg ft ft ft ft ft ft 45.50 0.00 0.00 45.50 -81.10 0.00 0.00 5945377.64 558930.95 TIE LINE i 120.00 0.20 47.82 120.00 -6.60 0.09 0.10 5945377.73 558931.05 CB-GYRO-SS 171.00 0.14 285.78 171.00 44.40 0.16 0.10 5945377.80 558931.05 CB-GYRO-SS 265.00 0.27 139.61 265.00 138.40 0.03 0.14 5945377.67 558931.09 CB-GYRO-SS 352.00 2.78 197.00 351.96 225.36 -2.15 -0.35 5945375.49 558930.62 CB-GYRO-SS 450.00 6.34 203.00 449.64 323.04 -9.40 -3.16 5945368.21 558927.87 CB-GYRO-SS 536.00 7.46 210.17 535.02 408.42 -18.60 -7.82 5945358.98 558923.28 CB-GYRO-SS i 635.00 9.75 215.20 632.90 506.30 -31.01 -15.88 5945346.51 558915.31 CB-GYRO-SS t 735.00 12.62 218.15 730.99 604.39 -46.52 -27.51 5945330.91 558903.80 CB-GYRO-SS 815.00 14.54 214.61 808.75 682.15 -61.66 -38.62 5945315.68 558892.82 CB-GYRO-SS ~~ 848.68 14.47 210.72 841.36 714.76 -68.76 -43.17 5945308.55 558888.32 MWD+IFR-AK-CAZ-SC 942.92 13.87 206.23 932.73 806.13 -89.01 -54.18 5945288.21 558877.48 MWD+IFR-AK-CAZ-SC 1037.30 17.05 197.44 1023.70 897.10 -112.37 -63.33 5945264.79 558868.51 MWD+IFR-AK-CAZ-SC 1134.76 21.29 193.44 1115.73 989.13 -143.23 -71.73 5945233.87 558860.35 MWD+IFR-AK-CAZ-SC ~, 1228.85 25.03 191.05 1202.23 1075.63 -179.39 -79.51 5945197.65 558852.85 MWD+IFR-AK-CAZ-SC 1324.31 29.33 189.97 1287.13 1160.53 -222.26 -87.44 5945154.73 558845.26 MWD+IFR-AK-CAZ-SC 1419.52 33.46 185.70 1368.39 1241.79 -271.37 -94.08 5945105.57 558839.00 MWD+IFR-AK-CAZ-SC 1515.12 36.71 182.56 1446.62 1320.02 -326.16 -97.98 5945050.76 558835.54 MWD+IFR-AK-CAZ-SC 1609.68 42.44 181.81 1519.47 1392.87 -386.33 -100.25 5944990.57 558833.73 MWD+IFR-AK-CAZ-SC 1704.86 45.67 181.69 1587.87 1461.27 -452.47 -102.27 5944924.42 558832.23 MWD+IFR-AK-CAZ-SC 1798.73 49.25 182.85 1651.32 1524.72 -521.57 -105.03 5944855.31 558830.02 MWD+IFR-AK-CAZ-SC I ! 1895.85 53.54 180.56 1711.91 1585.31 -597.41 -107.24 5944779.47 558828.40 MWD+IFR-AK-CAZ-SC I ~ 1990.76 56.49 178.87 1766.33 1639.73 -675.15 -106.83 5944701.74 558829.41 MWD+IFR-AK-CAZ-SC I 2085.78 62.49 175.78 1814.55 1687.95 -756.87 -102.95 5944620.06 558833.94 MWD+IFR-AK-CAZ-SC 2180.15 65.96 175.41 1855.58 1728.98 -841.59 -96.42 5944535.40 558841.13 MWD+IFR-AK-CAZ-SC 2275.63 70.43 172.88 1891.05 1764.45 -929.74 -87.35 5944447.33 558850.89 MWD+IFR-AK-CAZ-SC • • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. llate: 1!23!2007 Time: 13:53:18 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: WeII: 1 J-136, True North Site: Kuparuk 1J Pad Vertical(TVD)Rcfcrence: '1J-136L1PB2: 126.6 Well: 1J-136 Sectiun (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-136L1PB2 Survey CalculationMethod: MinimumCurvature llb: Oracle Survev MD Inc! Azim TVD Sys TVD iY/S E/W AlapN MapF Tool ft dey deg ft ft ft ft ft ft 2370.17 75.31 170.62 1918.89 1792.29 -1019.11 -74.36 5944358.07 558864.57 MWD+IFR-AK-CAZ-SC 2466.49 77.31 168.78 1941.68 1815.08 -1111.18 -57.63 5944266.15 558882.03 MWD+IFR-AK-CAZ-SC 2562.02 77.65 165.14 1962.40 1835.80 -1202.01 -36.59 5944175.49 558903.77 MWD+IFR-AK-CAZ-SC 2656.89 78.08 161.08 1982.35 1855.75 -1290.74 -9.64 5944086.99 558931.41 MWD+IFR-AK-CAZ-SC 2751.03 77.04 158.83 2002.63 1876.03 -1377.10 21.86 5944000.89 558963.58 MWD+IFR-AK-CAZ-SC 2847.52 74.33 155.61 2026.49 1899.89 -1463.28 58.04 5943914.99 559000.43 MWD+IFR-AK-CAZ-SC 2942.22 75.53 155.39 2051.11 1924.51 -1546.49 95.96 5943832.09 559039.00 MWD+IFR-AK-CAZ-SC 3037.83 74.33 155.49 2075.97 1949.37 -1630.46 134.33 5943748.44 559078.02 MWD+IFR-AK-CAZ-SC 3133.17 74.30 156.45 2101.75 1975.15 -1714.29 171.71 5943664.91 559116.05 MWD+IFR-AK-CAZ-SC 3227.45 71.25 155.98 2129.66 2003.06 -1796.69 208.02 5943582.81 559153.00 MWD+IFR-AK-CAZ-SC ~ 3322.39 77.47 155.05 2155.25 2028.65 -1879.84 245.90 5943499.96 559191.53 MWD+IFR-AK-CAZ-SC 3416.75 76.91 154.82 2176.17 2049.57 -1963.19 284.88 5943416.93 559231.16 MWD+IFR-AK-CAZ-SC 3466.52 76.15 154.70 2187.76 2061.16 -2006.97 305.52 5943373.31 559252.14 MWD+IFR-AK-CAZ-SC 3552.93 74.51 155.23 2209.64 2083.04 -2082.71 340.89 5943297.87 559288.10 MWD+IFR-AK-CAZ-SC 3647.71 75.21 157.64 2234.40 2107.80 -2166.56 377.46 5943214.31 559325.32 MWD+IFR-AK-CAZ-SC 3742.63 75.74 157.42 2258.21 2131.61 -2251.47 412.58 5943129.68. 559361.10 MWD+IFR-AK-CAZ-SC ~ 3838.51 75.42 159.32 2282.09 2155.49 -2337.79 446.81 5943043.65 559396.00 MWD+IFR-AK-CAZ-SC ' 3933.33 75.40 160.21 2305.97 2179.37 -2423.88 478.55 5942957.81 559428.41 MWD+IFR-AK-CAZ-SC 4027.56 77.96 161.69 2327.68 2201.08 -2510.55 508.47 5942871.39 559459.00 MWD+IFR-AK-CAZ-SC 4123.78 77.54 162.94 2348.10 2221.50 -2600.13 537.03 5942782.04 559488.26 MWD+IFR-AK-CAZ-SC 4218.48 76.69 163.15 2369.21 2242.61 -2688.43 563.95 5942693.96 559515.87 MWD+IFR-AK-CAZ-SC 4314.18 75.58 163.58 2392.15 2265.55 -2777.46 590.55 5942605.16 559543.16 MWD+IFR-AK-CAZ-SC 4408.86 75.71 163.49 2415.62 2289.02 -2865.42 616.55 5942517.41 559569.84 MWD+IFR-AK-CAZ-SC 4503.15 76.55 164.02 2438.22 2311.62 -2953.30 642.16 5942429.74 559596.14 MWD+IFR-AK-CAZ-SC I 4600.43 76.13 164.36 2461.20 2334.60 -3044.25 667.91 5942339.00 559622.60 MWD+IFR-AK-CAZ-SC 4694.51 75.86 164.53 2483.97 2357.37 -3132.19 692.39 5942251.26 559647.76 MWD+IFR-AK-CAZ-SC ~ 4789.98 74.97 165.83 2508.01 2381.41 -3221.51 716.02 5942162.14 559672.09 MWD+IFR-AK-CAZ-SC 4885.79 76.74 165.10 2531.42 2404.82 -3311.44 739.34 5942072.41 559696.11 MWD+IFR-AK-CAZ-SC 4981.19 75.05 165.10 2554.67 2428.07 -3400.85 763.13 5941983.20 559720.60 MWD+IFR-AK-CAZ-SC 5075.80 75.79 165.70 2578.49 2451.89 -3489.45 786.21 5941894.78 559744.37 MWD+IFR-AK-CAZ-SC 5171,78 76.40 165.52 2601.55 2474.95 -3579.70 809.37 5941804.73 559768.22 MWD+IFR-AK-CAZ-SC 5265.59 74.53 166.26 2625.09 2498.49 -3667.76 831.50 5941716.85 559791.05 MWD+IFR-AK-CAZ-SC 5361.20 74.24 165.03 2650.83 2524.23 -3756.96 854.33 5941627.84 559814.57 MWD+IFR-AK-CAZ-SC 5457.33 74.26 164.10 2676.92 2550.32 -3846.15 878.96 5941538.86 559839.89 MWD+IFR-AK-CAZ-SC 5552.50 77.11 162.26 2700.45 2573.85 -3934.40 905.65 5941450.82 559867.27 MWD+IFR-AK-CAZ-SC 5647.52 76.07 162.59 2722.49 2595.89 -4022.51 933.55 5941362.94 559895.86 MWD+IFR-AK-CAZ-SC 5742.83 75.16 164.48 2746.17 2619.57 -4111.04 959.72 5941274.63 559922.72 MWD+IFR-AK-CAZ-SC ~ 5836.32 76.20 162.83 2769.30 2642.70 -4197.96 985.22 5941187.92 559948.89 MWD+IFR-AK-CAZ-SC 5932.78 76.49 163.50 2792.07 2665.47 -4287.68 1012.36 5941098.43 559976.74 MWD+IFR-AK-CAZ-SC ~i 6028.11 78.25 163.26 2812.91 2686.31 -4376.81 1038.97 5941009.51 560004.04 MWD+IFR-AK-CAZ-SC 6123.03 78.56 164.09 2831.99 2705.39 -4466.04 1065.11 5940920.50 560030.87 MWD+IFR-AK-CAZ-SC ~ 6218.26 77.83 164.18 2851.47 2724.87 -4555.71 1090.59 5940831.04 560057.05 MWD+IFR-AK-CAZ-SC 6312.97 78.26 164.81 2871.09 2744.49 -4644.99 1115.36 5940741.96 560082.51 MWD+IFR-AK-CAZ-SC 6407.99 78.39 165.64 2890.32 2763.72 -4734.97 1139.09 5940652.18 560106.94 MWD+IFR-AK-CAZ-SC 6502.97 78.14 164.05 2909.64 2783.04 -4824.73 1163.40 5940562.63 560131.95 MWD+IFR-AK-CAZ-SC 6598.32 76.41 164.52 2930.64 2804.04 -4914.25 1188.59 5940473.31 560157.84 MWD+IFR-AK-CAZ-SC 6693.68 76.48 163.31 2952.99 2826.39 -5003.33 1214.27 5940384.45 560184.22 MWD+IFR-AK-CAZ-SC 6788.75 77.51 162.41 2974.39 2847.79 -5091.84 1241.57 5940296.16 560212.21 MWD+IFR-AK-CAZ-SC 6885.02 77.09 162.36 2995.55 2868.95 -5181.35 1269.99 5940206.88 560241.33 MWD+IFR-AK-CAZ-SC ' 6980.08 75.74 161.32 3017.88 2891.28 -5269.15 1298.79 5940119.32 560270.81 MWD+IFR-AK-CAZ-SC 7073.70 76.06 161.10 3040.69 2914.09 -5355.11 1328.04 5940033.60 560300.72 MWD+IFR-AK-CAZ-SC 7169.70 75.37 159.78 3064.37 2937.77 -5442.77 1359.18 5939946.20 560332.55 MWD+IFR-AK-CAZ-SC 7264.91 75.32 160.47 3088.46 2961.86 -5529.39 1390.49 5939859.83 560364.54 MWD+IFR-AK-CAZ-SC ~I • i Halliburton Company Survey Report ~ltSsv~ .C~ t•'j.o7 Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Site: Kuparuk 1 J Pad Well: 1 J-136 Wellpath: 1 J-136L1 PB2 Su rvc}~ - _ _-_ Date: 1/23/2007 't'ime: 13:53:18 Page: 3 Co-ordinate(NE)Reference: Well: 1J-136, True North Vertical ('1'VD) Reference: 1J-136L1 PB2: 126.6 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Survey Cakulation btethod: Minimum Curvature Db: Oracle MD Incl Azim TVD Sys TVD N/S EIW ft deg deg ft ft ft ft - - - _ -_- 7360.01 75.91 160.13 3112.09 2985.49 -5616.12 1421.55 ~'I 7455.22 75.95 159.52 3135.24 3008.64 -5702.81 1453.40 7548.91 75.50 160.57 3158.34 3031.74 -5788.15 1484.39 7645.28 75.37 160.94 3182.57 3055.97 -5876.21 1515.13 7738.81 74.66 160.16 3206.76 3080.16 -5961.40 1545.21 7835.65 73.99 161.81 3232.92 3106.32 -6049.55 1575.59 7930.56 74.02 161.73 3259.08 3132.48 -6136.21 1604.13 8025.73 77.06 160.74 3282.84 3156.24 -6223.45 1633.78 8119.36 76.89 161.17 3303.94 3177.34 -6309.68 1663.55 8216.42 75.28 162.91 3327.28 3200.68 -6399.29 1692.60 8312.10 76.06 162.35 3350.96 3224.36 -6487.76 1720.28 8407.06 74.58 162.16 3375.03 3248.43 -6575.25 1748.27 8502.36 76.41 162.53 3398.90 3272.30 -6663.16 1776.25 8598.36 75.80 162.40 3421.95 3295.35 -6752.02 1804.33 8693.47 76.14 165.01 3445.01 3318.41 -6840.58 1830.21 8700.00 76.25 165.25 3446.57 3319.97 -6846.71 1831.84 8787.00 77.74 169.13 3466.15 3339.55 -6929.35 1850.62 8882.71 82.01 171.81 3482.98 3356.38 -7022.24 1866.20 8976.03 81.74 174.42 3496.17 3369.57 -7113.95 1877.28 9072.21 82.69 176.94 3509.20 3382.60 -7208.97 1884.45 9084.00 82.46 177.12 3510.72 • 3384.12 -7220.64 1885.06 9182.98 87.16 178.50 3519.67 3393.07 -7319.11 1888.82 9278.32 87.33 179.82 3524.26 3397.66 -7414.33 1890.22 9373.19 88.94 181.14 3527.34 3400.74 -7509.14 1889.42 9467.44 90.73 182.26 3527.62 3401.02 -7603.35 1886.63 9566.53 91.79 181.00 3525.44 3398.84 -7702.37 1883.81 9661.20 92.77 182.37 3521.67 3395.07 -7796.92 1881.03 9756.28 92.02 181.58 3517.70 3391.10 -7891.86 1877.75 9851.03 90.35 180.26 3515.74 3389.14 -7986.57 1876.23 9946.21 90.91 179.07 3514.69 3388.09 -8081.74 1876.79 10041.31 90.60 179.66 3513.44 3386.84 -8176.83 1877.84 10136.91 90.48 180.87 3512.54 3385.94 -8272.42 1877.40 10230.65 90.60 181.06 3511.65 3385.05 -8366.14 1875.82 10326.60 91.10 180.30 3510.23 3383.63 -8462.07 1874.68 10421.58 91:04 180.88 3508.46 3381.86 -8557.03 1873.70 10515.61 88.99 181.04 3508.43 3381.83 -8651.04 1872.13 it 10609.39 91.10 183.37 3508.36 3381.76 -8744.74 1868.52 10703.46 91.90 184.70 3505.90 3379.30 -8838.54 1861.91 10799.57 91.96 181.23 3502.66 3376.06 -8934.46 1856.94 ~ 10895.47 91.34 176.63 3499.90 3373.30 -9030.27 1858.73 10991.15 93.51 176.09 3495.85 3369.25 -9125.67 1864.80 11086.57 92.64 176.54 3490.73 3364.13 -9220.75 1870.92 11181.19 91.28 177.34 3487.49 3360.89 -9315.18 1875.97 'I 11276.28 89.80 175.84 3486.60 3360.00 -9410.09 1881.62 it 11372.32 86.83 177.61 3489.42 3362.82 -9505.92 1887.11 11467.59 86.40 177.75 3495.05 3368.45 -9600.94 1890.96 11562.18 86.90 180.11 3500.57 3373.97 -9695.35 1892.72 11652.29 93.26 183.12 3500.45 3373.85 -9785.37 1890.18 11752.76 92.08 182.29 3495.77 3369.17 -9885.61 1885.45 11846.80 90.41 182.51 3493.72 3367.12 -9979.55 1881.51 11943.01 91.41 181.32 3492.20 3365.60 -10075.69 1878.29 12038.43 89.30 177.66 3491.60 3365.00 -10171.08 1879.14 11apN ~tapE Tool ft ft __ __ 5939773.35 _ 560396.26 - MWD+IFR-AK-CAZ-SC I, 5939686.93 560428.79 MWD+IFR-AK-CAZ-SC II 5939601.84 560460.44 MWD+IFR-AK-CAZ-SC 5939514.03 560491.87 MWD+IFR-AK-CAZ-SC I 5939429.08 560522.62 MWD+IFR-AK-CAZ-SC 5939341.19 560553.68 MWD+IFR-AK-CAZ-SC 5939254.76 560582.90 MWD+IFR-AK-CAZ-SC 5939167.76 560613.22 MWD+IFR-AK-CAZ-SC 5939081.78 560643.66 MWD+IFR-AK-CAZ-SC 5938992.41 560673.41 MWD+IFR-AK-CAZ-SC 5938904.16 560701.78 MWD+IFR-AK-CAZ-SC 5938816.90 560730.45 MWD+IFR-AK-CAZ-SC 5938729.22 560759.12 MWD+IFR-AK-CAZ-SC 5938640.59 560787.89 MWD+IFR-AK-CAZ-SC 5938552.25 560814.46 MWD+IFR-AK-CAZ-SC 5938546.13 560816.14 MWD+IFR-AK-CAZ-SC 5938463.65 560835.56 MWD+IFR-AK-CAZ-SC 5938370.89 560851.87 MWD+IFR-AK-CAZ-SC 5938279.28 560863.66 MWD+IFR-AK-CAZ-SC 5938184.33 560871.58 MWD+IFR-AK-CAZ-SC 5938172.66 560872.27 MWD+IFR-AK-CAZ-SC 5938074.23 560876.80 MWD+IFR-AK-CAZ-SC 5937979.04 560878.95 MWD+IFR-AK-CAZ-SC 5937884.23 560878.89 MWD+IFR-AK-CAZ-SC 5937790.02 560876.83 MWD+IFR-AK-CAZ-SC 5937690.99 560874.79 MWD+IFR-AK-CAZ-SC 5937596.43 560872.75 MWD+IFR-AK-CAZ-SC 5937501.48 560870.22 MWD+IFR-AK-CAZ-SC 5937406.76 560869.44 MWD+IFR-AK-CAZ-SC 5937311.61 560870.74 MWD+IFR-AK-CAZ-SC 5937216.54 560872.54 MWD+IFR-AK-CAZ-SC ~ i 5937120.96 560872.85 MWD+IFR-AK-CAZ-SC 5937027.24 560872.00 MWD+IFR-AK-CAZ-SC 5936931.31 560871.61 MWD+IFR-AK-CAZ-SC j 5936836.36 560871.38 MWD+IFR-AK-CAZ-SC 5936742.34 560870.54 MWD+IFR-AK-CAZ-SC 5936648.63 560867.66 MWD+IFR-AK-CAZ-SC ~ ' 5936554.79 560861.78 MWD+IFR-AK-CAZ-SC 5936458.85 560857.57 MWD+IFR-AK-CAZ-SC 5936363.06 560860.11 MWD+IFR-AK-CAZ-SC 5936267.72 560866.92 MWD+IFR-AK-CAZ-SC ~ 5936172.70 560873.79 MWD+IFR-AK-CAZ-SC 5936078.32 560879.57 MWD+IFR-AK-CAZ-SC 5935983.46 560885.97 MWD+IFR-AK-CAZ-SC 5935887.69 560892.20 MWD+IFR-AK-CAZ-SC 5935792.71 560896.80 MWD+IFR-AK-CAZ-SC 5935698.33 560899.30 MWD+IFR-AK-CAZ-SC 5935608.30 560897.47 MWD+IFR-AK-CAZ-SC 5935508.03 560893.51 MWD+IFR-AK-CAZ-SC 5935414.08 560890.31 MWD+IFR-AK-CAZ-SC 5935317.93 560887.85 MWD+IFR-AK-CAZ-SC 5935222.55 560889.45 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 1/23/2007 Time: 13:53:18 Page: 4 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-136, True North Site: Kuparuk 1J Pad Vertical (TVD)Re ference: 1J-136L1P62: 126.6 Well: 1J-136 Sectio n (VS)Reference: Well (O.OOtV,0. 00E,180.00Azi) Wellpath: 1J-136L1PB2 Sur.~ey Calculation Method: Minimum Curvature Db: Oracle ____ ___i Surve~~ - -- ~1D Incl ~zim TVD SysTVD ~lS E/V1' MapN MapE , Tool ft deg deg ft ft ft ft ft ft I 12132. 52 91.41 177. 98 3491 .02 3364. 42 -10265 .09 1882.72 5935128. 58 560893.76 MWD+IFR-AK-CAZ-SC 12228. 40 88.50 176. 25 3491 .10 3364. 50 -10360 .84 1887.55 5935032. 88 560899.33 MWD+IFR-AK-CAZ-SC 12322. 96 92.15 177. 57 3490 .56 3363. 96 -10455 .24 1892.64 5934938. 53 560905.17 MWD+IFR-AK-CAZ-SC 12418. 40 93.88 178. 67 3485 .54 3358. 94 -10550 .49 1895.77 5934843. 32 560909.04 MWD+IFR-AK-CAZ-SC 12513. 54 95.24 181. 15 3477 .98 3351. 38 -10645 .32 1895.92 5934748. 50 560909.93 MWD+IFR-AK-CAZ-SC 12608. 47 94.87 181. 77 3469. 61 3343. 01 -10739 .85 1893.51 . 5934653. 97 560908.26 MWD+IFR-AK-CAZ-SC 12703. 38 94.44 180. 28 3461 .91 3335. 31 -10834 .43 1891.82 5934559. 39 560907.31 MWD+IFR-AK-CAZ-SC 12799. 20 93.63 180. 36 3455 .17 3328. 57 -10930 .01 1891.29 5934463. 81 560907.53 MWD+IFR-AK-CAZ-SC 12894. i 96 91.65 180. 48 3450 .76 3324. 16 -11025 .66 1890.59 5934368. 17 560907.57 MWD+IFR-AK-CAZ-SC 12989. 38 89.98 178. 56 3449 .41 3322. 81 -11120 .06 1891.38 5934273. 79 560909.10 MWD+IFR-AK-CAZ-SC 13083. 48 90.48 179. 19 3449 .03 3322. 43 -11214 .14 1893.22 5934179. 73 560911.69 MWD+IFR-AK-CAZ-SC 13178. 71 90.17 181. 11 3448 .49 3321. 89 -11309 .36 1892.98 5934084. 52 560912.18 MWD+IFR-AK-CAZ-SC ~i 13273. 60 90.17 181. 58 3448 .21 3321. 61 -11404 .23 1890.75 5933989. 65 560910.70 MWD+IFR-AK-CAZ-SC it 13275. 00 90.18 181. 61 3448 .21 3321. 61 -11405 .63 1890.71 5933988. 25 560910.67 MWD+IFR-AK-CAZ-SC i 13367. 83 87.09 182. 85 3450 .42 3323. 82 -11498 .35 1887.10 5933895. 52 560907.79 MWD+IFR-AK-CAZ-SC t 13397. 00 87.09 182. 85 3451 .90 3325 .30 -11527 .44 1885.65 5933866. 41 560906.57 PROJECTED to TD ~~ Description of Casing Well : 1J-136 L1 ~t3~'1OCQ~'t1~~i~5 Slofted and Blank Liner Date : lz/xs/os aiaeka, ~~,a. Supervisors: Mike Thornton/Granville Rizek Rig : Doyon 15 FINAL DETAIL DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS Plop & Drop 9282.31 "B" Lateral ZXP @ 9196.90' / XO @ 9227.26' 9282.31 Note: "D" lateral window top @9,084'/ Bttm @ 9,100' 9282.31 TOL 210' out in open hole @ 9,294' 9282.31 9282.31 982.31 9282.31 9282.31 5" DP to Surface =_> 9282.31 Liner Runnin Too15" Does not sta in hole 12.26 9282.31 7" Baker "HR" Liner Setting Sleeve (8.3" O.D x T=5" LD.) 8.57 9294.57 7" Hydril 521 Pin X 5.112" Hydril 521 Pin Crossover 1.06 9303.14 5-1/2", 15.5 ppf, L-8U, Hydri1521 PUP Jt. 3.51 9304.20 Jts 1s8 to 1s8 1 Jts 5-1(2",15.5 ppf, L-&0, Hydril 521 Blank Casing 36.03 9307.71 Jts 187 to 187 1 Jts 5-1/2",15.5 ppf, L-80, Hydril 521 Slatted Casing 42.06 9343.74 Jts 186 to 186 1 Jts _ _ 5-1/2",15.5 ppf, L-80, Hydril 521 Blank Casing ~ 34.64 9385.80 Jts 185 to 185 1 Jts 5-112",15.5 ppf, L-80, Hydril 521 Slotted Casing 41.29 9420.44 Jts 184 to 184 1 Jts 5-1/2",15.5 ppf, L-80, Hydril 521 Blank Casing 41.88 9461.73 Jts 183 to 1'83 1 Jts 5-1/2",15.5 ppf, L-80, Hydril 521 Slotted Casing 41.52 9503.61 Jts 182 to 182 1 Jts 5-1/2",15.5 ppf, L-80, Hydril 52T Blank Casing 41.90 9545.13 Jts 181 to 181 1 Jts 5-112' ;15.5 ppf, L-80, Hydril 521 Slotted Casing 41.70 9587.03 Jts 180 to 180. 1 Jts 5-112",75.5 ppf, L-80, Hydri1521 Blank Casing .41.91 9628.73 Jts 179 to 179 1 Jts 5-112"-,15.5 ppf, L-80, Hydril 521 Slotted Casing 41.19 9670.64 Jts 178 to 178 1 Jts 5-1/2",15.5 ppf, L-80, Hydril 521 Blank Casing 42.16 9711.83 Jts 177 to 177 1 Jts 5-1/2",15.5 ppf, L-80, Hydril`521 Slotted Easing 36.59 9753.99 Jts 171 to 176 6 Jts 5-1l2" ,15.5 ppf, L-80, Hydri1521 Blank Casing 247.11 9790.58 Jts 169 to 170 2 Jts 5-112",15:5 ppf, L-80, Hydril 521 Slotted Casing 83.05 10037.69 Jts 168 to 168 1 Jts 5-1/2"-,15.5 ppf, L-80, Hydril 521 Blartk Casing 41.31 10120.74 Jts 167 to 167 1 Jts 5-1/2",15.5 ppf, L-80, Hydril 521 Slotted Casing 40.59 10162.05 Jts 166 to 166 1 Jts 5-1t2",i5.5 ppf, L-80, Hydri1521 Blank Casing 41.23 10202.64 Jts 165 to 165 1 Jts 5-1/2?'-,15.5 ppf, L-80,,Hydril-521: Slotted Casing 41.81 10243.87 Jts 16a to 16a 1 Jts 5-1/2",15.5 ppf, L-$0, .Hydril 521 Blank Casing 42.19 10285.68 Jts 163 to 163 1 Jts _ 5-1/2",15,5 ppf, L-80, .Hydril 527 Slatted Easing 41.79 10327.87 5-1/2" Hydri1521 box x 5-1 /2" BTC pin Crossover 1.66 10369.66 Jts 162 to 162 1 Jts 5-1/2",-15.5 ppf, L-80, BTC Blank Casing 39.96 10371.32 Jts 161 to 161 1 Jts 5 -1(2",15.5 ppf, L-80, BTC Slotted Casing 43.36 10411.28 Jts 160 to 160 1 Jts 5 -1/2",15:5 ppf, L-80, BTC Blank Casing 39.60 10454.64 Jts 159 to 159 1 Jts 5 -112",15.5 ppf, L-80, BTC Slotted Casing 43.35 1049424 4-1/2" :Ran total of 63 Jts Blanks 2701.3T and 34 Jts Slotted= 1454.76', Up Wt 250K 5-1/2" :Ran total of 57 Jts Blank= 2287.85' and 34 Jts Slotted= 1429.85', Dn Wt OK Slots are w/ (32) 2.5" long x .125" @ 4 Circumferential adjacent rows, Black Wt 70K 3" Centers Staggered 18 deg., 3 ft. non-slotted ends. Rot Wt 144K Used Run-N-Seal thread compound on all connections. ~unrtea 5-vz° casing to 4.833" tk 47/2" to 3.885 w/ teflon rabbit. Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 2 LENGTH TOPS Jts 153 to 158 s Jts 5-112",.15.5 ppf, L-80, BTC Blank Casing 247.73 10537.59 Jts 151 to 152 2 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing ss.oo 10785.32 Jts 150 to 130 1 Jts .5-1/2",15.5 ppf, L-80, BTC Blank Casing 39.a4 .10871.32 Jts 149 to 149 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing a3.a7 10910.76 Jts 148 to 148 1 Jts 5-1/2",15.5 ppf, L-80, BTC Blank Casing 39.33 10954.23 Jts 147 to 147 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slatted Casing. 