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Home My WebLink About202-049 STATE OF ALASKA ALKA OIL AND GAS CONSERVATION COASION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdow n Performed: Suspend fl Perforate fl Other Stimulate n Alter Casing rChange Approved Program Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Scale Inhibitor Treatment Si 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 202-049 3.Address: 6.API Number: Stratigraphic r Service P. 0. Box 100360,Anchorage,Alaska 99510 50-103-20415-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380075 CRU CD2-50 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 11624 feet Plugs(measured) none true vertical 7242 feet Junk(measured) none Effective Depth measured 11624' feet Packer(measured) 7660 true vertical 7242' feet (true vertical) 7103 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 2348 9.625 2385 2381' PRODUCTION 7871 7 7906 7194' RECEIVED AUG 272015 Perforation depth: Measured depth: open hole 7906'-11624' True Vertical Depth: 7194'-7242' i ,j E AOGCC SWOP Tubing(size,grade,MD,and TVD) 4.5, L-80,7783 MD, 7160 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER S-3 PACKER @ 7660 MD and 7103 TVD NIPPLE-CAMCO BAL-O NIPPLE W/WRDP INSTALLED @ 2004 MD and 2000 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 7906'-11624' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 678 904 165 1485 _ 202 Subsequent to operation 641 387 122 1462 202 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Fi Exploratory fl Development F.7 Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil re Gas r WDSPL Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r 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: none Contact Kerry Freedman (a'7,265-6579 Email Kerry.C.Freedman(aconocophillips.com Printed Name Kerry Freedman Title Principal Production Engineer Signature lil.c.c.e . -- Phone:265-6579 Date S 1161 is— ie )-— Form 10-404 Revised 5/2015 RBONieNiG 17 2011 Submit Original Only • • CD2-50 Scale Inhibition Treatment 7/31/15 Hybrid Scale Inhibitor Squeeze Job pumped 7/31/15 from 07:30 to 15:30. LRS= Little Red Services - Initial pressure TBG/IA/OA-278/1486/455 - LRS pumped 135 bbls Diesel/M209/WAW5206 pre-flush at 1-2 bpm,TBG/IA/OA-0/950/466 - LRS pumped 136 bbls Seawater/SCW3001WC scale inhibitor main treatment at 2 bpm, TBG/IA/OA—0/655/697 - LRS pumped 1,466 bbls Dead Oil/M209 over-flush at 2—5 bpm,TBG/IA/OA—0/606/764 Interval treated:7,906' -11,624' WNS PROD 110 CD2 50 C011000Phllli5n((GWeil Attributes Max.Angle&MP A7 TQNamgo UBicai O ., Wellbore APIIUWI Field Name Wellbore Status knot C) MO(ftKB) Act Btm(ftKB) Lr+wxsWlulopc 501032041500 ALPINE PROD 91.22 10,904.92 11,624.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date CD2-50,4/320144:27:08 PM SSSV:WRDP Last WO: 43.93 5/2/2002 Yenical uFaemat c{aauap ... "'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 10,998.0 6/19/2008 Rev Reason:RESET WRDP lehallf 4/3/2014 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WVLen(I...Grade Top Thread I CONDUCTOR 16 14.688 37.0 114.0 114.0 109.00 H-40 WELD ,1=4 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread " SURFACE 95/8 8.921 36.6 2,385.0 2,38111 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 111, PRODUCTION 7 6.276 35.2 7,906.3 7194 0 26.00 L-80 MBTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread OPEN HOLE 61/8 6.125 7,906.3 11,624.0 7,242.4 I 1 I Q Tubing Stnngs 3 Tubing Descript String Ma ID(a) T p(ftKB) Set Depth(ft Set Depth(ND)( Wt(IMB) G ade Top Connecta I TUBING 41/21 39581 3311 778311 715961 1260IL80 IIBTM -4-l --54k compl o Detai[# '° `,' CONDUCTOR;37.0-114DNominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (an) I, 33.1 33.1 0.00 HANGER FMC TUBING HANGER 4.500 2,003.8 1,999.9 0.28 NIPPLE CAMCO BAL-0 NIPPLE 3.812 E..�1, 7,551.9 7,041.8 51.87 SLEEVE BAKER CMD SLIDING SLEEVE w/3.813"BX PROFILE 3.813 WRDP,2,003 8 NIPPLE,2,0038, 7,660.2 7,103.0 58.65 PACKER BAKER S-3 PACKER 3.875 7,664.0 7,105.0 58.87 MILLOUT BAKER S-3 PACKER MILLOUT EXTENSION 4.500 11 7,770.9 7,154.8 66.09 NIPPLE HESXN NIPPLE 3.725 7,782.1 7,159.2 67.16 WLEG BAKER WIRELINE GUIDE 3.958 OtheirIn„Hole(Wirel neiretrievable plugs raIvesa pumps,fish1'etc) t -r Top(ND) Top Incl iiii ii: Top(ftKB) (ftKB) (°) Dec Com Run Date ID(in) 2,003.8 1,999.9 0.28 WRDP 3.813"WRDP(S/N:HRS-72) 5/18/2013 2.125 im li Stulations&Treatments in _ SURFACE:36.6-2,305.0-0 r. 6 . Mln Top Mae Btm Depth Depth TopBtm( (ftKB) (ftKB) (ftKB)KB) 11 (ftKB) Type Date Com 7,909.0 11,624.0 7,194.4 7,242.4 FRAC 3/25/2007 OPEN HOLE FRAC w/16/30 BADGER SAND&16/20 CARBOLITE w/7 ppa,132384#OF PROP IN FORMATION;29250#16/20 CARBOLITE LEFT IN Gns LIFT;3s48s WELLBORE Mandrel Inserts 11 St III ata 00 Top(ND) Valve Latch Port Size TRO Run iiiii iii N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com itt 1 3,948.5 3,862.4 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/21/2007 2 6,014.7 5,706.5 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,693.0 10/27/2009 3 7,441.2 6,965.4 CAMCO KBG-2 1 GAS LIFT OV BK 0.188 0.0 10/27/2009 GAS LIFT,6,014.7 ' Notes:Gene1'ai&Sate 1 I' .( G''.. ,�, t l End Date , Annotation 9/3/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 I GAS LIFT;7,441.2 ,,,i.,:. ,,,;,,:; SLEEVE;7,551.9 i',. ) PACKER;7,6542 im-F.Ui MILLOUT;7,664.0 !IIi. NIPPLE;7,770.9 a C WLEG,7,782.1 PRODUCTION;35.2-7,906.3 FRAC;7,909.0 I OPEN HOLE;7,906.3.11,624.0 Imagt )roject Well History File Cover f- ..1e 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. :l QJ. - 0 !f qWell History File Identifier Organizing (dOli":) R,CAN \9' Color items: Grayscale items: D Two~Sided DlrAL DATA \I Diskettes, No. D Other, Noffype D D Poor Quality Originals: Other: D NOTES: BY: BEVERLY ROBIN VINCENT SHERY~-;~'0'INDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERe,NDY ¡Rescan Needed ... OVERSIZED (Scannable) D Maps: Other items scannable by large scanner D OVERSIZED (Non-Scannable) 0 Logs of various kinds Other 0 ,f , DATE: ftJ J-' ólf Isl DATE:1o ;¡. Dt( Isl ð) ;J /:d f ../Î ~ C~ W~ ~ :r 141° Scanning Preparation Lf-x 30 = /c1D + b = TOTAL PAGES / X' Ú1JJUV r?~ etJciuI PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ES - NO BEVERLY ROBIN VINCENT SHERY~~INDY DATE:iJ . ('1 6lt/SI rVl P BY: BEVERLY ROBIN VINCENT SHERYLBWINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: BY: , n DATE:b ydf/s, BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: DATE: /s/ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECiAl ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) ReScanned (ìm/Í\fidu;J( plg" [.,;{'(~(:ì.ll ,~f10!HhlJ v;,!/nil!~J t:D/Ppll:fOdJ RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Noles or Comments about this file: - YES - NO DATE: /s/ Quality Checked (hll('\ 12/1 OlO2Rev3NOTScanned. wpd v OF Ti t ,few \ I %% s v THE STATE Alaska Oil and as ®fl l Conservation C ission GOVERNOR SEAN PARNELL \= 333 West Seventh Avenue O F Q. Anchorage, Alaska 99501 -3572 ALAS/1'P' Main: 907.279.1433 Fax: 907.276.7542 Robert Blakney Completion Engineer Q ConocoPhillips Alaska, Inc. �� P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2 -50 Sundry Number: 313 -063 SCANNED LIAR 0 6 2013 Dear Mr. Blakney: 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, Cathy P. oerster Chair DATED this i of February, 2013. Encl. RECEIVED STATE OF ALASKA FEB O ALASKA OIL AND GAS CONSERVATION COMMISSION O 01 3 APPLICATION FOR SUNDRY APPROVALS t �'1tJ�i( CC 20 MC 25.280 , HLJ 1. Type of Request: Abandon r Plug for Redrtii r Perforate New Pool f Repair well r Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Ectensiorl r Operational Shutdow n r Re -enter Susp. Well (" Stimulate J . Alter casing r Other: 2. Op erator Name: 4. Current Well Class: 5. Permit to Drill Number. Development - Exploratory ConocoPtnlltps Alaska, Inc. J` P Y r" 202 - 049 ' 3. Address: Stratigraphic E Service (""` 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20415.00 • 7. If perforating, What 8. Well Name and Number. Regulation or Conservation Order govems well spacing in this pool? Mtit planned perforations require spacing exception? Yes I No Fii CD2 - 50 9. Property Designation (Lease Number): 10. Fiekt/Pool(s): ADL 380075. Colvffie River Field / A4aine Oil Pod 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): 11624 - 7242 11624' - 7242' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 2348 9.825 2385' 2381' PRODUCTION 7871 7 7906' • 7194' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole 7909' - 1624' 7194' - 7242' 4.5 L - 80 7783 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER S -3 PACKER ' MD= 7660 TVD= 7103 SSSV - 3.8" WRDP ' MD= 2004 TVD=2000 12. Attachments: Description Summary of Proposal • W 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Stratigraphic I evelopment ? Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2013 Oil M . Gas I WDSPL r Suspended r 16. Verbal Approval: Date: WINJ f GINJ F wAG r Abandoned I Commission Representative: GSTOR r SPLUG I'"" 17. I hereby certify that the foregoing Is true and correct to the best of my knowledge. Contact: Robert Blakney @ 265 -6417 Email: Blikidgakkiled22409999liffiRLill2M Printed Name ¢ y2' Title: Completion Engineer �� Signature Phone: 265-6417 Date 1 Commission Use Only , Sundry Number: 5i 5 J' 3 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance F Other. RBDMS FEB 15 20 Spacing Exception Required? Yes ❑ No 21 Subsequent Form Required: d _ 4a if APPROVED BY `t "/ Approved by: . o vcd application is va � t� !it h s from th T��t� l ry Date: 2 - 1 7 "` 3 Form 10-403 (Revised 10/2012) Y L , Submit Form and Attachments in Duplicate ORIGINAL ;//3/ ;//3�� ,,q. • e .- - p WNS CD2 -50 ConocoPhillips e , Well Attributes Max Angle & MD TD Alaska hE F`" "w", Wellboro APWWI Field Name Well Status Incl(•) MD (0K8) Act 81m (ftKB) c, l 501032041500 ALPINE PROD 91.22 I 10,904.92 11624.0 ' ' Comment 1125 (ppm) Date Annotation End Dale 08.074 (IN Rig Release Date weneenrw'- cpbSO1 I21Plt]glit SSSV: WRDP Last WO: 43.93 5/2/2002 ScMn, 07 -9.Nal Annotation Depth (MSS) End Data y Annolatlon Leif Mod .. End Dale Last Ta9 : 10,998.0 6/19/2003 Rev Reason: WELL REVIEW/TD OSl30r) 10/26/2012 Casing Strings Casing Description String 0... String ID ... Top (MK8) Set Depth (1... Set Depth (TVD(... String Wt... String... Siring Top Thrd CONDUCTOR 16 14.688 37.0 114.0 114.0 10900 H - 40 WELD h AhG[P. 33 = { ? , Casing Description String 0... Siring ID... Top (gK8) Set Depth (f... Set Depth (WO) ... String Wt... Stang... String Top Thrd _ : SURFACE 95/8 8,921 36.6 2,385.0 2,381.1 36.00 J - 55 BTC II ' Casing Description String 0... String ID... Top (MOS) Set Depth (7... Sot Depth (TVD) ... String Wt.. 5tring ... String Top Thrd 11 air 111 PRODUCTION 7 6.276 35.2 7,906.3 7,194.0 26.00 L-80 MBTC 1 Casing Description String 0... String 10_. Top(ftKR) Set Depth (t... Sol Depth(TVD)... Stang Wt.. String... Slang Top Thrd OPEN HOLE 6118 6.125 7,906.3 11,624.0 7,242.4 1 Tubing Strings Tubing Description SIrIng1 O... Slring .... Top (1 Sal Depth(7... Set Depth (TVD)... String Wt... String._ String Top Thrd TUBING ( 4 1/2 I 3.958 5 I 33 1 7 , 7 83.1 l 7,159.6 I 12.60 I L-80 I IBTM Completion Details / top Depth (TVD) Top loci Norni.. l Top (It(B) ORB) (^I gem Description Comment ID (in) CONDUCr.n4 TOR, 33.1 33.1 -0.23 HANGER FMC TUBING HANGER 4.500 0 2,003.8 1,999.9 0.22 NIPPLE CAMCO BAL -O NIPPLE 3.812 E l 7,5519 7,041.7 51.87 SLEEVE BAKER CMO SLIDING SLEEVE w /3.813" BX PROFILE 3.813 0R00, 2.004 1 7,660.2 7,103,0 58.65 PACKER BAKER S -3 PACKER 3.875 tIIPPLE. 2.004 - 7,664.0 7.105.0 58.87 MILLOUT BAKER S -3 PACKER MILLOUT EXTENSION 4.500 7,770.9 7,154.6 66.04 NIPPLE HES XN NIPPLE 3.725 7,782.1 7,159.2 67.14 WLEG BAKER WIRELINE GUIDE 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth ( 5010 ) Top Inc! Top(h /e) (500) (') Description Comment Run Data ID (in) 2,003.8 1,999.9 0.22 WRDP 3.813' WRDP (S/N. HVS -266) 9/13!2011 2.125 SUR:AGE, Al 1 l Stimulations & Treatments 37 - 2585 . - Bottom Idin Top Max 8tm Top Depth Depth ti. Depth Depth (TVD) (ND) (00th (gK8) (gK8) (BRED Type Dale Comment 7,909.0 11,624.0 7,194.4 7, 242.4 FRAC 3 /25/2007 OPEN HOLE FRAC w1 16/30 BADGER SANG & Gns s FORMATION,2 2508 16/20 6 RB LEFT IN WELLBORE Notes: General & Safety End Date Annotation -- 9/312010 NOTE. VIEW SCHEMATIC w /Alaska Schematic9. GASLIIT. BOtS GAS 1:8 c _ 7 631 7 5111550 7,552 1 , _-_--: p PAC21 R. 7CM __ ' -.ate MO UT, IIIVAII esy 1? 8 1.771 1111 I ll Mandrel Details 111. E0 7,782 0 7 Top Depth Top Pon (1V0) Inc! 00 Wee Latch Size TRO Run Sin Top OMB) ( ('I Make Model (In) Sere Type Type (In) (psi) Run Delo Com... 1 3,948.5 3,862.4 26.76 CAMCO K8G -2 1 GAS LIFT DMY BK 0.000 00 3/21/2007 2 6,014.7 5,766.6 26.94 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1,693.0 10/27/2009 3 7,441.2 6,965.0 41.13 CAMCO 080 -2 1 GAS LIFT OV BK 0.188 0.0 10/27/2009 l FR050571011. 357,006 0 • 0 O rPAC HOLE, '. •o 700 HOLE, ist 7.90611 624 T0(1:02.60). • i 1,624 • • CD2 -50 Sundry Application CD2 -50 was completed in June of 2001 targeting the Alpine C formation. The well was completed with 4.5" tubing. Initially hydraulically fractured in March 2007, —130,000#'s of 16/30 Badger Sand was placed. We intend to re- stimulate the Alpine C formation with a single stage treatment placing —300,000#'s of 16/20 CarboLite. If the stimulation is successful we anticipate an increased production of 250 bpd in 2013. Proposed Procedure: Schlumberger Pumping Services: (Alpine C Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10 -403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 7 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10 %. Load tanks with 100° F seawater (approx. 3150 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 8,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 180 bbl breakdown stage (25# linear gel, WF125) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 40 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 40bpm with a maximum expected treating pressure of 2500 psi. Stage 1 • 680 bbls YF125ST Pad • 221 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 442 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 408 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 535 bbls YF125ST w/ 7 ppa 16/20 Carbolite • Flush with 130 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx. 315,000 lbs 16/20 Carbolite 12. Monitor the surface pressure fall -off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). RB • • 15. Foowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) Cement Evaluation of CD2 -50 and wells within' /4 mile of CD2 -50 CD2 - 50: 7" Casing cement job was pumped on 3/16/2002 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.3 ppg brine. The plug was bumped and floats held. CD2 - 42: 7" Casing cement job was pumped on 5/26/2001 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.9 ppg mud. The plug was bumped and floats held. CD2 - 47: 7" Casing cement job was pumped on 11/11/2001 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.6 ppg brine. The plug was bumped and floats held. A pressure test was performed at 3500 psi and held for 30 min. CD2 - 55: 7" Casing cement job was pumped on 7/25/2003 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 8.8 ppg brine. The plug was bumped to 1400 psi and floats held. CD2 - 60: 7" Casing cement job was pumped on 6/30/2005 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.6 ppg mud. The plug was bumped to 1550 psi and floats held. CD2 - 43: 7" Casing cement job was pumped on 1/9/2004 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.8 ppg mud. The plug was bumped to 1500 psi and floats held. CD2 - 40: 7" Casing cement job was pumped on 8/20/2003 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.8 ppg mud. The plug was bumped to 1260 psi and floats held. Full returns were observed throughout the job. CD2 - 05: 7" Casing cement job was pumped on 8/9/2004 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.8 ppg mud. The plug was bumped to 1200 psi and floats held. Full returns were observed during the job. CD2 - 467: 7 5/8" Casing cement job was pumped on 7/25/2008 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.8 ppg mud. The plug was bumped to 960 psi and floats held. Full returns were observed during the job. CD2 - 30: 7" Casing cement job was pumped on 9/3/2003 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement. The plug was bumped to 1500 psi and floats held. RB • • CD2 - 56: 7" Casing cement job was pumped on 9/23/2004 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.8 ppg mud. The plug was bumped to 1150 psi and floats held. Full returns were observed during the job. CD2 - 33: 7" Casing cement job was pumped on 8/24/2001 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement. The plug was bumped to 1200 psi and floats held. CD2 - 41: 7" Casing cement job was pumped on 6/30/2002 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.3 ppg brine. The plug was bumped at 1200 psi and the floats held. The casing was pressure tested to 3500 psi and held for 30 minutes and deemed OK. CD2 - 48: 7" Casing cement job was pumped on 6/7/2002 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced at 5.6 bpm. The plug was bumped at 1000 psi and the floats held. CD2 -58: 7" casing cement job was pumped on 5/30/2003. A 15.8 ppg Class G cement was pumped and displaced with 9.8 ppg mud. Did not bump plug but received full returns. The casing was pressure tested to 3500 psi and held for 30 minutes. Based on the date a competent cement job was achieved. CD2 - 49: 7" Casing cement job was pumped on 1/30/2002 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.6 ppg mud. The plug was bumped to 1600 psi and floats held. Full returns were observed during the job. The casing was pressure tested to 3500 and held for 30 min. CD2 - 32: 7" Casing cement job was pumped on 2/28/2002 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.6 ppg mud. The plug was bumped to 1000 psi and floats held. Full returns were observed during the job. The casing was pressure tested to 3500 and held for 30 min. CD2 - 25: 7 Casing cement job was pumped on 4/15/2002 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.7 ppg mud. The plug was bumped and floats held. Full returns were observed during the job. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a' /4 mile radius or any other nearby well. RB • i Stimulation Surface Rig -Up Tattp 2 k 5 - 1 , ti. Tale Tail a k Q L • Minimum pressure rating on all surface treating lines 10,000 psi i > • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. u w • Y 4 41 1 dhrrd U Pop Of Tags m C C Pump Truck µop v^ft 1 auk cn,4 z ' -^7('`1Dat- CI Hu; Pump f — ' rit,1 Fra:. Pump Frac. Pump N . Ilt•J Frac F unp Fray Pump 1".J Fra; Pump RB ,. . • • • Stimulation Tree Saver OPEN POSITION CLOSED POSITION M , ERA( IRON CONNECTION X < . * ' ' ' t ; „ ' : i sj'' t ' ! Mg REMOTE OFT RATE 0 „, ittti Of itt 3 ),,,,,,,,,,,,,4 „„ ' MASTER VALVE IINIIIIIIIII4 kt910111.1 it ,&0 ) t,Sk , WINUAL OPERA q 0 : T ' ,,,,„, tosiroz VAI VI 1 7 4 11&,\,,e' •:', ‘\ \ ..,, --„. • Stinger Stinger . — ...., MANDREE -..- JIL WLINIE ' - ' i K \ VE NT , Ali Oki .0. Oro ...). .,‘,..., , WM TEE ANC/ , , 4 . VENT VALVE WED I tEA0 VALVES S OPEN 1 N 'Illa / .- f ' ' waLkitAn i VALVES I IXISE 0 Afa ; KM. E IN TUBING TI /RING • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 '/2 tubing and 1.75" down 3 '/2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm RB • CD2- 50 Alpine C Frac Model • F rac Design . 1 stage Job Execution — Step Step Cum. Step Cum. Step Cum. Avg. Step Cum. Name Fluid Fluid Slurry Slurry Prop Prop. Surface Tim Time Ill Volume Volume Volume Volume (Ib) (Ib) Pressure e (min) (gal) (gal) (bbl) (bbl) (psi) (min) PAD 28560 28560 680.0 680.0 0 0 1671 17.0 17.0 2.0 PPA 9269 37829 240.0 920.0 18537 18537 1470 6.0 23.0 4.0 PPA 18586 56415 520.0 1440.0 74345 92883 1329 13.0 36.0 4.0 PPA 17157 73572 480.0 1920.0 68626 161509 1417 12.0 48.0 7.0 PPA 22505 96077 700.0 2620.0 157538 319047 1574 17.5 65.5 Fluid Totals 96077 gal of YF125ST • 9030 gal of YF125ST Proppant Totals 319000 Ib of CarboLite 16/20 Model Results Initial Fracture Top TVD 7145.0 ft Initial Fracture Bottom TVD 7280.0 ft • Propped Fracture Half- Length 270.9 ft EOJ Hyd Height at Well 142.5 ft Average Propped Width 0.483 in • Disclaimer Notice: — This model was generated using commercially available • modeling software and is based on engineering estimates of reservoir properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. � (....L)1-4Y • .:' . .':. 7+44 CD2 : 25' •: 2 i : 6,p1 32P61 + 336 ' ;.,� • : i • GD2 -30 CD'Z =241: I Yr4.:; :� ii +" • • :,.. ............. .,,.:. .......:..... . ., 1:.:,..... '. }... CD2 34P61 :, • \i5Q144P61 • �, , :�:[;:. "" •.,.. CD2 29 1 f • .f - ' : CD -50 PB : ::e0.2 : 34 • T CD1 --+4.,.../ laE • • CD2 -05 : \•••. ,. ><1l,PINE 1 •:D2 -19 � �.:., ; a p2 26 • <�� ??/3•1 * \ r • + 'y • >Y[i2 46 • C[12 -39P61 • . . y • 'craz aop61 • } Legend • • 43PB1 \ CDC Well • Suspended CD2 -50 ll • • 49 ALPINE 1E T P +A • + Service • Producer • • • C m 2 42 : .� L • Observation • • • Injection: S • • ' ` CD ,i-40 ♦ Injection: SAPW • • CD 2 -33A CD2-39 ♦ Injection: PW • i CD2 -464 • CD2- 467RB1 Injection: MWAG ' -+ • ACTIVE, INJ, MG • • `; 4 ACTIVE, INJ, IWAG • • ,/. •" CD2 -38 ACTIVE, INJ, GAS • CD2 470 7 aD2 -41 4 ACTIVE, INJ, DG • NEYE 1 • �' • ACTIVE, INJ, <Null> • • "!CD2 467 C ,D2 -48 ' '• f Disposal • A. A : 1/4 Mile Radius \•,. , • • • D2 -56 02 47 y %'CD2 -58L1 Conoco Phillips Cpl -55 : : yli rte • GD2 -60P61 CD2 -50 Fracture Radius • . ��D 2 -43 t + N CONFIDENTIAL • CD2 -56L1 y • • • A CD4 -304 CD4 -16 i n 025 • • ., ''.\ , • , • • t. A ( Miles • y FracProgram2013.mcd CSR i -10 -2012 • • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 01, 2011 RECEIVED Commissioner Dan Seamount Alaska Oil & Gas Commission tkirrigka & Go Cony. CuilLais$1o1 333 West 7 Avenue, Suite 100 nordufs Anchorage, AK 99501 AMOIF,ND APR 0 8 zoil Aoc Commissioner Dan Seamount: bJ Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped March 13 -15 and March 27 -28, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 04/01/2011 CD2 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD2 -14 50103203900000 2011770 4" n/a 16" n/a 5.4 3/14/2011 CD2 -16 50103204260000 2021440 4" n/a 14" n/a 3.6 3/14/2011 CD2 -17A 50103204060100 2051700 4" n/a 14" n/a 3.6 3/14/2011 CD2 -24 50103203770000 2010950 6" n/a 14" n/a 3.4 3/15/2011 CD2 -25 50103204180000 2020740 4" n/a 14" n/a 3.9 3/28/2011 CD2 -26 50103203970000 2012320 4" n/a 16" n/a 2.7 3/27/2011 CD2 -33B 50103203810200 2011250 4" n/a 15" n/a 2.7 3/27/2011 CD2 -41 50103204240000 2021260 4" n/a 14" n/a 4.3 3/28/2011 CO2 -50 50103204150000 2020490 8" n/a 16" n/a 3.5 3/27/2011 CD2 -51 50103204410000 2022490 510" 0.80 15" 3/21/2007 3.9 3/27/2011 CD2 -56 50103204980000 2041500 SF n/a 15" n/a 3.8 3/27/2011 CO2 -58 50103204570000 2030850 6" n/a 6" n/a 3.5 3/28/2011 CD2 -59 50103205050000 2042480 6" n/a 6" n/a 5 3/27/2011 CD2 -60A 50103205110100 2091150 6" n/a 6" n/a 5.25 3/27/2011 CD2 -74 50103205910000 2081970 10'9" 1.20 9" 3/26/2011 1.7 3/27/2011 CD2 -76 50103206030000 2090980 32" n/a 32" n/a 9.7 3/27/2011 CD2 -78 50103206010000 2090660 6" n/a 6" n/a 1.7 3/27/2011 CD2 -466 50103205760000 2080950 8" n/a 17" n/a 3.4 3/27/2011 1 °R,4/~~f1~/l ~~l L ProActive Diagnostic Services, Inc. To: State of Alaska - AOGCC Christine Mahnken 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 .] ~~~~~ ~~F ~ ~.~ ~DG~S RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the foAowing : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C ~~~-6~lni ~(0~3~ Anchorage, AK 9951$ Fa~c (907) 245-8952 ~ a~ -~ ~ 3 l ~~3 ~ ~1) Depth Correlation 09Sep-08 ~_ CD2-50 Mylar Film / BL / EDE 50-103-20415-00 2) Depth Correlation 10Sep~8 CD2-13 Mylar Film / BL/ EDE 50-1 03-2043 1-00 - ~~ ~t~+ w~wUti+ i~Of lal - ~ - - J ,~ SAP 2 2~~~ Signed : ~- ,~ , ' L--/~~ Dbt~'- . ~!~ Print Name: ~~ ~,f~~ ,.o ~ ~.~,c. ~.~~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : IsdsanchoraaeCa?merrlorvloa.corra WEesITE : www.riterrloryiog.com h C:\Documents and SetGngs\Ownet~Desktop\Transmit_Conoco-doc L 11~1111V I/V{41V A1~1A.VVI~VJ • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, September 15, 2008 10:26 AM To: 'Schneider, Tim S.' Cc: Haas, Jeanne L; Kemner, Maria R Subject: RE: Alpine Scale Squeezes C] Tim, et al, It is acceptable to perform these operations without submitting a sundry. Be sure that the work is documented by submitting a 404 with appropriate attachments. Call or message with any questions. Tom Maunder, PE AOGCC 1 mss., 1 .,1 From: Schneider, Tim S. [mailto:Tim.S.Schneider@conocophillips.com] Sent: Monday, September 15, 2008 9:54 AM To: Maunder, Thomas E (DOA) Cc: Haas, Jeanne L; Kemner, Maria R Subject: RE: Alpine Scale Squeezes ~~~~ ~~~ ~ ~Qa~ Tom, Per our conversation, here is our preliminary list of wells we'd like to perform scale squeezes on. CD2-34 (201-191) CD1-27 (200-006) GD1-35 (199-038) CD1-43 (200-106) CD2-50 (202-049) ~"- We'll incorporate in our plans to submit 10-404's to provide AOGCC with a summary of the treatments: Thanks Tim From: Schneider, Tim S. Sent: Monday, September 15, 2008 9:26 AM To: 'Maunder, Thomas E (DOA)' Subject: RE: Alpine Scale Squeezes Tom, We will be treating the producers: Rough volumes: Producers with watercut < 25% • 60 bbl inhibitor pill (85% MEG, 15% scale inhibitor) • Flush will be with dead Alpine crude (350-450 bbls) • Will attempt to stay below frac gradient (varies from 0.5-0.6) We need to treat as much of the OH as is possible due some GR logs run in August that indicate the presence of Barium scale within the reservoir. This will require that we stay below the frac gradient. Even distribution is the 9iisi2oos A1~1L1V 1JVGLIV 1.J~uVVLVJ L' ~~~-ai, =.,ui ~'~i~~r~i;~. ~i.'y' :ii2a `!v'. ..v' 1;;3r;1.,~_. For a'~rGC~uC'LrS `i?llth '~latercut > ~~~/c ~FV~`ll r2~iaC~ the ~tl~~~ ~filii ~ Se~4ila~~1' aS ~/?i~ a~ t~?L ~?~iS?i. s u~v v va ~. U~le clan to perform ~~ ~~,~ells prior to the ice road season to e~raluafe results and improve upon our prooedures for up to 20 treatments during ice road {dependent on RU time-simops, etc.) The scale inhibitor designs are based on core work done in 2002-2004 to determine a scaie inhibitor that would not damage the Alpine reservoir and we erlere able to identify a product {acrolyte vs. a phosphonate {used at Gi{A}) that doesn't damage the reservoir. Afield test has not been performed, but the scale inhibitor product is currently being used for surface scale management. Hope this helps explain our plans. Let me know if further information is needed. Thanks, Tim From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, September 15, 2008 9:13 AM To: Schneider, Tim S. Subject: RE: Alpine Scale Squeezes Tim, Can you give me an idea of the number of wells, injectors or producers and general procedure? Thanks, Tom Maunder, PE AOGCC From: Schneider, Tim S. [mailto:Tim.S.Schneider@conocophillips.com] Sent: Monday, September 15, 2008 9:12 AM To: Maunder, Thomas E (DOA) Subject: Alpine Scale Squeezes Tom, We are planning to perform scaie squeezes at Alpine to control barium sulfate scale deposition. Our goal will be to inject below parting pressure. Is a 10-403 required to perform these? Thanks, Tim S. Schneider Subsurface Development Staff Production Engineer WNS- Alpine S Phone: 907-265-6859 S Fax: 907-2656472 ~ Mobile: 907-63Z-8136 Email: timsschneiderC~conocophiAips,com 9/15/2008 &;7 ~ r.:: \,., t: I V r:: u STATE OF ALASKA "-/ ~("JU APR 1 9 2007 ALASKA Oil AND GAS CONSERVATION COMMISSION Alaska Oil & Gas C C " REPORT OF SUNDRY WELL OPERATIONS Ancho:ang~ ommlsslon 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate [2] Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [2] Exploratory D 202-049 ~ 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20415-00 / 7. KB Elevation (ft): 9. Well Name and Number: RKB = 33' / C02-50 < 8. Property Designation: ADL 380075 (' 11. Present Well Condition Summary: 10. Field/Pool(s): Colville River Field 1 Alpine Oil Pool Total Depth measured 11624' ( 7242' ./ feet Effective Depth measured feet feet feet Plugs (measured) Junk (measured) true vertical true vertical Casing Structural CONDUCTOR SURFACE PRODUCTION OPEN HOLE Length Size MD TVD Burst Collapse 114' 2333' 7857' 3715' 16" 7" 114' 2385' 7909' 11624' 9-5/8" 6-1/8" Perforation depth: Measured depth: sCANNED APR 2 5 2007 true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7783' MD. Packers & SSSV (type & measured depth) Packer = 7660' SSSV = 2004' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 2294 None 3214 88 15. Well Class after work: Exploratory D Development [2] Service D 16. Well Status after proposed work: Oil [2] GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 307 -056 13. Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Oil-Bbl 3168 4280 Casinç¡ Pressure 1087 1213 Tubinç¡ Pressure 289 319 Daily Report of Well Operations_X WDSPLD Contact Maria Kemner Printed Name ~r' Kemner Title Signature ... ~ Phone dIúUA . Form 10-404 Revised 04/2006 0 R ) GIN A L Production Engineer all / I ~ 265-6945 Date I I <g b-J 7J:;;;;;;0 RBDMS 8Ft APR 2 4 2D07 Submit Original Only ~ "~/ C02-50 Stimulation results: Summary of stimulation job: 3-25-07: Pump frac stages in stair steps; 2, 4, & 7 PPA. Screen out occurred in the ih stage. 1200 bbls total slurry, 20 bbls diesel for freeze protect. AIR-40 BPM, AIP-3800 psi., ISIP-130 psi., 132,384Ibs.16/20 Carbolite and 16/30 White Sand in perfs. Well test: 4/5/07: 4280 bopd, 88 bwpd, 3.2 mmcfpd, 319 WHP . . ~ ConocoPhillips Alaska :/!.ÚR ~; ') !...0 P.O. BOX 100360 ANCHORAGE, AlASKA 99510-0360 ¡J.¡J %f.