42.9s 10993.56 Jts 146 to 146 1 Jts 5-1/2",15.5 ppf, L-80, BTC Blank Casing 39.39 11036.55 Jts 145 to 145 1 Jts 5-112",15.5 ppf, L-80, BTC Slotted Casing 43.48 11075.94 Jts 144 to 144 1 Jts 5-112",15.5 ppf, L-80, BTC Blank Casing 3s.3s 11119.42 Jts 129 to i43 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing x3.51 11157.78 Jts 142 to 142 1 Jts 5-1/2",155 ppf, L-80, BTC Blank Casing 3s.9s 11201.29 Jts 141 to 141 1 Jts 5-1/2",15.5 ppf, L$0, BTC Slotted Casing 43.04 11241.25 Jfs 135 to 140 s Jts 5-1F2", 15.5 ppf, L-80, BTC Blank Casing 23x.22 1128429 Jts 134 to 134 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing a3.23 11522.51 Jts 133 to 133 1 Jts 5-1/2' ;15.5 ppf, L-80, BTC Blank Casing 39.55 11565.74 Jts 132 to 132 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing x3.27 11605.29 Jts 131 to 131 1 Jts 5-1/2",15.5 ppf, L-80, BTC BIanK Casing 3ss7 11648.56 Jts 130 to 130 1 Jts 5-112",15.5 ppf, L-$0, BTC Slotted Casing 43.18 11688.13 Jts 129 to 129 1 Jts 5-1/2",15.5 ppf, L-80, BTC Blank Casing 3x.55 . 11731.31 Jts 128 to 128 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 3s.2s 11770.86 Jts 127 to 127 1 Jts 5-1/2",15.5 ppf, L-80, BTC Blank Casing 3as3 1.1807.12 Jts 126 to 126 1 Jts 5-1/2°,15.5 ppf, L-$0, BTC Slotted Casing 43.08 11841.75 Jts 12s to 12s 1 Jts 5-112' ;15.5 ppf, L-80, BTG Blank Casing 3s.a~ 11884.83 Jts 124 to 124 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing a3.2a 11924.30 Jts 123 to 123 1 Jts 5-1/2", 15'.5 ppf, L-80, BTC Blank Casing 3ss5 11967.54 Jts 122 to 122 1 Jts 5-112",15.5 ppf, L-80, BTC Slotted Casing 3sss 12007.39 Jts 116 to 121 s Jts 5-1/2",15.5 ppf, L-80; BTG Blank Casing 2a2.o1 12046.94 Jts 115 to 115 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 4262 . 12288.95 Jts 114 to 114 1 Jts 5-1/2",15.5 ppf, L-80, BTC Blank Casing 3s.a5 12331.57 Jts 113 to-113 1 Jts 5-1t2",15.5 ppf, L-80, BTC Slotted Casing 43.19 12371.02 Jts 112 to 112 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing 39.3s 1241421 Jts 111 to 111 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing at70 12453.59 Jts 110 to 110 1 Jts 5-112",15.5 ppf, L-80, -BTC Blank Casing ao.52 12495.29 Jts 109 to 109 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 43.1s 12535.81 Jts 108 to 108 1 Jts 5-1/2",15.5 ppf, L-80, BTC Blank Casing 3s.3s 12579.00 Jts 107 to 107 1 Jts 5-1/2",15.5 ppf, L-80, BTC Stoned Casing a3.11 12618.36 Jts 106 to 106 1 Jts 5-1/2",15.5 ppf, L-80, BTC Blank Casing ao.n 12661.47 Jts 105 to 105 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 43.14 12701.64 Remarks: Jt Number Num ofJts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 3 LENGTH TOPS Jts 104 to 104 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing 3x.23 12744.78 Jts 103 to 103 1 Jts 5-1/?'°,15.5 ppf, L-80, BTC Slotted Casing ao.3o 12784.01 Jts 98 to 102 5 Jts 5-1/2",15.5 ppf, L-80, BTC Blank Casing 2o2.7s 12824.31 41/?" BTC Pin x 5-1/2" BTC Box Crossover 1.42 13027.07 Jts 97 to 97 1 Jts 41/2",11.6 ppf, L-80, BTC Blank Casing 3s.3s 13028.49 Jts ss to ss 1 Jts 41/?",11.6 ppf, L-80, BTC Slotted Casing a3.2s 13066.88 Jts 95 to 95 1 Jts 41/2", 11.6 ppf, L-80, BTC Blank Casing a2ss 13110.14 Jts 94 to 94 1 Jts 4112",11.6 ppf, L-80, BTC Slotted Casing x3.23 .13153.00 Jts 93 to 93 1 Jts 41/2",11.6 ppf, L-80, BTC Blank Casing a3.1s 13196.23 Jts 78 to 92 1 Jts 41/2",11.6 ppf, L-80, BTC Slotted Cas'sng 41.15 13239.41 Jts 91 to 91 1 Jts 41/2",11.6 ppf, L-80, BTC Blank Casing a2.gg 13280.56 Jts so to so 1 Jts 4-1/2",11.6 ppf, L-80, BTC S{otted Casing a2.as 13323.55 Jts ss to ss 1 Jts 41/?",11.6 ppf, L-80, BTC Blank Casing a2.2s 13366.04 Jts ss to 88 1 Jts 4-1/?",11.6 ppf, L-80, BTC Slotted Casing x3.01 13408.33 Jts s7 to s7 1 Jts 41/2", 11:6 ppf, L-80, BTC Blank Casing x3.53 13451.34 Jts 88 to 86 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.37 13494.87 Jts so to s5 s Jts 4-1/?",11.6 ppf, L-80, BTC Blank Casing 25s.7s 13538.24 Jts 79 to 79 1 Jts 4-1/2°,11.6 ppf, L-80, STC Slotted Casing 43.31 13795.02 Jts 78 to 78 1 Jts 41/2",11.6 ppf, L-80, BTC Blank Casing a3.2o 13838.33 Jts 77 to 77 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.34 13881.53 Jts 76 to 76 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing a2.a7 13924.87 Jts 75 to 75 1 Jts 4-11?",11.6 ppf, L-80, BTC Slotted Casing aoso 13967.74 Jts 74 to 74 1 Jts 41/2",11.6 ppf, L-80, BTC Blank Casing x3.17 14008.34 Jts 73 to 73 1 Jts 4-112",11.6 ppf, L-$0, BTC Slotted Casing a3.13 14051.51 Jts 72 to 72 1 Jts 41/2",11.6 ppf, L-80, BTC Blank Casing a3.3s 14094.64 Jts 71 to 71 1 Jts 41/?",11.6 ppf, L-80, BTC Slotted Casing a3.2a .14138.03 Jts 80 to 70 11 Jts 4-1/2",11.6 ppf, L-80, BTC Blank Casing a72sa 14181.27. Jts 59 to 59 1 Jts 4-1I?` ;11.6 ppf, L-80, BTC Slotted Casing ao.7z 14653.91 Jts sa toss 1 Jts 4-1/?",11.6 ppf, L-80, BTC Blank Casing x3.37 14694.68 Jts 57 to 57 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing a3.2a 14738.05 Jts 56 to 56 ~ Jts 41/?",11.6 ppf, L-80, BTC Blank Casing a3.3o 14781.29 Jts 85 to 55 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.a3 14824.59. Jts 5a to 54 1 Jts 41/2",11.6 ppf, L-80, BTC Blank Casing x1.37 14868.02 Jts 53 to 53 1 Jts 41/2",11.6 ppf, L-80, BTC Slotted Casing a3.3s 14909.39 Jts 52 to 52 1 Jts 4-1/?",-11.6 ppf, L-$0, BTC Blank Casing x2.32 14952.75 Jts 51 to 51 1 Jts 4-1/?",11.6 ppf, L-80, BTC Slotted Casing x3.87 14995.07 Jts so to so 1 Jts 41/2",11.6 ppf, L-80, BTC Blank Casing a2se 15038.94 Jts49 to 49 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing a3.3a 15081.79 Remarks: * ~ Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 4 LENGTH TOPS Jts a3 to 48 6 Jts 4112", 11.6 ppf, L-80, BTG Blank Casing 257.05 15125.13 Jts42to42 1 Jts 41/2",11.6 ppf, L-80, BTC Slotted Casing a3.32 15382.18 Jts41 to 41 1 Jts 4112",11.6 ppf, L-80, BTC Blank Casing a3.2a 15425.50 Jts ao to ao 1 Jts 4-112",11.6 ppf, L-80, BTC Slotted Casing a3.3s 15468.78 Jts 39 to 39 1 Jts 4-1/2",11.6 ppf, L-80, BTC Blank Casing a3.1s 15512.16 Jts 38 to 38 1 Jts 4-1/2",11.6 ppf, L-8Q BTC Slotted Gasing 43.24 15555.34 Jts 37 to 37 1 Jts 41/2",11.6 ppf, L-80, BTC Blank Casing a3.a1 15598.58 Jts 36 to 36 1 Jts 4-112"',11.8 ppf, L-80, BTC Slotted Casing a3:3s 15641.99 Jts 35 to 35 1 Jts 4112", 11.6 ppf, L-80, BTC Blank Casing a1 sa 15685.38 Jts 20 to 34 1 Jts 41/2",11.8 ppf, L-80, BTC Slotted Casing a1.87 15727.22 Jts 28 to 33 s Jts 4112", 11.6 ppf, L-$0, BTC Btank Casing 2so.57 15769.09 Jts 27 to 27 1 Jts 4-1/2",11.8 ppf, L-80, BTC Slotted Casing ao.s1 16029.66 Jts 26 to 26 1 Jts 4112", 11.6 ppf, L-80, BTC Blank Casing a3.3~ .16070.47 Jts 25 to 25 1 Jts 4-1/2",11.8 ppf, L-80, BTC Slotted Casing a3.2s 16113.78 Jts 24 to 24 1 Jts 41/2", 11.6 ppf, L-80, BTC Blank Casing a2s3 16157.06 Jts 23 to 23 1 Jts 41/2",11.6 ppf, L-80, BTC Slotted Casing a2.o3 16199.99 Jts 22 to 22 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing aos5 16242.02 Jts 21 to 21 1 Jts 4-1/2",11.6 ppf, L-80, BTG Slotted Casing a3.13 16282.87 Jts 20 to 20 1 Jts 41/2",11.8 ppf, L-80, BTC Blank Casing x3.32 16326.00 Jts 19 to 19 1 Jts 4-1/2";11.6 ppf, L-80, BTC Slotted Casing a3.22 16369.32 Jts 18 to 18 1 Jts 41/2",.11.8 ppf, L-80, BTC Blank Casing a2ss 16412.54 Jts 17 to 17 1 Jts 41/2",11.6 ppt, L-80, BTC Slatted Casing a3.25 16455.42 Jts 11 to 16 s Jts 4112", 11.6 ppf, L-80, BTC Blank Casing 25769 16498.67 Jts 9 to 10 2 Jts 4U2",11.6 ppf, L-80, BTC Slotted Casing ss.62 16756.56 Jts 8 to 8 1 Jts 41/2",11.8 ppf, L-80, BTC Blank Casing a3z1 16843.18 Jts 7 to 7 1 Jts 4-112",11.6 ppf, L-80, BTC Slotted Casing a3.13 16886.39 Jts 6 to 6 1 Jts ¢1/2",11.6 ppf, L-$0, BTC Blank Casing az.1s 16929.52 Jts 5 to 5 1 Jts 4112",11.6 ppf, L-80, BTC Stotted Casing 39.58 16971.68 Jts a too 1 Jts 4112",11.6 ppf, L-80, BTC Blank Casing a3.3o 17011.26 Jts 3 to 3 1 Jts 41/2",11.6 ppf, L-80, BTC Slotted Casing x3.22 17054.56 Jts2to2 1 Jts 41/2", 11.6 ppf, L-80, BTC Blank Casing a3s9 17097.78 Jts 1 to 1 tJts 4-1/2",11.8 ppf, L-80, BTC Slotted Casing a3.1s 17141:47 3-1/2", EUB 8rd Pin x 4-1/2" BTC Box tai 17184.62 3-1/2", 9.3 ppf, L-80, EUE 8rd Blank Casing PUP 5ss 17186.05 3-1/2", 9.3 ppf, L-8Q EUE 8rd Blank Casing 31.35 17192.00 3-1/2", EUE 8rd Baker Float Shoe s0 17223.35 17223.95 17223.95 Remarks: Jt Number Jt Number Num of Jts Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 5 Page 5 LENGTH LENGTH TOPS .TOPS TO 8 t2" hole ~ 13333' MD I3 4I8' iVD TD 8 1!2" hole @ 13,333' MD / 3,448' TVD 1]22:1.45 17223.95 TD 6 3/4" hole @ 17,233' MD / 3,41 T TVD 17223.95 4-1/2"Shoe @ 17,223' MD 13,418' TVD (Rathole 9.05') 17223.95 17223.95 17223.95 Total Parts used: 17223.95 96- 4-1/2"x 6.13" HydroFORM (#80549) Centralizers, 17223.95 96- 4112" stop rings in the middle of each joint. 17223.95 91- 5-1/2"x 8.00" HydroFORM (#80589)Centralizers, 17223.95 91- 5-172" stop rings in the middle of each joint. 17223.95 Do not run centralizer on 4-112" Joint #1 17223.95 Run 1 HydroFORM every jt. Floating w/ stops on 17223.95 center of jt every Jt except #1 17223.95 Run 1 HydroFORM per jt floating with a stop ring in 17223.95 center of each jt. fl Jt 2 thru Jt 188 17223.95 17223.95 Run torque rings from joint #53 thru #162 17223.95 Total of 45- 4-112" torque rings & 65- 5-112" torque rings 17223:95 Ran a 5-112" torque ring in the 5-1/2" x4-1/2" x-o. 17223.95 17223.95 17223.95 17223.95 17223.95 17223.95 17223.95 17223.95 17223.95 17223.95 17223.95 17223.95 17223.95 17223.95 17223.95 17223.95 17223.95 17223.95 17223.95 17223.95 Remarks: ~ ~ TirTie Lo s- - -- - -- - _ - + Date_ _ From _-To _ _- D_ ur - S_Du h 1 12/11/20U6 12:45 00:00 1.25 691 -- - - =. DEpth_P 691 P - - - - - -- Code __- h~se_ __ ROD2 RIGMN S -- Suhcode T VRG P - - - - - - - - - - - - - -- - t'ONl - - - - ~ - - -- Held PJSM with crew. Discuss safety issues and procedure for changing out Top drive saver sub. Change out saver sub. ut of Top Drive 12/12/2006 0 0:00 00:15 0.25 691 691. P ROD2 RIGMN SVRG P Complete change o saver sub. /8" 00:15 06:00 5.75 691 8,303 P ROD2 STK TRIP P - Continue trip in hole.with 9 5 Whipstock assembly @ 2 minutes stand as per BOT rep. Fill drill string ,~ every 30 stands. Fluid losses = 1-2 BBLS /HR. Crew Chan e 06:00 06:15 0.25 8,303 8,377 PROD2 STK TRIP P Continue TIH with whipstock assembly from 8303' - 837T @ 2 minutes / ` ~ stand. ~/ PASS log from 8377 D e 06:15 06:45 0.50 8,377 8,404 PROD2 EVALVI~ OTHR P . Perform MA i t l s . o -8404' MD as per MWD and Geo Q stock assembly hi ith 06:45 07:45 1.00 8,404 9,149 PROD2 STK TRIP P .. p w Contiue TIH w ' ' ~ . - 9149 from 8404 nnection and obtain i 07:45 08:-00 0.25 9,149 9,149 PROD2 STK CIRC P ve co Make Top dr circulation. k face to 7 degreesleft t " 08:00 08:30 0.50 9,149 9,149 PROD2 STK OTHR P oc Orient whips M t an. as per DD & Co. of high side ,~ ~ . Pumps @ 300 GPM's -..800 PSI. UP ~ WT = 235K, SO WT = 90K. al liner at 9202' (5' t f B l 08:30 09:00 50 0 9,149 9,084 PROD2 STK OTHR P er a Tag top o . Deep). set seals into liner top and set I c/u~, V ~ Q ~J ~ ~ BTA. Pull 10K over to verify set. Attempt to shear bolt.. Unsuccessful with SFMOBM in hole. Not enough downweight. Top of whipstock at 9084'. t SFMOBM with OBM @ e 09:00 10:00 1.00 9,084 9,084 PROD2 STK. CIRC P ou Displac 450 GPM's -1600 PSI. tock bolt with 50K set hi 10:00 10:45 0.75 9,084 9,084 PROD2 STK OTHR P pos Shear off w down weight. Pick up to neutral position, rotate free with 90 RPM's - 10K for ue. 9 5/8" casing from w in the i d 10:45 12:00 .1.25 9,084 9,088 PROD2 STK OTHR - o n P Mill w 9084' - 9088'. indow from 9088' - ill ~~'~ 12:00 17:15 5.25 9,088 9,130 PROD2 STK OTHR w P Continue.m bottom ofwindow @.9100`. Mill in Open hole to 9130' MD. Pump ~~~' ~ weighted Hi Visc sweeps as 17:15 18:00 0.75 9,130 9,130 IPROD2 STK CIRC 18:00 18:15 0.25 9,130 9,130 IPROD2 I STK I CIRC P Pump 40 .BBL Hi Visc weighted sweep and work mills through window area to clean up window. UP WT = 210K, SO WT = 122K, ROT WT = 130K. Crew Chan e P Continue pump 40 BBL Hi Visc weighted sweep and work mills through window area to clean up window. UP WT = 210K, SO WT = 122K, ROT WT = 130K. Pump Rate aC~. 600 GPM's - 2400 PSL ~ ~ I I ~ i I ~ ~ ~ ~ - ____ L-_ _ _ _ - -- - -- - - ,^~-~/ _Time Logs - __ - - - - - - - - - -- - - - --- - - - -- - Cate _ 5ro;:; To ~. Dur _- SDepth_ E Depth- Pna~e - CodE - Subcode_ -T -Ln~~1 _ _ -_ -- - -- - - -- 12/12/2006 18:15 18:30 0.25 9,130 r y,130 PROD2 STK OTHR P Work mills through window with no pumps or rotation. Observe clean window. 18:30 19:00 0.50 9,130 9,130 PROD2 STK OTHR P l Observe well for 15 minutes -static. Pump dry job. Blow down Top drive & ines. 19:00 22:00 3.00 9,130 3,712 PROD2 STK TRIP P POOH on elevators from 9084' - 3712' MD. Observed ro er hole fill 22:00 00:00 2.00 3,712 2,100 PROD2 STK TRIP P Continue POOH inspecting, moving and replacing Super Slideras as needed. Pull from 3712' - 2100'. Strap DP on TOH. 12/13/2006 00:00 02:45 2.75 2,100 383 PROD2 STK TRIP P Continue POOH inspecting, moving. and replacing Super Sliders as rieeded. Pull from 2100' - 383'. Replaced a total of 8 sleeves and 27 collars on the su er sliders. 02:45 03:30 0.75 383 83 PROD2 STK PULD P Stood back 2 stands of 5" HWDP & 1 stand of flex drill collars. lay down Bum er'ar. d MWD l 03:30 04:15 0.75 83 83 PROD2 STK OTHR P oa Plug in and down assembl . down k out & la H 04:15 05:15 1.00 83 0 PROD2 STK PULD P y brea Continue POO BHA. Inspect & gauge mills to full au a of 8.5". send tools 05:15 05:45 0.50 0 0 PROD2 STK PULD P Clean & clear floor area, outside. Brin tools to floor Crew hin b 05:45 06:00 0.25 0 0 PROD2 WELCT BODE P g. us Rig up & pull Wear chan e: and flush tool hi 06:00 07:00 1.00 0 0 PROD2 WELCT OTHR P , ng Rig up stack was BOP stack of iron cuttings. Lay down tool: nd tools out S fl 07:00 07:45 0.75 0 0 PROD2 WELCT BOPE P . e oor. Clean & clear rig Hold PJSM with crew. Discuss safety issues and procedure for rigging up & testin BOP's. uipment test e Ri 07:45 08:45 1.00 0 0 PROD2 WELCT BOPE P q g up Install test plug. & lines and test'oints to test. on location e GCC ' 08:45 12:00 3.25. 0 0 PROD2 WELCT BOPE P r p s. AO Test BOP to witness testa on AOGCC re P' 12:00 14:30 2.50 0 0 PROD2 WELC T BOPE P p s. Continue test BO location to witness test. 3 1/2" x 6" variable 14:30 15:30 1.00 0 0 PROD2 WELC T BOPE T Attempt to test bore rams. Test failed. Perform OP' 15:30 17:00 1.50 0 0 PROD2 WELC T BOPE P s. Continue test B accumulator draw down test. Pull test 'oint. Test Blind rams. 17:00 18:00 1.00 0 0 PROD2 WELCT BOPE T Pull test plug. Drain BOP stack. PJSM with crew. Discuss safety issues and procedure for changing out Upper rams. Rig up and change rams. Crew chan e. er rams t n 18:00 19:30 1.50 0 0 PROD2 WELCT BOPE T . upp ge ou Continue cha Remove 3 1/2" x 6" VBR's .Install 4 1/2" x 7" VBR's. P~c~ . ~~ €~•F r~ i _- - - -- Time Logs..-- ---- _-_ ~ __ _ - i Date From To Dur S- Depth_ E Depth Prase __ Code _ Suhcode _ T ('ON1 _ - - -_ _ - - - - 12/13/2006 19:30 22:15 2.75 0 0 PROD2 WELCT ROPE T Re-test with 5" ahd 5 1/2" test joints. Good tests. 22:15 23:45 1.50. 0 0 PROD2 WELCT BODE T Attempfto test with 4 1/2" test joint. Test failed. Rig up & retest with 5" test joint as per AOGCC rep. Good test. Pull & lay down test joint & pull test lu 23:45 00:00 0.25 0 0 PROD2 WELCT BOPE P Makeup & install wear bushing. RI LDS. 12/14/2006 00:00 00:30 0.50 0 0 PROD2 WELCT BOPE P Blow down all choke & kill lines. Blow down mud lines. 00:30 01:15 0.75 0 90 PROD2 DRILL PULD P Held PJSM-with crew, Sperry sun reps. Discuss safety issues and procedure for making up and runnung BHA# 6, 8 1/2"drilling assembly with Geo-Pilot. MU BHA. 01:15 02:00 0.75 90 90 PROD2 DRILL OTHR P Plug in and upload MWD assembly. 02:00 03:00 1.00 90 457 PROD2 DRILL PULD P Continue make upTemaihing BHA. Make u Centurion Circulation valve. 03:00 03:30 0.50 457 457 PROD2 DRILL PULD P Perform shallow pulse test. Good test. Pum s 550 GPM's - 1000 PSt. 03:30 06:00 2.50 457 6,169 PROD2 DRILL TRIP P Trip in hole with BHA # 6 from 45T - 6169' MD. Observed proper hole fill. Obtain T&D parameters as per rig engineer every 10 stands. Crew than e. 06:00 08:30 2.50 6,169 9,015 PROD2 DRILL TRIP P Continue trip in hole with BHA # 6 from 6169' - 9015' MD. Observed proper hole fill. Obtain T&D parameters as per rig engineer every 10 stands. 08:30 09:30 1.00 9,015 9,015 PROD2 RIGMN SVRG P Held PJSM with crew. Discuss safety issues and procedure for. slipping & cutting. Slip & cut drilling line, inspect & ad'ust draw works brakes. 09:30 10:30 1.00 9,015 9,015 PROD2 RIGMN SVRG P Service Top Drive, draw works, Blocks and crown section. Ins ect saver sub. 10:30 11:15 0.75 9,015 9,130 PROD2 DRILL TRIP P Continue trip in hole from 9015'- 9130'. Observed no issues with BHA oin throu h window area. 11:15 12:00 -0.75 9,130 9,184 PROD2 DRILL DDRL P Directional dill 8 1/2" hole in the D Lateral from 9130' - 9184'. ECD = 10.2 PPG. ADT = .49 HRS. 12c00 12:15 0.25 9,184 9,210 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D Lateral from 9184' - 9210'. ECD = 10.3 PPG. ADT = .12 HRS. 12:15 12:30 0.25 9,210 9,210 PROD2 DRILL CIRC T Trouble shoot MWD. Failed signals. 12:30. 13:00 0.50 9,210 9,272 PROD2 DRILL DDRL P Directional drill 8 1/2'' hole in the D Lateral from 9210' - 9272': ECD = 10.2 PPG. ADT = 1.01 HRS. 13:00 16:00 3.00 9,272 9,272 PROD2 DRILL CIRC T Trouble shoot MWD. Failed signals. Pull drill string into casing. Obtain ood ulses. RIH to 9272'. m.^ - __ Time Logs - - --- - - _ --- - _ - - ~, - - - - - - - - - Uate Frem To_ _D~~r S. Depth E D~pfn_-Ph~~~_ ~ ode_ ~~t.code_T __C _ _ _- tional drill 8 112" hole in the D UURL P Dire c 12/14l2006 16:00 18:00 2.00 9,272 9,385 PROD2 DRILL Lateral from 9272' - 9385'. ECD = 9.85 PPG. ADT =.2.08 HRS. Crew Chan e 18:00 2 0:30 2.50 9,385 9,509 PROD2 DRILL DDRL P D irectional drill 8 1/2" hole in the D ' L . ECD = ateral from 9385` - 9509 9 .93 PPG. ADT = 1.69 HRS. 20:30 00:00 3.50 9,509 3,220 PROD2 DRfLL TRIP T Lost-MWD signal. POOH, 5 stands. Pump dry job. Continue POOH from 9509' - 3220' Observed ro er hole fill. 12/15/2006 00:00 01:00 1.00 3,220. 460 PROD2 DRILL TRIP T Continue POOH from 3220' - 460'. Observed ro er hole fill 01:00 02:15 1.25 460 80 PROD2 DRILL PULD T Stand back Flex drill collars & HWDP. ' . . Pull to MWD assembl 02:15 03:00 0.75. 80 80 PROD2 DRILL OTHR T Plug in and down load MWD assembl . 03:00 03:30 0.50 80 0 PROD2 DRILL PULD T POOH, Break out & lay down MWD - Inspect & grade assembly. Pull tabu. bit. WiH rerun bit. 03:30 04:00 50 0 0 80 PROD2 DRILL PULD T RIH-with Bit & Geo-Piloy assembly. . Make up new MWD assembly. BHA #7. 04:00 04:30 0.50 80 80 PROD2 DRILL OTHR T Plug in and upload. MWD assembly. 