¡ Æ;iltl t "'i:\Z, ~_~ß1i 'mf 131' !nr~ e'M'i~..,-, .! I " $$!I:Iff lœàlH;/ March 24, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100. '. MAR 2 B 2007 Anchorage, AK 99501 scANNEDi ;»f~-64,q Dear Mr. Maunder: .." ,.". ........ Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG2401 engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on March 21st, 2007. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing tOf of cement. The corrosion inhibitor sealant was pumped in a similar manner March 21 st_ 22n ,2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, \]7# ¡:: Arend- ConocoPhillips W ell Integrity Field Supervisor -~ Attachment . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2007 Initial top of Well Name PTO # cement ft Final top of Cement top off cement date ft Corrosion RG casing filler inhibitor! sealant vol. date al . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2007 Initial top of Well Name PTO # cement ft Final top of Cement top off cement date ft Corrosion RG casing filler inhibitor! sealant vol. date al . ~~~~Œ LID~ !Æ~!Æ~æ!Æ . AI,ASIi& ORAND GAS CONSERVATION COMMISSION SARAH PAUN, GOVERNOR 333 W. 7th AVENUE. SUITE 100 ANCHQRAGE. ALASKA 99501-3539 PHONE (907) 279-1433 F~ (907)276-7542 Maria Kemner Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2-50 Sundry Number: 307-056 ~~ FEB 1 6 2007 _ 0)'" 'Q\{ q ~lxr Dear Ms. Kemner: 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 L!lday of February, 2007 Enc!. . 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0- Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 202-049 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage,Alaska 99510 50-103-20415-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes 0 No 0 CO2-50 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380075 RKB 33' Colville River Field 1 Alpine 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): 11624' . 7242' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 2333' 9-5/8" 2385' PRODUCJJON 7857' 7" 7909' OPEN HOLE 3715' ~ 11624' \" Co \cltJf!r Jl\'-\ Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" L-80 7783' Packers and SSSV Type: Packers and SSSV MD (ft) Baker S-3 Packer Parcker = 7660' Camco BAL-O Nipple SSSV= 2004' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: February 2007 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. 1 h«eby ~Æe '0""0'0' ¡, 'we ao' oo"ect 10 the be" of my ',owled,e Contact: Maria Kemner @ 265-6945 Printed Name Mana Kemner Title: Production Engi~er ¡ It Signature~ II ~ -'II OMILA0J/l Phone 265-6945 Date nz O(j 07- l , Commission Use Only Sundry Number: - () EM Conditions of approval: Notify Commission so that a representative may witness ~7 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: ~~ RBDMS BFt FFB 1 6 2007 Subsequent Form Required: APPROVED BY Date: ~ -It{-()r Approved by: ER THE COMMISSION Form 10-403 Rer¡ Irh AL( V Submit in Duplicate /~ Þ . J ~D ~ ./1'.7 1'1 . [) 7S .1../1 ~ RECEIVED STATE OF ALASKA k ALASKA OIL AND GAS CONSERVATION COMMISSION . ~~"V\ FEB 0 8 ZUO 1 APPLICATION FOR SUNDRY APPROV A~18ska Oil & Gas Cons. Commission 20 MC 25 280 1:< \N 'l . . Overview: ./ C02-50: A hydraulic fracture treatment will be performed in the openhole horizontal section to establish communication vertically and longitudinally through the Alpine "C" sand. This will increase the wells production rate and reserves. A coil clean out will only be performed should it be necessary post-fràc. Procedure: 1. MIRU seven clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10%. Load tanks with seawater from the injection system (approximately 2500 bbls are required for the treatment) 2. Rig up Dowell equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 3. Pressure test surface lines to 9500 psi 4. Pump the 100 bbl Breakdown with Dowell's YF125ST fluid system. Bring pumps up to maximum rate ASAP. ..... F"">.. \ ß" \\ .~. L? r---'"'t ~ \ '-.J ~"'" \J~ ct..... ~ v 'M.;, \^~ ~ \ v'-S- 5. Pump the following schedule at 30 BPM with a maximum pressure of 9000 psi, add breaker as per lab results. Maintain 3000 ri : the IA during t~e treatment. · 300 bbls YF125ST Pad ç>vb\'\:"':>~~ \0~\~ \:,\,,)">\ "'><ÖOOO~~'\ · 240bbrs YF125ST ",,72 ppà 16/30WhitèSand · 480 bbls YF125ST wI 4 ppa16/30 White Sand · 1000 bbls YF125ST wI 7 ppa 16/30 White Sand · Flush with linear YF125ST and freeze protect Total Sand: -310,000Ibs. 6. Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 7. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. FCO if required with slick diesel. e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ~, /~ J I]\I'1'J... tj -\~~ ~ DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020490 Well Name/No. COLVILLE RIV UNIT CD2-50 Operator CONOCOPHILLlPS ALASKA INC >fJ ~ f'lt.,\. ~ À.- API No. 50-103-20415-00-00 MD 11624 /' ìVD 7242 ~/ Completion Date 5/2/2002 ...--> Completion Status 1-01L Current Status 1-01L UIC N ----------- - ~- ------- -------~--~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~---- ---- - -- -- ~----------- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Logl Electr Data Digital Dataset Log Log Run Interval OHI -- Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments klog--~--~----- Density 25 Blu 1 2395 7927 Open 8/6/2002 r e, Log Neutron 25 Blu 2395 7927 Open 8/6/2002 {-(óg Induction/Resìstivity 25 Blu 2395 7927 Open 8/6/2002 I ~ Gamma Ray 25 Blu 2395 7927 Open 8/6/2002 ~ C ¿, 11395 See Notes 114 7927 Open 12/13/2002 Digital Well Logging Data I Rate of Penetration, Dual Gamma Ray, i Electromagnetic Wave ~D Resistivity C :" ,J1394 See Notes 114 11624 Open 12/13/2002 Digital Well Logging Data I Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity I-f--fD D v11602 See Notes 9300 1 0095 Case 1/21/2003 Flow Back Profile ~g See Notes 5 8M 9300 10095 Case 1/21/2003 Flow Back Profile ~ LR> D Directional Survey 0 637 Open 5/24/2002 PB1GYRO V-°g Neutron 25 Blu 2395 7927 Open 8/6/2002 ;1!6 C ~050 See Notes 2395 7927 Open 8/6/2002 RWD - MPRlNEU/DEN/GR I . . Directional SUrveY 0 7927 Open 5/24/2002 :'«pt PB1 4£ó D 01183 LIS Verification 2354 11582 Case 1 0/15/2002 : tRpt LIS Verificàtion 2354 11582 Case 10/15/2002 ~ 25 Blu 2395 7927 Open 8/6/2002 ~t LIS 2354 7886 Case 10/15/2002 PB1 ~ Directional Survey 0 637 Open 5/24/2002 PB1GYRO 1__._- ---~-- Permit to Drill 2020490 MD 11624 ~ -~~ --- - - - -------- -"+'(og i ~ \.Æóg t-EO D 'la1i t'J-g) \l..é6 ~g c/log D D "- ------ - -----._- Well Cores/Samples Information: Name DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Well Name/No. COLVILLE RIV UNIT CO2-50 . Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20415-00-00 TVD 7242 Completion Date I nduction/Resistivity Directional Survey Gamma Ray Directional Survey 5/2/2002 Completion Status 1-01L 25 Blu 25 Blu Current Status 1-01L 2395 7927 Open 8/6/2002 6756 11624 Open 5/24/2002 2395 7927 Open 8/6/2002 6756 11624 Open 5/24/2002 2395 7927 Open 8/6/2002 0 7927 Open 5/24/2002 PB1 UIC N LIS Verification Directional Survey 01184 LIS Verification 2354 7886 Case 10/15/2002 PB1 2395 7927 Open 8/6/2002 2395 7927 Open 8/6/2002 ~ Gamma Ray Density 25 25 Blu Blu Interval Start Stop Sample Set Number Comments Sent Received Well Cored? ADDITIONAL INFORMATION yÁN) Daily History Received? &)N &/N Chips Received? Analysis Received? -_.----" -- ---~--- ..,-rn- Formation Tops ~ Comments: ----- ~-- ------------ ~ -----------. - ----- ------ --- -------- Compliance Reviewed By: ¡ JuvYV.- Ç{~ \. ( ~ Date: Ðo:9 - J.l~ Annular Disposal during the second quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-10 9972 100 0 10072 388 21204 31664 March April 3S-21, 3S-08, 3S-23 2003 2003 lC-22 21553 100 0 21653 0 27044 48697 March May 1C-190, 1C-174, 1C-178, 1C-19 2003 2003 Puviaq #1 5063 100 0 5163 0 4731 9894 March April Puviaq 1 ) 2003 2003 CD2-46 31393 100 0 31493 371 0 31864 April May 2003 CD2-51, CD2-12 2003 3S-16 31006 100 0 31106 357 0 31463 April May 2003 3S-23,3S-17,3S-06,3S-16 2003 Hansen 1 47382 100 0 47482 0 67796 115278 January June 2003 Hansen, Hansen 1A 2002 lC-19 31325 100 0 31425 0 0 31425 May 2003 June 2003 1C-184, 1C-170, 1C-172 3S-08B 31610 100 0 31710 290 0 32000 May 2003 June 2003 3S-24,3S-03,3S-19 CD2-19 30860 100 0 30960 377 0 31337 May 2003 June 2003 CD2-58, CD2-52 CD2-41 3900 100 0 4000 377 0 4377 June 2003 June 2003 CD2-20 3S-17A 4559 100 0 4659 361 5020 5020 June 2003 June 2003 3S-19 Total Volumes into Annuli for which Disposal Authorization Expired during the second quarter 2003: \ Freeze Protect Total Volume Start End Source Wells ) Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-17 17709 100 0 372 18181 Open, Freeze Protected May 2002 Feb 2003 CD2-08, CD2-48, CD2- 46 CD2-32 31337 100 0 379 31816 Open, Freeze Protected June 2002 July 2002 CD2-19, CD2-41, CD2- 23 CD2-S0 31530 100 0 370 32000 Open, Freeze Protected July 2002 Sept 2002 CD2-41, CD2-38 ID-ll 32102 100 0 235 32437 Open, Freeze Protected May 2002 June 2002 1D-103 lC-18 32251 100 0 373 32724 Open, Freeze Protected June 2002 July 2002 1 C-1 04 ) ) ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 'I \ \ ~ S.. ()~~,___i :JCD-'''' ) " DEPTH VOLUME TYPE SACKS ----"-'-'----- BBlS Cement CD1-1 2.25' 0.3 WI 1.8 CD1-2 4' 0.6--- WI '----i6- CD1-3 10' 1.4 MI 8.5 "-"- CD1-4 7.33' 1 P 6.0 CD1-5 4' 0.6 MI 3.6 CD1-6 10.42' 1.4 GI 8.5 CD1-16 14.33' 2 WI 12.1 CD1-17 8.75' 1.2 P 7.2 CD1-21 13' 1.8 MI 10.9 -"._----' ------- -.-----. CD1-22 1.83' 0.3 P 1.8 ,----,",,----",------"-------,,""--"'---'-"'--- .- .-.--.-.-.. ---_._._.~--- CD1-23 15.42' 2.1 MI 12.7 CD 1-24 -------"-----2-ï-"---- 0.3 P 1.a- - ----~- CD1-25 5.66' 0.8 P 4.8 -.- ------..,.--. .,--- ----- dOC:r~ c.o CD 1-27 --,---~-~:!3_~~,---,-----_-.?:~- P - ! 5. 7 CD1-28 6.75' 1 P 6.0 -- -----.,--.--.-..-.----.------ ------~ ..'~._----- \~~-'oy. _<2QJ_-=~~---------~-~~-~' .1.2 P 7.2 JaQ'-~~3 _ÇD1-3j_____-~J&~~--- 5.7 P -------~-~~~----- , .- -,-- ~t;c:c\\) CD1-36 16.75' 2.3 WI 13.9 ~'-'-'._'--'--'-' -----_._-_."-----~--'- -------. --_.,._--._~_. -..." JC$J'-OO~~ - __g9J -~~--------_?:_?~----,______9~~__- --______e 3.0 - \,=\ ~- \ \<; -~g1-4.~_.--?~~:_--,-------Q:?_____~L______------_i:§-- d~.-~~~:\'~ CD2-1~__q,____J_1~~~___----_.!:.~____-'.NJ 9.7_- J~if-\\d I d$~\ ---~g~~--_!I{~,____~;L____L==~~~:Þ~~ - J~-~~) --ÇQ~.:?_?_-- ,_J~._~~--______1_:.?___--_!!:!J_JP..:~..- död~~ \-\ : -Ç"Ç>..?.:?~_____?I:_~?~_------~..? P ---- -------~~L- ~ JD\ -:ð~") _CD~~?'§__.__1Q..:1_?~___---- 1.4 _1~.~__._---_JJ.5 ;}Q~d J-O\ -\)i:¡ --~g~~;~-_:-_:~r~=:--:::==t~-=--='~~==-::_:=iL dó- -\ '=\ \ to _gg?-34__- --- 4' ----~~ P __3.?- ~()'6d- JOd-:\'J-- - g~~~~ --V~4~~-- ___\6 ,~------H- d-O d ðOd" \0 ~.=-~-Çþ?~~?==- ~-_~_~fõ :-~3~ .:~~ '--~-~~~t4_-=~=~-~~-~=_J~~-=~~~~-~=-_:_~~:_5=~_-~~ ':)0\ -- d'~ -__C.Q?=1~__- --~~~~~----------_!.._~---__.___I~~____-------_.?~?_-- ; d D d-\)~ CD2-50 1.66' 0.25 P I 1.5 WEllS \~<;,-\~O ;~O-~\~ \<\c,- 'ð~ ! : ;y::{)-O'is 3» \ ~<;-ùC;L\ : I ;)ÙO'. \4 ç dO\-OÙ\o : \~ ')- ),S:), ,Sc;.-()<o-3> JOD... \ \ Ù \ ~~-bð (.. d c::j:)'~~~ ~ d aC)- \"- " ~ d-O \ -- \ d- '--\ ~\ - \ ð 5 ) ConocJP'hillips Alaska ) P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. In the fall of 2002, CD 1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16t11, 2003. Dowell- Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender. The cement was pumped via high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The blender/pump and hose worked down the line, filling the identified wells until the list was completed. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, JelT)' Dethlefs ConocoPhillips Problem Well Supervisor Attachment Alpine Cement Top Fill ) Subject: Alpine Cement Top Fill Date: Wed, 23 Apr 2003 17:38:26 -0800 From: "Jerry C Dethlefs" <Jerry.C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n1617" <n1617@conocophillips.com> Tom: Attached is a letter and spreadsheet with the data mentioned in the previous email. Thanks for the relief on all the Sundry's! Let me know if you need additional information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska(See attached file: AOGCC ALPINE cement top outs 04-16-03.xls)(See attached file: Cement Top Fill AOGCC Letter 04-23-03.doc) Tom Maunder <tom_maunder@admin.state.ak.us> 04/23/2003 12:51 PM To: Jerry C Dethlefs/PPCO@Phillips cc: Subject: Re: Sundry's for topping off cement Hi Jerry, I agree Jerry that individual404's aren't necessary. Send a "global document" with the information you list. There should also be some sort of introduction that describes why you did what you did and how you did it. Tom Jerry C Dethlefs wrote: > Tom: Last week we had a cement crew go down the line at Alpine, top filling > the conductors with cement. I believe 34 wells were treated. Chuck Scheve > and John Crisp were notified but declined to witness when we told them what > we were doing. Some time past we had agreed to submit a 10-404 for this > kind of work. Due to the number of these, is a 10-404 needed on each well? > I don't want to commit the time to doing this if it is not necessary; > 10-404's are time consuming to prepare. Would a list ofthe jobs suffice, > or something similar? We have the well numbers, depth to cement top, and > sacks used to fill the void. My proposal would not affect future > submissions of 10-404's for this work. What do you think? Thanks! > > Jerry Dethlefs (See attached file: tom_maunder.vcf) 1 of 2 4/24/20037:55 AM Alpine Cement Top Fill ) ) . "ó.w.-.. "....----""" f ,'..v '.I ,.' ._,.._.vw-.' II.." " n" Name: AOGCC ALPINE cement top outs 04-16-03.xls ~AOGCC ALPINE cement top outs 04-16-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 ......,.......................,...".............................."'''''0''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''"""""",,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,""""'"................................,..................................""""'"''''''''''''''''''''''''''''''''''''''''''''''''''''''''''.................................,.........................-..................."""'''''''''''''''''................"........................................ \ .. '," .. -. . ,., ',\ .\'I.v. .\T""- 'A." '" "\' \, " L ""'W!','I','."Io'. kl""''''' /, .\.' ." A'A " ow Name: Cement Top Fill AOGCC Letter 04-23-03.doc DCement Top Fill AOGCC Letter 04-23-03.doc Type: WINWORD File (application/msword) Encoding: base64 ^ ^ _\ V vr ^ -~ . \W ^ \". ". -, III"'. M ,.w..",.' v '1..1 V.- "'M wv;..\ v v."'.", V.(¡ ;,\_, ".,,- .\/, " i. ^' Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2of2 4/24/2003 7:55 AM ids ~ II- ) Wl:LL LOG TRANSMITTAL ).,i ',I'U ~ ,I'¡.:,.. '~f If d~ oL/q II Co °d L'¡ 2003 ProActive Diagnostic Services, Inc. Ai(~s~a OJi~ {~{ (;Œ]Sd To: AOGCC 333 West 7th Ave. Ste. 1 00 Anchorage, AK 99501-3539 "" RE: Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUE LINE Open Hole 1 CD 02-50 11/14/02 Res. Eva!. CH 1 1 1 Mech. CH Caliper Survey 1 Rpt or 1 Color Signed: dm. IJ~ Date: Print Name: PRoAcTivE DiAGNOSTic SERViCES, INC., } 10 K STREET SUiTE 200, ANC~ORAGE, AK 99~01 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage@memOIylog.com Website: \vww.memorylog.com ) a o~- 0<-/ 9 113gLj P6/- 113'15 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 October 2, 2002 RE: MWD Formation Evaluation Logs - CD2-50 + PBl, AK-MW-22042 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AI( 99518 1 LDWG formatted CD Rom. API#: 50-103-20415-00, 70. ~~ IrS-C~1 . 11 Vt> '~~~ " ~C 1 C:D q:. . . J ., ( ~ G'.- . <a..?':J ~'\ "'< ..ð..,. ~~\.... ''''1.~~ Yl¡~; . . ~ ~'lJ¡,.. $IIR.. . .'V~~ J :J- a ~ Kuparuk and Alpine Annular Disposal during the third quarter of 2002: () h(l) h(2) h(3) Total for Freeze Previous Ñew Start End Source Wells Well Name V olumè Volume Volume Quarter Protect Total Total Date Date Volumes CD2-32 12701 100 0 12801 379 18636 31816 June 2002 July 2002 CD2-19, CD2-23, CD2-41 CD2-50 31530 100 0 31630 370 0 32000 July 2002 Sept 2002 CD2-41, CD2-19, CD2-16, CD2~38 IC-IS 27969 100 0 28069 379 4276 32724 June 2002 July 2002 1 C-1 04 ) CD2-39 1966 100 0 2066 379 27500 29945 Oct. 2001 Sept2002 CD2-15, CD2-47, CD2-44 CD2-15 10459 100 0 10559 371 20722 31652 March Sept 2002 CD2-50, CD2-25, CD2-44 2002 CD2-26 13802 100 0 13902 380 0 14282 Sept 2002 Sept 2002 CD2-38, CD2-44, CD2-29 Cook Inlet Annular Disposal during the third quarter of2002: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes Hansen #1 52255 100 0 52355 0 14869 67224 January Sept 2002 Hansen #1 2002 ) Total Volumes into Annuli for which Disposal Authorization Expired during the third quarter 2002: Freeze Protect Total Volume Start End Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-24 33524 100 0 375 33999 Open, Freeze Protected July 2001 Oct 200 1 lC-26 34160 100 0 0 34260 Open, Freeze Protected August September 2001 2001 2N-332 31453 100 0 325 31878 Open, Freeze Protected August 2001 Sept 200 1 lC-16 32017 100 0 0 32117 Open, Freeze Protected Sept 2001 Oct 2001 Source Wells CD2-33, CD2-39, CD2- 14, CD2-15 lC-123, lC-119, lC-102 2N-348, 2N-350 lC-102, lC-131, lC-125 ~ECE1VED OCT 2 4 2002 Alaska Oil & Gas Cons. Commlssiofl Anchorage ) aOc3-0Y9 I J I ~3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West i~h Avenue, Suite 100 Anchorage, Alaska. 99501..3539 October 11, 2002 RE: MWD Formation Evaluation Logs - CD2-50, AK-MW-22042 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20415-00. ~~ RECE'VED OCT 1 5 L002 Aiuka Oi\ & Gas Cons. CommiS8ion Anchoflge ,) ) doa-oL/ 9 / I J<6i WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 October 11, 2002 RE: MWD Formation Evaluation Logs - CD2-50 PBl, AK-MW-22042 The technical data listed below is being subnutted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Dtilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20415-70. ~~ RECEIVED OCT 1 5 2002 AI_a or¡ & Gas Cons. Commi88ion And1or8ge ) Transmittal Form INTEQ ) r&l. BAKER HUGHES Anchorage GEOScience Center AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 To: Attention: Lisa Weepie Reference: CD2-50PB1 II Contains the following:-~~~~---~~~-il 111. II I; 1 LDWG Compact Disc ¡ (Includes Graphic Image files) I ¡ 1 LDWG lister summary I,i. ¡ 1 blueline - MPR Measured Depth Log I 1 blueline - MPR TVD Log 1 blueline - DensitylNeutron Measured Depth Log I' I 1 blueline - Density/Neutron TVD Log I ¡ II i Ii -==_0:::=:::::::::::::==='::===::::-"::::::::::::::-'::-.':::::::::.=::'::::::=':::=--------_._---___.Jl I II ,I I I L-~~c ~~b#: 270765 Date: July 31,2002 , Sent By: Gle~~e~ Received BC ~ (~ OQL r<, ) Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Õ?Od-Ol/9 I L__~UT'~' '""~~:~:-I 1.'.'.'."."."',:;';":,::~";:i;;.~:'~~I-..'."'.- I ""-',',.' ,IIU'III' "" ,*,~I ...~ "'~ I(tW ¡,' ,.,., "'., ....... :INMO'~, ~, ~,,'.,!1 !I't'II.(.: . -., "... ... ~ ... ,w."' n~ '¡'~'.. ,--------------------------..--- :::.. =-- . . r r :~',':,~"'" l . i :::~:'I~~ , ....I,.,.."," i----------~~:_----_:.._------------- ~ft: .:~'v,:'_n ,.~ RECE\VED .' Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 t,UG 06 2002 .~ ~,- - -- -.-> Ai_a Qii & Gas Cons. Com_ion Ancttorag6 ') ") <'~ . , ..m~m PHilliPS Alaska, Inc. ~ A Subsidiary of PHilLIPS PETROLEUM COMPANY . Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 July 10, 2002 Commissioner Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD2-50/CD2-50PB 1 (202-049) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD2-50. If you have any questions regarding this matter, please contact me at 265-6120 or Vern Johnson at 265 -6081. Sincerely, ~L -( Ot( G. C. Alvord Alpine Drilling Team Leader P AI Drilling GCNskad RECE\\IED ,--IUL 1"' 2002 Alaska Oil & Gas Cons. CommISSIon Anchorage OR... ~r\~'l\L ,,\ Ll ~ ¡\Jt.., ) STATE OF ALASKA ") ALASKA OIL AND GAS CONSERVATION COMtvL . ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Oil 0 Gas D 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface Suspended D Abandoned D Service D 2063' FNL, 1503' FEL, Sec. 2, T11 N, R4E, UM At Top Producing Interval 1553' FSL, 2219' FWL, Sec. 2, T11N, R4E, UM At Total Depth 1853' FNL, 1357' FEL, Sec. 11, T11N, R4E, UM (ASP: 371797,5969223) 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. RKB 33' feet ADL 380075 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. March 6, 2002 April 29, 2002 May 2, 2002 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 11624' MD 17242' TVD 11624' MD I 7242' TVD YES 0 No D 22. Type Electric or Other Logs Run G R/Res/Dens/Neut 23. (ASP: 371733,5974294) (ASP: 370148, 5972658 ) "¡',.,, - .'''' ."i1N'I.'~ t~~',.} ,~'\. ~,"'""\¿~'W~ ~ I'"."I~~Á Z:r . -' \: \ ii" -- (.,~"":....,. _f....~,.,....~". ,,'... J "".,-.' . i r... \, t, Ii.. ." -;" " ~. ". l ~..'UHI~ L.t ¡ ; i.~'%:Ji Æ 2/!}' ~:l ~ ~ . , L '.- ~. ~ ~Vi1il~"~_r.:lI',~~IL~~~~~ Classification of Service Well 7. Permit Number 202~049 I 8. API Number 50-1 03-20415~00 I 50-1 03-20415-70PB 1 9. Unit or Lease Name Colville River Unit 10. Well Number CD2-50 I CD2-50PB1 11. Field and Pool Colville River Field Alpine Oil Pool 15. Water Depth, if offshore 16. No. of Completions NI A feet MSL 1 20. Depth where SSSV set 21. Thickness of Permafrost SSSV @ 2004' 1556' GRADE H-40 J-55 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 2385' Surface 7909' CEMENTING RECORD 10 cu yds Portland Type 3 336 sx AS III Lite, 228 sx Class G 150 sx Class G CASING SIZE 16" WT. PER FT. 62.5# 36# 26# HOLE SIZE 42" 9.625" 12.25" 7" 8.5" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE open hole completion 26. AMOUNT PULLED CO2-50 PB1 cement plug dressed off to 6750' to start CO2-50 sidetrack TUBING RECORD DEPTH SET (MD) 7783' 4.5" PACKER SET (MD) 7660' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Plug #1: 7344' - 7922' 195 sx 15.8# Class G Plug #2: 7435' - 6750' 338 sx 17# Class G 27. Date First Production May 22, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil Production for OIL-BBL GAS-MCF 1546 714 OIL-BBL GAS-MCF 4266 2973 CORE DATA 5/23/2002 7.7 hours Flow Tubing Casing Pressure press. 405 psi 674 28. Test Period> Calculated 24-Hour Rate> WATER-BBL 0 W A TER-BBL 0 Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE CHOKE SIZE 96% OIL GRAVITY - API (corr) not available GAS-OIL RATIO 697 Rtl~EI\/E[) II Ii 'I 'j 200? '- '- - L.' Alaska OB & Gas Cons. LO:'ili¡¡¡SSIÙ¡ ,Anchora08 Submit in duplicate RBDMS BFl JUL I 2 2002 Gr:: 29. ') 30. ') FORMATION TESTS GEOLOGIC MARKERS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME CD2-50 Top Alpine D Top Alpine C Base Alpine 7759' 7807' 7958' 7150' 7168' 7200' CO2-50 PB1 Top Alpine D Top Alpine C 7615' 7634' 7148' 7165' R F (~ F , \1 F D ".I "I}" L.., \." ,""'" 11 :r1 "-,,, ."1':' q " I' ;,,¡¡ n n !. I LUUt: "- 'I..J....... Alas'!<a Oii & Gas Gons. Commission Anchorage 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Vern Johnson 265-6081 Signed ft:i--'( O{¡¡( Chip Alvord Title Alpine Drilling Team Leader Date 7/1 f ( ( 2...,- Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ~I 'II. ' ~" f~r li~ ~ ) Page 1 of 9 PHILLIPS ALASKA INC. Operations ßummary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/5/2002 3/6/2002 3/7/2002 CD2-50 CD2-50 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub From"" To HoursCbde Code Phase 11 :00 - 13:30 2.50 MOVE MOVE MOVE 13:30 - 14:30 1.00 MOVE MOVE MOVE 14:30 - 18:00 3.50 MOVE MOVE MOVE 18:00 - 19:00 1.00 MOVE MOVE MOVE 19:00 - 19:30 0.50 MOVE MOVE MOVE 19:30 - 23:30 4.00 WELCTL NUND SURFAC 23:30 - 00:00 0.50 DRILL PULD SURFAC 00:00 ~ 01 :00 1.00 DRILL PULD SURFAC 01 :00 - 01 :30 0.50 DRILL OTHR SURFAC 01 :30 - 02:00 0.50 DRILL SFTY SURFAC 02:00 - 02:30 0.50 DRILL PULD SURFAC 02:30 - 04:30 2.00 RIGMNT RGRP SURFAC 04:30 - 05:30 1.00 DRILL PULD SURFAC 05:30 - 00:00 18.50 DRILL DRLG SURFAC 00:00 - 05:00 5.00 DRILL DRLG SURFAC 05:00 - 05:30 0.50 DRILL CIRC SURFAC 05:30 - 08:00 2.50 DRILL WIPR SURFAC 08:00 - 09:00 1.00 DRILL CIRC SURFAC 09:00 - 11 :00 2.00 DRILL TRIP SURFAC 11 :00 - 13:30 2.50 DRILL PULD SURFAC 13:30 - 15:00 1.50 CASE RURD SURFAC 15:00 - 18:00 3.00 CASE RUNC SURFAC 18:00 - 18:30 0.50 CEMENT PULD SURFAC 18:30 - 20:00 20:00 - 22:00 1.50 CEMENTCIRC SURFAC 2.00 CEMENT PUMP SURFAC Spud Date: 3/5/2002 End: 5/2/2002 Group: Start: 3/4/2002 Rig Release: 5/2/2002 Rig Number: 19 Description of Operations Nuhook & jack up pit module - move pit & m otor complex ~ jack back rig floor & raise wi nd walls & feet Move rig back off well - remove 20" diverter f/ subbase to CD2-50 & NU - test seal to 40 0 ps i Move f/CD2-32 to CD2-50 - spot rig - level & lower feet & wind walls Jack rig floor into place - spot motor & pit c omplex Hook up electrical lines - steam,air, &water to rig - install safety equip - take on spud mud NU riser ~ turn buckles - flow line - drain Ii nes - mud lines - perform Accumlator functi on test - AOGCC waived wittnessing of test ACCEPT RIG @ 1930 hrs. 3/5/2002 PU BHA #1 equip & tools PU 8" DC & std back in derrick Fill hole wI mud check for leaks Pre spud & safety meeting wI crew MU BHA Work on dynamic brake Continue MU BHA - test mud lines to 2500 p si Spud in & drill 12 1/4" hole If 114' to 2138' TVD 2133' ADT 9.9 ART 7.6 AST 2.3 Drill 12 1/4" hole f/ 2138' to 2395' TVD 239 l' ADT 4 ART 4 Circulate hole clean 13 BPM 1400 psi R&R P i pe Wiper trip f/ 2395' to 1096 I - RIH to 2300' - Safety wash & ream to 2395' Circulate hole clean 13 BPM 1350 psi R&R P i P e Monitor well (static) POOH to BHA - monitor well (static) stand back HWDP LD 8" DC, Pony collar, syab, MWD, motor, & bit - clean up floor Rig up to run 9 5/8" casing - PJSM Run 9 5/8" 36# J-55 BTC casing 55 jts. wI s hoe @ 2385' FC @ 2304' - Baker-Loc first 4 connections - ran 32 bow spring cent. as pe r program LD fill up tool & landing joint - blow down to p drive - MU cement head & lines Circulate & condition for cement job - PJSM Cement 9 5/8" casing - pumped 40 bbls bioz an spacer wI nut plug - 5 bbls water - test Ii nes to 2500 psi - Drop btm plug - 50 bbls Ar co spacer @ 10.5 ppg - Lead slurry (ASL3) @ 10.7 ppg - observed nut plug @ shakers w I 257 bbls lead pumped - pumped down surg Printed: 5/16/2002 1 :28:23 PM ) <'Mï7ùPS'. ~ ') PHILLIPS ALASKA INC. Operations .Sul11maryR~port Page 2019 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-50 CD2-50 ROT - DRILLING doyon1 @ppco.com Doyon 19 C Sub Hours. .. ode Code Spud Date: 3/5/2002 End: 5/2/2002 Group: Start: 3/4/2002 Rig Release: 5/2/2002 Rig Number: 19 Description;of. Operations Date From- To 3/7/2002 20:00 - 22:00 2.00 CEMENT PUMP SURFAC 22:00 - 23:00 1.00 CEMENT PULD SURFAC 23:00 - 00:00 1.00 DRILL OTHR SURFAC 3/8/2002 00:00 - 03:00 3.00 WELCTL NUND INTRM1 03:00 - 07:30 4.50 WELCTL BOPE I NTRM 1 07:30 - 08:00 0.50 DRILL OTHR INTRM1 08:00 - 11 :00 3.00 DRILL PULD INTRM1 11 :00 - 12:00 1.00 RIGMNT RSRV INTRM1 12:00 ~ 18:00 6.00 DRILL PULD INTRM1 18:00 - 18:30 0.50 DRILL TRIP INTRM1 18:30 - 19:30 1.00 DRILL TRIP INTRM1 19:30 - 20:00 0.50 DRILL CIRC INTRM1 20:00 - 21 :00 1.00 DRILL OTHR INTRM1 21 :00 - 23:00 2.00 DRILL TRIP INTRM1 23:00 - 23:30 0.50 DRILL TRIP INTRM1 23:30 - 00:00 0.50 DRILL INTRM1 3/9/2002 00:00 - 00:30 0.50 CEMENT DSHO INTRM1 00:30 - 01 :00 0.50 DRILL DRLG INTRM1 01 :00 - 02:00 1.00 DRILL FIT INTRM1 02:00 - 21 :00 19.00 DRILL DRLG INTRM1 21 :00 - 22:00 1.00 DRILL CIRC INTRM1 e can - 280 bbls total lead vol. - switched 0 ver & pump tail slurry - "G" @ 15.8 ppg - 48 bbls total vol. - Drop top plug wI 20 bbl wa ter fl Dowell swithced to rig pumps & displa ce wI 9.6 ppg mud 161 bbls - Bumped plug w 11200 psi - floats held - CIP @ 2200 hrs. - Full returns wI 120 bbls 10.7ppg cement ret urns to surface RD cement head - LD casing elevators & Ian ding joint Flush 20" stack - Remove diverter line ND 20" diverter system - NU FMC wellhead & test - NU BOPE Set test plug - Test BOPE - pipe ram, blind rams, choke manifold valves, choke & kill Ii ne valves, floor & top drive valves to 250 ps i low & 5000 psi high - Hydril to 250 psi low & 3500 pis high - performed accumlator clo sure test - Witnessing of test waived by Lou Grimaldi AOGCC Pull test plug & set wear bushing Install bails & elevators - rig to LD 5" DP RIH wI 19 stds 5" DP - pull & LD pipe Cut & slip 90' drill line MU BHA#2 -wI Sperry Sun & Baker (LWD) - Orient tools - load RA sources - continue P UI BHA RIH wI HWDP to 1102' Change to 4" tools & RIH to 2240' Establish circulation - @ 11 BIM 2200 psi - 30 rpm - Circulate & condition mud for casin g test RU & test 9 5/8" casing to 2500 psi for 30 m ins. - RD Pull to 1765' - BOP kick drill - PJSM - perfo rm stripping drill - strip in to 1950' Pull back to 1765' - remove dart valve & TI W valve - RIH to 2302' tag top cmt C/O cmt - wiper plugs -Drill FC @ 2304' - dr ill cement to 2339' Continue C/O cement in 9 5/8" casing f/ 233 9' - drill shoe @ 2385' - C/O rat hole to 239 5' Drill 20' new hole f/ 2395' to 2415' - Circula te for F.I.T. RU - perform F.I.T. to 16.1 ppg EMW wI 9.6 ppg mud wI 800 psi - RD Dril18 1/2" hole f/ 2415' to 4917' 14726' TV D ADT 12.4 ART 10.1 AST 2.3 *Changed over to 9.4 ppg LSND mud @ 2415' while dri II i n 9 Pump sweep & circulate hole clean for wiper trip - monitor well (static) blow down top d Printed: 5/16/2002 1 :28:23 PM ~þ ~ ) ) PHILLIPS ALASKA INC. Operations. SummaryRC!P.ort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CO2-50 CO2-50 ROT - DRILLING doyon1 @ppco.com Doyon 19 3/9/2002 3/10/2002 3/11/2002 Sub Gode Phase 21 :00 - 22:00 1.00 DRILL CIRC INTRM1 22:00 - 23:30 1.50 DRILL WIPR INTRM1 23:30 - 00:00 0.50 RIGMNT RSRV INTRM1 00:00 - 01 :30 1.50 DRILL TRIP INTRM1 01 :30 - 02:00 0.50 DRILL REAM INTRM1 02:00 - 00:00 22.00 DRILL DRLG INTRM1 00:00 - 05:30 5.50 DRILL DRLG INTRM1 05:30 - 06:30 1.00 DRILL CIRC INTRM1 06:30 - 11 :00 4.50 DRILL TRIP INTRM1 11 :00 - 12:30 1.50 DRILL TRIP INTRM1 12:30 - 16:00 3.50 DRILL PULD INTRM1 16:00 - 16:30 0.50 DRILL OTHR INTRM1 16:30 - 17:30 1.00 CEMENTTRIP INTRM1 17:30 - 