04:30 05:00 0.50 80 460 PROD2 DRILL PULD T Make up remaining BHA # 7. Total ' . len th = 460.79 05:00 06:00 1.00 460 1,701 PROD2 DRILL TRIP T Perform shallow pulse test with pumps @ 550 GPM's - 1050 PSI. Good test Continue TIH with BHA # 7 from 460' - 1701' MD. Crew Chan e. 06:00 06:30 0.50 1,701 1,701 PROD2 DRILL TRIP T Continue trip in hole with BHA from 1701' - 2651'. Fill drill strin . 06:30 07:30 1.00 1,701 1,701 PROD2 RIGMN SVRG T Service rig.ServiceTop-Drive. Check swivel packing, draw works, Electrician serviced control .card in the drilling console: Tested same. Good test. 07:30 11:30 4.00 1,701 9,509 PROD2 DRILL TRIP T Continue trip in bole with BHA from 1701' - 9509'. No issues passing. throu h window area. 11:30 12:00 50 0 .9,509 9,523 PROD2 DRILL DDRL P Directional drill in the D lateral from ' . s 9509' - 9523'. ADT = .53 HRS. ECD = 10.1 PPG 12:00 18:00 6.00 9,523 9,972 PROD2 DRILL DDRL P Directional drill in the D lateral from 9523' -9972' MD. ADT = .4.47 HRS. ECD's = 10.1 PPG 18;00 00:00 6.00 9,972 10,573 PROD2 BRILL DDRL P Directional drill in the D lateral from 9972' - 10573' MD. ADT = .4.54 HRS. ECD's = 10.21 PPG the D lateral from ill i d 12/16/2006 00:00 06:00 6.00 10;573 11,208 PROD2 DRILL DDRL P n r Directional- 10573' - 11208' MD. ADT = 4:01 HRS. ECD's = 10.49 PPG Crew Chan e the D lateral from ill i 06:00 12:00 00 6 1.1,208 11,653 PROD2 DRILL DDRL P n Directional d-r . 11208' - 11653' MD. ADT = 4.52 HRS.. ECD's = 10.38 PPG i €~~~a? 3~i'+~f his i TimeL_ogs - _ _ _ _ _ -- - --- - --- - -- - - _- -- -- - - - - - D,.,e ., From To Dur S _Dco~h E- DEpth_ Ph~~e_ ,Code Sibco~e_-T_ COM- __ - - _ - - - - - 12/16/2006 12:00 18:00 6A0 11,653 12,255. PROD2 DRILL DDRL P Directional drill. in the D lateral from 11653' - 12255' MD. ADT = 3.07 HRS. ECD's = 10.61 PPG Crew Chan e 18:00 00:00 6.00- 12,255 12,826 PROD2 DRILL DDRL- - P Directional drill in the D lateral from 12255' - 12826'.. MD: ADT = 4.96 HRS. ECD's = 10.75 PPG 12/17/2006 00:00 01:00 1.00 12,826 12,990 PROD2 DRILL DDRL P Directional drill in the D lateral from 12826' - 12990' MD. ADT = .82 HRS. ECD's = 10.75 PPG 01:00 03:00 2.00 12,990. 13,275 PROD2 DRILL DDRL P Directional drill in the D lateral from 12990' - 13275'. MD. ADT = 1:43 HRS. ECD's = 10.97 PPG 03:00 06:00 3.00 13,275 13,586 PROD2 DRILL DDRL P Directional drill in the D lateral from 13275' - 13586' MD. ADT = 1.55 HRS. ECD's =10.84 PPG Crew Chan e 06:00 07:00 1.00 13,586 13,707 PROD2 DRILL DDRL P Directional drill in the D lateral from 13586' - 13707 MD:ADT = .85 HRS. ECD's = 10.75 PPG Observed Geo-Pilot Failure. 07:00 07:45 0.75 13,707 13,707 PROD2 DRILL CIRC T Circulate @ 620 GPM's - 2850 PSI @ 90 RPM's troublshootin Geo-Pilot. 07:45 08:45 1.00 13,707 13,707- PROD2 DRILL CIRC T Continue circulate bottoms up @ 640 GPM's - 2850 PSI: 08:45 12:00 3.25 .13,707 11,021 PROD2 DRILL TRIP T POOH due to failed Geo-Pilot on elevators from 13707 - 11021'. Pump out every 5th stand for improper hole fill: 12:00 12:30 0.50 11,021 11,021 PROD2 DRILL CIRC. T Mix & pump dry job. Blow down Top Drive. & lines. 12:30- 13:30 1.00 11,021 9,024 PROD2 DRILL TRIP T Continue POOH on elevators from 11021' - 9024'. Observe proper hole fill Monitor well at window -static. 13:30 16:45. 3.25 9,024 460 PROD2 DRILL TRIP T Continue POOH from 9024' - 460'. Observe proper hole fill. Record T&D parameters every 10 stands as per rig en ineer. 16:45. 17:45 .1.00 460 80 - PROD2 DRILL- PULD T Breakout &-stand back BHA # 7 to MWD assembl . d MWD l 17:45 18:00 0.25 80 80 PROD2 DRILL OTHR T oa Plug in and down assembly. Calculated displacement = 101 BBLS. Actual Fill = 123 BBLS. Crew Chan e 18:00 18:30 0.50 80 . 0 PROD2 DRILL PULD T Continue breakout and lay down BHA # 7. Inspect & grade bit to 2/1M/T/N/X/I/NO/DTF: Plan to rerun. BHA # 8 with rerun bit 18:30 19:30 1.00 0 80 I?ROD2 DRILL PULD T . -Make up L THR T in and Upload MWD assembly. Plu 19:30 20:00 0.50 80 80 PROD2 L DRI O g 20:00 20:45 0.75 80 461 PROD2 DRILL PULD T Continue make up remaining BHA # 8. 20:45 21:00 0.25 461 461 PROD2 DRILL PULD T . Perform sahllow pulse test with pumps 575 GPM's - 1075 PSI. Good test: 21:00 00:00 3.00 461 8,500 PROD2 DRILL TRIP T ' Trip in hole with BHA #8 from 460' - 8500' MD. Fill drill string every 25 stands. Observe ro er hole fill `-, I P~c,~ 37 ~f 55 ~- -- a - - - - --__ _ - - - - - _ _ __ _ - oys Tune L _ - - - _-- - _ - Deotf~ E Depth PhasE_ ~'~ e _ S~.bcod_ e_ T_ CO_M __ -- __ _ _ - - _- - Dur 5- Date From To ' _ _ - 12/18/2006 00:00 00:30 0.50 8,500 9,027 PROD2 DRILL TRIP T Continue trip in hole. from 8500 902T. 00:30 01:30 1.00 9,027 9,027 PROD2 RIGMN SVRG T Service rig & top drive. 01:30 02:30 1.00 9,027 9,027 PROD2 RIGMN SVRG T Held PJSM. Slip & cut 115' of drilling l ine. 02:30 03:15 0.75 9,027 10,100 PROD2 DRILL TRIP T Continue trip in hole from 9027 - 10100'MD. Ran out of downweight, be in wash & rotate. down from 10100'. 03:15 06:00 2.75 10,100 12,390 PROD2 DRILL REAM T Wash & ream in fhe hole from 10100' - 12390'. MD. Pumps @ BPM - 2000 PSI: 50 RPM's. Crew Chan e 06:00 07:45 1.75 12,390 13,707 PROD2 DRILL REAM T Continue wash & ream in the hole from 12390' - 13707. MD. Pumps @ 4 BPM - 2200 PSI. 60 RPM's. 07:45 09:45 2.00 13,707 13,968 PROD2 DRILL DDRL P Directional drill8 1/2" hole from 13707 - 13968' MD. ADT= 1.14 HRS. ECD = 10.8 PPG: 09:45 10:45 1.00 13,968 13,968. PROD2 DRILL REAM T BROOH-from 13968' - 13687. Ream - back into hole to 13968' as per Geo. Sus ect ossible STat this oint. 10:45 12:00 1.25 13,968 14,159 PROD2 DRILL DDRL P Directional drill 8 1/2" hole from 13968' -14159' MD. ADT = 1.51 HRS. ECD = 11.1 PPG. 12:00 14:00 2.00 14,159 14,426 PROD2 DRILL DDRL P Directional drill 8 1/2" hole from 14159' - 14426' MD. ADT = 1.12 HRS. ECD = 11.1 PPG. Observed Geology issue with being low. On attempts to come up, DD observed drop in Inclination and ri ht hand walk in Azimuth. 14:00 18:00 4.00 14,426 13,500 PROD2 DRILL TRIP T Pump out of hole from 14426' - 13500'. Observe hole swabbing when attempt to POOH on elevators. Crew Chan e 13500' f of h l 18:00 18:30 0.50 13,500 13,244 PROD2 DRILL TRIP T rom o e Continue Pump out - 13244' 18:30 19:30 1.00 13,244 13,275 PROD2 DRILL DDRL T Time drill for sidetrack from 13244' - 13275' MD. Kick off at 13275'. 19:30 19:45 0:25 13,275 13,275 PROD2 DRILL DDRL T Make connection and pump up sunre s. 275'- 13398' 19:45 20:45 1.00 13,275 13,398 PROD2 DRILL DDRL T Directional drill from 13 with 100 % deflection on the GeoPilot. brill down full stand. Pump up survey to observe drop in inclination with 2 1/2 degrees right hand walk. Decision to POOH to change Geo-Pilot & MWD tools. 20:45 21:15 -0.50 13,398 13,398 PROD2 DRILL OTHR T Cycle pumps, obtain surveys & discuss options while reciproctae & rotate drill strin . hted i Hi Vi 21:15 22:30 1.25 13,398 13,398 PROD2 DRILL CIRC T g sc we Mix & pump 35 BBL sweep. Reciprocate & rotate drill string. Observe increase in cuttings @ 25%. 22:30 22:45 0.25 13,398 13,398 PROD2 DRILL OWFF T MonitorwelL Slight flow, slowing down to sto .Well breathin . ~'~~~ 33a~f ~u _._ i • ~I Tirne Logs __ _ - - -- - -- _ - ___ _ _ ___ - _ 1 - __- ~Date From To Dur _ S Deoth _E. De to Phase Code Subeude T COM _ 12/18/2UU6 22:45 00:00 1.25 13,398 12,546 PROD2 DRILL TRIP T POOH on elevators for 3 stands: Observe well swabbing. Continue pump out of hole 15 stands. Pull from 13398' - 12546 12/19/2006 .00:00 04:00 4.00 12,546 10,170 PROD2 DRILL TRIP T Continue POOH, Observe well swabbing. Continue pump out of hole from 12546' - 10170'. Observe well stopped swabbing and fluid dropping. Pumping 4 bpm w/ 450 psi. Pulling 45 ft/min. 04:00 04:15 0.25 10,170 10,170 PROD2 DRILL CIRC T Pump dry job, Blow down Top Drive & lines. 04:15 06:00. 1.75 10,170 8,361 PROD2 DRILL TRIP. T Continue POOH on elevators-from 10170' - 8361' 06:00 08:45. 2.75 8,361 461 PROD2 DRILL TRIP T Continue POOH on elevators from 8361' to 461'. 08:45 09:30 0.75 461 70 PROD2 DRILL TRIP T Stand back 5" HWDP and jars. Lay down centurian circ valve. Stand back flex-drill collars and float sub. 09:30 10:00 0.50 70 70 PROD2 DRILL OTHR T Downlaod MWD. 10:00 10:45 0.75 70 0 PROD2 DRILL TRIP T Change out pulsar, UD MWD, smart stab, Gamma/Res/PWD. Check oil in eo ilot, break off bit. 10:45 11:45 .1.00 0 72 PROD2 DRILL TRIP T MU BHA #9. Change jetsin bit, MU bit, geopilot (TL055), nm flex DC, smart stab, Gamma/Res/PWD, MWD/HCIM and ulsar. 11:45 12:30 0.75 72 72 PRODZ DRILL OTHR T Uplaod MWD 12:30 13:00 0.50. 72 455 PROD2 DRILL TRIP T MU flex DC w/ float sub, centurian valve, HWD and 'ars. 13:00 13:30 0.50 455 455 PROD2 DRILL OTHR T Shallow test MWD. Pumping 550 gpm wf 1000 si. 13:30 -17:00 3.50 455 9,023 PROD2 DRILL TRIP T Trip in hole w/ BHA #9/ Record torque and dra eve 10 stands. 17:00 17:30 0.50 9,023 9,023 PROD2 RIGMN SVRG T Blow down top drive. Service drawworks and wash i e. 17:30 19:45 2.25 9,023 9,023 PROD2 RIGMN SVRG T .Inspect and change out saver sub on fo drive: 19:45 20:00 0.25 9,023 9,023 PROD2 .DRILL OWFF T Monitor welC OK 20:00 21:15 1.25 9,023 10,048 PROD2 DRILL TRIP T - Trip in hole. Record PU and SO wei ht's eve 5 stands. 21:15 00:00 .2.75 10,048 11,586 PROD2 DRILL REAM T Ream in hole (no down wt). 220 gpm w/ 600 si: 50 r m w/ 12-13k for ue. 12/20/2006 00:00 02:00. 2,00 11,586 12,915 PROD2 DRILL REAM T Ream in hole (no down wf). 50 rpm w/ 13-14k for ue: 02:00 04:00 2.00 12,915 12,990 PROD2 STK KOST T Troughing f/ sidetrack. Rotating 120 w/ 12-13k tro ue. 04:00 06:00 2.00 12,990 13,204 PROD2 DRILL DDRL T Drilling. ECD's 10.3 ppg. Jar hours 171.37. 06:00 07:30 1.50 13,204 13,333 PROD2 DRILL DDRL T Drilling. ECD's 10.3 ppg. ~a~~~39c~f5~i' j C._ - -- - ~ ~ _ _ _ _ _- t-_- - - - Time Logs __ _ - - - - __ _ - - - - - - - - - - - - -- _ _ - - - - ----- Date_ _ From_ To Dur S .Dept(~_E Depth Ph~se_ Code _- Subc~cleT -~0~~1 -- _ - _ - - -- - -- 12/20/2006 07:30 08:00 0.50 13,333 13,333 PRUD`Z DRILL SRVY T Check shot surrey. Survey showed. unable to control Geo-Pilot (Dropping angle and hard right hand turn with strai ht u tool face). 0 8:00 10:45 2.75 13,333 13,333 PROD2 DRILL CIRC T Circulate 3 BU .Rotate 120 rpm w/ 15k ft Ib torque. Pumped 10 ppg 122 vis swee sli ht increase in cuttin s 10:45 12:00 1.25 13,333 12,825 PROD2 DRILL REAM T Backream out of hole. Rotate 120 rpm w/ 14k ft Ib for ue. 12:00 18:45 6.75 12,825 9,023 PRODZ DRILL REAM T Backream out of hole. Rotating 120 rpm w/ 11-14k ft Ib torque.. Pulling s eed 40-45 ft/min: 18:45 20:15 1.50 9,023 9,023 PROD2 DRILL CIRC T Circulate bottom's up: Rotate 120 rpm w/ 11k ft Ib torque. Bring (12) 5" LoTads to the rig floor, to be installed while pullin out. of hole. 20:15 20:30 0.25 9,023 9,023 PROD2 DRILL. CIRC T Monitor well. Pump dry job. 20:30 20:45 0.25 9,023 9,023 PROD2 DRILL OTHR T Blow down top drive. 20:45 21:15 0.50 -9,023 8,359 PROD2 DRILL TRIP T Continue POOH 5"drill pipe w! super sliders, rackin on off driller's side. 21:15 21:30 0.25 8,359 8,357 PROD2 DRILL SFTY T PJSM on installing LoTads on 5"drill i e while POOH. e while i 5"drill 21:30 00:00. 2.50 8,357 7,217 PROD2 DRILL TRIP T p p Install LoTads on POOH. Install between bottom single and middle joint of stand. Drift LoTads w/ 2.5"drift. Total of 12 picked up @ midni ht. l 12/21/2006 00:00 04:15 4.25 2,217 4,550 PROD2 DRILL TRIP T bottom single POOHLI stall between and middle joint of stand. Drift LoTads w/ 2:5" drift. Total of 40 LoTads picked u 04:15 05:30 1.25 4,550 940 PROD2 DRILL TRIP T PUnalnd SO we ght Beveryl0 tands in casin . 05:30 06:00 0.50 940 459 PROD2 DRILL TRIP. T Lay-down 8-1/2" ghost reamer. Pull. and stand back 5 stands of 5" d . jars HWDP 06:00 08:00. 2.00 459 72 PROD2 DRILL PULD T , , UD BHA #9. (8) 5" Centurian circ sub, (3) nm flex dc's, and float sub. Sun MWD r d S l 08:00 08:30. 0.50 72 72 PROD2 DRILL OTHR T . ry pe oa Down 08:30 09:15 0.75 72 0 PROD2 DRILL PULD T Continue UD BHA #9. 09:15 11:00 1.75 0 0 PROD2 WELCT EQRP T Change top pipe rams f/ 4-1 /2" x 7" to 3-1 /2" x 6". wear o/Gra t ll V 11:00 11:30 0.50 0 0 PROD2 WELCT OTHR T y c e Drain stack. Pu bushing: Set test plug. Fill stack with. water. - §'ac~~ ~tD cif s Time Logs ~ °~Date From To Dur S. De t~ti E: Da th_ Pf~,ase _ Code Sul~code T __ COM __ _ 12/21/2006 11:30 17:00 _ _ 5.50 0 0 PflUD'2 WELCT BOPE T 14 day BOP test. Witness of test waived by AOGCC inspector Jeff Jones. Choke manifold and floor safety valves (4" and 5") were tested while POOH. Koomey tested. Upper pipe rams were tested w/ 4", 4-1/2", 5" and 5-1/2". Annular was tested w/ 4" pipe. Blinds were tested. Tests were held 5 min each @ 250 psi low then 3000 high. Inside kill and choke tested. Top drive IBOP tested. 17:00 18:00 1.00 0 0 PROD2 WELCT OTNR T Pull test plug, install Vetco/Gray wear bushing. Rig down test equipment. - Blow down kill and choke line and. choke manifold. 18:00 18:30 0.50 0 0 PROD2 RIGMN SVRG T Service drawworks, top drive and rease crown. 18:30 23:00 4.50 0 0 PROD2 DRILL PULD T Lay down 38 stands of 5"drill pipe from derrick using mouse hole in rota table. 23:00 23:15 0.25 0 0 PROD2 DRILL OTHR T Move 5 stands of 5" drill pipe f/ drillers side to DC finger on DS. This pipe is slick (no super sliders and no LoTads). PU crossovers and subs f/ BHA #10 to ri floor. 23:15 00:00 0.75 0 0 PROD2 DRILL OTHR T Move 35 stands of 5" dp w/-super sliders f/ ODS to DS of derrick. 12/22/2006 00:00 00:15 0.25 0 0 PROD2 DRILL OTHR T Move 5 stands of 5" drill pipe f/ drillers side to ODS pipe rack w/ the other slick drill pipe. This pipe is slick (no su er sliders and no LoTads). 00:15 00:30 0.25 0 0 PROD2 DRILL OTHR T Change elevators to 4". Clear and clean ri floor. 00:30 00:45 0.25 0 0 PROD2 DRILL SFTY T PJSM on picking up BHA #10. 00:45 02:00- 1.25 0 123 PROD2 DRILL PULD T PU/MU BHA #10. Orient motor w! MWD. ' 02:00 03:00 1.00 0 93 PROD2 DRILL OTHR T Upload Sperry Sun MWD. 03:00 03:30 0.50 93 123 PROD2 DRILL OTHR T PU a 4-3/4" flex DC. Shallow test MWD tools. 59 spm (250 gpm) w/ 970 si. 03:30 03:45 A.25 123 123 PROD2 DRILL OTHR T Blow down top drive. Clean floor area. 03:45 04:00 0.25 123 185 PROD2 DRILL. PULD T PU two more 4-3/4" flex collar. Chan a elevators f/ 3-1/2" to 4". 04:00 06:00 2.00 185 1,780 PROD2 DRILL PULD T Continue PU/MU BHA#10. Rabbit4" d w/ 2-7/16" rabbit. 06:00 06:30 0.50 1,780. .1,800 PROD2 DRILL PULD T MU agitator and shock sub. 06:30 07:00 0.50 1,800 1,800 PROD2 DRILL CIRC T MU top drive,. fill pipe. Pump through string. 87 gpm = 800 psi, 130 gpm = 1025 psi, 181 gpm = 1175 psi--but then pressured up to 2600 psi. Slowed rate to 87 gpm w/ :2000 psi. Excessive ressure while testin a itor. l - --- --- F'a~~~1 tsf~5 • • Tirne Loys - _ - - - __ _-_ - - D ate From To Dur 5 Depth E Depth Phase_ Code Subcoda T COfv1_ _ _ _ -_ ~ - - 12/22/2006 07:00 07:30 0.50 1,800 1,780 PROD2 DRILL PULD T Lay down shock sub and agitator. MU to drive to strip . 07:30 07:45 0.25 ' 1,780 1,780 PROD2 DRILL CIRC T Pump through string without shock sub and agitator. Pumping 168 gpm = 850 psi, 211 gpm = 1100 psi, 253 gpm 1400 psi, 295 gpm =.1700 psi, 316 m = 1950 si. Break out top drive. 07:45 08:00 0.25 1,780 1,800 PROD2 DRILL PULD T MU another agitator and same shock sub. Make u to drive: 08:00 08:30 0.50 1,800 1,800 PROD2 DRILL CIRC T Circulate through string. Pumping 87 gpm = 450 psi, 168 gpm = 1150 psi, 211 gpm = 1350 psi, 253 gpm = 1850 psi, 295 gpm = 2400 psi, 316 gpm = 2700 psi. Break off top drive. Blow down top drive. Agitator seems'to be OK. 08:30 10:30 2.00 1,800 4,170 PROD2 DRILL PULD T Continue in the hole picking up 4" dp fl i e shed. 10:30 14:00 3.50 4,170 9,000 PROD2 DRILL TRIP T Change elevators f/ 4" to 5". PU Centurian circ valve w/ ball catcher. Then trip in from out of derrick to 7024'. Record PU and SO weight's every 10 stands incasing. Fill pipe eve 25 stands: 14:00 15;15 1.25 9,000 9,000 PROD2 RIGMN SVRG T Slip and cut 102' of 1-3/8" drilling line. 15:15 16:15 1.00 9,000 9,000 PROD2 RIGMN' SVRG T Service top drive and dPawworks. 16:15 18:00 1.75 9,000 10,828 PROD2 DRILL TRIP T Continue trip in hole. Shallow test MWD, good. Record PU and SO weight's every 5 stands in open hole. Fill i e eve 20 stands. 18:00 20:30 2.50 10,828 13,302 PROD2 DRILL TRIP T Continue trip in hole. Record PU and SO weight's every 5 stands in open. hole. Fill i e eve 20 stands. 20:30 21:30 1.00 13,302 13.,302 PROD2 DRILL CIRC T Fill pipe. SPR's @ 13302'. Survey. Rotate to tag fill/bottom. Tagged @ 13302' w/o rotatin . 21:30 23:45 2.25 13,302 13,333 PROD2 DRILL REAM T Wash and-ream 8-1 /2" hole. 23:45 00:00. 0.25 13,333 13,365 PROD2 DRILL DDRL T Drilling. ECD's 9.3. 12/23/2006 00:00 06:00. 6.00 13,365 13,591 PROD2 DRILL DDRL T_ Drilling. ECD's 9.3-9.4. Jar hrs 146.08 hrs. Av as 15 units. 06:00 12:00 6.00 13,591 14,113 PROD2 DRILL DDRL T Drilling. ECD's 9.4-9.55. Jar hours 149.66 hrs.. Max as 180 units. 12:00 16:30 4.50 14,113 14,426 PROD2 DRILL DDRL T Drilling. ECD's 9.55- 9.81. Jar hours 151.94 hrs. Max as 116 units. 16:30 18:00 1.50 14,426 14,645 PROD2 DRILL DDRL. P Drilling. ECD's 9.81-9.87. Jar hours 152.86 hrs. Max as 84 units. 18:00 00:00. 6.00 14,645 14,948 PROD2 DRILL DDRL P Driliinge ECD's 9.887-9.8; Jar hours 155.46 hrs. Max as 56 units. 12/24/2006 00:00 06:00 6.00 14,948 15,134 PROD2 DRILL DDRL P Drilling. ECD's 9.80-9.84. Jar hours 158.51 hrs. Max as 34 units. 06:00 12:00 6.00 15,134 15,343 PROD2 DRILL DDRL P Drilling. ECD's 9.84-9.97. Jar hours 162.08 hrs. Max as 48 units. ~~:te ~~ '~ ~ ~ Time Loc~s_ __ - uate From To Dur o. Deptt_i_ E_ DFpth- PV ~s~ _ Cade Sut~code T c;~")f~1 _ - --- -- ---- - - - - 92/24/2006 12:00 14:30 2.50 15,343 15,496 PROD2 DRILL DDRL P Drilling. ECD's 9.97-10.. Jar hours - 163.36 hrs. Max as 95 units. 14:30 15:30 1.00 15,496 15,496 PROD2 DRILL CIRC P Circulate prior to POOH f/ geoPilot. Difficult in slidin . 15:.30 16:30 1.00 15,496 14,556 PROD2 DRILL TRIP P POOH f/ geopilot and 6-3/4" bit du to difficulty in sliding. POOH w/ BHA #10, checkin LoTads, SLM.. 16:30 17:00 0.50 14;556 14,556. PROD2 DRILL OWFF P Monitor well. Pump dry job. Blow down to drive. 17:00. 15;00 1.00 14,556 13,665 PROD2 DRILL TRIP P Continue POOH. Checking LoTads and super sliders. SLM. 18:00 22:30 4.50 13,665 9,072 PROD2 DRILL TRIP P Continue POOH to above window. Checking LoTads and super sliders. SLM. 22:30 22:45 0.25 9,072 9,072 PROD2 DRILL OWFF P Monitor well @ wiridow. Static.. 22:45 23:15 0:50 9,072 9,072. PROD2 DRILL- CIRC P Pump 25 bbls dry job (Dry job #2). Blow down top drive. Install air slips and stri er rubber. _ 23:15 00:00 0.75 9,072 8,072 PROD2 DRILL TRIP P Continue POOH. Checking LoTads and su er sliders. SLM. 12/25/2006 00:00 02:30 2.50 8,072 4,169 PROD2 DROLL TRIP P Continue POOH. SLM.. 02:30 03:15 0.75 4,169 4,150 PROD2 DRILL PULD P Lay down Centurian circulating sub and crossovers. Change elevators to 4". Clear and clean ri floor. 