21 :00 3.50 CEMENTTRIP INTRM1 21 :00 - 22:00 1.00 CEMENTCIRC INTRM1 22:00 - 23:00 1.00 CEMENT PLUG INTRM1 23:00 - 00:00 1.00 CEMENT TRIP INTRM1 3/12/2002 00:00 - 00:30 0.50 CEMENTCIRC ABANDN 00:30 - 01 :30 1.00 CEMENT PLUG ABANDN 01 :30 - 02:30 1.00 CEMENT OTHR ABANDN 02:30 - 05:00 2.50 CEMENTTRIP ABANDN 05:00 - 07:00 2.00 CEMENTTRIP ABANDN 07:00 - 09:30 2.50 DRILL PULD INTRM1 09:30 - 12:30 3.00 DRILL TRIP INTRM1 12:30 - 15:15 2.75 DRILL REAM INTRM1 15:15 - 16:30 1.25 DRILL REAM INTRM1 16:30 - 18:00 1.50 DRILL TRIP INTRM1 18:00 - 20:30 2.50 DRILL TRIP INTRM1 20:30 - 21 :30 1.00 DRILL PULD INTRM1 21 :30 - 23:00 1.50 CEMENT TRIP INTRM1 Page 3 019 Start: 3/4/2002 Rig Release: 5/2/2002 Rig Number: 19 Spud Date: 3/5/2002 End: 5/2/2002 Group: r i v e Wiper trip fl 4917' to 2339' (27 stds) hole in good condition Monitor well @ 2339' - static - prep to serv ice top drive TIH f/ 2339' to 4820' Safety wash & ream f/ 4820' to 4917' - pump hi vis sweep Dril18 1/2" hole f/ 4917' to 7494' I 7038' TV D ADT 14.1 ART 12 AST 2.1 Drill 8 1/2" hole f/ 7494' to 7927' I TVD - 74 34' ADT 4.4 ART 4.4 AST 0 Top Alpine 7638 ' MD I 7164' TVD Base 7704' MD Circulate hole clean - 13 BIM @ 3150 psi - R&R pipe - monitor well (static) POOH wI bit # 2 to BHA Pull & stand back HWDP Hnadle BHA - LD flex DC - remove RA sourc es - down load MWD - LD bit motor & MDW's Housekeeping - clear BHA tools f/ rig floor PU 3 1/2" tbg (30 joints) for cement stinger - Change over to 4" tools RIH wI 3 1/2" tbg stinger on 4" drill pipe to 7922' Circulate for cement job - PJSM Set plug # 1 wI stinger @ 7922' wI 195 sxs ( 40 BBLS) "G" @ 15.8 ppg - displace to equal ize - calc top @ 7351' CIP @ 2300 hrs. Pull up to 7344' to circulate Circ @ 7339', 12 bpm, 1650 psi, 30 rpm. RU and test cement lines to 2500 psi. Mix a nd pump 32.5 bbls of 17.0 ppg cement - disp lace to equalization, CIP @ 0130 hrs. Pull to 6676', circ BU @ 12 bpm - 1500 psi, 30 rpm. POH. RU and lay down 30 joints of tubing. Change running tools to 4". MU BHA #3, scribe tools - initialize LWD. RIH to 6900', fill pipe every 2000'. Wash and ream, cleaned out slight cement s tringers 6900' to 7070', CBU, slight cement contaminated mud back. Continue to wash and ream with reduced rat e 6 bpm - 980 psi ~ 20 rpm. Tagged cement at 7400', cleaned out firm cement to 7437'.C BU, displaced hole with new mud. POH to 6030', 25-35k overpull from 6970' to 6860', pump dry job. POH to 2300', monitor well @ shoe, static.P OH stand back hwdp. LD BHA. RU and run 30 joints of 3 1/2" tubing, chang Printed: 5/16/2002 1 :28:23 PM ~ ~ ) ) PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/12/2002 3/13/2002 3/14/2002 3/15/2002 CO2-50 CO2-50 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub Hours Code Code Phase From ...To 21 :30 - 23:00 23:00 - 00:00 1.50 CEMENT TRIP INTRM1 1.00 CEMENT TRIP INTRM1 00:00 - 02:30 02:30 - 04:00 2.50 CEMENTTRIP INTRM1 1.50 CEMENTCIRC INTRM1 04:00 - 05:00 1.00 CEMENT PLUG INTRM1 05:00 - 06:30 1.50 CEMENTOTHR INTRM1 06:30 - 08:30 2.00 CEMENTTRIP INTRM1 08:45 - 10:45 2.00 CEMENTTRIP INTRM1 1 0:45 ~ 12:00 1.25 DRILL PULD INTRM1 12:00 - 13:00 1.00 DRILL TRIP INTRM1 13:00 - 14:30 1.50 RIGMNT RSRV INTRM1 14:30 - 16:15 1.75 DRILL TRIP INTRM1 16:15 - 16:30 0.25 CEMENT OTHR INTRM1 16:30 - 17:30 1.00 DRILL CIRC INTRM1 17:30 - 00:00 6.50 DRILL DRLG INTRM1 00:00 - 21 :00 21.00 DRILL DRLG INTRM1 21 :00 - 22:00 1.00 DRILL CIRC INTRM1 22:00 - 00:00 2.00 DRILL WIPR INTRM1 00:00 - 02:45 2.75 DRILL WIPR INTRM1 02:45 - 03:45 1.00 DRILL CIRC INTRM1 03:45 - 05:15 1.50 DRILL WIPR INTRM1 05:15 - 06:30 1.25 DRILL CIRC INTRM1 Page 4 of 9 Start: 3/4/2002 Rig Release: 5/2/2002 Rig Number: 19 Spud Date: 3/5/2002 End: 5/2/2002 Group: e running tools to 4". RIH with tubing tail below 4" drill pipe to 33 33' @ midnight. RIH with 3 1/2" tubing tail to 7435'. Circ and condition mud 10 bpm 1050 psi 30 r pm. RU and test cement lines to 2500 psi. Mix a nd pump 338 sxs of 17.0 ppg cement, displa ce to equalization, CIP @ 0430 hrs, pulled u p to 6740'. Circ and condition mud from 6740', monitor well, static. POH with 4" drill pipe. RU and lay down 30 joints of 3 1/2" tubing, change running tools. MU BHA #4, scribe tools and initialize LWD. RIH to 2300', shallow test tools. Slip and cut drilling line - service top drive. RIH to 6600', wash down, tagged cement at 6750' . Polish off plug from 6750' to 6820'. Circ and condition mud 12 bpm - 2650 psi - 990 rpm. Sidetrack well and drill 8 1/2" hole to 7077'. Drill from 7077' to 7958', (7200 tvd) casing point. ART=3.5 AST=12.6 Pump 40 bbl 300 FV sweep and circ clean. M onitor well, static. Pump out to 7673', pulled to 6255' 5-15K ov er. Monitor well - static. RIH from 6255', worked through tight spot fr om 7480' to 7490' 35k drag. RIH worked pip e from 7615' to 7630' with 30k drag. Wash d own from 7605' to 7640'- 7 bpm - 1230 psi. RIH to 7660', unable to pass with 30k drag, wash down to 7695'. Pulled up (no pump) 25 k over from 7680' to 7650', 7625' to 7615' 3 0-40k over, pump out to 7605'. RIH from 760 5' 5k drag to 7730 increased to 30k drag. W ash down from 7710' to 7780 and RIH to 795 8' . Circ and conditon mud, 14 bpm - 3750 psi - 100 rpm, increased wt. from 9.6 ppg to 9.8+ ppg. Observed lots of 1/2" to 1" pieces of r ound edged soft shale with first BU, reduced to a few small pieces 2nd BU. Wipe hole to 7200', 5-10k drag, RIH to 9758 , 5-10k drag Pumped 40 bbl 300FV sweep and circ hole cl ean 14 bpm ~ 3750 psi - 100 rpm - minimal a mount of shale back through 1st BU moderat Printed: 5/16/2002 1:28:23 PM ) ~. ~~ ~ ) PHILLIPS ALASKA INC. ..Operations Summary Report Legal Well Name: CD2-50 Common Well Name: CD2-50 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From- To Hours Code Sub . Phase Code 3/15/2002 05:15 - 06:30 1.25 DRILL CIRC INTRM1 06:30 - 11 :45 5.25 DRILL TRIP INTRM1 11 :45 - 13:15 13:15 - 15:30 1.50 DRILL PULD INTRM1 2.25 CASE RURD INTRM1 15:30 - 16:45 1.25 CASE RURD INTRM1 16:45 - 17:00 0.25 CASE SFTY INTRM1 17:00 ~ 19:30 2.50 CASE RUNC INTRM1 19:30 - 20:00 0.50 CASE CIRC INTRM1 20:00 - 22:30 2.50 CASE RUNC INTRM1 22:30 - 23:00 0.50 CASE CIRC INTRM1 23:00 - 00:00 1.00 CASE RUNC INTRM1 3/16/2002 00:00 - 01 :00 1.00 CASE RUNC INTRM1 01 :00 - 01 :30 0.50 CASE CIRC INTRM1 01 :30 - 03:00 1.50 CASE RUNC INTRM1 03:00 - 03:30 0.50 CEMENT PULD INTRM1 03:30 - 04:45 1.25 CEMENT CI RC INTRM1 04:45 - 05:30 0.75 CEMENT PUMP I NTRM 1 05:30 - 06:30 1.00 CEMENT DISP INTRM1 06:30 - 07:00 0.50 CEMENT PULD INTRM1 07:00 - 08:00 1.00 CASE DEQT INTRM1 08:00 - 10:00 2.00 DRILL PULD INTRM1 10:00 - 16:00 6.00 DRILL SUSPEN 16:00 - 19:30 3.50 CMPL TN OTHR SUSPEN 19:30 - 23:00 3.50 CMPL TN NUND SUSPEN 23:00 - 00:00 1.00 CMPL TN FRZP SUSPEN Page 5 of9 Spud Date: 3/5/2002 End: 5/2/2002 Group: Start: 3/4/2002 Rig Release: 5/2/2002 Rig Number: 19 . Description of Operations e increase with sweep back. Shakers clean t hrough 2nd BU. Pump out to 7673', pulled slowly to 7200' 5- 10k drag. Continue to POH to HWDP, no pro blems. Flow checks at shoe and HWDP= stat ic - Stand back HWDP. Down load LWD - lay down BHA. Remove drilling bails from TD - PU wash sub and flush BOP stack. Pull wear bushing an d set test plug. Change top pipe rams to 7" and test 250/5000 psi. Pull test plug - set thin wall wear bushing. I nstall long bails, RU elevators, slips, power tongs and fill up tool. Held safety and opts meeting with crew. Run 7",26#, L-80 casing to 2374'. Circ and condition mud - 7 bpm - 390 psi, P UW 135k SOW 135k. Run casing to 4908'. Circ and condition mud - 5 bpm - 420 psi, P UW 190k SOW 170k. Run casing - 6140' @ midnight. Run casing to 6897'. Circ BU - 5 bpm - 560 psi - PUW 240k SOW 190k Run casing - Mu hanger and LJ- land casing with shoe @ 7948' - FC @ 7862'. Lay down fill up tool MU cement head and break circulation. Stage pumps up to 6 bpm, 550 psi reciproca te pipe and condition mud. POW 270k - SOW 195k full returns throughout - PJSM. Test lines to 3500 psi, pumped 20 bbls of Ar co wash, 50 bbls of 12.5 ppg spacer and 31 bbls of 15.8 ppg cement. Displaced cement @ 6 bpm with 30 bbls of F Wand 271 bbls of 9.6 ppg kcl brine, bumped plugs ~ floats held. CIP @ 0615 hrs. Confir med 9 5/8 X 7" annulus static. Remove cement head and LD landing joint. Pull slim wear bushing, install and test pack off to 5000 psi. LD casing bails - PU drilling bails - LD 5" h wdp from derrick. RIH with 4" drill pipe to 5300' - POH lay do wn drill pipe. RIH with 4" drill pipe, MU tubing hanger, ins tall TWC and land kill string @ 2334'. Test hanger seals to 5000 psi. Change top pipe rams to 4 1/2" X 7" - ND B OP stack - NU adapter flange and tree, test to 5000 psi. Pull TWC. RU to Dowell and test lines to 2000 psi, beg Printed: 5/16/2002 1 :28:23 PM ~~ ~ ) ) PHILLIPS ALASKA INC. . Operatiol1sSUI11 mary ..Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/16/2002 3/17/2002 4/23/2002 4/24/2002 From ..;,. To 23:00 - 00:00 00:00 - 01 :00 01 :00 - 02:00 12:00 - 00:00 00:00 - 04:00 04:00 - 06:30 06:30 - 07:00 07:00 - 08:00 08:00 - 09:30 09:30 - 13:00 13:00 - 16:30 16:30 - 17:30 17:30 ~ 18:30 18:30 - 00:00 CO2-50 CO2-50 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub Hours. CoqeCode Page60f 9 Spud Date: 3/5/2002 End: 5/2/2002 Group: Start: 3/4/2002 Rig Release: 5/2/2002 Rig Number: 19 Description .01 Operations 1.00 CMPL TN FRZP SUSPEN i n p u m pin g die s elf 0 r f r e e z e pro t e c t ion. 1.00 CMPL TN FRZP SUSPEN F r e e z e pro t e c t Kills t r i n g and 7" ann u Ius wit h 64 bbls of diesel. Blow down and Rd lines. 1.00 CMPL TN OTHR SUSPEN 12.00 MOVE MOVE SUSPEN 4.00 MOVE MOVE SUSPEN 2.50 DRILL OTHR SUSPEN 0.50 DRILL OTHR SUSPEN 1.00 DRILL OTHR SUSPEN 1.50 DRILL OTHR SUSPEN 3.50 WELCTL NUND SUSPEN 3.50 WELCTL BOPE SUSPEN 1.00 DRILL PULD SUSPEN 1.00 DRILL TRIP CRCVRY 5.50 WELCTL BOPE INTRM1 4/25/2002 00:00 - 00:30 0.50 DRILL OTHR INTRM1 00:30 ~ 04:30 4.00 DRILL PULD INTRM1 04:30 - 05:30 1.00 DRILL TRIP INTRM1 05:30 - 09:00 3.50 DRILL TRIP INTRM1 Install BPV and secure wellhead and cellar. released rig @ 0200 hours. Blow down water & steam lines - separate pi t & motor complexes - jack back floor - rais e feet& wind walls - move off CD2-25 - Chan ge out BOP's for yearly inspection Move & spot rig over well - set feet & close in sub - mate up pit & motor complexes - mo ve in pipe shed" Accept rig @ 0330 hrs. 41 24/2002 RU to pull BPV ~ Drain diesel in tree - heat tree wI steam - Pull BPV RU to displace freeze protect diesel wI 9.6 ppg brine Clean pit #6 - take on 9.6 ppg brine Test line to 2000 psi - displace freeze prote ct diesel f/ well wI 9.6 ppg brine - blow dow n & rig down lines Set TWC - ND tree - NU 13 5/8 5K BOPE - in stall bell nipple, flow line, turnbuckles, & d rain hoses PU 4 1/2" test jt. & screw into tbg hanger - Fill stcak wI water - RU test equip - Begin t esting BOPE - unable to get low or high pre ss test to hold - checked surface equip - ma de several attempts unsuccessful - assume d TWC leaking - LD test jt. Received permi ssion from AOGCC inspector to pull hanger & kill string & test wI test plug PU landing jt. - screw into tbg hanger - bac k out lock down screws - pull tbg hanger to surface - LD landing jt. & tbg hanger - remo ve TWC Pull & std back 23 stds 4" DP (kill string) Set test plug - test BOPE : Hydril to 250 psi low & 3500 psi high - Pipe rams, blind ram s, choke & kill line valves. choke manifold v alves, top drive manual & auto valves, dart & TIW valves to 250 psi low & 5000 psi high - performed accumalator closure test - pull test plug - set wear bushing - wittnessing of test waived by John Spalding AOGCC Blow down choke, kill, & flare lines MU 6 1/8" BHA - Orient & download MWD - S urface function test PBL sub - tool would no t lock open ~ LD PBL sub RIH wI HWDP - change out drilling jars - PU 33 jts. 4" DP f/ pipe shed RIH to 7735' - tag cmt Printed: 5/16/2002 1 :28:23 PM .) <,~þ ~. ) Page 70f 9 PHILLIPS ALASKAINC~ Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CO2-50 CO2-50 ROT - DRILLING doyon1 @ppco.com Doyon 19 Hours Code.. Sub ... . . .. ..Code Phase 4/25/2002 09:00 - 10:30 10:30 - 11 :00 11 :00 - 12:00 12:00 - 16:00 1.50 CEMENT COUT INTRM1 0.50 DRILL CIRC INTRM1 1.00 DRILL DEQT INTRM1 4.00 CEMENT DSHO INTRM1 16:00 - 16:30 0.50 DRILL DRLG INTRM1 16:30 - 18:30 2.00 DRILL CIRC INTRM1 18:30 - 19:30 1.00 DRILL LOT INTRM1 19:30 - 22:30 3.00 DRILL OTHR PROD 22:30 - 00:00 1.50 DRILL OTHR PROD 4/26/2002 00:00 - 00:00 24.00 DRILL DRLG PROD 4/27/2002 00:00 - 17:30 17.50 DRILL DRLG PROD 17:30 - 18:00 0.50 DRILL CIRC PROD 18:00 - 00:00 6.00 DRILL TRIP PROD 4/28/2002 00:00 ~ 02:00 2.00 DRILL TRIP PROD 02:00 - 03:00 1.00 DRILL PULD PROD 03:00 - 03:30 0.50 DRILL PULD PROD 03:30 - 08:00 4.50 DRILL TRIP PROD 08:00 ~ 09:30 1.50 RIGMNT RSRV PROD 09:30 - 11 :00 1.50 DRILL TRIP PROD 11 :00 - 12:00 1.00 DRILL REAM PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 00:00 - 21 :30 21.50 DRILL DRLG PROD 21 :30 - 00:00 2.50 DRILL CIRC PROD 4/29/2002 4/30/2002 00:00 - 00:30 0.50 DRILL CIRC PROD 00:30 - 07:00 6.50 DRILL TRIP PROD 07:00 - 10:30 3.50 DRILL TRIP PROD 10:30 - 14:30 4.00 DRILL TRIP PROD 14:30 - 15:30 1.00 RIGMNT RSRV PROD 15:30 - 18:00 2.50 DRILL TRIP PROD Spud Date: 3/5/2002 End: 5/2/2002 Group: Start: 3/4/2002 Rig Release: 5/2/2002 Rig Number: 19 Description.of Operations C/O hard cmt fl 7735' to 7792' Circ hole clean RU & test 7" casing to 3500 psi - RD C/O 7" shoe track - hard ctm f/ 7792' - rubb ers plugs & FC @ 7823' - hard cmt to 7907' Drill out FS @ 7907 to 7909' - C/O rat hole to 7958' Drill 20' new hole f/ 7958' to 7978' Pump hi vis brine pill & circ hole clean RU & perform LOT to 12.3 ppg EMW wI 9.6 P pg brine - RD Ship brine to GIS unit - clean pits for OBM - take on 8.7 ppg OBM Displace well f/ 9.6 ppg brine to 8.7 ppg OB M - clean surface equip - flow check - well s tatic - no losses during change over Drill 6 1/8" hole f/ 7978' to 8844' TVD 7213 ADT 14 AST 3.2 ART 10.8 Dril16 1/8" hole fl 8844' to 9554' TVD 7230 ADT- 11.5 AST- 6.8 ART- 4.7 Circ hole clean - monitor well (static) POOH to check bit & motor - Pump out to 76 20' (20 stds) - monitor well (static) continue to POOH on trip tank f/ 7620' to 3899' Finish POOH f/ 3899' Down load MWD - LD bit, motor & turbo back s tab MU bit #5, motor & MWD - RIH to 371' - shal low test MWD RIH wI bit # 5 & BHA # 6 to 7500' - fill pipe every 2000' Service top drive RIH f/ 7500' to 9440' - fill pipe every 2000' Safety wash & ream f/ 9440' to 9554' Drill 6 1/8" hole f/ 9554' to 10230' TVD 72 39' ADT- 8 AST- 1.6 ART- 6.4 Drill 6 1/8" hole f/ 10230' to 11624' TVD- 7242' ADT- 14.7 AST- 1.3 ART- 13.4 Pump sweep - 10 bbl mineral oil & 40 bbls h i-vis - Circulate hole clean 223 GPM @ 110 SPM Circulate hole clean - 5 BPM @ 2500 psi Monitor well (static) - POOH - Pump out f/ 1 1624' to 7314' (45 stds) Continue POOH on trip tank - f/ 7314' to 56 00' - Pump dry job - continue POOH f/ 5600' to 3000' POOH - LD excess 4" DP (84 jts) Monitor we II (static) PJSM - Cut & slip 60' drill line Handle BHA - Std back HWDP & jars - LD N M flex collars - down load MWD ~ LD MWD, motor & bit - clean up rig floor Printed: 5/16/2002 1 :28:23 PM ) ~~ ~ ) PHILLIPS ALASKA INC~ Operations SUrnmary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-50 CD2-50 ROT - DRILLING doyon1 @ppco.com Doyon 19 From- To Hours Code SUb Phase Code 4/30/2002 18:00 - 22:00 4.00 DRILL PULD PROD 22:00 - 23:30 1.50 DRILL CIRC PROD 23:30 - 00:00 0.50 DRILL TRIP PROD 5/1/2002 00:00 - 05:00 5.00 DRILL TRIP PROD 05:00 - 06:30 1.50 CMPLTN OTHR CMPL TN 06:30 - 19:30 13.00 CMPL TN RUNT CMPL TN 19:30 - 21 :00 1.50 CMPL TN RUNT CMPL TN 21 :00 - 22:30 1.50 WELCTL NUND CMPL TN 22:30 - 00:00 1.50 CMPL TN OTHR CMPL TN 5/2/2002 00:00 - 02:00 2.00 CMPL TN NUND CMPL TN 02:00 - 04:00 2.00 CMPL TN FRZP CMPL TN 04:00 - 05:00 1.00 CMPL TN PCKR CMPL TN 05:00 - 06:30 1.50 CMPL TN PCKR CMPL TN 06:30 - 07:30 1.00 CMPL TN OTHR CMPL TN 07:30 - 09:00 09:00 - 13:00 1.50 CMPL TN OTHR CMPL TN 4.00 MOVE DMOB MOVE Page ßof9 Spud Date: 3/5/2002 End: 5/2/2002 Group: Start: 3/4/2002 Rig Release: 5/2/2002 Rig Number: 19 Description of Operations MU 7" casing scraper assembly - RIH to 772 6' Pull up to 7633' - Pump 5 bbls mine rial oil p Ius 10 bbls hi vis sweep - circulate hole cle an - monitor well (static) - Blow down top dr i ve POOH wI scraper 1/ 7633' - 7442' Finish POOH wI 7" casing scraper - LD 12 jt s. 4" Dp, 5 Jts. 4" HWDP & jars Pull wear bushing - RU to run 4 1/2" com pie tion - Held PJSM Run 4 1/2" completion: WLEG, 4 1/2" pup jt , XN nipple, 2 jts. 4 1/2" 12.6# L-80 IBTM tb g, Baker S-3 packer assembly wI mill out ex tension, 2 jt. 4 1/2" 12.6# L-80 IBTM tbg, B aker CMD sliding sleeve wI 3.813 X profile, 2 jts. 4 1/2" 12.6# L~80 IBTM tbg, Camco G LM assembly wI dummy valve, 32 jts. 4 1/2" 12.6# L-80 IBTM tbg, Camco GLM assembly wI dummy valve, 47 jts. 4 1/2" 12.6# L-80 IB TM tbg, Camco GLM assembly wI dummy val v e, 44 jts. 4 1/2" 12.6# L-80 IBTM tbg, Camc 0 SSSV assembly wI 2.25" ID dummy, 45 jts. 4 1/2" 12.6# L-80 IBTM tbg. wI 1/4" control line attached, FMC 4 1/2" tbg hanger - run control line through hanger & test connectio ns to 5000 psi - Land tbg hanger wI tail @ 7 783' - XN @ 7770, Packer @ 7660', Sliding Sleeve @ 7551', GLM # 1 @ 7441, GLM #2 @ 6014', GLM #3 @ 3948, SSSV @ 2003' Run in lock downs on hanger - LD landing jt. A - Set TWC- install landing jt. B ~ test ha nger seals too 5000 psi - LD landing jt ND flow line, bell nipple, turnbuckles, mous e hole, choke line, ND BOPE and set back & secure Hook up SSSV balance & control lines throu gh well head, Test lines to 5000 psi MU & test tree to 5000 psi PJSM - displace tbg & anuunuls wI diesel RU rig lubircator - drop rod/ball to set pack er - RD lubircator - MU hard line Pressure up on tbg to 3500 psi to set packe r - test tbg for 30 mins.- tbg bleed down to 1600 psi & held 1600 psi for last 8 mins. of test - No increase in pressure on annulus si de - packer set - GLM & SS holding - assum e leaking by ball seat - pressure test annulu s to 3500 psi for 30 mins. Vacumm out hard lines - RD down lines and manifold RU FMC lubircator - Set BPV ~ Secure well Move out pit & motor copmplexes - jack floo Printed: 5/16/2002 1 :28:23 PM <~ ~ ) ) Page 9 of 9 PHILLIPS ALASKA INC. Opé.ratiol1s Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 5/2/2002 5/3/2002 CD2-50 CD2-50 ROT - DRILLING doyon1 @ppco.com Doyon 19 Spud Date: 3/5/2002 End: 5/2/2002 Group: Start: 3/4/2002 Rig Release: 5/2/2002 Rig Number: 19 Description.. of Ope rations H. .. .c d. Sub From-To .. ours. 0 e Code Phase 09:00 - 13:00 13:00 ~ 15:00 15:00 - 16:30 16:30 - 00:00 00:00 - 12:00 4.00 MOVE DMOB MOVE 2.00 MOVE MOVE MOVE 1.50 MOVE POSN MOVE 7.50 MOVE OTHR MOVE 12.00 MOVE OTHR MOVE r back - raise feet & windwalls - Move rig of f of CD2-50 - to clean snow for move to CD2 -46 (due to blizarrd) ~ install well gaurd on CD2-45 Move rig over CD2-46 - spot & level rig Jack floor - spot motor & pit complexes Clean mud pit after OBM - Unable to stay ov er CD2-50 to clean pit - Needed to move rig to remove snow from Phase 2/3 conditions t 0 be able to move on CD2-46 Will release r ig f/ CD2-50 & Accept @ CD2-46 when pits a re cleaned Continue cleaning mud pits and rig f/ OBM Release Rig @ 1200 hrs. 5/3/2002 Printed: 5/16/2002 1 ;28:23 PM = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00130 Sidetrack No. Page --=----- of 4 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: 19 Field ALPINE FIELD Well Name & No. PAD CD#2/50 PB1 - 50 SUNey Section Name Definitive SUNey BHI Rep. C MILCHAK INTECI WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -2062.81 Grid Correction 0.000 Depths Measured From: RKB ~ MSL D SSD Target Description Target Coord. ENJ Slot Coord. E/W -1501.69 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 1 OOft~ 30mD 10mD Vert. Sec. Azim. 231 .92 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA SUNey SUNey Inc!. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (per 100FT) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 06-MAR-02 GSS 114.00 0.00 0.00 114.00 114.00 0.00 0.00 0.00 0.00 0.00 ~ 06-MAR-02 GSS 275.00 0.45 323.00 161.00 275.00 -0.01 0.50 -0.38 0.28 0.28 06-MAR-02 GSS 365.00 0.80 258.00 90.00 364.99 0.55 0.66 -1.21 0.82 0.39 06-MAR-02 GSS 458.00 2.15 250.00 93.00 457.96 2.79 -0.08 -3.48 1.46 1.45 06-MAR-02 GSS 547.00 3.15 238.00 89.00 546.87 6.81 -1.94 -7.12 1.28 1.12 06-MAR-02 GSS 637.00 4.50 218.00 90.00 636.67 12.69 -6.04 -11.40 2.09 1.50 06-MAR-02 MWD 752.03 5.51 212.45 115.03 751.26 22.28 -14.25 -17.14 0.97 0.88 -4.82 06-MAR-02 MWD 843.46 5.94 223.76 91.43 842.23 31.10 -21.37 -22.77 1.32 0.47 12.37 06-MAR-02 MWD 932.98 5.70 226.64 89.52 931 .29 40.11 -27.77 -29.20 0.42 -0.27 3.22 06-MAR-02 MWD 1 028.37 5.90 222.67 95.39 1026.19 49.67 -34.63 -35.97 0.47 0.21 -4.16 06-MAR-02 MWD 1123.57 6.21 221.97 95.20 1120.86 59.57 -42.05 -42.73 0.33 0.33 -0.74 06-MAR-02 MWD 1218.88 5.33 221.05 95.31 1215.69 69.00 -49.22 -49.08 0.93 -0.92 -0.97 06~MAR-02 MWD 1314.69 4.35 219.66 95.81 1311.16 76.92 -55.38 -54.32 1.03 -1.02 ~' 06-MAR-02 MWD 1409.64 3.11 224.73 94.95 1405.90 82.99 -59.98 -58.43 1.35 -1.31 06-MAR-02 MWD 1504.76 1.62 229.14 95.12 1500.94 86.89 -62.69 -61.27 1.58 -1.57 06-MAR-02 MWD 1599.37 0.87 224.02 94.61 1595.53 88.94 -64.08 -62.78 0.80 -0.79 Q6-MAR-02 MWD 1694.11 0.95 219.10 94.74 1690.26 90.42 -65.21 -63.77 0.12 0.08 06-MAR-02 MWD 1789.25 0.53 224.04 95.14 1785.39 91.62 -66.14 -64.58 0.45 -0.44 06-MAR-02 MWD 1884.32 0.27 240.33 95.07 1880.46 92.28 -66.57 -65.08 0.30 -0.27 06-MAR-02 MWD 1979.96 0.27 252.67 95.64 1976.09 92.71 -66.75 -65.49 0.06 0.00 06~MAR-02 MWD 2075.06 0.29 249.91 95.10 2071 .19 93.15 -66.89 -65.93 0.03 0.02 07 -MAR-02 MWD 2170.36 0.38 265.15 95.30 2166.49 93.65 -67.00 -66.47 0.13 0.09 07 -MAR-02 MWD 2265.73 0.32 . 262.29 95.37 2261.86 94.14 -67.07 -67.05 0.07 -0.06 ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00130 Sidetrack No. Page 2 of 4 - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: 19 Field ALPINE FIELD Well Name & No. PAD CD#2/50 PB1 - 50 Survey Section Name Definitive Survey BHI Rep. C MILCHAK INTEQ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -2062.81 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. E/W Slot Coord. E/W -1501.69 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. 231.92 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (per 100FT) Drop (-) Left (-) 07-MAR-D2 MWD 2330.18 0.16 295.60 64.45 2326.31 94.34 -67.05 -67.31 0.32 -0.25 09-MAR~02 MWD 2461 .05 0.19 4.59 130.87 2457.18 94.27 -66.76 -67.46 0.15 0.02 - 09-MAR-02 MWD 2556.58 0.30 346.63 95.53 2552.71 94.06 -66.36 -67.50 0.14 0.12 09-MAR-D2 MWD 2651.84 2.16 238.65 95.26 2647.95 95.74 -67.05 -69.09 2.38 1.95 09-MAR-02 MWD 2746.34 5.51 235.34 94.50 2742.22 102.04 -70.55 -74.35 3.55 3.54 -3.50 09-MAR-02 MWD 2842.71 8.79 232.93 96.37 2837.83 114.02 -77.63 -84.03 3.42 3.40 -2.50 09-MAR~02 MWD 2938.43 11.70 234.54 95.72 2932.01 131.03 -87.67 -97.77 3.05 3.04 1.68 09-MAR-02 MWD 3033.28 14.02 236.06 94.85 3024.48 152.10 -99.66 -115.14 2.47 2.45 1.60 09-MAR-02 MWD 3128.56 16.91 234.12 95.28 3116.30 177.46 -114.23 -135.95 3.08 3.03 -2.04 09-MAR-02 MWD 3224.06 19.69 233.28 95.50 3206.96 207.43 -132.00 -160.10 2.92 2.91 -D.88 09-MAR-02 MWD 3320.35 22.28 232.08 96.29 3296.86 241.91 -152.92 -187.51 2.73 2.69 -1.25 09-MAR-02 MWD 3415.19 25.20 230.12 94.84 3383.66 280.08 -176.92 -217.19 3.19 3.08 -2.07 09-MAR-02 MWD 3511.36 25.70 229.14 96.17 3470.50 321 .37 -203.69 -248.67 0.68 0.52 -1.02 09-MAR-D2 MWD 3606.81 25.69 229.31 95.45 3556.51 362.71 -230.71 -280.01 0.08 -0.01 0.18 - 09-MAR~02 MWD 3701.68 26.60 232.95 94.87 3641 .68 404.49 -256.92 -312.56 1.94 0.96 3.84 09-MAR-02 MWD 3796.86 26.65 234.01 95.18 3726.77 447.13 -282.30 -346.84 0.50 0.05 1.11 09-MAR-02 MWD 3892.32 26.56 232.30 95.46 3812.12 489.86 -307.93 -381.05 0.81 -0.09 -1.79 09-MAR-02 MWD 3986.13 26.81 232.73 93.81 3895.94 531.99 -333.57 -414.48 0.34 0.27 0.46 09-MAR-02 MWD 4083.29 26.93 232.83 97.16 3982.61 575.90 -360.13 -449.45 0.13 0.12 0.10 09-MAR-02 MWD 4178.69 26.75 231.82 95.40 4067.73 618.97 -386.46 -483.54 0.51 -0.19 -1.06 09-MAR-02 MWD 4274.18 26.78 230.92 95.49 4152.99 661 .97 -413.30 -517.13 0.43 0.03 -0.94 09-MAR-02 MWD 4369.37 26.71 229.99 95.19 4238.00 704.79 -440.57 -550.16 0.45 -D.07 -0.98 09~MAR-02 MWD 4464.74 26.93 230.88 95.37 4323.11 747.80 -467.98 -583.33 0.48 0.23 0.93 09-MAR-02 MWD 4559.96 26.63 230.59 95.22 4408.12 790.70 ~495.13 -616.55 0.34 -0.32 -0.30 - ~. - ----.- - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00130 Sidetrack No. Page 3 of 4 - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: 19 Field ALPINE FIELD Well Name & No. PAD CD#2I50 PB1 - 50 Survey Section Name Definitive Survey BHI Rep. C MILCHAK INTEQ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -2062.81 Grid Correction 0.000 Depths Measured From: RKB ~ MSL D SSD Target Description Target Coord. E/W Slot Coord. ENV -1501.69 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 1 OOft~ 30mD 10mD Vert. Sec. Azim. 231.92 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / See) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (OD) (OD) (FT) (FT) (FT) (FT) (per 100FT) Drop (-) Left (-) 09-MAR-02 MWD 4656.35 26.55 230.38 96.39 4494.31 833.83 -522.59 -649.84 0.13 -0.08 -0.22 09-MAR-02 MWD 4752.16 27.37 232.27 95.81 4579.71 877.26 -549.72 -683.75 1.24 0.86 1.97 09-MAR-02 MWD 4846.41 27.44 232.45 94.25 4663.38 920.64 -576.21 -718.10 0.12 0.07 0.19 09-MAR-02 MWD 4942.72 27.60 232.06 96.31 4748.80 965.14 -603.45 -753.29 0.25 0.17 -0.40 1 0-MAR-02 MWD 5038.27 27.36 231.46 95.55 4833.56 1009.23 -630.74 -787.92 0.38 -0.25 -0.63 1 O-MAR-02 MWD 5134.04 27.18 231.68 95.77 4918.69 1 053.11 -658.02 -822.29 0.22 -0.19 0.23 1 0-MAR-02 MWD 5229.64 27.02 232.63 95.60 5003.80 1096.66 -684.74 -856.68 0.48 -0.17 0.99 1 O~MAR-02 MWD 5324.98 26.75 232.58 95.34 5088.83 1139.77 -710.92 -890.93 0.28 -0.28 -0.05 1 O-MAR-02 MWD 5421 .10 26.40 233.02 96.12 5174.80 1182.76 -736.92 -925.18 0.42 -0.36 0.46 1 0-MAR-02 MWD 5516.81 26.10 232.20 95.71 5260.64 1225.09 -762.62 -958.82 0.49 -0.31 -0.86 1 O-MAR-02 MWD 5612.43 25.39 232.07 95.62 5346.76 1266.62 -788.11 -991.61 0.74 -0.74 -0.14 1 O-MAR-02 MWD 5707.94 25.60 233.37 95.51 5432.97 1307.73 -813.01 -1024.32 0.63 0.22 1.36 1 0-MAR-02 MWD 5803.87 27.47 234.48 95.93 5518.79 1350.55 -838.23 -1058.96 2.02 1.95 1.16 1 0-MAR-02 MWD 5897.63 27.03 234.97 93.76 5602.15 1393.43 -863.03 -1094.01 0.53 -0.47 0.52 ~~ 1 0~MAR-02 MWD 5993.73 26.97 234.36 96.10 5687.77 1437.01 -888.26 -1129.60 0.29 -0.06 -0.63 1 0-MAR-02 MWD 6088.95 26.60 234.28 95.22 5772.78 1479.88 -913.29 -1164.45 0.39 -0.39 -0.08 1 0-MAR~02 MWD 6184.34 26.16 234.43 95.39 5858.23 1522.23 -937.99 -1198.90 0.47 -0.46 0.16 1 0-MAR-02 MWD 6279.64 27.35 232.64 95.30 5943.33 1565.11 -963.49 -1233.39 1.51 1.25 -1.88 1 O-MAR-02 MWD 6374.52 27.57 231.78 94.88 6027.52 1608.86 -990.30 -1267.96 0.48 0.23 -0.91 1 O-MAR-02 MWD 6469.77 26.61 232.54 95.25 6112.32 1652.23 -1016.92 -1302.21 1.07 -1.01 0.80 1 0-MAR-02 MWD 6565.49 26.13 232.41 95.72 6198.08 1694.74 -1042.81 -1335.93 0.51 -0.50 -0.14 1 0~MAR-02 MWD 6661 .31 25.44 231.27 95.82 6284.36 1736.42 -1 068.56 -1368.71 0.89 -0.72 -1.19 1 0-MAR-02 MWD 6756.79 24.87 231 .27 95.48 6370.79 1777.01 -1093.95 -1400.37 0.60 -0.60 0.00 1 0-MAR~02 MWD 6850.95 25.55 233.54 94.16 6455.98 1817.10 -1118.41 -1432.15 1.26 0.72 2.41 ~,c "-=....r ,.~ '"_N__''' .. ,.-.' .......,,>- -" .~..~.;8 ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 045().()()130 Sidetrack No. Page 4 of 4 - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: 19 Field ALPINE FIELD Well Name & No. PAD CD#2/50 PB1 - 50 Survey Section Name Definitive Survey BHI Rep. C MILCHAK 1NrEQ. WELL DATA Target lVD (FT) Target Coord. N/S Slot Coord. N/S -2062.81 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SSO Target Description Target Coord. E/W Slot Coord. E/W -1501.69 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 100ft~ 30mO 10mO Vert. Sec. Azim. 231.92 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length lVD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DD) (FT) (FT) (FT) (FT) (Per 100FT) Drop (-) Left (-) 1 0-MAR-02 MWD 6947.60 26.34 233.31 96.65 6542.89 1859.37 -1143.61 -1466.10 0.82 0.82 -0.24 1 0-MAR-02 MWD 7043.36 26.09 231.74 95.76 6628.80 1901 .67 -1169.34 -1499.67 0.77 -0.26 -1.64 '- 10-MAR-02 MWD 7138.20 25.53 231.59 94.84 6714.18 1942.96 -1194.95 -1532.06 0.59 -0.59 -0.16 1 O-MAR~02 MWD 7234.74 25.74 233.24 96.54 6801.22 1984.72 -1220.42 -1565.16 0.77 0.22 1.71 1 0-MAR-02 MWD 7330.62 24.81 233.02 95.88 6887.92 2025.65 -1244.98 -1597.91 0.97 -0.97 -0.23 1 0-MAR-02 MWD 7425.55 24.12 234.20 94.93 6974.32 2064.95 -1268.31 -1629.55 0.89 -0.73 1.24 1 O-MAR-02 MWD 7521 .07 23.73 234.21 95.52 7061 .63 2103.65 -1290.96 -1660.97 0.41 -0.41 0.01 1 O-MAR-02 MWD 7616.52 22.97 234.07 95.45 7149.27 2141.45 -1313.13 -1691.63 0.80 -0.80 -0.15 1 0-MAR-02 MWD 7711 .89 23.27 234.22 95.37 7236.98 2178.87 -1335.06 -1721.98 0.32 0.31 0.16 1 O-MAR-02 MWD 7807.71 23.47 234.01 95.82 7324.94 2216.85 -1357.34 -1752.78 0.23 0.21 -0.22 1 0-MAR-02 MWD 7856.35 23.54 233.78 48.64 7369.54 2236.24 -1368.77 -1768.45 0.24 0.14 -0.47 1 0-MAR-02 MWD 7927.00 23.54 233.78 70.65 7434.31 2264.44 -1385.44 -1791.22 0.00 0.00 0.00 Projected Data - NO SURVEY ~' ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00130 Sidetrack No.1 Page 1 of 3 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: 19 Field ALPINE FIELD Well Name & No. PAD CD#2/50 PB1 - 50 Survey Section Name Definitive Survey BHI Rep. D NEWLON / D BALLOU INTEQ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -2062.81 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. E/W Slot Coord. E/W -1501.69 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 10Ott~ 30mD 10mD Vert. Sec. Azim. 231.92 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) MWD 6756.79 24.87 231.27 6370.79 1777.43 -1093.95 -1400.37 TIE IN POINT 13-MAR-02 MWD 6832.60 23.93 229.87 75.81 6439.83 1808.31 -1113.83 -1424.56 1.46 ~1.24 -1.85 ~ 13-MAR-02 MWD 6861 .52 23.35 225.73 28.92 6466.32 1819.87 -1121.62 -1433.15 6.08 -2.01 -14.32 13-MAR-02 MWD 6893.71 24.11 221.73 32.19 6495.79 1832.69 -1130.98 -1442.10 5.53 2.36 -12.43 13-MAR-02 MWD 6925.61 25.12 218.39 31.90 6524.80 1845.68 -1141.15 -1450.64 5.39 3.17 -10.47 13-MAR-02 MWD 7021 .13 28.59 220.23 95.52 . 