03:15 03:30 0.25 4,150 4,150 PROD2 DRILL SFTY P Monitor well, static. PJSM on Laying down BHA. 03:30 05:00 1.50 4,150 1,800 PROD2 DRILL TRIP P POOH w/ 4" dp. SLM. 05:00 05:30 0.50 1,800 1,780 PROD2 DRILL PULD P Lay down shock sub and agitator and x-o's. 05:30. 06:00 0.50 1,780 1,217 PROD2 DRILL TRIP P Continue POOH w/ BHA #10. SLM. - 06:00 07:30 1.50 1,217 95 PROD2 DRILL TRIP P Continue POOH w/ BHA #10. SLM. 07:30 08:15 0.75 95 95 PROD2 DRILL OTHR P Download Sperry Sun MWD. 08x15 09:00- 0.75 95 0 PROD2 DRILL PULD P Continue L/D BHA #10. 09:00 09:30 0.50 0 0 PROD2 DRILL OTHR P Clear and clean rig floor, 09:30 10:45 1.25 0 85 PROD2 DRILL PULD P PU/MU BHA #11. 10:45 11:15 0.50 85 85 PROD2 DRILL OTHR P Upload Sperry Sun MWD. 11:15 12:00 0.7b' 85 650 PROD2 DRILL PULD P Continue MU BMA #11. 12:00 12:30 0.50 650. 650 PROD2 DRILL OTHR P . Shallow test MWD and Geopilot. Blow down to drive. 12:30 15:15 ' 2,75 650. 4,120 PROD2 DRILL. TRIP P RIH w/ 4" dp and BHA #11. Fill pipe eve 20 stands. 15:15 15:30 0.25 4,120 4,144 PROD2 DRILL .PULD P Change elevators to 5". MU Centurian circulatin valve and crossover. 15:30 18:00 .2.50 4,144. 8,902 PROD2 DRILL TRIP P RlH w/ BHA #11 on 5" dp.,Fill every 20 stands. Record PU and SO wt's every 10 stands. ' €'~ge 43 of 56 . ~~ - ~ ~ Time Logs _ - _ __: Date From To Dur S- Depth E Depth P}~~~e _ Cody SuE co~'_e T COf~~1 _ __ __ - - - - - -- 12/25/2006 18:00 19:00 1.00 8,902 8,902 PROD2 RIGMN SVRG P Fill pipe. Service top drive. 19:00 00:00 5.00 8,902 13,332 PROD2 DRILL TRIR P Continue RIH w/ BHA #11 on 5" dp (44 stands slick, 35 stands w/super sliders, then 17 stands w/ Lotads. Filled pipe every 10 stands. Recorded PU and SO wt's every 5 stands: Observed no SO wt 13332'. 12/26/2006 00:00 01:30 1.50 13,332 13,438 PROD2 DRILL REAM P Ream and work hole transition f/ 8-1/2" x 6-3/4" 01:30 02:30 1.00 13,438 13,438 PROD2 DRILL REAM P Ream out of hole working transition f/ 13438' to 13243', then back down to 13438'. 02:30 02:45 0.25 13,438 13,470 PROD2 DRILL TRIP NP Trip in hole. 02:45 06:15 3.50 93,470 15,496 PROD2 DRILL REAM NP Ream'in hole. 06:15 12:00 5.75 15,496 16,090 PROD2 DRILL DDRL P Drilling: ECD's 10.12-10.49 ppg. Jar hours 166.90 hrs. Max as-95 units. 12:00 18:00 6.00 16,090 16,491 PROD2 DRILL. DDRL P Drilling. ECD's 10.34 - 10.5 ppg. Jar hours 170.67 hrs. Max as 110 units. 18:00 00:00 6.00 16,491 17,007 PROD2 DRILL DDRL P Drilling. ECD's 10.35- 10.41 ppg. Jar hours 174.42 hrs. Max as 94 units. 12/27/2006 00:00. 03:15 3.25 .17,007 17,233 PROD2 DRILL DDRL P Drilling. ECD's 10.41-.10.45 ppg. Jar hours 176.81 hrs. Max as 121 units. 03:15 03:45 0:50 17,233 17,233 PROD2 DRILL SRVY P Survey and verify TD of "D" lateral @ 17233'. 03:45 05:15 1.50 17,233 17,233 PROD2 DRILL CIRC P Pump 35 bbls 10.6 ppg 130 vis sweep. Follow w/ circ @ 325 gpm w/ 3400 psi. Rotate 140 rpm w/ 17k torque. PU 250k, SO 72K, Rot 148k. Recip f/ 17233' to 17135'. 05:15 05:30 0.25 17,233 17,233 PROD2 DRILL OTHR NP Break off single. Drop 2-1/8" steel ball to open Centurian circulating valve: Valve 13097. 05:30 06:15 0.75 17,233 17,233 PROD2 DRILL CIRC NP Wth 2-1/8" ball dropping : Circ @ 28 spm (2.8 bpm, 118 gpm) w/ 740 psi: PU wt 248k, SO wt 70k, Rot wt 142k. Rotating 120 rpm w/ 17k ft Ib torque. Working pipe f/ 17233' to 17200'. Ball on seat @after 1366 strokes pumped 137 bbls . 06:15 06:30 0.25 17,233 .17,233 PROD2 DRILL OTHR NP Pressure to 1400 psi, hold f/ a minute, increase to 1900 psi, hold f/ 30 seconds, increase to 2380 psi when valve. shifted open allowing pressure to drop. Bleed pressure to zero. Pump @ 28 spm w/ 350 psi indicating valve o en. P~~e ~~ of ,e8 • • Tirne Logs Da~e Frofa, _ _ To _ Dur S - D~nth - - E_Depth - - _ Phase_ _ - - Co~a - - _ - 5u~code_T - _ _ - - - - - - - - _ - - -- - COM _ - - _ - - - - - - h Centurian circulating h 50 4 233 17 'L33 P 17 ROD2 DRILL CIRC N P roug Circulate t 12/27/2006 0 6:30 1 1:00 . , , late and rotate 13097. Circu valve @ 120 rpm w/ 16k ft Ib torque, recip 90'. PU wt w/ rotating 150k, SO wt w/rotating 120k. Pump one BU @ 550 gpm w/ 1870 psi. Then go to 650 gpm w/ 2430 psi till almost another bottoms, then go to 700 gpm w/ 2680 psi until another BU+, then try 750 gpm f/ a little while (appears hole might be taking a little fluid), drop back to 700 gpm w/ 2640 psi. Pump a total of 6 BU from circ sub (39352 strokes=.3951 bbls). Hole appears very clean @ shakers. Total fluid loss-while circulating was 33 bbls. lose ll t b " 11:00 12:00 00 1 17,173 17,173 PROD2 DRILL CIRC NP o c a steel Drop 2-1 /8 . Centurian circulatiori valve. Pump @ 28 spm (2.8 bpm) w/ 310 psi. Ball on seat with 1590 strokes (159.6 bbls). Increase pressure to 1400 psi, hold f/ one minute. Increase pressure to 1900 psi, hold f/thirty seconds. Increase pressure to 2300 psi when valve shifted (pressure loss). Let pressure drop, then bleed off all pressure. Note: PJSM on displacing to solids free oil base mud held while ball was bein circulated down. 12:00 12:15 0.25 17,173 17,173 PROD2 DRILL CIRC NP Bring. pumps to 28-spm w/ 340 psi. Bring pumps up to 324 gpm w/ 830 psi. Valve appears to be in open osition. 12:15 13:00 0.75 17,173 17,173 PROD2 DRILL CIRC NP Call vendor. Discuss situation. Prior to dropping another ball to activate tool, tried to circulate. String pressured up. Went through sequence again to shift too-. Went to 1400 psi, then 1900 psi, shifted @ 2300 psi. let pressure drop. to 740 while then maintaining 28 spm w/ 800 si. Tool a ears to be shut. 13:00 13:30 0.50 17,173 17,233 PROD2 DRILL CIRC P Ream in hole. Rotate 120 rpm w/ 16-17k ft Ib torque: Pumping 77 spm (324 m) w/ 2950 si. 13:30 16:15 2.75 17,233 17,233 PROD2 DRILL CIRC P Displace 8.5 Oil Base mud from well with 8.7 ppg solids free Oil base mud.Reciprocate 30'. Pumping 320 gpm w/ 2740 psi. Rotate 120 rpm. w/ 16-18k ft Ib torque. ECD's 10.25 ppg. PU wt 240k, SO wt 70k unless rotating. Pumped total of 1166 bbls to dis lace well 16:15 16:30 0.25 17,233 17,233 PROD2 DRILL OWFF P Monitor well, static. 16:30 17:15 0.75 17,233 16,284 PROD2 DRILL TRIP P POOH on elevators. Pulling wet pipe. __ _ ~ ~.q~, ~'~ of ~6 ~ ~ Time Logs Date Frorn To _= nur S. De th _~ E_ IJept -- ha5~___ Code _ Subcode T__ COM_ - -- 12/27/2006 17:15 18:00 0:75 16,284 16,284 PROD2 DRILL CIRC P . Drop ball to actibvate Centurian circulating valve. With 2-1/8" ball dropping :Circ @ 29 spm (2.91 bpm, 122.3 gpm) w/ 530 psi. PU wt 240k, SO wt 70k unless rotating, Rot wt 135k. Rotating 120 rpm w/ 17k ft Ib torque. Working pipe f/ 16284' to 116224'. Ball on seat @ after 1305 strokes pumped (131 bbls). Increase pressure to 1500 psi and hold f/ a minute. Increase pressure to 2000 psi holding f/thirty seconds: Increased pressure and shifted valve @ 2350 psi. Pumped @ 28 spm w/ 160 psi--Valve o ened. 18:00 00:00 6.00 16,284 6,618 PROD2 DRILL TRIP P Continue POOH w/ BHA #11. .Recording PU and SO wt's every 5 stands in open hole, every 10 stands in casing. Monitor well on trip tank. Nole took 17 bbls over calculated ort tri to this de th. . RL P Drillin . EGD's 10.41-10.45 ppg. Jar hours 176.81 hrs. Max as 121 un' 3:15 03:45 0.50 17,233 17,233 PROD2 DRILL SRVY P Survey and verify TD of "D" la al @ 17233'. 03:45 '15 1.50 17,233 17,233 PROD2 DRILL CIRC P Pump 35 bbls 10.6 p 1.30 vis sweep. Follow w/ circ 5 gpm w/ 3400 psi. Rotate rpm w/ 17k torque. PU 250k, S 2K, Rot 148k, Recip f/ 172 to 17135'. 05:15 05:30 0.25 17,2 17,233 PROD2 DRILL OTHR NP reak off single. Drop 2-1/8".steel ball to open Centurian circulating valve. Valve 13097. 05:30 06:15 0.75 17,233 17,233 OD2 DRILL NP With 2-1/8" ball dropping :Circ @ 28 spm (2.8 bpm, 118 gpm) w/ 740 psi. PU wt 248k, SO wt 70k, Rot wt 142k. Rotating 120 rpm w/ 17k ft Ib torque. Working pipe f/ 17233' to 17200'. Ball on seat @after 1366 strokes pumped (137 bbls). 06:1.5 06:30 0.25 17,233 ,233 P D2 D OTHR N ressure to 1400 psi, hold f/ a minute, inc. se to 1900 psi, hold f/ 30 ~ secon 'ncrease to 2380 psi when ~' valve shifte en allowing pressure to drop, Bleed Ares re to zero. Pump @ 28 spm w/ 350 psi in ' ating valve o en. ~ ~'~~,, 443 s~f 5 Tune Logs te rom o - - Cur 5 - --- . Depth _E - - - _Depth- F __ ' ~~se - _ .- Code_ - - Subco~ ~ _ - T - - - - - - - - - - - - - - - - C _- - _ _ _ - turian circulating C _ 92 7/2UU6 _ 06:30 _ 11:00 4.50. 17,233 17,233 P RUD`L DRILL CIRC NP en Circulate through valve @ 13097. Circulate and rotate 120 rpm w/ 16k ft Ib torque, recip 90'. PU wt w/ rotating 150k, SO wt e ~ `' w/rotating 120k. Pump one BU @ 550 gpm w/ 1870 psi. Then go to 650 gpm ~ ' w/ 2430 psi till almost another a .~. bottoms, then go to 700 gpm w/ 2680 ~~L~ ~ psi until another BU+, then try 750 ,,~/t ` /" .-~,( d gpm f/ a little while (appears hole d l i ~ ~ ~ rop u d), might be taking: a little f back to 700 gpm w/ 2640 psi. mp a total of 6 BU from circ sub 352 strokes= 3951 bbls). Ho appears very clean @ shaker otal fluid. loss while circulatin s 33 bbls. 11:00 12:00 1.00 17, 73 17,173 PROD2 DRILL CIRC. NP Drop 2-1/8" st ball to close Pum @ alve ti ' p . on v cula Centurian 28'spm .8 bpm) w/ 310 psi. Ball on seat h 1590 strokes (159.6 bbls). Tirne Logs - - _ _ - { _ _ - - -- -- - - - - D_a_te __ From To Dur_ _ S_Daoth E Depth_ Phase__ Code Subco~ie T COM - - - _ -_ - - 7/2006 17:15 18:00 0.75 16,284 16,284 PROD2 DRILL GIRC P Drop ball to actibvate Centurian circulating valve. With 2-1/8" dropping : Circ @ 29 (2.91 bpm, 122.3 gpm) w! psi. PU wt 240k, f>~ SO wt 7 nless rotating, Rot wt ~~ 1 otating 120 rpm w/ 17k ft Ib torque. Working pipe f/ 16284' to 116224'. Ball on seat @ after 1305 "~. strokes pumped (131 bbls). Increase pressure to 1500 psi and hold f/ a minute. Increase pressure to 2000 psi holding f/thirty seconds. Increased pressure and shifted valve @ 2350 psi. Pumped @ 28 spm w/ 160 psi--Valve o d. 18:00 00:00 .00 16,284 6,618 PROD2 DRILL TRIP P Continue OH w/ BHA#11. Recording PU SO wt's every 5 stands in open hole, a 10 stands in casing. Monitor well on to k. Hole took 17 bbls over calculated o •• #ri to this de th, 12/28/2006 00:00 06:00 6.00 6,618 375 PROD2 DRILL TRIP P Continue POOH w/ BHA #11. Recording PU and SO wt's every 10 stands in casing. Monitor well on trip tank. Hole took 17 bbls over calculated on tri to this de th. 06:00 06:30 0.50 375 85 PROD2 DRILL TRIP P Monitor well @ BHA, POOH 4" HWDP and jars, rack in derrick. L/D Flex drill collars. 06:30 07:30 1.00 85 85 PROD2 DRILL OTHR P Download Sperry Sun MWD. 07:30 08:30 1.00 85 0 PROD2 DRILL PULD P Lay down BHA #11.Bieak bit. Hole took 34 bbls over calculated f/trip out of hole. 08:30 09:30 1.00 0 0 COMPZ DRILL OTHR P Clear and clean rig floor. Remove bits and subs. Rig down skate extension. Change elevators to 5". Monitor hole f/ losses: 09:30 09:45 0.25 0 0 COMPZ DRILL SFTY P PJSM on cutting the drilling line. 09:45 11:15 1.50 0 0 COMPZ RIGMN SVRG P Slip and cut 129' of 1-3/8"drilling line... 11:15 12:00 0.75 0 0 COMPZ CASIN( OTHR P Move one-row of 5" drill pipe w/super sliders to off driller's side pipe rack to avoid pinch point while PU liner from i e shed. 12:00 13:30 1.50 0 0 COMPZ CASIN( RURD P Rig up equipment to run 4-1/2" x 5-1/2"slotted/blank liner f/ "D" lateral. 13:30 14:00 0.50 0 0 COMPZ CASIN( SFTY P PJSM on running liner. 14:00 .14:30 0.50 0 0 COMPZ RIGMN SVRG P Service top drive and. lubricate rig. 14:30 15:30 1.00 0 0 COMPZ RIGMN OTHR P Derrick inspection: - - _____.~_ . _~--...__. _..__.~----:~~., _..._' --------------- __ ~_`~~g~ ~3 of a~ ~ ~ Time LocL _ _ - - - -- -- - CJepth E. L7epth Phi ~__ Code__ 5ubcode T ('QM __ S. ur From To D Date __ _ _ __ 12/28/2006 15:30 18:00 2:50 0 2,610. COMPZ CASING RNCS N MU/RIH w/ 3-1 /2" shoe, 3-1/2" 9.3 ppf eue shoejt, x-o, x-o, 4-1/2" 11.6 ppf BTC blanks and slotted liner. 60 jts of 4-1/2" in hole. Record PU and SO wt's eve 10 'ts. 18:00 19:30 1.50 2,610 4,274 COMPZ CASIN( RNCS P Crew change. Continue PU/MU 4-1/2" 11.6 ppf. BTC liner (jt # 97 in hole), x-o, 3 jts of 5-1/2" 15:5 ppf BTC. (3 jts of 5-1 /2" in the hole, 't# 100 in the hole 19:30 21:15 1.75 4,274 4,274 COMPZ CASINI OTHR P PU 5-1/2" hydroform centralizers to the floor. Lay down,4-1/2" handling tools.Change out GBR tongs. PJSM on removing Sperry Sun tools from pipe shed. Remove tools from pipe shed. Post safety meeting on removin tools from i e shed. 21:15 23:30 2.25 4,274. 6,851 COMPZ CASIN( RNCS P Continue PU/MU 5-1/2" 15.5 ppf BTG slotted/blank liner. Jt # 162 in the hole. 23:30 00:00 0.50 6,851 7,225 COMPZ CASIN( RNCS P Install 5-1 /2" 15,5 ppf BTC x 15.5 ppf Hydril 521 x-o. Continue PU/MU 5-1/2" slotted/blank liner. Jt # 171 in the hole. Note: Hole taking approx 2bph throw hout the da . 12/29/2006 00:00 00:45 0.75. 7,225 7,914 COMPZ CASIN( RNCS P Continue PU/MU 5-1/2" slotted/blank liner. Run Jt # 172 to jt # 188.. Recording PU and SO wt's every 10 jts. Note: Hole taking approx 2bph throw hout the da . 00:45 01:30 0.75 7,914 7,941 COMPZ CASIN( RUNL P MU Baker 7" "HR"liner running tool w/ crossovers f/ 5-1/2" hydril 521 liner top and 4-1/2" handling running tools on top (5" dp). Lay down GBR tongs. Clear and clean ri floor. 01:30 01:45 0.25 7,941 7,941 COMPZ CASIN( RUNL P MU a stand of drill pipe. While rotating _ 30 rpm: PU wt 120k, SO wt 115k, rotating wt 118k. Torque 4000 ft Ib. Pum in 31 s m with 150 si. 01:45 06:00 4.25. 7,941 12,740 COMPZ CASIN( RUNL P Run liner in the hole on 5" drill pipe. Inspecting super sliders w/super slider rep. Recording PU, SO, rotating wt's and rotating torque every 10 stands. Filling pipe every 10 stands. Note: 5" string to run liner will be 4 stands slick, 35 stands w/super sliders, 40 stands with LoTads, then 17 stands slick. -_ Time ogs - - _ - - - - - -_ - - -_-- - - Data 2 From - To 30 2 ~u~ 50 6 _ ~ D~ th 12 740 - E D~,th C 17 224 Phase- .UMPZ . Code_ - CABIN( Subc_c,de - _ RUNL T CO_M_ _ - - -- - -- - -- - - P Continue running liner in the hole on 5" 9/2006 12/ 06.00 . 1 : . drill pipe. Recording PU, 50, rotating wt's and rotating torque every 10 stands. Filling pipe every 10 stands. Started rotating liner/string @ 12740'. - Rotating w/ 30 rpm. Watching and recording torque.. Tag bottom of hole. @ 17233'. PU and put liner on depth, with shoe @ 17224 ;top of liner to be 9294.5T. 12:30 13:30 1.00 17,224 17,224 COMPZ CABIN( CIRC P Drop 3/4"ball: Circ ball to seat pum in 4 b m w1430 psi. 13:30 13:45 0.25 17,224 9,295 COMPZ CABIN( OTHR P Ball on seat after pumping 168.4 bbls. Pressure to 3000 psi: Continue to pressure to 4300 psi to release f/liner. PU wt 215k, SO wt 100k after releasin f/ runnin tool 13:45 14:15 0.50 9,295 9,060 COMPZ DRILL TRIP P Lay down single in the pipe shed. POOH to circ @ the slot of the whi stock 9060'. - 14:15 15:00 0.75 9,060 9,060 COMPZ DRILL CIRC P Circulate bottom's up while washing slot of whipstock. Circulate @ 430 m w/ 1130 si. Circulated 500 bbls. 15:00 15:15 0.25 .9,060 9,060 COMPZ DRILL OWFF P Monitor well. Static: 15:15 18:00 2.75 9,060 4,005. COMPZ DRILL TRIP P POOH w/ Baker running tools. Inspecting LoTads and super sliders. Note: Removed Sperry Sun GeoPilot skid from the ri floor while tri in . 18:00 20:30 2.50 4,005 25 COMPZ DRILL TRIP P Continue to POOH w/ Baker running tools f/ "D" lateral liner. Cleanin its. 20:30 21:00 0.50 25 0 COMPZ DRILL PULD P Lay down Baker 7" "HR" liner setting sleeve and inner strin .Cleanin its. 21:00 21:30 0.50 0 0 COMPZ DRILL OTHR P Rig up to lay down 4" drill pipe. Pull mouse hole, drain in pipe shed. Install mousehole in rotary table. Gather up 4" thread rotectors to the ri floor. 21:30 21:45 0.25 0 0 COMPZ DRILL SFTY P PJSM on laying down 4" drill. pipe from the derrick using mousehole in rotary table. 21:45 00:00 2.25 0 0 COMPZ DRILL PULD P Lay down Weatherford 4" dp f/derrick. 12/30/2006 00:00 02:15 2.25 0 0 COMPZ DRILL PULD P Lay down Weatherford 4" dp f/derrick. e f T " 02:15 03:45 1.50 0 0 COMPZ DRILL OTHR P er som rans . Change elevators to 5 5" dp to off driller's side of derrick. Remove mousehole from rotary table. Bring tools to rig floor for BHA #12. Weekly function tesYof choke and kill HCR, blinds, upper and lower pipe rams and annular. 03:45 04:00 0.25 0 0 COMPZ FISH SFTY P Pre job safety meeting on PU/MU BHA # 12 retrieve whi stock . 04:00 04:45 0.75 0 245 COMPZ FISH PULD P PU/MU BHA #12 (Whipstock retrieval assembl ). Cleanin pits. f'a~e 5t3 cif ~~ , __ ~ ~~~~ i ~._ _ - i • I Tirne Loys - - - -- Date From Tc Dur S DF^th E De~ah Pn use Code Subcod_e_ T COAd __ -. 12/30/2006 04:45 06:00 1.25 245 2,100 COMPZ FISH TRIP P Trip in hole w/ BHA #12 to retrieve whipstock. Fill ever 20 stands. Record PU and SO wt's eve 10 stands. 06:00 10:30 4.50 2,100 9,053 COMPZ FISH TRIP P Continue trip in hole w/ BHA #12 to retrieve whipstock. Fill ever 20 stands. Record PU and. SO wt's every 10 stands. 10:30. 10:45 0.25 9,053 9,053 COMPZ FISH CIRC P Fill pipe and circulate. 10:45 11:00 0.25 9,053 9,178 COMPZ FISH FISH P Finish RIH locate slot @.9091' w/ hook, PU to 50k over, 60k, 70k, 80k over when anchor released. Pull up hole 30'. Hole took 31 bbls of fluid when ulled free. 11:00 12:30 1.50 9,178 9,178 COMPZ FISH CIRC P Circulate bottom's up. Pumping 340 gpm w/ 1460 psi. Losing 1 bpm. Slowed rate to 5 bpm w/ 580 psi. Losing .5 bpm.. Max gas 14 units. Losf total of 54 bbls fluid while circulatin 12:30 12:45 0.25 9,.178 9,178 COMPZ FISH OTHR P Observe well for flow. Static. 12:45 13:00 0.25 9,178 9,178 COMPZ FISH OTHR P Install stripping rubber, air slips, blow down to drive. 13:00 18:00 5.00 9,178 501 COMPZ FISH TRIP P POOH carefully w/ Window master slide assembly (117.71') and fishing BHA#12. 18:00 20:15 2.25 501 0 COMPZ FISH TRIP P Crew change. Continue POOH carefully w/ Window master slide assembly (117.71') and fishing. BHA #12. Lay down all. Lost 31 bbls of fluid while POOH w/ whipstock. Slide looked reall ood. 20:15 20:45 0.50 0 0 COMPZ FISH PULD P UD Baker tools- Clear and clean rig floor. 20:45 22:00 1.25 0 0 COMPZ RPCOh RURD P PU and RU tools to run Baker PZ Hook Han er f/ Plo and dro s stem. 22:00 22:15 0.25 0 0 COMPZ RPCOh SFTY P Pre job safety meeting for running Hook han er assembl . 22:15 23:15 1.00 0 233 COMPZ RPCOh RCST P PU/MU Hook hanger assembly. 23:15 00:00 0.75 233 233 COMPZ RPCOh RCST P Rig up to run inner string, Making up inner string. Note: Total fluid losses f/ the day = 137.5 bbls. Static losses a rox 1-1/2 b h. 12/31/2006 00:00. 00:30 0.50 233 233 COMPZ RPCOh OTHR P Making up inner string. MU inner strin to hook han er. 00:30 01:15 0.75 233. 270. COMPZ RPCO6 OTHR P Making up inner string, including Sperry sun MWD super slim 3-1/8". Orient to hook. Lower hook hanger to floor. 01:15 02:00 0.75 270 270 COMPZ RPCOh RURD P Rig down GBR and Baker tools. Lay down same. Clear and clean floor. rare i1 ~sf ~ • Time Logs Da;e From To Dur S Depth_ E Depth Pnase -Code Subcode T COM - - -- - - 12/31/2006 02:00 02:30 0.50 270 3fi0 COMPZ RPCOh OTHR P RIH with Baker PZ Plop and drop hook hanger on a stand of 5"drill pipe. Shallow test Sperry Sun super slim tools. Pumping 120 gpm w/ 560 psi, 5% flow. PU wt 80k, SO wt 80k. Blow down to drive. 02:30 06:00 3.50 360 6,550 COMPZ RPCOf~ TRIP P RIH w/ PZ hook hanger assembly on 5"drill pipe. Record PU and SO wt's eve 10 stands. 06:00 08:00 2.00 6,550 9,303 COMPZ RPCOh TRIP P Continue RIH w/ PZ hook hanger assembly on 5" drill pipe. Record PU and S0 wt's eve 10 stands. 08:00 08:45 0.75 9,303 9,317 COMPZ RPCOb TRIP P Tagged up @ 9303' in main/mother wellbore--??. POOH to 9077 (above window: TOW @ 9084', BOW @ 9100'). MU top drive. Orient Hook w/ MWD while circulating 118 gpm w/ 700 psi. RIH to 931 T, going out window 9084' -9100') into o en hole: 08:45 10:30 1.75 9,317 9,347 COMPZ RPCOh TRIP P POOH to i-e-orient to hookbottom of window @ 9104' MD (approx 4' deep). PU wt 205k, SO wt 105k, blocks 70k. 10:30 11:15 0.75 9,347 9,347 COMPZ RPCOh OTHR P Hooked bottom of window with hook @ 9104' w/ tail (mule shoe of bent jt) @ 9347. MWD indicating 12 right after hooked w/ 30k slack off. PU 25', turn 180 deg, work string 8' past window, Pick hook back up above window. Re orient and set hook on window 9104' w/ end of bent joint @ 9347' inside of Plop and drop "D" lateral liner. MWD indicated 10 right w/ 30k on hook han er. 11:15 12:15 1.00 9,347 9,347 COMPZ RPCOh PACK P Drop 1-3/4" ball, cir`c ball down 1200 strokes @ 124 gpm w/ 760 psi, then slow to 84 gpm w/ 800 psi, ball on seat @ 1310 strokes. Pressure to 2000 psi, held f/ a minute, pressure to 2800 psi to open and inflate ECP (Hook hanger assembly. was pinned to release with 2065 psi) pressures bleed down to 1250 psi. Took 9 strokes to pressure back up to 2800 psi. Inflated ECP w/ .904 bbls (38 gals) 8.7 ppg solids free oil base mud. 12:15 -18:00 5.75 9,347 1,600 COMPZ RPCOh TRIP P POOH w/ Baker hook hanger running tools and inner string w/ Sperry Sun su er slim MWD, 18:00 19:30 1.50 1,600 185 COMPZ RPCOh TRIP P Continue POOH w/ Baker hook hanger. running tools and inner. string w/ S er Sun su er slim MWD. 19:30. 20:45 1.25 185 0 - COMPZ RPCOh PULD P Lay down Baker running tools and 2-3/8" inner string and Sperry Sun su er slim 3-1/8" MWD. 20:45 21:45 1.00 0 0 COMPZ RPCOh OTHR P Clear and clean floor. RD tools f/ hook hanger. RU to runBaker LEM f/ Plop and dro . Pac~a 52 oaf 5fs ~. -- -- • ~ Time Logs I Date... From To Dur S Depth E_ De_~h .Phase _ Cade SubcoeiP _T_ _ COM _ _ 12/31/2006 21:45 22:00 0.25 0 0 COMPZ RPCOA SFTY P PJSM on PU/MU Baker 4-1/2" LEM assembl . 22:00 23:00 1.00 0 195 COMPZ RPCOh RCST P PU/MU 4-1 /2" Baker LEM assembly. for to and dro . 23:00 23:15 0.25 195 195 COMPZ RPCOh OTHR P Change elevators to 5". 23:15 23:45 0.50. 1.95 195 COMPZ RPCOh PULD P PU 9-5/8'' x 7" Baker ZXP w/running tool.. MU inner string w/ Sperry Sun 3-1 /2"super slim MWD oriented to the bottom point of LEM (o enin of LEM). 23:45 00:00 0.25 195 227 COMPZ RPCOh RCST P MU 9-5/8" x 7" ZXP w/ running tool and inner string.. Note: Total fluid lost to hole toda = 36 bbls 01/01/2007 00:00 01:15 1.25 227 227 COMPZ RPCOh RURD P Rig down equjpment to run LEM f/the "D"lateral 1J-136L1 . Clear ri floor. 01:15 01:30 0.25 227 320 COMPZ RPCOh TRIP P RIH w/ LEM assembly on one stand of 5".drill pipe. Shallow test Sperry Sun MWD tool. Pump 120 gpm wl500 psi. O K. 01:30 06:00 4.50 320 6,309 COMPZ RPCOh TRIP P Trip in hole w/ LEM on 5"drill pipe. Record PU and SO wt's every 10 stands. Run 90 ft/min max. Fill pipe eve 20 stands. 06:00 09:00 3.00 6,309 9,226 COMPZ RPCOh TRIP P Continue RIH w/ LEM after crew change. Ran LEM on 4 stands of 5" dp slick, 35 stands w/super sliders, 40 stands w/ LoTads, then 14 slick 5"d 09:00 09:30 0.50 9,226. 9,226 COMPZ RPCOh CIRC P PU a single from the pipe shed. Circulate and orient Lem. PU wt 205k, SO wt 105k. 09:30 10:30 1.00 9,226 9,240 COMPZ RPCOh PACK P RIH to 9240'. Latch LEM. Sperry Sun MWD indicating 4 deg left w/ 30k down. Pull to 240k snapped out. Set back down 30k to latch. Drop ball Circulate ball to seat w/ 3 bpm. Bali on seat @ 1140 strokes. Presssure to 2800 psi, Set ZXP packer, continue to pressure to 4000 psi to release running tool f/ LEM assembly. Top of ZXP 9018.78'. 10:30 10:45 0.25 9,240 9,063 COMPZ RPCOh DHEO P Rig up and test 7" x 9-5/8" "SLZXP" Liner top packer to 1000 psi f/ 5 min. Chart test OK. 10:45 11:30 0,75 9,063 7,893 COMPZ RPCOh TRIP P Pull out of hole with LEM running tools and 5" d 11:30 12:00 0.50 7,893 7,893 COMPZ RPCOh OTHR P Blow down top drive and kill line. Install stripper rubbers after monitoring well. Static. 12:00 15:30 3.50 7,893 225 COMPZ RPCOh TRIP P Crew change. Continue POOH w/ LEM runnin tools. 15:30 16:30 1.00 225 0 COMPZ RPCOh PULD P Lay down LEM running tools, inner string w/ Sperry. Sun 3-1/8" super slim MWD. 16:30 17:00 0.50 0 0 COMPZ RPCOh OTHR P Pull Vetco Gray 42-3l8" ID wear buskin . rage a3 of ~o • Tirne Los ' --- _ _---- _- --_ - _-~- - - _ - -J Y C`~ae_ _ From_ To Dur S- De th E Depth PhaSP Code Siibcode T COM_ __ __ ____ __ 01/01/2007 17:00 17:30 0.50 0 0 COMPZ RPCO4 PULD P Rig down tools f/ LEM, Clear and clean ri floor. 17:30 18:45 1.25 0 0 COMPZ RPCOh RURD P RU to run 4-112".completion. 18:45 19:15 0.50 0 0 COMPZ RPCOh SFTY P PJSM on running 4-1/2" completion. 19:15 20:15 1.00 0 0 COMPZ RPCOh OTHR T Change out 4-1l2" tubing tongs. An "O" ring on the shaft of the throttle control was cut/damaged. Rig up backu ton s. 20:15 00:00 3.75 0 4,023 COMPZ RPCOh RCST P Run 4-1/2" 12.6 ppf.L-80 IBT-mod completion per running. order. Jt # 130 in hole midni ht. 01/02/2007 00:00 06:00 6.00 4,023 9,060 COMPZ RPCOh RCST P Run 4-1/2" 12.6 ppf L-80 IBT-mod completion per running order. Run from 4023' - 9060' MD. Ran 291 joints, tagged up 15' in on joint # 292. Crew Chan e 06:00 07:30 1.50 9,060 9,060. COMPZ RPCOh RCST P POOH lay down 5 jnts 4 1/2" tubing. Pick up 3 joints for space out as per BOT re & Co. Man. 07:30 08:00 0.50 9,060 9,060 COMPZ RPCOh RCST P Make up tubing hanger. Install BPV. Make u landin 'oint. O8:00 09:30 1.50 9,060 9,060 COMPZ RPCOh HOSO NP Attempt to land tubing hanger. Observed landing high. Pull to floor & inspect same. Attempt to land. No go. Pull up 4'. Heat well head with steam. Land tubing hanger in correct position as per Vetco Gray rep. RILDS. SIMOPS: Cleaning pits, change out piston rubbers, liners & seats in mud um s. and valves on #2. 09:30 10:00 0.50 9,060 0 COMPZ RPCOh RCST P Back out & pull landing joint. Rig down all tubin runnin a ui merit. 10:00 10:15 0.25 0 0 COMPZ RPCOM1 OTHR P Rig up and test upper & lower hanger seals to 5000 PSI. Hold for 10 minutes each. 10:15 10:45 0.50 0 0 COMPZ RPCOA OTHR P Pull Mouse hole. Install in rotary table for la in down DP from derrick. 10:45 12:00 1.25 0 0 COMPZ RPCOh OTHR P Held PJSM with crew. Discuss safety issues and procedure for laying down DP from derrick. Discuss removal procedures for LoTads & Super Sliders. Begin lay down DP from derrick. 12:00 18:00 6.00 0 0 COMPZ RPCOh OTHR P Continue break out & lay down drill pipe from derrick, removing Lotads & super sliders. Note: Sliders froze to DP. needed to use steam to thaw out sliders for removal. WWf Reps on rig floor. Crew Chan e • • Time Logs __ - ~~~ D eta From To Dur S De nth E_ De_ pth Ph~~s~ Coda Subcode T COP~1 1 - - - - - __ 01/02/2007 18:00 00:00 6.00 0 0 COMI'Z RPCU4 (~THR P Continue break out & lay down drill pipe from derrick, removing Lotads & super sliders. Note: Sliders froze to DP. needed to use steam to thaw out sliders for removal: WWT Reps on rig floor. SIMOPS: Continue clean pits and prepare for rig move. purge all. lines from SFMOBM. 01/03/2007 00:00 06:00 6.00 0 0 COMPZ RPCOh OTHR P Continue break out & lay down drill pipe from derrick, .removing Lotads & super sliders: Note: Sliders froze to DP. needed to use steam to thaw out sliders for removal. WWT Reps on rig floor. Crew Chan e 06:00 11:30 5.50 0 0 COMPZ RPCOh OTHR R Continue break out & lay down drill pipe from derrick: SIMOPS: Remove suction line from Mud pup #1 -repair same. Install new guides for suction screen on #1 pump, suction pod. re are rockwasher for ri move: 11:30 12:00 0.50 0 -0 COMPZ RPCOt~ RURD P Remove mousehole from rotary tale & lay down same. Clean & clear floor area of all thread protectors, lift subs, su er sliders and clam s. 12:00 12:15 0.25 0 0 COMPZ WELCT SFTY P Held PJSM with crew. Discuss safety issues and procedure for nipple up and down BOP stack & tree. 12:15 14:00 1.75 0 0 COMPZ WELCT NUND P Nipple down BOP stack & lines. Remove all drill pipe from pipe shed. Blow down & Ri down all mud lines. 14:00 16:00. 2.00 0 0 COMPZ WELCT NUND P Nipple up Tree as per Vetco Gray re s. 16:00 17:00 1.00 0 0 COMPZ RPCOh FRZP P . PJSM with rig crew & Little Red Services. Discuss safety issues, rigging up and pumping freeze protect diesel. Rig up all flanges and lines. test lines to 1000 PSI. Spot & rig up vac trucks and lines. Designate a Spill cham ion. 17:00 18:00 1.00 0 0 COMPZ RPCOh FRZP P Pump down annulus taking returns through tubing and through the choke mainfiold with little Red. Pumping @ 4 BPM -average 500 PSI. monitoring fluid loss. No loss at 4 BPM. Crew Chan e 18:00 20:45 2.75 0 0 COMPZ RPCOh FRZP P Continue pump down annulus taking returns through tubing and through the choke mainfiold with little Red. Pumping @ 4 BPM -average 500 PSI. Observe pumping a total of 675 BBLS of diesel to get good diesel returns. Total of 660 BBLS returned. Loss = 15 BBLS. 20:45 21:00 0.25 0 0 COMPZ RPCOh FRZP P Shutdown Little Red. Shut in well FCP = 300 PSL • Time Logs -- - _- - _- _ - - - -- --- _ _ __ _ _ I I Date From To Dur S Depth E Depth Phase Code Sa~U~code T COfvt __ _ ___ 01/03/2007 21:00 21:30 0.50 0 0 COMPZ RPCOh FRZP P Blow down Choke line. Suck out lines to Little Red. Rig down Little Red & Vactrucks. 21:30 22:00 0.50 0 0 COMPZ RPCOh OTHR P Rig Up Vetco Gray lubricator with BPV. Install Lubricator & set BPV as per Vetco Gray reps. RD Lubricator. Shut in and secure well. Install blanking flanges. Shut in pressures = Tubing = 150 PSI. IA = 200 PSI. OA = 150 PSI. 22:00. 00:00 2.00 0 0 COMPZ MOVE DMOB P Continue clean pits and rig down cellar lines. Clean drip pan. Clean out cellar box. Wipe down tree. Rig Released @ 2400 HRS. ', ~ i~rac~~ ~~ ~rf ~~' 02-Feb-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-136L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 12,989.38' MD Window /Kickoff Survey 12,990.00' MD (if applicable) Projected Survey: 17,233.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~,7 I-~+r~.~Ap 7 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) 02-Feb-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-136L1 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,072.21 ' MD Window /Kickoff Survey 9,084.00' MD (if applicable) Projected Survey: 14,426.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date o2 ~'"[o~ ~07 Signed, Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) • 02-Feb-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-136L1 PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 13,273.60' MD Window /Kickoff Survey 13,275.00' MD (if applicable) Projected Survey: 13,397.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date~~an. ~.0~A7 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) p~,CZ(p" ~5~~! 1J-136 PB and 1J-136 L1 (PTD #'s 206-154, and 206-155 respectively) Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, January 23, 2007 3:31 PM To: Thomas E Maunder Cc: NSK Prod Engr Tech; NSK West Sak Prod Engr Subject: 1J-136 PB and 1J-136 L1 (PTD #'s 206-154, and 206-155 respectively) Tom, CPAI would like to give notice of intent to producing 1 J-136 PB and 1 J-136 L1 (PTD #'s 206-154, and 206-155 respectively). The well will be produced by gas lift down the IA and through the sliding sleeve for a period of approximately 30 days. The well was designed and drilled to be a pre produced injector. After the production clean up phase, the appropriate paperwork will be submitted to change its service status to injector. Let me know if you have any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com 7/3/2007 1J-136 D Lateral Hole Size Change? Subject: Re: 1J-136 D Lateral Hole Size Change? From: Thomas Maunder <tom_maunder a,admin.state.ak.us> Date: Thu, 21 Dec 2006 11:01:06 -0900 To: "Reilly, I?atrick .1" --Patrick..1.Reill~~~%~i?conocohhillips.com== Pat, Your email is sufficient, since you are not proposing to change the BHL. Hope you have better luck. Call or message with any questions. Tom Maunder, PE AOGCC Reilly, Patrick J wrote, On 12/21/2006 10:56 AM: Tom, • i ,~ - ~~ ~ ~°.~, ~~A `~ ~~ We are continuing to have directional control problems with our rotary steering tools for our 8.5" hole section. We have drilled to 13,333' MD. We would like to pick up a 6 3/" motor and agitator assembly to finish drilling this lateral. We would then complete the lateral with a 5.5" x 4.5" liner. Is that plan acceptable to you? If so, what documentation do you require for that change? Thanks. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX I'atrick.J.Reilly cx conocophillips.com «Patrick.J. Reilly{~conocophilli ps.com.vcf» 1 of 1 12/26/2006 9:11 AM 1J-136 D Lateral Tool Failure Sidetracks #1 & #2 Subject: l,(-136 D Lateral Tool Failure Sidetracks #1 & #2 From: "Reilly, Patrick J" <Patrick.J.Reilly~,conocophillips.com> Date: Wed, 20 Dec 2006 18:13:50 -0900 ~ ~ (.~ •~ (S ~ 'I'o: Thonuis [~9aundcr -tom mauilctcr(~t~;admin.state.ak.us=~ Tom, We had two tool failure related sidetracks in the last 2 days. The details of the sidetracks are as follows: 1J-136 L1 P61 • Well: 1 J-136 • Rig: Doyon 15 • Date: 12/18/06 • Time: 1930 hrs • Last Casing Window: 9,100 • MD of abandoned section: 13,275' - 14,426' 1J-136 L1 PB2 • Well: 1 J-136 • Rig: Doyon 15 • Date: 12/20/06 • Time: 0200 hrs • Last Casing Window: 9,100 • MD of abandoned section: 12,290' - 13,398' We are abandoning two crooked hole sections that were caused by malfunctioning rotary steerable tools. We made two low side sidetracks. We are planning to isolate both sidetracks by allowing them to collapse. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J. Reilly@conocophillips.com «Patrick.J. Rei I ly@conocophillips.com.vcf» 1 of 1 12/26/2006 9:53 AM Saahjecf: 2J-1 ~~ ~p~~d Tiaing Update (Probably ~'uesday or -4Vet3nesday~ 1"r®ra~ "Keilly, Patrick 34' <Patrick.J.Reilly@conocophiliips.com> lflate: Thu, 09 Nov 2006 08:56:16 -0900. To: Tlozn~.` M~~uider ~~tom_maunde~ cr a~inli~.state:ak.us? t/C: "Allsup-Drake. Sharon K" <Sharon.K.Allsup-Drake@~onocaphillips.conl> Tom, if all goes well 0 1J-182, should be moving 1J-136 on esday or Wednesday. Pat Reilly ConocoPhillips Ala r<a Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.Reilly@conocophillips.com «Patrick.J.Reilly@conocophillips. com.vcf» 1 ~~'~~ ~ ` ~5~~ ~~ Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99~ 10 Re: Kuparuk River Field, West Sak Oil Pool, 1J-136L1 FRANK H. MURKOWSKl, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ConocoPhillips (Alaska), Inc. Permit No: 206-155 Surface Location: 1565' FSL, 2282' FEL, Sec. 35, TL1N, R10E, UM Bottomhole Location: 2077' FSL, 439' FEL, Sec. 14, T10N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service 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. The permit is for a new wellbore segment of existing well KRU IJ-136, Permit No 206-154, API 50-029- 23331-00. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission speciftcally authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of t~e Commission to witness any required test, contact the Commission's petroleum field inspector at (90~~ °'f'-3607 (pager). DATED this day of November, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w!o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 I~`t,l® 2~~~ 1 a. Type of Work: Drill Q ~ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^ Stratigraphic Test ^ Service Q Development Gas ^ Multiple Zone^ Single Zone ^ 1 a Spe i ' Coalbed Methane ^;~nl~~106~~drates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: 1J-136L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 17101' TVD: 3373' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1565' FSL, 2282' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25662 & 380058 West Sak Oil Pool Top of Productive Horizon: 483' FNL, 411' FEL, Sec. 11, T10N, R10E, UM 8. Land Use Permit: ALK 2177 & 4604 13. Approximate Spud Date: 11/20/2006 Total Depth: 2077' FSL, 439' FEL, Sec. 14, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to ~ Nearest Properly: > s ~ 9 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558931 y- 5945378 ' Zone- 4 10. KB Elevation (Height above GL): 40' RKB feet 15. Distance to Nearest , /b/ ~ Well within Pool: 1J-102L2 ,~5' ft, 16. Deviated wells: Kickoff depth: 9100 ft. Maximum Hole Angte: 94° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1586 psig Surface: 1198 psig 18. Casing Program if ti S Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" 62.5# H-40 Welded 80' 40' 40' 120' 120' 260 cf ArcticCRETE 16" 13.375" 68# L-80 BTC 3549' 40' 40' 3589' 2197' 680 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 9506' 40' 40' 9546' 3573' 630 sx DeepCRETE 8.5" 5.5" 15.5# L-80 BTCM 8001' 9100' • 3505' • 17101' • 3373' 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 ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): t ` r n~ IUl "~/ Perforation Depth TVD (ft): 20. Attachments: Filing Fee - BOP Sketch^ Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis ~ Properly Plat ~ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowled9e• Contact P8t Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature r Phone Z C- ~ Lz~ 3~i Date t t l ~ ~~ ~, P a n k Commission Use Only Permit to Drill /~ Number: ;L,UCi~ ~ ~S~ API Number: ,', 22 50- aZg~ l~~~^ (od Permit Approv Date: 9 See ver letter for other requirements Conditions of approval : If box is checked, well ma not be used to explore for, test, or produce coalbed m t ane, g rates, or gas contained in shales: 3wQegi ~~~ ~-~5~ e~c, n~p~~t\~~ i Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No [r]' Other: ` C HAS measures: Yes ^ No Dire Tonal svy req'd: Yes [~ No ^ ~EE a~~o-i~ ~ ~~r-®~~cr ~~~•~ APPROVED BY THE COMMISSION DATE: ~/ ~ / ~O ,COMMISSIONER Form 10-401 Revised 12/200-; -- ~,`~ I`~~ A L Suet in Dup~l'icat P I~~ • ~ ~~~~~ r e oG t d ~ ` ~' R°'crn rskut$ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 t-y ~,.. & ry~t~_ v l~ T ~ .~.~;~ ~~~as~~~ ~ ~ ,. 