6610.00 1887.79 -1174.50 -1478.00 3.74 3.63 1.93 13-MAR-02 MWD 7117.46 28.94 219.44 96.33 6694.45 1933.12 -1210.09 -1507.69 0.54 0.36 -0.82 14-MAR-02 MWD 7212.67 30.08 218.20 95.21 6777.30 1978.79 -1246.64 -1537.08 1.36 1.20 -1.30 14-MAR-02 MWD 7245.87 31.35 212.92 33.20 6805.85 1995.04 -1260.43 -1546.92 8.98 3.83 -15.90 14-MAR-02 MWD 7277.92 32.26 208.05 32.05 6833.09 2010.75 -1274.98 -1555.48 8.49 2.84 -15.20 14-MAR-02 MWD 7308.40 33.44 204.27 30.48 6858.70 2025.63 -1289.81 -1562.76 7.76 3.87 -12.40 14-MAR-02 MWD 7340.19 34.80 199.95 31.79 6885.02 2041 .09 -1306.33 -1569.45 8.74 4.28 -13.59 14-MAR-02 MWD 7371.72 35.68 194.89 31.53 6910.78 2056.07 -1323.68 -1574.89 9.67 2.79 -16.05 14-MAR-02 MWD 7404.63 37.89 191.64 32.91 6937.14 2071 .44 -1342.85 -1579.39 8.95 6.72 -9.88 _/ 14-MAR-02 MWD 7436.43 40.51 187.76 31.80 6961.78 2086.30 -1362.66 -1582.76 11.28 8.24 -12.20 14-MAR~02 MWD 7468.87 43.62 185.81 32.44 6985.86 2101.63 -1384.24 -1585.31 10.40 9.59 -6.01 14-MAR-02 MWD 7500.71 46.49 183.08 31.84 7008.36 2116.84 -1406.70 -1587.05 10.86 9.01 -8.57 14-MAR-02 MWD 7532.86 49.87 181.29 32.15 7029.79 2132.32 -1430.64 -1587.95 11.30 10.51 -5.57 14-MAR-02 MWD 7564.38 53.18 178.43 31.52 7049.40 2147.47 -1455.31 -1587.88 12.68 10.50 -9.07 14-MAR-02 MWD 7595.97 55.22 176.48 31.59 7067.88 2162.36 -1480.90 -1586.73 8.17 6.46 -6.17 14-MAR-02 MWD 7626.65 56.65 175.40 30.68 7085.07 2176.58 -1506.25 -1584.93 5.50 4.66 -3.52 14-MAR-02 MWD 7658.72 58.56 173.35 32.07 7102.25 2191.10 -1533.19 -1582.27 8.04 5.96 -6.39 14-MAR-02 MWD 7690.49 60.44 172.47 31.77 7118.37 2205.19 -1560.36 -1578.89 6.38 5.92 -2.77 14-MAR-02 MWD 7722.25 62.51 169.33 31.76 7133.54 2218.70 -1587.90 -1574.47 10.86 6.52 -9.89 ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00130 Sidetrack No.1 Page 2 of 3 - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: 19 Field ALPINE FIELD Well Name & No. PAD CD#2/50 PB1 - 50 Survey Section Name Definitive Survey BHI Rep. D NEWLON I D BALLOU 'I\IT'EQ. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -2062.81 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. E/W Slot Coord. E/W -1501.69 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 1 OOft~ 30mD 10mD Vert. Sec. Azim. 231.92 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 14-MAR-02 MWD 7754.22 64.48 167.11 31.97 7147.81 2231.37 -1615.90 -1568.63 8.75 6.16 -6.94 14-MAR-02 MWD 7785.92 67.53 165.26 31.70 7160.70 2243.27 -1644.02 -1561.71 11.00 9.62 -5.84 - 14-MAR-02 MWD 7818.18 70.74 163.26 32.26 7172.19 2254.72 -1673.03 -1553.53 11.51 9.95 -6.20 14-MAR-02 MWD 7849.97 74.23 161 .61 31.79 7181.75 2265.34 -1701.92 -1544.38 12.04 10.98 -5.19 14-MAR-02 MWD 7881.68 77.89 159.71 31.71 7189.39 2275.22 -1730.95 -1534.18 12.92 11.54 -5.99 14-MAR-02 MWD 7899.75 79.84 158.97 18.07 7192.88 2280.53 -1747.54 -1527.93 11.52 10.79 -4.10 26-APR-02 MWD 7920.37 81.90 157.88 20.62 7196.16 2286.31 -1766.47 -1520.44 11.27 9.99 -5.29 26-APR-02 MWD 7944.82 84.11 156.49 24.45 7199.13 2292.70 -1788.84 -1511.03 10.66 9.04 -5.69 26-APR-02 MWD 8037.11 88.85 154.21 92.29 7204.80 2314.08 -1872.53 -1472.62 5.70 5.14 -2.47 26-APR-02 MWD 8135.73 90.65 153.34 98.62 7205.23 2334.34 -1960.99 -1429.04 2.03 1.83 -0.88 26-APR-02 MWD 8229.68 90.63 152.85 93.95 7204.18 2352.54 -2044.77 -1386.53 0.52 -0.02 -0.52 26-APR-02 MWD 8327.62 90.34 153.18 97.94 7203.35 2371 .39 -2132.04 -1342.09 0.45 -0.30 0.34 26-APR-02 MWD 8423.64 90.15 152.63 96.02 7202.94 2389.69 -2217.52 -1298.36 0.61 -0.20 -0.57 26-APR-02 MWD 8519.30 89.27 151.42 95.66 7203.42 2406.47 -2302.00 -1253.49 1.56 -0.92 -1.26 ---- 26-APR-02 MWD 8614.71 88.29 150.86 95.41 7205.46 2421.75 -2385.54 -1207.45 1.18 -1.03 -0.59 26-APR-02 MWD 8710.39 88.12 149.96 95.68 7208.45 2435.87 -2468.70 -1160.23 0.96 -0.18 -0.94 26-APR-02 MWD 8806.04 88.12 149.70 95.65 7211.59 2449.03 -2551.35 -1112.18 0.27 0.00 -0.27 27-APR-02 MWD 8902.04 88.36 152.54 96.00 7214.54 2464.37 -2635.36 -1065.84 2.97 0.25 2.96 27-APR-02 MWD 8997.21 88.49 152.90 95.17 7217.16 2482.20 -2719.92 -1022.24 0.40 0.14 0.38 27 -APR-02 MWD 9093.00 88.97 152.64 95.79 7219.28 2500.22 -2805.07 -978.42 0.57 0.50 -0.27 27-APR-02 MWD 9188.30 88.56 151.86 95.30 7221 .33 2517.31 -2889.39 -934.06 0.92 -0.43 -0.82 27-APR~02 MWD 9282.82 88.80 151.87 94.52 7223.51 2533.63 -2972.72 -889.50 0.25 0.25 0.01 27-APR-02 MWD 9377.63 88.58 151.79 94.81 7225.68 2549.94 -3056.28 -844.75 0.25 -0.23 -0.08 27 -APR-02 MWD 9472.14 88.53 151.85 94.51 7228.06 2566.18 -3139.56 -800.13 0.08 -0.05 0.06 .. - -- ... SURVEY CALCULATION AND FIELD WORKSHEET ~ INTEQ Company PHILLIPS ALASKA, INC. Well Name & No. PAD CD#2/SO PB1 - 50 Target TVD Target Description Target Direction (FT) (DO) - Job No. 0450-00130 - Rig Contractor & No. Doyon Drilling Co. - Rig: 19 Survey Section Name Definitive Survey WELL DATA Target Coord. NIS Slot Coord. N/S Target Coord. E/W Slot Coord. E/W Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. SURVEY DATA Date Survey Survey Incl. Hole Tool Depth Angle Direction Type (FT) (oD) (DO) 28-APR-02 MWD 9568.57 88.78 152.56 28-APR-02 MWD 9663.96 89.13 28~APR-02 MWD 9759.38 89.47 28-APR-02 MWD 9854.41 89.87 28~APR-02 MWD 9950.21 89.96 28-APR-02 MWD 10044.63 88.44 28-APR-02 MWD 10140.09 88.49 29-APR-02 MWD 10236.58 90.03 29~APR-02 MWD 10331.54 90.55 29~APR-02 MWD 10427.54 90.65 29-APR-02 MWD 10522.58 90.49 29~APR-02 MWD 10617.70 90.63 29~APR-02 MWD 10714.34 90.90 29-APR-02 MWD 10807.87 90.84 29-APR-02 MWD 10904.92 91.22 29-APR-02 MWD 11000.26 90.57 29-APR-02 MWD 11095.64 89.88 29-APR-02 MWD 11188.76 88.49 29~APR-02 MWD 11286.16 88.38 29-APR-02 MWD 11382.10 88.38 29~APR-02 MWD 11474.97 88.51 29-APR-02 MWD 11569.30 88.53 29-APR-02 MWD 11624.00 88.53 153.08 153.02 153.12 153.58 153.68 153.47 154.02 154.35 154.63 153.22 152.94 153.25 153.14 153.56 153.81 154.79 154.53 154.54 155.05 154.74 154.94 154.94 Course Length (FT) 96.43 95.39 95.42 95.03 95.80 94.42 95.46 96.49 94.96 96.00 95.04 95.12 96.64 93.53 97.05 95.34 95.38 93.12 97.40 95.94 92.87 94.33 54.70 TVD (FT) 7230.32 7232.06 7233.23 7233.78 7233.92 7235.24 7237.79 7239.04 7238.56 7237.55 7236.61 7235.68 7234.39 7232.97 7231.23 7229.74 7229.36 7230.69 7233.35 7236.06 7238.58 7241 .02 7242.42 Vertical Section 2583.40 2601.43 2619.85 2638.23 2657.21 2676.37 2695.65 2715.42 2735.59 2756.48 2776.25 2794.66 2813.39 2831.67 2850.90 2870.34 2890.79 2911.32 2932.58 2953.95 2974.80 2995.88 3008.20 -2062.81 -1501.69 231.92 Grid Correction Magn. Declination Magn. to Map Corr. Total Coordinate Build Rate N(+) / S(-) E(+) / W(-) DL Build (+) (FT) (FT) (Per 100 FT) Drop (-) -3224.84 -755,18 0.78 0.26 -3309.68 -3394.73 -3479.45 -3565.08 -3649.66 -3735.11 -3821 .64 -3907.12 -3993.76 -4079.12 -4163.93 -4250.10 -4333,57 -4420.29 -4505.74 -4591,69 -4675.84 -4763.74 -4850,51 -4934.58 -5019.93 -5069.46 -711.62 -668.37 -625.33 -582.36 -540.43 -497.96 -455.29 -413.93 -372.59 -330.82 -287.76 -244.03 -201 .86 -158.33 -116.08 -74.71 -34.86 7.00 47.84 87.23 127.32 150.48 0.66 0,36 0.43 0.49 1.61 0.23 1.69 0.65 0.31 1.49 0.33 0.43 0,13 0.58 0.73 1.26 1.52 0.11 0.53 0.36 0,21 0.00 -1,61 0.05 0.10 -0.17 -0.06 0.39 -0.68 -0.72 -1 .49 -0.11 0.37 0.36 0.42 0.09 1.60 0.55 0.15 0.28 0.00 0.14 0.02 0.00 0.000 0.000 0.000 Walk Rate Right (+) Left (-) 0.74 0.55 ... ~ c "'~""'''''''' ~~""'""- Sidetrack No.1 Page ~ of 3 Field ALPINE FIELD BHI Rep. D NEWLON / D BALLOU Depths Measured From: RKB ~ MSLD SSD Calculation Method MINIMUM CURVATURE Map North to: OTHER Comment -0.06 0.11 0.48 0.11 -0.22 0.57 0.35 0.29 -1 .48 -0.29 0.32 -0.12 .~ 0.43 0.26 1.03 -0.28 0.01 0.53 -0.33 0.21 0.00 Projected Data - NO SURVEY ) ) ctÐ d," 0 'Ie¡ 17-May-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-50PB1 Gyro Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Su rvey: Window / Kickoff Survey Projected Survey: 0.00' MD , MD (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED r.A ,I 'v' 11 :: 'J (\02 ¡,""""I; L L ~ LV Alaska Oil & Gas Cons. Con1n1Iion AndJorage . , CJ ~ 0 l r6 0" r{)' " ,~ Kuparuk River Unit North Slop~ Alaska Alpine CD-2, Slot CD2-50 CD2-50PB1 Gyro Job No. AKMW22042, Surveyed: 11 March, 2002 ~ SURVEY REPORT 14 May, 2002 Your Ref: 501032041570 Surface Coordinates: 5974293.84 N, 371733.00 E (70° 20' 16.8106" N, 151002' 26.8355" W) Kelly Bushing: 52.43ft above Mean Sea Level 51 ---"raY-SLJr1 DAILL.ING SERVices A Halliburton Company Survey Ref: svy9865 .: . .. ~J~~" . Sperry-Sun Drilling Services Survey Report for CD2-50PB1 Gyro Your Ref: 501032041570 Job No. AKMW22042, Surveyed: 11 March, 2002 ..::. . North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) ~ 0.00 0.000 0.000 ~52.43 0.00 0.00 N O.OOE 5974293.84 N 371733.00 E 0.00 Tolerable Gyro 114.00 0.000 0.000 61.57 114.00 0.00 N O.OOE 5974293.84 N 371733.00 E 0.000 0.00 .~ 275.00 0.450 323.000 222.57 275.00 0.50N 0.38W 5974294.35 N 371732.63 E 0.280 -0.01 365.00 0.800 258.000 312.56 364.99 0.66 N 1.21 W 5974294.52 N 371731.80 E 0.815 0,54 458.00 2.150 250.000 405.53 457.96 0.088 3.48W 5974293.82 N 371729.52 E 1.465 2,78 547.00 3.150 238.000 494.44 546.87 1.948 7.12W 5974292.02 N 371725.84 E 1.279 6.80 637.00 4.500 218.000 584.24 636.67 6.038 11.40 W 5974288.00 N 371721.50 E 2.088 12.69 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.109° (05-Mar-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 231.850° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 637.000., .'~ The Bottom Hole Displacement is 12.90ft., in the Direction of 242.096° (True). Survey tool program for CD2-50PB1 Gyro From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 637.00 636.67 Tolerable Gyro 14 May, 2002 - 15:29 Page 2 of 2 Dri/lQuest 2.00.08.005 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-50PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , MD (if applicable) 7,927.00' MD ) aoa.. ()~q 17-May-02 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED t.'1 "'y' 2 /. "002 ,,"""\. ,'- Alaska Oil & Gas Cons. Commission Anchorage 0- -:¡- () I ~ CQ ., ~ ,.- Kuparuk River Unit North Slope, Alaska Alpine CD-2, Slot CD2-50 CD2-50PB1 Job No. AKMW22042, Surveyed: 11 March, 2002 SURVEY REPORT 14 May, 2002 Your Ref: API 501032041570 Surface Coordinates: 5974293.84 N, 371733.00 E (700 20' 16.8106" H, 151002' 26.8355" W) Kelly Bushing: 52. 43ft above Mean Sea Level ~. ~I~~' .V-EiU.., q RI-L L'nW¡-. :'.!I\ RV- C E 5 A Halliburton Company Survey Ref: svy9867 Sperry-Sun Drilling Services . Survey Report for CD2-50PB1 Your Ref: AP/501032041570 Job No. AKMW22042, Surveyed: 11 March, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northlngs Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 637.00 4.500 218.000 584.24 636.67 6.03 S 11.40 W 5974288.00 N 371721.50 E 12.69 MWD Magnetic .-/--""" 752.03 5.510 212.450 698.83 751.26 14.25 S 17.14 W 5974279.88 N 371715.62 E 0.973 22.28 843.46 5,940 223,760 789.80 842.23 21.37 S 22.77 W 5974272.86 N 371709.87 E 1.318 31.10 932.98 5.700 226.640 878.86 931.29 27.77 S 29.20 W 5974266.57 N 371703.33 E 0.422 40.12 1028.37 5.900 222.670 973.76 1026.19 34.63 S 35.97 W 5974259.83 N 371696.44 E 0.470 49.68 1123.57 6.210 221.970 1068.43 1120.86 42.05 S 42.73 W 5974252.52 N 371689.56 E 0.335 59.58 1218.88 5,330 221.050 1163.26 1215.69 49.22 S 49.08 W 5974245.46 N 371683.08 E 0.928 69.01 1314.69 4.350 219.660 1258.73 1311.16 55.38 S 54.32 W 5974239.40 N 371677.74 E 1.030 76.93 1409.64 3.110 224.730 1353.4 7 1405.90 59.98 S 58.43 W 5974234.87 N 371673.55 E 1.350 83.00 1504.76 1,620 229.140 1448.51 1500.94 62.69 S 61.27 W 5974232.20 N 371670.67 E 1.577 86.91 1599.37 0.870 224.020 1543.10 1595.53 64.08 S 62.78 W 5974230.84 N 371669.13E 0.801 88.96 1694.11 0.950 219,100 1637.83 1690.26 65.21 S 63.77 W 5974229.73 N 371668.12 E 0.118 90.43 1789.25 0.530 224.040 1732.96 1785.39 66.14 S 64.58 W 5974228.81 N 371667.30 E 0.446 91.64 1884.32 0.270 240.330 1828.02 1880.45 66.57 S 65.08 W 5974228.40 N 371666.79 E 0.296 92.30 1979.96 0.270 252.670 1923.66 1976.09 66.75 S 65.49 W 5974228.22 N 371666.38 E 0.061 92.73 2075.06 0.290 249.910 2018.76 2071.19 66.89 S 65.93 W 5974228.08 N 371665.94 E 0.025 93.17 2170.36 0,380 265,150 2114.06 2166.49 67.00 S 66.47 W 5974227.98 N 371665.39 E 0.132 93.66 --- 2265.73 0.320 262.290 2209.43 2261.86 67.07 S 67.05 W 5974227.93 N 371664.81 E 0.066 94.16 .......-....- 2330.18 0.160 295.600 2273.88 2326.31 67.05 S 67.31 W 5974227.95 N 371664.55 E 0,320 94.35 2461.05 0,190 4,590 2404.75 2457.18 66.76 S 67.46 W 5974228.25 N 371664.41 E 0.153 94.28 2556.58 0,300 346.630 2500.28 2552.71 66.36 S 67.50 W 5974228.65 N 371664.37 E 0.139 94.07 2651.64 2.160 238.650 2595.32 2647.75 67.05 S 69.09 W 5974227.99 N 371662.78 E 2.389 95.75 2746.34 5.510 235.340 2689.79 2742.22 70.56 S 74.35 W 5974224.56 N 371657.45 E 3.544 102.06 2842.71 8.790 232.930 2785.40 2837.83 77.63 S 84.04 W 5974217.66 N 371647.65 E 3.417 114.04 2938.43 11.700 234.540 2879.58 2932.01 87.67 S 97.78 W 5974207.85 N 371633.73 E 3.055 131.05 3033.28 14.020 236.060 2972.05 3024.48 99.67 S 115.15 W 5974196.16 N 371616.16 E 2.472 152.12 3128.56 16,910 234,120 3063.87 3116.30 114.24 S 135.96 W 5974181.94 N 371595.11 E 3.081 177.48 3224.06 19,690 233.280 3154.53 3206.96 132.00 S 160.11 W 5974164.60 N 371570.66 E 2.924 207.45 3320.35 22.280 232.080 3244.43 3296.86 152.92 S 187.52 W 5974144.15 N 371542.90 E 2.726 241.93 3415.19 25,200 230.120 3331 .23 3383.66 176.92 S 217.20 W 5974120.66 N 371512.81 E 3.189 280.09 -~ ---------- . --. ----- --- 14 May, 2002 - 15:29 Page 2 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-50PB1 Your Ref: AP/501032041570 Job No. AKMW22042, Surveyed: 11 March, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) ,- 3511.36 25.700 229.140 3418.07 3470.50 203.69 S 248,68 W 5974094.43 N 371480.87 E 0.680 321.39 3606,81 25.690 229.310 3504.08 3556.51 230,72 S 280.02 W 5974067.94 N 371449.07 E 0.078 362.73 3701,68 26,600 232.950 3589.25 3641.68 256.92 S 312.57 W 5974042.30 N 371416.08 E 1.943 404.51 3796.86 26.650 234.010 3674.34 3726.77 282,31 S 346.85 W 5974017.51 N 371381.37 E 0.502 447.15 3892.32 26.560 232.300 3759.69 3812.12 307.94 S 381.06 W 5973992.46 N 371346.73 E 0.808 489.88 3986.13 26.810 232.730 3843.51 3895,94 333.58 S 414.49 W 5973967.40 N 371312.87 E 0.337 532.01 4083,29 26.930 232.830 3930.18 3982.61 360.14 S 449.46 W 5973941.44 N 371277.45 E 0.132 575.92 4178.69 26.750 231.820 4015.30 4067.73 386.46 S 483,55 W 5973915,71 N 371242.91 E 0.514 618.99 4274.18 26.780 230.920 4100.56 4152.99 413.31 S 517.14W 5973889.44 N 371208.87 E 0.426 661.99 4369.37 26.710 229.990 4185.57 4238.00 440.58 S 550.17 W 5973862.73 N 371175.37 E 0.446 704.81 4464,74 26.930 230.880 4270.68 4323.11 467.99 5 583.34 W 5973835,90 N 371141.74 E 0.480 747.82 . 