1a. Type of Work: Drill 0 Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory Development Oil ^ Stratigraphic Test ^ Service Q Development Gas ^ Multiple Zone ^ Single Zone ^ 1c. Specify if well is proposed or Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-136L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 17101' ND: 3373' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1565' FSL, 2282' FEL, Sec. 35, T11N, R10E, UM 7. Property Designation: ADL 25662 & 380058 West Sak Oil Pool Top of Productive Horizon: 483' FNL, 411' FEL, Sec. 11, T10N, R10E, UM 8. Land Use Permit: ALK 2177 & 4604 13. Approximate Spud Date: 11/20/2006 Total Depth: 2077' FSL, 439' FEL, Sec. 14, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: > 2 miles 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558931 y- 5945378 Zone- 4 10. KB Elevation (Height above Gl): 40' RKB f :Distance to Nearest Well within Pool: 1J-102L2 , 12095' 16. Deviated wells: Kickoff depth: 9100 ft. Maximum Hole Angle: 94° deg 17. Maximum Anticipated Pressu in psig (see 20 AAC 25.oa5) Downhole: 1586 psi Surface: 1198 psig 18. Casing Program ecific ti S Setting pth Quantity of Cement Size ons p a Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD MD ND (including stage data) 40" 20" 62.5# H-40 Welded 80' 40' 40' 120' 120' 260 cf ArcticCRETE 16" 13.375" 68# L-80 BTC 3549' 40' 40' 3589' 2197' 680 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 9506' 40' 9546' 3573' 630 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTCM 8001' 9100' 3505' 17101' 3373' slotted liner 19 PRESENT WELL CONDITION SUMMA (To be com pleted for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (me red) Effective Depth MD (ft): Effective Depth ND (tt): Junk (measured) Casing Length Si Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): ~(~ ` Perforation Depth ND (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: Commis on Representative: Date: 22. I hereby certify that the regoing 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 ~~6~ 3 ~ Date tO ~Z.~o G P h n k Commission Use Only Permit to Drill Number: API Number: 50- Permit Approval Date: See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained in shales: ^ Samples req'd: Yes ^ No ^ Mud log req'd: Yes ^ No ^ Other: H2S measures: Yes ^ No ^ Directional svy req'd: Yes ^ No ^ APPROVED BY THE COMMISSION DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 ° ~ Submit in Duplicate App~n for Permit to Drill, Well 1J-136 L1 Revision No.O Saved: 27-Oct-06 Permit It -West Sak Well #1J-136L1 ""~ Application for Permit to Drill Documen r.~ +~k t ~~~~ Mldxirriixg VJ~I I Valu e Table of Contents 1. Well Name .................................................................................................................. 2 Re uirements o 20 AAC 2S.OOS ................................................................ 2 2. Location Summary ..................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2)-.........--~--~-~-~---~ ...............:........................................................:........ 2 Requirements of 20 AAC 25.050(b) ...............................................................................................:........:..:. 2 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 25.OOS(c)(3) ......................................................................................................... 3 4. Drilling Hazards Information ..................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ........................................................................................................ 3 5. Procedure for Conducting Formation Integrity Tests .................................................. 3 Requirements of 20 AAC 25.005 (c)(S) ........................................................................:............................... 3 6. Casing and Cementing Program ................................................................................. 3 Requirements of 20 AAC 2S.OOS(c)(6) ......................................................................................................... 3 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 Lateral Mud Program (MI VersaPro Mineral Oil Base) ...............................................:............................... 4 9. Abnormally Pressured Formation Information ........................................................... 4 Requirements of 20 AAC 25.005 (c)(9) ........................................................................................................ 4 10 . Seismic Analysis ......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ...................................................................................................... 5 11. Seabed Condition Analysis .......................................................................................... 5 Re uirements o 20 AAC 25.005 c 11 ..: ............................... 9 f ()( ) .................................................................... 5 12. Evidence of Bonding ................................................................................................... 5 1J-136 L1 PERMIT IT Page 1 of 6 Printed: 27-Oct-O6 OR161NAL i Appl~ for Permit to Drill, Well 1J-136 L1 Revision No.0 Saved: 27-Oct-06 Requirements of 20 AAC 25.005 (c)(12) ...................................................................................................... 5 13. Proposed Drilling Program ......................................................................................... 5 Requirements of 20 AAC 25,005 (c)(13) ...................................................................•--•-•-•--......................... 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 6 Requirements of 20 AAC 25.005 (c)(14) ............................•----..................................................................... 6 15. Attachments ............................................................................................................... 6 Attachment 2 Directional Plan (6 pages) .................................................................................................... 6 Attachment 3 Drilling Hazards Summary (1 page) ...................................................................................... 6 Attachment 4 Well Schematic (1 page) .......................................................•----•--........................................ 6 1. Well Name Requirements of 20 AAC 25.005 (~ Eac1a well roust be identifed by a unique name designated Gy the operator and a unique API number assigned by the cammssdon'atnder 20 AAC 25.040{`b). Fbr a ~well'with multiple well branches, each brezru•h mzrst similarly be identified by a unique name and API rturnber vy adding a suffrx to tlae Warne designated fcrr the well fiv the operator and to the number assigned to the well by the eontmissian. The well for which this Application is submitted will be designated as 1J-136 L1. 2. Location Summary Requirements of 20 AAC 2S.OOS(c)(2) ,4n application for a Permit io Dri1X must be accampanied by each of the fallowing items, except for an item already on file witJz the cornrrtission and identified in the applu•atiora: (2) u plat ident~ing ilae pro)rerty arzd the property's owners and showing (A)the caordinates of the proposed location of tlae well czt the surface. at the tap of each objective f n•mation, and at total depth, referenced to governrnental section lines, {g} the caordinates of the proposed location of the well at the strrfizce, referenced to the state plane coordinate syatern for this state as muirttuiraed by the Natioral Geodetic Survey in th.n National CJceanic and Atmospheric Administration; {C,) the proposed depth of the well at the tap r2f each objective formation and at total depth; Location at Surface 1,565' FSL, 2282' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 121' AMSL Northings: 5,945,378 Eastings: 558,931 Pad Elevation 81' AMSL Location at Top of Productive Interval (West Sak "D" Sand 483' FNL,, 411' FEL, Section 11, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 9,097 Northings: 5,938,066 Eastings: 560,866 Total Vertical Depth, RKB: 3,505 Total Vertical Depth, SS.• 3,384 Location at Total De th 2,077' FSL, 439' FEL, Section 14, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB.' 17,101 Northings: 5,930,068 Eastings: 560,909 Total Vertical De th, RKB: 3,373 Total Vertical Depth, SS: .3,251 and (DJ other information required l?y 2tl AAC 25.050(1r); Requirements of 20 AAC 2S.OS0(b) If a well is to be intentiortatly deviatetJ, the appluatian for a Permit to Drill (Form 1O-COI) rrutst (1) inchtde a plat, drawn to a suitable scale, showirrg the path of the proposed wellbare, iraclrrdirag all adjcicrent wellbores within 200 feet of ezny portion of the proposed well; 1J-136 L1 PERMIT /T Page 2 of 6 Printed: 27-Oct-O6 ORIGINAL • Please see Attachment 1: Directional Plan Appl~ for Permit to Drill, Well 1J-136 L1 Revision No.O Saved: 27-Oct-06 arul (2), fnr all wells rovithin 2011 feet of the proposed avellbore (.A) list the names of the operators ~f'those weds, to the extent that those names are known or discoverable in public records, and show that each named operator has lreen,furrtished acopy of the application l~v certified mar.'l; or (&) state that tlae applicant is Che only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Informafion Requirements of 20 AAC 25.005(c)(3) An applieaCicrn for as Ferrrtit Co Drill must lreaccornpanied by each of the following items, except firr an item already on file with the contrnission rznd ident~ed in the application: (3) a diagrzznt and description of the hlo~vout pr eventicm equipment (HOPE) as required by 20 AAC 23.035, 20,9,40 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-136 L1. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) Ara alrplicatiorz, for a Permit to Drill must be accompanied by each of the following items, except for an item already on Pale with the commission anal identified in the applicatian: (~l) inforntatiorx on drilling hazards, including (A) tlxe maximum downhole pressure shut Wray be encountered, critcxia used to determine it,, and rncaxirnum potential surface pressure based on a methane gradient; The expected reservoir pressure in the West Sak sands in the 1J-136 L1 is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) is 1,198 psi. Based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak D sand formation is 3,524'. The MPSP is: MPSP = (3,524 ft)(0.45 - 0.11 psi/ft) =1,198 psi - (B) data ora poiential gas zones; The well bore is not expected to penetrate any gas zones. And (C) data concerning potential causes ofhole problems such as abnormzzlly geo-pressured strata, last circulation zones, and zones that hcrve a propensity.for differential stickzng; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formafion Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application for a Ferrrtit to Drill must be accompanied by each of the following items, except for art item already on file with the cnmrnission and identfied in the application: (3) a description of the procedure for conducting formation integrtty tests, as required under 20 AAC 25.030(n; No formation integrity test will be performed in the drilling of 1J-136 L1 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application fir a Permit to Drill must be accompanied by each of the fcrllnwing iterras, except fir an item already on file y~ith 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 of`any slotted liner; pre-perforated liner; or screen to be irzstallea;• 1J-136 L1 PERMIT IT Page 3 of 6 Panted: 27-Oct-O6 ORIGINAL • Casing and Cementing Program See also Attachment 3: Cement Summar 7. er ystem Information Requirements of 20 AAC 25.005(c)(7) An upplication frrr a Permit to IJrill must he accompanied by eacFt r f the fallowing iterrts, excc~lt frrr an item already on file with tF2e commissior ar~d iclentitied in the appb~cation: (?) ct diagram ancd descr~iptian of the diverter system as required by 20 AAC 2S.U3.5, artless this rer~uirement is waived by the commission ur2der• zo AAC 2s. t~3s(h)(z), No diverter system will be used during operations on 1J-136 L1 8. Drilling Fluid Program Requirements of 20 AAC 25.OOS(c)(8) An al~rplicatian, for u Permit to Drill must be accompanied by eacta of the fallowing items, ea'cept for an item alreual}~ or~t file rovith the cammissiart and identified in the application: ($) a drilling fluid Jrrogram, int;luding a diagram and description of the drilling_fluid system, as reyuir'c;d by 20 RAC 25.tI3~; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro Mineral Oil Base) Value Densi (pp) 9.0 Plastic Viscostiy 15-25 (lb/100 s Yield Point 18-28 (cP) HTHP Fluid loss (ml/30 min @ <4.0 200psi & 1 SO° Oil /Water Ratio 80:20 Electrical >600 Stability 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 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) Art application frrr a Permit to Drill must be accompanied by eacFt of the following items. ea-uept for an item already ort fle with the commissiara and ideniified in the upplication: App for Permit to Drill, Welf 1J-136 L1 Revision No.O Saved: 27-Oct-06 Hole Top Btm Csg/Tbg Size Weight Length MD/TYD MD/T[~D OD in (in) b/ t) Grade Connection t) t (ft Cement Pro ram 20" 40" 62.5 H-40 Welded 80 40' / 40' 120' / 120' Cemented to surface with 26o cf ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 3,549 40' / 40' 3,589' / 2,197' 68o sx ArcticSet Lite Lead, 220 sx Dee CRETE Tail Cement Top planned @ 6,045' 9-5/8" 12-1/4" 40 L-80 BTCM 9,506 40' / 40' 9,546' / 3,573' MD. Cemented w/ 630 sx Dee CRETE 4-1 6-3/4" B Sand Lateral 11. L-80 B CM 9 73' 17 40 ' / 3 436' Slotted- no cement slotted , , 4-1/2 6-3/4" DSandLateral 11.6 L-80 BTCM 8 001 9 100' / 3 505' 17 101' / 3 373' Slotted-no cement Slotted (IJ-136 Ll) , , , , , 7J-136 L1 PERMIT IT Page 4 of 6 n ~ Printed: 27-Oct-06 • Appl~ for Permit to Drill, Well 1J-136 L1 Revision No.1 Saved: 6-Nov-06 1. Proposed Drilling Program Revised -From Hybrid [13 3/8" x 9 5/8" x 4.5"] to Big Bore [13 3/8" x 9 5/8" x 5.5"] Casing Design RequiYements of 20 AAC 25.005 (c)(13) ,fin applrcation for a Permit to Drill nusst he accompar7ied frv each of tTte fbdlowirt,~, rtera~ts, ea~eept for- a~ item already ora file rovith the commr'ssior~a arcl identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-136 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 9,100' MD / 3,505' TVD, near the top of the "D" sand. 2. Mill 8-1/2" window. POOH. 3. Pick up 8-1!2" drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of "D" sand lateral at 17,101' MD / 3,373' TVD, as per directional plan. ~. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 5-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 10. 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. 11. POOH, laying down drill pipe as required. 12. PU completion as required and RIH to depth. Land tubing. Set BPV. 13. Nipple down BOPE, nipple up tree and test. Pull BPV. t4. Freeze protect well with diesel by pumping into 5-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 15. Set BPV and move rig off. 16. Rig up wire line unit. Pull BPV. 17. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 18. Rig up wireline. Replace gas lift valves with blank dummy valves. 19. Turn well over to operations. '~k;9~S~(,~ vt~ cva i3~~ l,c~lt5 v'. `~t~J~e~+s; A1~C~'L~t3s~~ 1J-136 L1 PERMITlTFINAL B!G BORE Page 1 of 2 Printed: 6-Nov-06 • App for Permit to Drill, Well 1J-136 L1 Revision No.O Saved: 27-Oct-06 {'9) for an exploratory or stratigraphic test will, u tabulation setting out the depths of predietec! abnormally geo pressured strata as required by '0 AAC 25.0330}; Not applicable: Application is not for an exploratory or stratigraphic test well: 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An ctphlication,for a Permit to Drill must bc: acrompunled by each of the following items, exccpt,fr>r an item adeeua'v on file with the contrttission and idertf~ed in the applications: (10) for an exploratory or stratigraphic test well a seismic refraction or reflection analysis as required lry ~ 0 AAC 2.5.061(x); Not applicable: Application is not for an exploratory or stratigraphic test well. 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 art item already on file with the commission and identified in the application: (11) for a well drilled frnm an gffshore platfcrrrn, mobile bottom founded structure,./ack-up rig, or floating drilling vessel, tzn analysis of seabed conditions as requir°ed by .2D AAC 25.061(h}; Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application fir a Permit to DrilX must he accompanied by each of the fallowing items, except for an item alreudv on file with the corrarnission and identified in the application: (I2) evidence showing that the rr:gtdremenis of 20 A..~G 2.025 {Bonding}hrxve 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 b}' each of the, following items, excelrt for cars item already on fzle with tlae comm~ssio, artd ident fed in the application: ~,/' The proposed drilling program is listed below. Please refer also to Attachment 3, Well Note: Previous operations are covered under the 1J-136 Application for Permit to Dr' . Run and set Baker WindowMaster whipstock system, at window point of 9,100' / 3,505' TVD, near the top of the "D" sand. 2. Mi116-3/4" window. POOH. s~~~~ "~~~-c~ t~ 3. Pick up 6-3/4" drilling assembly with LWD and MWD and P RIH. 4. Drill to TD of "D" sand lateral at 17,101' MD / 3,373',, D, as per directional plan. 5. POOH, back reaming out of lateral. POOH. ~~'~ 6. RIH with whipstock retrieval tool. Retrievipstock and POOH. 7. PU and run 4-1/2" slotted liner. , ,r<~ $, RIH, until liner hanger is jusve window. Orient hanger to window and land hanger. 9. Release hanger running~ool. POOH. 10. Make up junctio~•~isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop,a5sembly and release from assembly. 11. POOH3•'laying down drill pipe as required. 12. completion as required and RIH to depth. Land tubing. Set BPV. ~. Nipple down BOPE, nipple up tree and test. Pull BPV. 1J-136 L1 PERMIT IT Page 5 of 6 Printed: 27-Oct-O6 • Appi~ for Permit to Drill, Well 1J-136 L1 Revision No.O _ _.----'~ Saved:27-Oct-06 14. Freeze protect well with diesel by pumping into 4-1/2" x 'annulus, taking returns from tubing and allowing to equalize. 15. Set BPV and moverig off. .~,-°""°~ ~ ~~~~~_ A lC ~~_. ~ ~v 16. Rig up wire line unit. Pull BPI: ',.~-~'""Y 17.: Set. gas lift valves in ~atdrels. Operate well on gas lift until ESP facilities are ready. 18. Rig up wirelit~e" Replace gas lift valves with blank dummy valves. 19. Turn Fell over to operations. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) _Arz application for aYermit td Drill mustc be accompanied by each of thej'ollowing items, except for un item ab^ecady ora.ftle with the commission and iclentif erJ in the rtpplication: {14) a general description of how the operator plans to depose of drilling rnud and cuttings atad a statement of whetlaer• the operator intends to request aaathorization under 20.4AC 25.t1t30 fnr an anrtular• disposal operation ira the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J 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 Well Schematic ORIGINAL 1J-136 L1 PERMIT IT Page 6 of 6 Printed: 27-Oct-O6 r: ConocoPhillips Alaska Plan: 1J-136 L1 (wp08) Sperry Drilling Services Proposal Report -Geographic 24 October, 2006 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-136 1J-136 L1 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan 1J-136 Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) N True API - US Survey Feet - -~ ~i Sperry Drilling Services na~GINAL Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-136 Wellbore: 1J-136 L1 Plan: 1J-136 L1 (wp08) -1 1 c ~1 0 0 0 WELL DETAILS: Plan 1J-136 Ground Level: 81.00 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 5945377.60 558931.10 70°15'40.916N 149°31'25.022W FORMATION TOP DETAILS No.TVDPath TVDSS MDPath Formation 1 1514.00 1393 1619.97 Permafrost 2 1662.00 1541 1831.37 K15 3 1985.62 1864.62 2711.67 T3 4 2197.17 2076.17 3588.53 T3+550 5 2910.40 2789.4 6544.79 Ugnu C 6 3117.92 2996.92 7404.94 Ugnu B 7 3183.40 3062.4 7676.35 Ugnu A 8 3365.74 3244.74 8432.13 K13 9 3504.50 3383.5 9097.43 West Sak D 10 NaN West Sak C 11 NaN West Sak B L1: 9 5/8" TOW - ~ 9100' MD, 3505' TVD: 488'FNL, 41T FEL - Sec11-T10N-R10E -- _ ~ ~ L1: BOW -Drill 30' of Rathole ~ 9117' MD, 3508' TVD 1 I ~ L1: Continue Geosteering in D Sand ~ 914T MD, 3512' TVD 1 1 1 1 1 i 1 ~ ~' i 0 1 o ~ ' >~ ~_ ~ _ __ _- _ _. _Si_-. ~- T ~- -o_ ~ O ~ ~ r O1Iw' o ' i m r O 9 5/8" TOW °a 0 .a Slot CASING DETAILS No TVD MD Name Size 1 2197.17 3588.53 13 318" 13-318 2 3505.00 9100.33 9 5/8" TOW 9-518 3 3372.86 17100.00 41/2" 41/2 . __._ -. __._ - - o ..__. . __....... O O t '~ - ~ r ~T ~ r + I N O o o e ° O ~ ~ " . ConocoPhillips Alaska 1J-136 L7 (wp08 --...41/2"-. ~ _. ._..... ` \ ~ _.. T 1~ I T _ _._. ......._ I O~ ~ ~ I O ° ~ O I o I 1J-1361(wp08 Drilling and Form.otlon Evaluation 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 14000 14500 15000 15500 Vertical Section at 180.00` (100D ft/in) i -sooo -~soo -sooo -ssoo -9000 -9500 -loooo losoo x 0 0 0 11000 + L O Z 11500 w 0 N CASING DETA' '~ Project: Kuparuk River Uni Site: Kuparuk 1J Pad No TVD MD Name Size Well: Plan 1J-136 1 2197.17 3588.53 13 3/8" 13-3/8 Wellbore: 1J-136 L1 2 3505.00 9100.33 9 5/8" TOW 9-5/8 Plan: 1J-136 L1 (wp08) 3 3372.86 17100.00 4 1 /2" 4-1 /2 L1: 9 5/8" TOW - @ 9100' MD, 3505' TVD: 486'FNL, 412' FEL - Sec11-T10N-R10E 95/8"TOW---- 180°------_-- - - - - - - - - - - L1: BOW -Drill 30' of Rathole @ 9117' MD, 3508' TVD 1J-136 L1 wp08 D-Landing - - - - - - - - - - _ _ _ L1: Continue Geosteering in D Sand @ 9147' MD, 3512' TVD -180° 1J-136 L1 wp08 T1 (Exit Upper) ---- 180° 1J-136 L1 wp08 T2 (Exit Lower) ---- 180° 1J-136 L1 wp08 T3 (Exit Upper) ---- - 180° 1J-136 L1 wp08 T4 (Exit Lower) - - -- T M - Magnetic North: 24.62° Magnetic Field Strength: 57553.9nT Dip Angle: 80.75° Date: 12/20/2004 Model: BGGM2005 -IVVVV 18U0 L1: BHL @ 17101' MD, 3373' TVD: 2078'FSL, 439' FEL - Sec14-T10N-R1 -15000 41 /2" - - - - `i J-136 L1 wp08 D-Toe -- ~ ~,, ~~- ~~ ~-~ ~~~' -15500 COCIOCOPII~)IIPS ~ Grilling and Far•motfon ;_;~, 1J-136 L1 (wp08) e~,aw°tt°^ -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 West(-)/East(+) (1000 ft/in) ORIGINAL / Halliburton Energy Services ConocoPhillips Planning Report -Geographic Alaska > ° I Orllling and Form®tlon Evaluation Database: _EDM_2003.11_b48 LocatCo-ordinate ReferenC®: Well Plan 1J-136 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) I Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-136 Survey Calculation Method: Minimum Curvature Wellbore: 1J-136 L1 Design: 1J-136 L1 %~~/pOS) 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 Zone 04 Using geodetic scale factor Well Plan 1J-136 Well Position +N/-S 0.00 ft Northing: 5,945,377.60 ft Latitude: 70° 15' 40.918" N +E/-W 0.00 ft Easting: 558,931.10 ft Longitude: 149° 31' 25.022" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.00 ft Wellbore 1J-136 L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength bggm2005 12/20/2004 24.82 80.75 57,554 Design 1J-136 L1 (wp08) Audit Notes: Version: 23 Phase: PLAN Tie On Depth: 9,100.31 Vertical Section: Depth From (TVD) +N/$ +El-W Direction (ft) (rt) (ft) (°) 40.00 0.00 0.00 180.00 10/24/2006 4:29:55PM Page 2 of 8 COMPASS 2003.11 Build 50 ~~x ~E~ • CancxaPhil~ps Alaska Halliburton Energy Services Planning Report -Geographic • Oriiling and Formation Evaluation Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-136 ~~ Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) j Project: Kuparuk River Unit MD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) ~ Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-136 Survey Calculation Method: Minimum Curvature Wellbore: 1J-136 L1 Design: 1J-136 L1 (wp08) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/_yy Rate Rate Rate tFO (ft) (°) (°~ (ft) (ft) {ft) (°/100ft) (`1100ft) (°l100ft) ~~~ 9,100.31 80.00 180.02 3,505.00 -7,330.22 1,877.78 0.00 0.00 0.00 0.00 9,116.81 82.24 180.02 3,507.55 -7,346.52 1,877.77 13.60 13.60 0.00 0.00 9,146.81 82.24 180.02 3,511.59. -7,376.25 1,877.76 0.00 0.00 0.00 0.00 9,241.19 86.49 179.95 3,520.86 -7,470.15 1,877.78 4.50 4.50 -0.07 -0.90 9,250.29 86.49 179.95 3,521.41 -7,479.24 1,877.79 0.00 0.00 0.00 0.00 9,373.72 90.81 180.02 3,524.32 -7,602.60 1,877.82 3.50 3.50 0.05 0.89 9,442.09 94.03 181.16 3,521.43 -7,670.90 1,877.12 5.00 4.71 1.67 19.46 9,605.23 94.03 181.16 3,509.96 -7,833.60 1,873.82 0.00 0.00 0.00 0.00 9,674.27 90.86 179.80 3,507.01 -7,902.56 1,873.24 5.00 -4.60 -1.97 -156.77 10,874.27 90.86 179.80 3,489.00 -9,102.42 1,877.43 0.00 0.00 0.00 0.00 10,969.46 86.99 176.27 3,490.79 -9,197.51 1,880.69 5.50 -4.07 -3.71 -137.68 11,020.08 86.99 176.27 3,493.44 -9,247.95 1,883.97 0.00 0.00 0.00 0.00 11,124.75 91.20 180.20 3,495.10 -9,352.51 1,887.19 5.50 4.02 3.75 43.06 12,374.75 91.20 180.20 3,468.92 -10,602.23 1,882.83 0.00 0.00 0.00 0.00 12,432.71 94.02 180.88 3,466.28 -10,660.12 1,882.29 5.00 4.86 1.17 13.50 12,565.64 94.02 180.88 3,456.97 -10,792.71 1,880.25 0.00 0.00 0.00 0.00 12,625.11 91.15 180.09 3,454.29 -10,852.11 1,879.75 5.00 -4.82 -1.32 -164.63 13,875.11 91.15 180.09 3,429.20 -12,101.86 1,877.79 0.00 0.00 0.00 0.00 13,936.28 88.40 178.74 3,429.44 -12,163.02 1,878.41 5.00 -4.49 -2.20 -153.84 14,065.42 88.40 178.74 3,433.03 -12,292.07 1,881.25 0.00 0.00 0.00 0.00 14,125.07 90.96 180.28 3,433.36 -12,351.71 1,881.76 5.00 4.28 2.58 31.06 15,375.07 90.96 180.28 3,412.42 -13,601.52 1,875.65 0.00 0.00 0.00 0.00 15,458.46 94.14 182.98 3,408.71 -13,684.78 1,873.29 5.00 3.82 3.23 40.20 15,567.16 94.14 182.98 3,400.86 -13,793.05 1,867.65 0.00 0.00 0.00 0.00 15,650.55 90.96 180.28 3,397.14 -13,876.30 1,865.29 5.00 -3.82 -3.23 -139.68 17,100.55 90.96 180.28 3,372.85 -15,326.08 1,858.21 0.00 0.00 0.00 0.00 10/24/2006 4:29:55PM Page 3 of 8 COMPASS 2003.11 Build 50 `~+ ~ G Y~ P Halliburton Energy Services ~-~.1 ~' Conoc a hillips Planning Report -Geographic Grilling end Formation Alaska Evaluation Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-136 Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+g1)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-136 Survey Calculation Method: P<linimum Curvature Wellbore: 1J-136 L1 Design: 1J-136 L1 (wp08) Planned Survey 1J-136 L1 (wp08) Map Map MD I nclination Azimuth ND SSND +N/S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) {it) (ft) (ft) (ft) lff) (ft) (°/100ft) (ft) 1,619.97 44.03 164.98 1,514.00 1,393.00 -397.55 106.67 5,944,980.93 559,040.87 0.00 397.55 Permafrost 1,831.37 49.67 164.98 1,662.OD 1,541.00 -543.21 145.75 5,944,835.60 559,081.09 2.67 543.21 K16 2,711.67 76.04. 164.98 1,985.62 1,864.62 -1,323.29 355.03 5,944,057.26 559,296.44 3.00 1,323.29 T3 3,588.53 76.04 164.98 2,197.17 2,076.17 -2,145.18 575.52 5,943,237.20 559,523.33 0.00 2,145.18 T3+550 -13 3!8" 6,544.79 76.04 164.98 2,910.40 2,789.40 -4,916.14 1,318.87 5,940,472.40 560,288.27 0.00 4,916.14 Ugnu C 7,404.94 76.04 164.98 3,117.92 2,996.92 -5,722.38 1,535.15 5,939,667.96 560,510.83 0.00 5,722.38 Ugnu B 7,676.35 76.04 164.98 3,183.40 3,062.40 -5,976.77 1,603.40 5,939,414.13 560,581.06 0.00 5,976.77 Ugnu A 8,432.13 76.04 164.98 3,365.74 3,244.74 -6,685.18 1,793.44 5,938,707.30 560,776.62 0.00 6,685.18 K13 9,097.43 80.00 180.02 3,504.50 3,383.50 -7,327.39 1,877.78 5,938,065.84 560,865.98 2.29 7,327.39 West Sak D 9,100.31 80.00 180.02 3,505.00 3,384.00 -7,330.22 1,877.78 5,938,063.00 560,866.00 0.00 7,330.22 ' L1: 9 5/8" TOW - @ 9100' MD, 3505' ND: 486'FNL, 412 ' FEL - Sec11-T10N-R10E - 9 6/8" TOW 9,116.81 82.24 180.02 3,507.55 3,386.55 -7,346.52 1,877.77 5,938,046.70 560,866.12 13.60 7,346.52 L1: BOW -Dri ll 30' of Rathole @ 9117' MD, 3508' ND 9,146.81 82.24 180.02 3,511.59 3,390.59 -7,376.25 1,877.76 5,938,016.98 560,866.34 0.00 7,376.25 L1: Continue Geosteering in D Sand @ 9147' MD, 3512' ND 9,200.00 84.64 179.98 3,517.67 3,396.67 -7,429.09 1,877.76 5,937,964.15 560,866.76 4.50 7,429.09 9,241.19 86.49 179.95 3,520.86 3,399.86 -7,470.15 1,877.78 5,937,923.09 560,867.10 4.50 7,470.15 9,250.29 86.49 179.95 3,521.41 3,400.41 -7,479.24 1,877.79 5,937,914.00 560,867.18 0.00 7,479.24 9,300.00 88.23 179.98 3,523.70 3,402.70 -7,528.89 1,877.82 5,937,864.36 560,867.60 3.50 7,528.89 9,373.72 90.81 180.02 3,524.32 3,403.32 -7,602.60 1,877.82 5,937,790.66 560,868.17 3.50 7,602.60 1J-136 L7 wp08 D-Landing 9,400.00 92.05 180.46 3,523.66 3,402.66 -7,628.87 1,877.71 5,937,764.39 560,868.27 4.99 7,628.87 9,442.09 94.03 181.16 3,521.43 3,400.43 -7,670.90 1,877.12 5,937,722.36 560,868.01 5.00 7,670.90 9,500.00 94.03 181.16 3,517.36 3,396.36 -7,728.65 1,875.95 5,937,664.61 560,867.29 0.00 7,728.65 9,600.00 94.03 181.16 3,510.33 3,389.33 -7,828.38 1,873.92 5,937,564.87 560,866.05 0.00 7,828.38 9,605.23 94.03 181.16 3,509.96 3,388.96 -7,833.60 1,873.82 5,937,559.66 560,865.98 0.00 7,833.60 9,674.27 90.86 179.80 3,507.01 3,386.01 -7,902.56 1,873.24 5,937,490.70 560,865.94 5.00 7,902.56 9,700.00 90.86 179.80 3,506.62 3,385.62 -7,928.29 1,873.33 5,937,464.97 560,866.23 0.00 7,928.29 9,800.00 90.86 179.80 3,505.12 3,384.12 -8,028.28 1,873.68 5,937,365.00 560,867.37 0.00 8,028.28 9,900.00 90.86 179.80 3,503.62 3,382.62 -8,128.27 1,874.03 5,937,265.03 560,868.50 0.00 8,128.27 10,000.00 90.86 179.80 3,502.12 3,381.12 -8,228.25 1,874.38 5,937,165.06 560,869.63 0.00 8,228.25 10,100.00 90.86 179.80 3,500.62 3,379.62 -8,328.24 1,874.73 5,937,065.08 560,870.76 0.00 8,328.24 10/24/2006 4:29:55PM Page 4 of 8 COMPASS 2003.11 Build 50 Halliburton Energy Services COt'1000P~'t1I~1 35 ~ Planning Report -Geographic Grilling and Formation ~~~ Evaluation Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Welf Plan 1J-136 Company: ConocoPhillips Alaska, Inc: TVD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+g1)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-136 Survey Calculation Method: Minimum Curvature Wellbore: 1J-136 L1 Design: 1J-136 L1 (wp08) Planned Survey 1J-136 L1 (wp08) ~Jlap Map MD Inclination Azimuth TVD SSTVD +N/-S +El-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft} Iftl (ft) eft) (ft) lft) (°/1001't) (ft} 10,200.00 90.86 179.80 3,499.12 3,378.12 -8,428.23 1,875.08 5,936,965.11 560,871.89 0.00 8,428.23 10,300.00 90.86 179.80 3,497.62 3,376.62 -8,528.22 1,875.43 5,936,865.14 560,873.02 0.00 8,528.22 10,400.00 90.86 179.80 3,496.12 3,375.12 -8,628.21 1,875.77 5,936,765.16 560,874.15 0.00 8,628.21 10;500.00 90.86 179.80 3,494.62 3,373.62 -8,728.19 1,876.12 5,936,665.19 560,875.29 0.00 8,728.19 10,600.00 90.86 179.80 3,493.12 3,372.12 -8,828.18 1,876.47 5,936,565.22 560,876.42 0.00 8,828.18 10,700.00 90.86 179.80 3,491.62 3,370.62 -8,928.17 1,876.82 5,936,465.25 560,877.55 0.00 8,928.17 10,800.00 90.86 179.80 3,490.11 3,369.11 -9,028.16 1,877.17 5,936,365.27 560,878.68 0.00 9,028.16 10,874.27 90.86 179.80 3,489.00 3,368.00 -9,102.42 1,877.43 5,936,291.02 560,879.52 0.00 9,102.42 1J-136 L1 wp08 T1 (Exit Upper} 10,900.00 89.82 178.85 3,488.85 3,367.85 -9,128.15 1,877.73 5,936,265.30 560,880.03 5.49 9,128.15 10,969.46 86.99 176.27 3,490.79 3,369.79 -9,197.51 1,880.69 5,936,195.98 560,883.52 5.50 9,197.51 11,000.00 86.99 176.27 3,492.39 3,371.39 -9,227.94 1,882.67 5,936,165.56 560,885.74 0.00 9,227.94 11,020.08 86.99 176.27 3,493.44 3,372.44 -9,247.95 1,883.97 5,936,145.56 560,887.20 0.00 9,247.95 11,100.00 90.20 179.27 3,495.40 3,374.40 -9,327.76 1,887.08 5,936,065.78 560,890.93 5.50 9,327.76 11,124.75 91.20 180.20 3,495.10 3,374.10 -9,352.51 1,887.19 5,936,041.04 560,891.24 5.51 9,352.51 11,200.00 91.20 180.20 3,493.52 3,372.52 -9,427.74 1,886.93 5,935,965.82 560,891.57 0.00 9,427.74 11,300.00 91.20 180.20 3,491.43 3,370.43 -9,527.72 1,886.58 5,935,865.85 560,892.00 0.00 9,527.72 11,400.00 91.20 180.20 3,489.33 3,368.33 -9,627.70 1,886.23 5,935,765.88 560,892.43 0.00 9,627.70 11,500.00 91.20 180.20 3,487.24 3,366.24 -9,727.68 1,885.88 5,935,665.91 560,892.87 0.00 9,727.68 11,600.00 91.20 180.20 3,485.15 3,364.15 -9,827.65 1,885.53 5,935,565.95 560,893.30 0.00 9,827.65 11,700.00 91.20 180.20 3,483.05 3,362.05 -9,927.63 1,885.18 5,935,465.98 560,893.73 0.00 9,927.63 11,800.00 91.20 180.20 3,480.96 3,359.96 -10,027.61 1,884.84 5,935,366.01 560,894.17 0.00 10,027.61 11,900.00 91.20 180.20 3,478.86 3,357.86 -10,127.59 1,884.49 5,935,266.04 560,894.60 0.00 10,127.59 12,000.00 91.20 180.20 3,476.77 3,355.77 -10,227.56 1,884.14 5,935,166.08 560,895.03 0.00 10,227.56 12,100.00 91.20 180.20 3,474.67 3,353.67 -10,327.54 1,883.79 5,935,066.11 560,895.47 0.00 10,327.54 12,200.00 91.20 180.20 3,472.58 3,351.58 -10,427.52 1,883.44 5,934,966.14 560,895.90 0.00 10,427.52 12,300.00 91.20 180.20 3,470.49 3,349.49 -10,527.50 1,883.09 5,934,866.17 560,896.33 0.00 10,527.50 12,374.75 91.20 180.20 3,468.92 3,347.92 -10,602.23 1,882.83 5,934,791.45 560,896.66 0.00 10,602.23 1J-136 L7 wp08 T2 (Exit. Lower} 12,400.00 92.43 180.49 3,468.12 3,347.12 -10,627.47 1,882.68 5,934,766.21 560,896.70 4.99 10,627.47 12,432.71 94.02 180.88 3,466.28 3,345.28 -10,660.12 1,882.29 5,934,733.56 560,896.57 5.01 10,660.12 12,500.00 94.02 180.88 3,461.57 3,340.57 -10,727.24 1,881.26 5,934,666.44 560,896.06 0.00 10,727.24 12,565.64 94.02 180.88 3,456.97 3,335.97 -10,792.71 1,880.25 5,934,600.97 560,895.57 0.00 10,792.71 12,600.00 92.36 180.42 3,455.06 3,334.06 -10,827.01 1,879.87 5,934,566.67 560,895.45 4.99 10,827.01 12,625.11 91.15 180.09 3,454.29 3,333.29 -10,852.11 1,879.75 5,934,541.57 560,895.54 5.01 10,852.11 12,700.00 91.15 180.09 3,452.78 3,331.78 -10,926.98 1,879.64 5,934,466.71 560,896.00 0.00 10,926.98 12,800.00 91.15 180.09 3,450.78 3,329.78 -11,026.96 1,879.48 5,934,366.74 560,896.63 0.00 11,026.96 12,900.00 91.15 180.09 3,448.77 3,327.77 -11,126.94 1,879.32 5,934,266.77 560,897.25 0.00 11,126.94 13,000.00 91.15 180.09 3,446.76 3,325.76 -11,226.92 1,879.16 5,934,166.80 560,897.88 0.00 11,226.92 13,100.00 91.15 180.09 3,444.76 3,323.76 -11,326.90 1,879.01 5,934,066.84 560,898.51 0.00 11,326.90 13,200.00 91.15 180.09 3,442.75 3,321.75 -11,426.88 1,878.85 5,933,966.87 560,899.13 0.00 11,426.88 13,300.00 91.15 180.09 3,440.74 3,319.74 -11,526.86 1,878.69 5,933,866.90 560,899.76 0.00 11,526.86 13,400.00 91.15 180.09 3,438.74 3,317.74 -11,626,84 1,878.54 5,933,766.93 560,900.38 0.00 11,626.84 13,500.00 91.15 180.09 3,436.73 3,315.73 -11,726.82 1,878.38 5,933,666.96 560,901.01 0.00 11,726.82 13,600.00 91.15 180.09 3,434.72 3,313.72 -11,826.80 1,878.22 5,933,566.99 560,901.63 0.00 11,826.80 13,700.00 91.15 180.09 3,432.71 3,311.71 -11,926.78 1,878.07 5,933,467.03 560,902.26 0.00 11,926.78 13,800.00 91.15 180.09 3,430.71 3,309.71 -12,026.76 1,877.91 5,933,367.06 560,902.88 0.00 12,026.76 10/24/2006 4:29:55PM Page 5 of 8 COMPASS 2003.11 Build 50 ORIG!NP.L ConocoPhillips Alaska Halliburton Energy Services Planning Report -Geographic LL. Oriiling and Formation Evaluation Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-136 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-136 Survey Calculation Method: Minimum Curvature Wellbore: 1J-136 L1 ', Design: 1J-136 L1 (wp08) Planned Survey 1J-136 L1 (wp08) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) {°) {ft) (ft) (ft) (flj (ft) (ft) (°l100ft) (ft) 13,875.11 91.15 180.09 3,429.20 3,308.20 -12,101.86 1,877.79 5,933,291.97 560,903.35 0.00 12,101.86 1J-136 L1 wp08 T3 (Exk Upper) 13,900.00 90.04 179.54 3,428.94 3,307.94 -12,126.74 1,877.87 5,933,267.09 560,903.63 4.99 12,126.74 13,936.28 88.40 178.74 3,429.44 3,308.44 -12,163.02 1,878.41 5,933,230.82 560,904.45 5.01 12,163.02 14,000.00 88.40 178.74 3,431.21 3,310.21 -12,226.69 1,879.81 5,933,167.16 560,906.35 0.00 12,226.69 14,065.42 88.40 178.74 3,433.03 3,312.03 -12,292.07 1,881.25 5,933,101.81 560,908.30 0.00 12,292.07 14,100.00 89.88 179.63 3,433.55 3,312.55 -12,326.64 1,881.74 5,933,067.24 560,909.06 4.99 12,326.64 14,125.07 90.96 180.28 3,433.36 3,312.36 -12,351.71 1,881.76 5,933,042.18 560,909.27 5.01 12,351.71 14,200.00 90.96 180.28 3,432.11 3,311.11 -12,426.63 1,881.39 5,932,967.26 560,909.49 0.00 12,426.63 14,300.00 90.96 180.28 3,430.43 3,309.43 -12,526.62 1,880.90 5,932,867.29 560,909.79 0.00 12,526.62 14,400.00 90.96 180.28 3,428.76 3,307.76 -12,626.60 1,880.41 5,932,767.31 560,910.08 0.00 12,626.60 14,500.00 90.96 180.28 3,427.08 3,306.08 -12,726.59 1,879.93 5,932,667.34 560,910.38 0.00 12,726.59 14,600.00 90.96 180.28 3,425.41 3,304.41 -12,826.57 1,879.44 5,932,567.36 560,910.67 0.00 12,826.57 14,700.00 90.96 180.28 3,423.73 3,302.73 -12,926.56 1,878.95 5,932,467.38 560,910.96 0.00 12,926.56 14,800.00 90.96 180.28 3,422.05 3,301.05 -13,026.54 1,878.46 5,932,367.41 560,911.26 0.00 13,026.54 14,900.00 90.96 180.28 3,420.38 3,299.38 -13,126.53 1,877.97 5,932,267.43 560,911.55 0.00 13,126.53 15,000.00 90.96 180.28 3,418.70 3,297.70 -13,226.51 1,877.48 5,932,167.46 560,911.85 0.00 13,226.51 15,100.00 90.96 180.28 3,417.03 3,296.03 -13,326.50 1,876.99 5,932,067.48 560,912.14 0.00 13,326.50 15,200.00 90.96 180.28 3,415.35 3,294.35 -13,426.48 1,876.51 5,931,967.51 560,912.43 0.00 13,426.48 15,300.00 90.96 180.28 3,413.68 3,292.68 -13,526.46 1,876.02 5,931,867.53 560,912.73 0.00 13,526.46 15,375.07 90.96 180.28 3,412.42 3,291.42 -13,601.52 1,875.65 5,931,792.48 560,912.95 0.00 13,601.52 1J-136 L1 wp08 T4 (Exit Lower) 15,400.00 91.91 181.08 3,411.80 3,290.80 -13,626.44 1,875.35 5,931,767.56 560,912.85 4.99 13,626.44 15,458.46 94.14 182.98 3,408.71 3,287.71 -13,684.78 1,873.29 5,931,709.22 560,911.23 5.01 13,684.78 15,500.00 94.14 182.98 3,405.71 3,284.71 -13,726.15 1,871.13 5,931,667.83 560,909.41 0.00 13,726.15 15,567.16 94.14 182.98 3,400.86 3,279.86 -13,793.05 1,867.65 5,931,600.92 560,906.45 0.00 13,793.05 15,600.00 92.89 181.92 3,398.84 3,277.84 -13,825.80 1,866.26 5,931,568.16 560,905.31 4.99 13,825.80 15,650.55 90.96 180.28 3,397.14 3,276.14 -13,876.30 1,865.29 5,931,517.65 560,904.74 5.01 13,876.30 15,700.00 90.96 180.28 3,396.32 3,275.32 -13,925.75 1,865.05 5,931,468.21 560,904.88 0.00 13,925.75 15,800.00 90.96 180.28 3,394.64 3,273.64 -14,025.73 1,864.56 5,931,368.24 560,905.18 0.00 14,025.73 15,900.00 90.96 180.28 3,392.96 3,271.96 -14,125.72 1,864.07 5,931,268.26 560,905.47 0.00 14,125.72 16,000.00 90.96 180.28 3,391.29 3,270.29 -14,225.70 1,863.58 5,931,168.28 560,905.77 0.00 14,225.70 16,100.00 90.96 180.28 3,389.61 3,268.61 -14,325.69 1,863.09 5,931,068.31 560,906.06 0.00 14,325.69 16,200.00 90.96 180.28 3,387.94 3,266.94 -14,425.67 1,862.61 5,930,968.33 560,906.35 0.00 14,425.67 16,300.00 90.96 180.28 3,386.26 3,265.26 -14,525.65 1,862.12 5,930,868.36 560,906.65 0.00 14,525.65 16,400.00 90.96 180.28 3,384.59 3,263.59 -14,625.64 1,861.63 5,930,768.38 560,906.94 0.00 14,625.64 16,500.00 90.96 180.28 3,382.91 3,261.91 -14,725.62 1,861.14 5,930,668.41 560,907.24 0.00 14,725.62 16,600.00 90.96 180.28 3,381.24 3,260.24 -14,825.61 1,860.65 5,930,568.43 560,907.53 0.00 14,825.61 16,700.00 90.96 180.28 3,379.56 3,258.56 -14,925.59 1,860.16 5,930,468.45 560,907.82 0.00 14,925.59 16,800.00 90.96 180.28 3,377.89 3,256.89 -15,025.58 1,859.67 5,930,368.48 560,908.12 0.00 15,025.58 16,900.00 90.96 180.28 3,376.21 3,255.21 -15,125.56 1,859.18 5,930,268.50 560,908.41 0.00 15,125.56 17,000.00 90.96 180.28 3,374.53 3,253.53 -15,225.55 1,858.70 5,930,168.53 560,908.70 0.00 15,225.55 17,100.00 90.96 180.28 3,372.86 3,251.86 -15,325.53 1,858.21 5,930,068.55 560,909.00 0.00 15,325.53 4 1/2" 17,100.55 90.96 180.28 3,372.85 3,251.85 -15,326.08 1,858.21 5,930,068.00 560,909.00 0.00 15,326.08 BHL @ 17101' MD, 3373' TVD: 2078'FSL, 439' FEL - Sec14-T10N-R10E - 1J-136 L1 wp08 D-Toe 10/24/2006 4:29:55PM Page 6 of 8 COMPASS 2003.11 Build 50 ~~ ~ ~ .s - Y ~ ..~~ COnoCt3Phl~tlps Halliburton Energy Services Alaska Planning Report -Geographic Oriiling and Formation Evaluation Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-136 Company: ConocoPhillipsAlaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-136 Survey Calculation Method: Minimum Curvature Wellbore: 1J-136 L1 Design: 1J-1£~~~ L' (wp08) Geologic Targets 1J-136 L1 TVD Target Name +N/-S +E/-W Northing Fasting (ft) -Shape ft ft (ft) (ft) 3,372.85 1J-136 L1 wp08 D-Toe -15,326.08 1,858.21 5,930,068.00 560,909.00 - Point 3,468.92 1J-136 L1 wp08 T2 (Exit Lower} -10,602.23 1,882.83 5,934,791.45 560,896.66 - Point 3,412.42 1J-136 L1 wp08 T4 (Exit Lower) -13,601.52 1,875.65 5,931,792.48 560,912.95 - Point 3,489.00 1J-136 L7 wpD8 T1 (Exit Upper) -9,102.42 1,877.43 5,936,291.02 560,879.52 - Point 3,524.32 1J-136 L1 wp08 D-Landing -7,602.60 1,877.82 5,937,790.66 560,868.17 - Point 3,429.20 1J-136 L1 wp08 T3 (Exit Upper) -12,101.86 1,877.79 5,933,291.97 560,903.35 - Point Prognosed Casing Points Measured Vertical Casing Hoie Depth Depth biameter diameter (ft) (ftl (") ("! 3,588.53 2,197.17 13-3/8 16 9,100.33 3,505.00 9-5l8 12-1/4 17,100.00 3,372.86 4-112 6-3/4 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (~} 1°) (°) (ft) (ftl (ftl Name 1,619.97 44.03 164.98 1,514.00 -397.55 106.67 Permafrost 1,831.37 49.67 164.98 1,662.00 -543.21 145.75 K15 2,711.67 76.04 164.98 1,985.62 -1,323.29 355.03 T3 3,588.53 76.04 164.98 2,197.17 -2,145.18 575.52 T3+550 6,544.79 76.04 164.98 2,910.40 -4,916.14 1,318.87 Ugnu C 7,404.94 76.04 164.98 3,117.92 -5,722.38 1,535.15 Ugnu B 7,676.35 76.04 164.98 3,183.40 -5,976.77 1,603.40 Ugnu A 8,432.13 76.04 164.98 3,365.74 -6,685.18 1,793.44 K13 9,097.43 80.00 180.02 3,504.50 -7,327.39 1,877.78 West Sak D 3,548.52 West Sak C 3,568.11 West Sak B 10/24/2006 4:29:55PM Page 7 of 8 COMPASS 2003.11 Build 50 ConocoPhillips Alaska Database: _EDM_2003.11_b48 Local Co-ordinate Referent®: Well Plan 1J-136 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121 OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Pfan 1J-136 Survey Calculation Method: Minimum Curvature Wellbore: 1J-136 L1 Design: 1J-136 L1 (wp08) Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W Comment (ft) (ft) (ft) {ft} 9,100.31 3,505.00 -7,330.22 1,877.78 L1: 9 5/8" TOW - @ 9100' MD, 3505' TVD: 486'FNL, 412' FEL - Sec11-T10N-R10E 9,116.81 3,507.55 -7,348.52 1,877.77 L1: BOW -Drill 30' of Rathole @ 9117' MD, 3508' TVD 9,148.81 3,511.59 -7,376.25 1,877.76 L1: Continue Geosteering in D Sand @ 9147' MD, 3512' TVD 17,100.55 3,372.85 -15,325.53 1,858.21 BHL @ 17101' MD, 3373' TVD: 2078'FSL, 439' FEL- Sec14-T10N-R10E Halliburton Energy Services Planning Report -Geographic ~-fL.~.,.: ~ Orllling end Formation Evaluation 10/24/2006 4:29:55PM Page 8 of 8 COMPASS 2003.11 Build 50 ConocoPhillips Alaska • Plan: 1J-136 L1 (wp08) Sp~l°ry- rillil~g Sar~i~es Anticollision Summary 25 October, 2006 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-136 1J-136 L1 Local Coordinate Origin: Centered on Well Plan 1J-136 Viewing Datum: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet .. _ - _ ^ _. _~ _; . ~ ___ . Sperry Grilling Services O V ..~~ „~ SURVEY PROGRAM Da1c:2W411F25TW:W:W Validated: Yc9 Vcnion: 23.U00 Depth From Depth Tn Sun-ey/Plan T6ml 1D.Ik1 378.53 C&GYRO-SS 37Y_53 YIW.31 M\YD+IFR-AK-CAZSC 91W.31 171W.S5 IJ-13fi L1 (x 1x98) MWD+IFR-AK-CAZLC 0 270 ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: SOStations Range From: 9100.31000178271 7017100.5496 Maximum Range:1910.05496398041 Reference: Plan: 1J-136 Lt (wp08) rom Colour o ---- sooo - 9250 - 9500 9750 10000 - 10250 - ~10500 10750 - 11000 - 11250 ----' 11500 - 11750 - 12000 - 12250 12500 - 12750 - 13000 .____ 13250 13500 13500 13750 13750 14000 14000 14250 14250 14500 14500 14750 14750 -~--- 15000 15000 15250 15250 ~~~_-~ 15500 15500 15750 15750 16000 16000 16250 16250 16500 16500 16750 16750 17000 17000 0 ki Tvo .ea-s .El-w OLeB .o Tpa<e vsel T4e0e1 0 1ao.oz 3s%.% -»3o.z: 1Bn2e o.% % sx.z6 1so.61 3%zs6 -]3%.Sx 1en.n 13% o.% n3o.zz o.% 73%.6x 82.2+ 180.02 3611.69 -]3]6.x5 18T7.16 0.% 86A9 1)9.% 3630% -]170.16 18]T]8 1.% 0.% TJ70.25 -0.% )6]0.16 %.69 1)9.% 36x1 d1 -]6)9.x0 1817.]9 0.00 %.B1 180.Ox )6x0.32 -]60x.60 1817.82 3.% 0.% T6)926 0.% )%1.% 111%L1 VIp08 DLa1Mirp %.Ol 181.16 J631.dJ -]6)0% 1677.12 6.% %.O3 181.16 3%9.% -IfiJ36p 181).82 0.00 19.K 76]0.% 0.% ]833.% %es 1]9so 3%zo7 a9oa% 1en26 6.% -1%.n )%x.% %a6 1]9.80 368900 -9102A3 7877.0.1 0.00 %.% 1]6.2] 31%.18 -919)51 188069 t.% 0.% 8103.62 11138 L1 Np08 T1 IE,u Upper) -1)1.68 9197.61 %.% 1]6.3] H90Y -910]95 188).97 0.00 91]0 180.x0 H%.f0 -9)5151 188].19 6.60 000 9x6).96 6).06 9363.51 81211 780.20 3K8.91 -106012) 1863.8) 0.% 81.02 18088 H%.28-1%fi0.12 1862.39 5.% 000 1%0223 1J-1%L11vp08 Tl )Fail L°nerl 13.50 1088012 %.O2 180.% H%.9] -10]92.]1 1880.x5 0.% 91.16 180.09 3151.39 -10852.11 18)9.]5 6.% 0.00 70]91]1 -181.63 1086111 81.15 180.% 34x9.10.1210186 18]]79 0.00 BB.b 1)8.70 J639.M ~1316J.03 18)841 6.00 0.00 1210186 111K L1 wpOB T)lE>it Upper) -16J.%7216).01 88.40 1]8.]6 SIII.OI -12292.0] 1881.x5 0.00 90% 18038 SIJJ.36-1iI51.i1 1881.]6 5.00 0.00 132920] 31.06 12)51]1 %% 180.x8 )412.01-1)601.52 18)5.65 0.00 0.00 13601 SZ 1J+1%L1 wp08 TB lEal LOxer) %.16 183.98 3108.]1 -1 J68d.76 1873.x9 5.00 %.16 182.98 JIOO.B6 -1]79].05 16165 0.00 +020 736%.7B 0.00 13193.06 %.% 18028 JJ9].14 .1 )6]6.10 1 85.29 500 %.% 180.28 3)]185 ~15126.OB 185821 000 -1]9.% 1)8]6.30 0.001W36.00 11136 L1 wpO8 DTa< 90 REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 1J-136, True North Vertical (ND) Reference: Doyon 15 (40+81) ~ 12f.00h (Doyon 15 (40+61)) Section (1/S) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: Doyon 15 (40+81) ~ 121.OOR (Doyon 15 (40+81)) Calculation Methotl: Minimum Curvature NAD 27 ASP Zone 4 : WELL DETAILS: PWn 1)-136 Ground Level: 81.00 +N/S +FJ-W Northing Easting Latittude Longitude O.W 0.00 5945377.60 558931.10 70°75'40.916N 149°31'25.022W COMPANY DETAILS: ConocoPhillips Alaska, Inc. Engineering Slot Calculation Method: Minimum Curvature Enor System: ISCWSA Scan Method: Trav. Cylinder North Error Sunace: Elliptical Conic Warning Method: Rules Basetl 180 Travelling Cylinder Azimuth (I'Fp+AZq i°I vs Centre f0 Centre Separation I15 R/inl 180 Travelling Cylinder Azimuth (TFO+ALI) ~°~ vs Ccnh•e to Centre Separation X75 ft/ink Cc~nocoF~~~lps AEasi<a Company: Project: Reference Site: Site Error: Reference Well: Well Error: Reference Wellbore Reference Design: Halliburton Energy Services Anticollision Report ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad O.OOft Plan 1J-136 O.OOft 1J-136 L1 1J-136 L1 (wp08) Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Grilling and Formation Evaluation Well Plan 1J-136 Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+g1)) Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) True Minimum Curvature 2.00 sigma _EDM_2003.11_b48 Offset Datum Reference 1J-136 L1 (wp08) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.OOft Error Model: Depth Range: 9,100.31 to 17,100.SSft Scan Method: Results Limited by: Maximum center-center distance of 1,910.OSft Error Surface: Warning Levels evaluated at: 0.00 Sigma ISCWSA Trav. Cylinder North Elliptical Conic Survey Tool Program Date 10/25/2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 40.00 378.53 1J-136 (wp08) (1J-136) CB-GYRO-SS Camera based gyro single shot 379.53 9,100.31 1J-136 (wp08) (1J-136) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,100.31 17,100.55 1J-136 L1 (wp08) (1J-136 L1) MWD+IFR-AK-CAZ-LC MWD+IFR AK CAZ LC Sperry Summary Reference Offset Centre to No-Go Allowabl© Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Pian Offset Nell -Wellbore -Design (ft) (ft) (ft} (fti I'uc~aruk 1J Pad 1 J-14 - 1 J-14 - 1 J-14 Out of range 1 J-184 - 1 J-184 - 1 J-184 Out of range 1J-184 - 1J-184 L1 - 1J-184 L1 Out of range Plan 1J-103 - 1J-103 - 1J-103 (wp06) 10,170.52 15,094.73 1,127.49 315.76 821.11 Pass -Major Risk Plan 1J-130 -Plan 1J-130 - 1J-130 (wp02) Out of range Plan 1 J-133 - 1 J-133 - 1 J-133 (wp06) - D141 Out of range Plan 1 J-133 - 1 J-133 - 1 J-133 Intermediate Out of range Plan 1J-133 - 1J-133 L1 - 1J-133 L1 (wp06) Out of range Plan 1J-135 -Plan 1J-135 - 1J-135 (wp02) 14,151.45 15,043.58 1,204.90 729.13 478.86 Pass -Major Risk Plan 1J-135 -Plan 1J-135 L1 - 1J-135 L1 (wp02) 14,152.56 15,040.17 1,201.16 681.30 520.34 Pass -Major Risk Plan 1J-136 - 1J-136 - 1J-136 (wp08) 9,100.31 9,100.00 0.31 0.91 -0.60 FAIL - No Errors Plan 1J-176 (02 Phase 2) - 1J-176 - 1J-176 wp02 Out of range Plan 1J-176 (02 Phase 2) - 1J-176 L1 - 1J-176 L1 Out of range Plan iJ-178 (03 Phase 2) - 1J-178 L1 - 1J-178 L1 Out of range Plan 1J-178 (03 Phase 2) -Plan 1J-178 - 1J-178 ( Out of range Plan 1J-180 -Plan 1J-180 - 1J-180 (wp08) Out of range Plan 1J-180 -Plan 1J-180 L1 - 1J-180 L1 (wp08) Out of range Rig: 1J-137 - 1J-137 - 1J-137 Rig 17,092.67 16,800.00 1,098.24 422.13 676.80 Pass -Major Risk Rig: 1J-137 - 1J-137 L1 - 1J-137 L1 15,650.55 15,350.00 929.74 383.91 546.34 Pass -Major Risk Rig: 1J-137- 1J-137 L1 PB1 - 1J-137 L1 PB1 12,057.38 11,750.00 1,110.72 300.11 811.86 Pass- Major Risk Rig: 1J-137- 1J-137 L1 PB2- 1J-137 L1 PB2 13,368.80 13,075.00 931.57 329.76 602.36 Pass- Major Risk Rig: 1J-182 - 1J-182 - 1J-182 Out of range Rig: 1J-182 - 1J-182 L1 - 1J-182 L1 (wp13) Out of range CC -Min centre to center distance or covergent paint, SF -min separation factor, ES -min ellipse separation 10!252006 6.05.39PM Page 2 of 2 COMPASS 2003.11 Build 50 ORIGINAL cin ~Um ~ O O Y Y Y ~ ~m a o U op Q cv m w ~~~ ~ ~~ ~f1 } C C C M N N N O ° ~ 0 d L n n 00 O !n t0 M M N 00 O o ~~M~~~~~~a~,~ ~` 0 aO'~~OO~~+'mNnov 0 Z 0 ~ M r 0 0 O n M 0 l n p 1 t0 cones 7f0aOMtt Q ~~e-N Mfpnnao 0100 Q ~OONnONOetON~ 0 00 0 ~ ~OOtD ~-e}O V n~n~n~- ~ n.M~a~D 011CNejMn n O ~Mt~W OnTONM~ V /• 00 0 ~ ~ ~ ~ N N N M M M M M o _ Zr'NMVtmm~ao Of ~.`-- 3 p_ O ° ~ _~ ~ 0 N ; / O J M O / "'I 0 ~ O / c") 0 1 O O ~ I 1 I ~ O f~ ~~ , ~ O 0 ;d I o O J 1 / ~~. I O ON ~ ~ n ~~ ` ~ o I fV_ O I ~ ~ Q \ O ~ '...1 ~ 3 I` C I I ~ ' O / O ~~ ~ ' L R ~~ M / ,i ~dM~Dp M ', ,, _ r~ r 3 , ~ n N cv 1C _R y M N r J i// ~~~a~c m =~~ ~ •o v~ a L ~ 3 a J ~ t+1 47 ~ '" a , J O a ~ ~ 3 , co ~ ~ ~ M N ~ ~ ~ CO ~ d J / M N •- _ r J ~ t} O n" N ~ r ~ i ~ ~ N M O ~~~~ ~ c J ~001VM ...-. 0 et ~ 0 Fa- Zo)~M O ~ ~ M 0 1M 0 ^\ (~ t\ Z ~00~0 Q O)~ M U O ~ ~ O r ~~~~ °o °o M M N O a o 0 0 ~ Z r N M O u Closest in POOL ,,.~ ~~ >• ~~ ,,, ~v x:~~ Closest A roach: Reference Well: 1J-13 6 L1 w 08 Plan Offset Well: 1J-102 L2 Coords. - Coords. - ASP ASP 3-D ctr-ctr ' Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth InG. An le TRUE Azi. TVD E(+)IW -) (180°) Comments Depth InG. Angle TRUE Azi. TVD E(+ /W(- (180°) Comments POOL Min Distance POOL Min Distance (485.62 ft) in POOL (485.62 ft) in POOL (9097.43 - 17100.55 (9097.43 - 17100.55 MD) to 1J-136 L1 MD) to 1J-102 L2 (wp08) Plan (4865.05 485.62 9097.43 80 180.02 3383.471 5938065.2 560866.7 7327.345 (4865.05 - 12095 MD) 12095 90.9 178.05 3380.138 5938487.5 560626.9 6903.232 - 12095 MD) Closest A roach: Reference Well: 1J-136 L1 w 08 Plan Offset Well: 1J-135 L1 w 02 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments Depth InG. An le TRUE Azi. TVD E(+)IW - 180° Comments POOL Min Distance POOL Min Distanc (1200.63 ft) in POOL (1200.63 ft) in PO (9097.43 - 17100.55 (9097.43 - 17100.55 MD) to 1J-135 L1 MD) to 1J-136 L1 (wp02) (7710.26 - (wp08) Plan (7710.26 1200.63 `r'i't'`. "=~ "" 14150 90.96 180.28 3311.927 5933016.2 560910.2 12376.6 15040.17 MD) 15040.17 91.35 180.41 3346.314 5933016.3 562110.4 12385.86 - 15040.17 MD) Closest A roach: Reference Well: 1J-136 L1 w 08 Plan Offset Well: 1J-137 L1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. Angle TRUE Azi. TVD E +)/W(-) 180° Comments De th InG. Angle TRUE Azi. TVD E(+)/W(-) (180°) Comments POOL Min Distance POOL Min Distance (929.99 ft) in POOL (929.99 ft) in POOL (9097.43 - 17100.55 (9097.43 - 17100.55 MD) to 1J-136 L1 MD) to 1J-137 L1 (wp08) Plan (8830.08 929.99 15650 90.98 180.3 3276.138 5931517 560905.7 13875.71 (8830.08 - 16840 MD) 15341.88 90.25 181.49 3271.547 5931529.6 559975.8 13855.78 - 16840 MD) J POOL Summary136.x1s 10/24/2006 3:15 PM 1~- rilling Hazard~Sam (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Production Hole 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 ~ ,A 1J-136L1 Drilling Hazards Summary 10/24/2006 7:25 AM Tubing, Special Drift to +/- 500' MD D8 Nipple, sat at +/- 500' MD /GLM, Camco, 4112" x 1" KBMG 13-318" Casing Shoe, fill#, L-80, BTC sat ~ 3589' MD, 2197' ND Tubing String 4112" 12.9#, L-B0, IBTM 3.958" ID, 3.833" Drift 7" x as/e° zxP Liner TOp Pxker wdm Rda Downs GLM, Camco, 4112" x 1" KBMG / CMD Sliding Sleeve, wl DB Nipple i CUtIOCQ~'tI~~1~J5 1 J-136 West Sak 9-5/8" Intermediate Dual Lateral Injector `~ Locatln9 Seal -,, Assamtly \r, ~ \~ /~Laleral Envy ModuINLEM) ` I *\ % / Onentlrrg ProBe 1 S r \Z( ~~ '\. ~\ ~~11 / Y s ; 1~` Rxeprede ~ B-sand Window 'D' Sand Lateral at 9100' MD, 3505' ND 6-1/Y 16.6e, Hydra filly 16.60, BTC, s11. L-BO Stoned Llror L-0D Slotted Liner `~~ y ~ S7/2" Pa YZone ECP Every Other Jdnt Every Other Jpnt 5712" X a6/B" MorMl'B' HOOK Hance - ~~ , ~ y (PZ Rework) \ ~~ f°`9 r1Y"'_'~`Mrh:ZS "e ... - a~ _ t,.. _ teem , Casing Saalbore 1.76" ID Lateral M o d ule (LEMI E nt rv ~ _ ss e m bl v A 7"X9.518"ZXP Liner Top . Packer with Hdd Downs 7.500" Tieback Ext ID 6.278" Tool Body ID -- Casing Sealbore Raceptade 4.75" ID, 5.75" OD 20' Length _ Orienting Profile Automatic Alignment of LEM _ _ - Positive Latching Collet Indicates Correct Location Seal Bore for Lateral .~ Isolation - 3.688" ID i, Access Window ~I, ~ Positive Uteral Access Vu Thro-Tubing Diverter Seal Bore for Lateral '~ Isolation - L6B8" ID ~,._ Isolation Seal Assmbly 4.75" Seal OD 3.875" SeaI1D 2' Length seal 7" Tieback Sleeve 3.662" DB Nipple 1112" As Planned ~~a~ `'pia its Baker Oil Tools With Diverters and Isolation LaterM Access Dlwrter Lateral Isdatlon Dlverter G9 Runnlnq Ted 9mr1g InstaBW InsMllatl (1.00" Lateral Dna) (250" ID Malnbore Drill) r_J 'G9' ProMa for . ~~'-- Cdl Connector ' ! RunninglReMavlrrq \~ , , . ~ (1.011 LsngN) ~ ~+ Snap InIShaP Out Bxk Pressuro Vlve Ik'..a.'a' Poslnw LOCating - ~ ~ r (1.80' Lergml Cdlet I~ " Lateral Isdatlon ~- Fl~Thrv sWlva secs I (1.25' LengNl I I, Lateral Dlvaner zl \ ) Hytlrarak / ' Remp '1 - IsdatloM MalnDOre - £~ ( .50' Len tnl 1 g ~ Dlwrter Sleeve _ - Gb Spear ~~ ~ e ~ (7.50'Length) ~ Lateral lsdatbn , sets B.t6 RApprOx OAL' tars may be r01ry1re0ln hlgNy hNaled 19' Dlvaner Lengm t9' Sleeve Length 5-112" Casing Shoe, 15.5#, L-80 BTCM Sat~~ 17101' MD, 3373' ND 4112" 12.8 Tubin9_._ ---- -~ 3.833" J.958"ID ~--~-~'- - i ~f 7" XaSIB"Z%P ~ ~ \ ` r~ `` / Liner Top Packer \~.. ' ~Aacarrlll 1.75" Seal OD ~ =.875"IU 'B' Sand Lateral \ ~ 6-112" tS.6a, Hydra 61II' 15.SM, BTC, 7" %a5/8 Flex Lock ~ 621 L-80 Slotted Liner L 80 Slotted Liner ~ Liner Manpar Liner Hangar I Pxkar Assembly at \ Every Other Jdn[ Every Omer Jdnt 5.112^ EccenWc +4 9200' MD ~ Guide Shoe . \Casinp Sealbora RxePtade , ~ ~\~~ ~ ^ ~ M_ . }r}re~ ~ 1.75"ID - y -~ j~ -_ 1- .. 117 , 9-5/8" Casing Shoe, 40.0#, L-80 BTC ~ 9546' MD, 3573' ND (84 day inc) e Barter Hughaa Swb. Tits document may net De reproduced or d,smaured. ,n whoN or m Parr, in any term or by any means Nectron,c er mechan,cal, including photocoPnng, recording, or DY any inlormation storage and rernevY aYatem now Nown or herealMr invented, wipour wnnen permrss~en Irom Baker Ru9hea Inc. Eauioment Scecifications 5-112" X 9-5/8" HOOK Hanger` Mainbon Drift: 7.00" Mainboro Draft, with diverter: 8.25" Lateral Dria, no diverter or LEM: 4.88" Lateral Drill, w/ diverter, no LEM: 0.50" LaterellMainbore Diverter OD: 8.50" 4112" Lateral Entry Module Mainbon Drih: 3.68" Mainbore Drift, wl isdation sleeve: 250" Lateral Drih, wl coil diverter: 1.00" OD of Divartar and Sleeve:+/-160" Divertar and Skave Length: +l- 19' 5.1/2" Casing Shoe, 15.5#, BTCM Set ~ 17408' MD, 3436' ND Dwa Tlaa: paw,na Ke. 3006 Wesl bale Dual Lateral Completmn - Inleclo, ~~NOVemDei a, 3006 pawns avwgn Kw spa Ne.. '~ Marc D. Kuck 1 • • ~~~~lS~~~~~T~~. L;~~~~~ ~~~~~~I~~ ~~l/LL ~AddE ,rGc~LC ~~~ l3~ G. ! PT®~ 2v(Q -- /SS Development ~ Sers~ice Explorator~~ Stratigraphic Pest lion-Conventional W"ell Cirele Appropriate d.etter !Paragraphs to be dncluded in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES ,r i~LTI LATERAL The permit is for anew-~w+e(Ib~or/e segment of existing i well u- ,l .d~ ' l.~to ~' ~ ~ (If last two digits in '~ ;API number are Peet '~O~ ~~ ~ ~'~ ~ AP[ No. 30- OZ -~~-~. between 60-69) ,Production should continue to be reported as a function of the original AP[ number stated above. PLOT HOLE In accordance with ~0 .~aC 25.00~(t~, al( records, data and logs I 'acquired for the pilot hole must be clearly differentiated in both ; we