4559,96 26.630 230.590 4355.69 4408.12 495.14 S 616.56 W 5973809.32 N 371108.06 E 0.344 790.72 4656.35 26.550 230.380 4441.88 4494,31 522.59 S 649.84 W 5973782.44 N 371074.31 E 0.128 833.85 4752.16 27.370 232.270 4527.28 4579.71 549.72 S 683.76 W 5973755.89 N 371039.94 E 1.238 877.28 4846.41 27.440 232.450 4610.95 4663.38 576.22 S 718.11W 5973729.99 N 371005.14 E 0.115 920.66 4942.72 27,600 232.060 4696.36 4748.79 603.46 S 753.30 W 5973703.36 N 370969.49 E 0.250 965.16 5038.27 27.360 231 .460 4781.13 4833.56 630.75 S 787.93 W 5973676.66 N 370934.40 E 0.383 1009.25 5134.04 27.180 231.680 4866.26 4918.69 658.02 S 822.30 W 5973649.98 N 370899.56 E 0.215 1053.13 ~ 5229.64 27.020 232.630 4951.36 5003.79 684.74 S 856.69 W 5973623.85 N 370864.72 E 0.483 1096.68 5324.98 26.750 232.580 5036.40 5088.83 710.92 S 890.94 W 5973598.26 N 370830.03 E 0.284 1139.79 5421,10 26.400 233.030 5122.36 5174.79 736.92 S 925.20 W 5973572.85 N 370795.33 E 0.420 1182.78 5516,81 26.100 232.200 5208.20 5260.63 762.62 S 958.83 W 597354 7,73 N 370761.26 E 0.495 1225.11 5612,43 25.390 232.070 5294.33 5346.76 788.11 S 991.62 W 5973522.80 N 370728.04 E 0.745 1266.64 5707,94 25.600 233.370 5380.54 5432.97 813.01 5 1024.33 W 5973498.47 N 370694.91 E 0.626 1307.75 5803.87 27.470 234.480 5466.36 5518.79 838,23 5 1058.97 W 5973473.84 N 370659.84 E 2.017 1350.57 5897.63 27.030 234.970 5549.72 5602.15 863.03 S 1094.02 W 5973449.65 N 370624.38 E 0.527 1393.45 5993.73 26.970 234.360 5635.34 5687.77 888.26 S 1129.61 W 5973425.03 N 370588.36 E 0.295 1437.02 6088.95 26,600 234.280 5720.35 5772.78 913.29 S 1164.47W 5973400.61 N 370553.08 E 0.390 1479.89 6184,34 26.160 234.430 5805.80 5858.23 937.99 S 1198.91 W 5973376.50 N 370518.22 E 0.467 1522.23 6279,64 27.350 232.640 5890.90 5943.33 963.49 S 1233.40 W 5973351.59 N 370483.30 E 1.508 1565.11 --~---- 14 May, 2002 - 15:29 Page 30f5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-50PB1 Your Ref: AP/501032041570 Job No. AKMW22042, Surveyed: 11 March, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6374.52 27,570 231.780 5975.09 6027.52 990.30 S 1267.97 W 5973325.37 N 370448.27 E 0.478 1608.86 6469.77 26.610 232.540 6059.89 6112.32 1016.92 S 1302.23 W 5973299.35 N 370413.57 E 1.071 1652.24 6565.49 26.130 232.410 6145.65 6198.08 1042.81 S 1335.94 W 5973274.03 N 370379.41 E 0.505 1694.75 6661.35 25.440 231.270 6231.97 6284.40 1068.57 S 1368.73 W 5973248.84 N 370346.19 E 0.886 1736.45 6756.79 24,870 231 .270 6318.35 6370.78 1093.95 S 1400.38 W 5973224.00 N 370314.11 E 0.597 1777.01 6850.95 25.550 233.540 6403.55 6455.98 1118.41 S 1432.16 W 5973200.09 N 370281.92 E 1.255 1817.11 6947.60 26.340 233.310 6490.46 6542.89 1143.60 S 1466.12 W 5973175.48 N 370247.54 E 0.824 1859.38 7043.36 26,090 231.740 6576.37 6628.80 1169.34 S 1499.69 W 5973150.33 N 370213.53 E 0.770 1901.67 7138.20 25.530 231.590 6661.75 6714.18 1194.95 S 1532.08 W 5973125.27 N 370180.71 E 0.594 1942.96 7234.74 25,740 233,240 6748.78 6801.21 1220.42 S 1565.17 W 5973100.37 N 370147.18 E 0.771 1984,73 7330.62 24.820 233.020 6835.48 6887.91 1244.98 S 1597.93 W 5973076.37 N 370114.01 E 0.965 2025.66 7425.55 24.120 234.200 6921.88 6974.31 1268.32 S 1629.58 W 5973053.58 N 370081.97 E 0.899 2064.96 7521.07 23.730 234.210 7009.20 7061.63 1290.97 S 1661.00 W 597~031.4 7 N 370050.16 E 0.408 2103.66 7616.52 22.970 234.070 7096.83 7149.26 1313.13 S 1691.66 W 5973009.83 N 370019.13 E 0.798 2141.47 7711.89 23,270 234.220 7184.54 7236.97 1335.07 S 1722.01 W 5972988.42 N 369988.41 E 0.321 2178.88 7807.71 23.4 70 234,010 7272.50 7324.93 1357.35 S 1752.80 W 5972966.67 N 369957.23 E 0.226 2216.86 7856.35 23.540 233.780 7317.10 7369.53 1368.78 S 1768.48 W 5972955.51 N 369941.37 E 0.237 2236.25 7927.00 23.540 233.780 7381.87 7434.30 1385.45 S 1791.24 W 5972939.23 N 369918.32 E 0.000 2264.45 Projected Survey .-~ All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.108° (05-Mar-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 231.850° (True). Based upon Min'imum Curvature type calculations, at a Measured Depth of 7927.00ft., The Bottom Hole Displacement is 2264.51ft., in the Direction of 232.280° (True). ---------------- --- -- ~-- --- --- -.----- 14 May, 2002 - 15:29 Page 4 of 5 DrillQuest 2.00.08.005 Kuparuk River Unit Comments ~~ Measured Depth (ft) 7927.00 Sperry-Sun Drilling Services Survey Report for CD2-SOPB1 Your Ref: AP/501032041570 Job No. AKMW22042, Surveyed: 11 March, 2002 . North Slope, Alaska Alpine CD-2 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7434.30 1385.45 S 1791.24 W Projected Survey Survey tool program for CD2-50PB1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 637.00 ~ 14 May, 2002 - 15:29 0.00 636.67 637.00 7927.00 636.67 Tolerable Gyro (CD2-50PB1 Gyro) 7434.30 MWD Magnetic (CD2-50PB1) ---- --------- ---~-- - - -'- . -~------- Page 5 0'5 DrillQuest 2.00.08.005 ) 16-May-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well CO2-50 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 6,756.79' MD Window / Kickoff Survey 6,820.00' MD (if applicable) Projected Survey: 11,624.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, Bill Allen Survey Manager REce\VED Attachment(s) M ,A,,',¡" 2. i~ 2002 \ 1.-'1, A1aska ai' & Gas Cons. eommiss\On Anchorage aca.. 0 Ljq 0- ~ O. \ ~. 'cr DEFINT VE ,-, Kuparuk River Unit North Slope, Alaska Alpine CD-2, Slot CD2-50 CD2-50 Job No. AKMW22042, Surveyed: 29 April, 2002 SUR'VEY REPORT 14 May, 2002 Your Ref: 501032041500 Surface Coordinates: 5974293.84 N, 371733.00 E (700 20' 16.8106" N, 151002' 26.8355" W) Kelly Bushing: 52. 43ft above Mean Sea Level ~-' -, -~~... . It;~.. .V-~ ...., D't\'3 'LI~. "=-wI.f\V'L..ES - ,.~'~,' ÁHdìburton Company Survey Ref: svy9866 -"-:: . Sperry-Sun Drilling Services Survey Report for CD2-50 Your Ref: 501032041500 Job No. AKMW22042, Surveyed: 29 April, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) -- 6756.79 24.870 231.270 6318.35 6370.78 1093.95 S 1400.38 W 5973224.00 N 370314.11 E 304.19 Tie On Point 6820.00 24.085 230.110 6375.88 6428.31 1110.54 5 1420.65 W 5973207.76 N 370293.57 E 1.456 309.26 Window Point 6832.60 23.930 229.870 6387.39 6439.82 1113.84 5 1424.57 W 5973204.54 N 370289.58 E 1.456 310.31 6861.52 23.350 225.730 6413.89 6466.32 1121.625 1433.16 W 5973196.90 N 370280.86 E 6.079 313.12 6893.71 24.110 221.730 6443.36 6495.79 1130.985 1442.11 W 5973187.70 N 370271.76 E 5.529 317.16 6925.61 25.120 218.390 6472.36 6524.79 1141.155 1450.65 W 5973177.67 N 370263.04 E 5.388 322.10 7021.35 28.590 220.230 6557.76 6610.19 1174.585 1478.07 W 5973144.72 N 370235.05 E 3.727 338.64 7117.46 28.940 219.440 6642.01 6694.44 1210.095 1507.70 W 5973109.72 N 370204.82 E 0.538 355.98 7212.67 30,080 218.200 6724.87 6777.30 1246.63 5 1537.09 W 5973073.68 N 370174.81 E 1.358 374.35 7245.87 31.350 212.920 6753.42 6805.85 1260.425 1546.93 W 5973060.06 N 370164.74 E 8.975 381 .87 7277.92 32.260 208.050 6780.66 6833.09 1274.975 1555.48 W 5973045.66 N 370155.94 E 8.494 390.66 7308.40 33.440 204.270 6806.27 6858.70 1289.81 5 1562.76 W 5973030.95 N 370148.40 E 7.760 400.31 7340.19 34,800 199.950 6832.59 6885.02 1306.335 1569.46 W 5973014.55 N 370141.43 E 8.739 411.72 7371.72 35.680 194.890 6858.35 6910.78 1323.67 5 1574.89 W 5972997.30 N 370135.70 E 9.669 424.45 7404.63 37.890 191.640 6884.71 6937.14 1342.85 5 1579.40 W 5972978.20 N 370130.86 E 8.946 439.24 7436.43 40.510 187.760 6909.35 6961.78 1362.66 5 1582.76 W 5972958.46 N 370127.16 E 11.282 455.11 7468.87 43.620 185.810 6933.43 6985.86 1384.235 1585.32 W 5972936.93 N 370124.23 E 10.398 472.93 ~ 7500.71 46.490 183.080 6955.92 7008.35 1406.705 1587.05 W 5972914.50 N 370122.12 E 10.865 491.92 .- 7532.86 49.870 181.290 6977.36 7029.79 1430.635 1587.96 W 5972890.58 N 370120.80 E 11.302 512.61 7564.38 53.180 178.430 6996.97 7049.40 1455.305 1587.88 W 5972865.91 N 370120.46 E 12.676 534.39 7595.97 55.220 176.480 7015.45 7067.88 1480.905 1586.74 W 5972840.30 N 370121.16 E 8.171 557.50 7626.65 56,650 175.400 7032.63 7085.06 1506.25 5 1584.94 W 5972814.93 N 370122.53 E 5.498 580,70 7658.72 58.560 173.350 7049.82 7102.25 1533.195 1582.28 W 5972787.94 N 370124.73 E 8.037 605.72 7690.49 60.440 172.4 70 7065.94 7118.37 1560.355 1578.90 W 5972760.72 N 370127.64 E 6.381 631.26 7722.25 62.510 169.330 7081.11 7133.54 1587.905 1574.48 W 5972733.11 N 370131.59 E 10.859 657.64 7754.22 64.480 167.110 7095,38 7147.81 1615.905 1568.63 W 5972705.01 N 370136.95 E 8.751 685.09 7785.92 67,530 165,260 7108.27 7160.70 1644.025 1561.71 W 5972676.78 N 370143.39 E 10.999 713.14 7818.18 70.740 163.260 7119.76 7172.19 1673.02 S 1553.53 W 5972647.63 N 370151.08 E 11.513 742.58 7849.97 74,230 161.610 7129.32 7181.75 1701.92 S 1544.38 W 5972618.59 N 370159.73 E 12.042 772.38 7881.68 77 ,890 159.710 7136.96 7189.39 1730.95 5 1534.19 W 5972589.38 N 370169.43 E 12.924 802.78 -----------. ---- 14 May, 2002 - 15:37 Page2of5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-50 Your Ref: 501032041500 Job No. AKMW22042, Surveyed: 29 April, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 7899.75 79.840 158.970 7140.45 7192.88 1747.54 5 1527.93 W 5972572.69 N 370175.40 E 11.515 820.36 ,-. 7920.37 81 .900 157.880 7143.72 7196.15 1766.47 S 1520.45 W 5972553.64 N 370182.56 E 840.59 11.271 7944.82 84. 11 0 156.490 7146.70 7199.13 1788.84 S 1511.04W 5972531.11 N 370191.59 E 10.655 864.75 8037.11 88.850 154.210 7152.37 7204.80 1872.53 S 1472.63 W 5972446.78 N 370228.56 E 5.697 956.66 8135.73 90.650 153.340 7152.80 7205.23 1960.99 S 1429.05 W 5972357.58 N 370270.62 E 2.027 1055.22 8229.68 90.630 152.850 7151.75 7204.18 2044.77 S 1386.54 W 5972273.09 N 370311.69 E 0.522 1149.14 8327.62 90.340 153.180 7150.92 7203.35 2132.04 S 1342.10 W 5972185.07 N 370354.63 E 0.449 1247.06 8423.64 90.150 152.630 7150.51 7202.94 2217.52 S 1298.37 W 5972098.85 N 370396.89 E 0.606 1343.06 8519.30 89.270 151.420 7150.99 7203.42 2302.00 S 1253.49 W 5972013.62 N 370440.31 E 1.564 1438.72 8614.71 88.290 150.860 7153.02 7205.45 2385.54 S 1207.45 W 5971929.30 N 370484.92 E 1.183 1534.10 8710.39 88,120 149.960 7156.02 7208.45 2468.70 S 1160.23 W 5971845.35 N 370530.71 E 0.957 1629.70 8806.04 88.120 149.700 7159.16 7211.59 2551.35 S 1112.19 W 5971761.89 N 370577.33 E 0.272 1725.23 8902.04 88.360 152.540 7162.11 7214.54 2635.36 S 1065.85 W 5971677.10 N 370622.23 E 2.967 1821.17 8997.21 88.490 152.900 7164.72 7217.15 2719.91 S 1022.25 W 5971591.81 N 370664.38 E 0.402 1916.29 9093.00 88.970 152.640 7166.85 7219.28 2805.07 S 978.43 W 5971505.92 N 370706.74 E 0.570 2012.05 9188.30 88.560 151.860 7168.90 7221.33 2889.39 5 934.06 W 5971420.85 N 370749.65 E 0.924 2107.32 9282.82 88.800 151.870 7171.08 7223.51 2972.71 S 889.50 W 5971336.78 N 370792.78 E 0.254 2201.82 9377.63 88.580 151.790 7173.24 7225.67 3056.27 S 844.76 W 5971252.46 N 370836.09 E 0.247 2296.60 -. 9472.14 88.530 151.850 7175.63 7228.06 3139.55 S 800.14 W 5971168.43 N 370879.27 E 0.083 2391.08 9568.57 88.780 152.560 7177.89 7230.32 3224.83 S 755.19 W 5971082.40 N 370922.76 E 0.780 2487.48 9663.96 89,130 153.080 7179.63 7232.06 3309.68 S 711.62 W 5970996.82 N 370964.87 E 0.657 2582.84 9759.38 89.470 153.020 7180.80 7233.23 3394.73 S 668.38 W 5970911.04 N 371006.65 E 0.362 2678.24 9854.41 89.870 153,120 7181.34 7233.77 3479.45 S 625.34 W 5970825.60 N 371048.23 E 0.434 2773.24 9950.21 89.960 153.580 7181.49 7233.92 3565.07 S 582.37 W 5970739.25 N 371089.73 E 0.489 2869.01 10044.63 88.440 153,680 7182.80 7235.23 3649.66 S 540.44 W 5970653.96 N 371130.21 E 1.613 2963.37 10140.09 88.490 153.470 7185.36 7237.79 3735.11 S 497.97 W 5970567.79 N 371171.21 E 0.226 3058.76 10236.58 90.030 154.020 7186.61 7239.04 3821.64 S 455.29 W 5970480.55 N 371212.40 E 1.695 3155.18 10331.54 90.550 154.350 7186.13 7238.56 3907.125 413.94 W 5970394.37 N 371252.29 E 0.649 3250.06 10427.54 90.650 154.630 7185.12 7237.55 3993.76 5 372.60 W 5970307.04 N 371292.14 E 0.310 3345.96 10522.58 90.490 153.220 7184.18 7236.61 4079.12 S 330.83 W 5970220.98 N 371332.45 E 1.493 3440.93 ------.-- ---- ---------- 14 May, 2002 - 15:37 Page30f5 DrillQuest 2.00.08.005 ~.........I)." . Sperry-Sun Drilling Servic'es Survey Report for CD2-50 Your Ref: 501032041500 Job No. AKMW22042, Surveyed: 29 April, 2002 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10617.70 90.630 152.940 7183.25 7235.68 4163.92 S 287.76 W 5970135.45 N 371374.05 E 0.329 3536.02 10714.34 90.900 153.250 7181.96 7234.39 4250.10 S 244.04 W 5970048.54 N 371416.30 E 0.425 3632.63 10807.87 90.840 153.140 7180.54 7232.97 4333.57 S 201.86 W 5969964.36 N 371457.04 E 0.134 3726.12 10904.92 91.220 153.560 7178.79 7231.22 4420.29 S 158.34 W 5969876.90 N 371499.07 E 0.584 3823.13 11000.26 90.570 153.810 7177.30 7229.73 4505.74 S 116.08 W 5969790.74 N 371539.86 E 0.730 3918.41 11095.64 89.880 154.790 7176.93 7229.36 4591.68 S 74.72 W 5969704.11 N 371579,75 E 1.257 4013.70 11188.76 88.490 154.530 7178.25 7230.68 . 4675.83 S 34.87 W 5969619.29 N 371618.15 E 1.519 4106.69 11286.16 88.380 154.540 7180.91 7233.34 4763.74 S 6.99E 5969530.68 N 371658,50 E 0.113 4203.95 11382.10 88.380 155.050 7183.63 7236.06 4850.51 S 47.83 E 5969443.22 N 371697.85 E 0.531 4299.73 11474.97 88.510 154.740 7186.15 7238.58 4934.57 S 87.22 E 5969358.50 N 371735.80 E 0.362 4392.43 11569.30 88,530 154.940 7188.58 7241.01 5019.93 S 127.31 E 5969272.47 N 371774.42 E 0.213 4486.60 11624.00 88.530 154.940 7189.98 7242.41 5069.46 S 150.47 E 5969222.55 N 371796.73 E 0.000 4541.21 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.057° (05-May-02) ",.-. "- The Dogleg Severity is in Degrees per 100 feet (US). . Vertical Section is from Well and calculated along an Azimuth of 151.860° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11624.00ft., The Bottom Hole Displacement is 5071.69ft., in the Direction of 178.300° (True). ----- ----- --- ------ --. ---- --- - _..- -- 14 May, 2002 - 15:37 Page 4 of 5 DrillQuest 2.00.08.005 ~~~'~t'i' . Sperry-Sun Drilling Services Survey Report for CD2-50 Your Ref: 501032041500 Job No. AKMW22042, Surveyed: 29 April, 2002 Kuparuk River Unit North Slope, Alaska Alpine CD-2 Comments ,- Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 6756.79 6820.00 11624.00 6370.78 6428.31 7242.41 1093.95 S 1110.54 S 5069.46 S 1400.38 W 1420.65 W 150.47 E Tie On Point Window Point Projected Survey Survey tool program for CD2-50 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 637.00 0.00 637.00 636.67 11624.00 636.67 Tolerable Gyro (CD2-50PB1 Gyro) 7242.41 MWD Magnetic (CD2-50PB1) /"'"'. .~- ----~ -------- - --~---------- 14 May, 2002 - 15:37 Page 5 0'5 DrillQuest 2.00.08.005 ) \;J6A )JJ- Ðt~ 4/15/01- vi/b~ -ð >- 7;G~ Z- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon - Suspend - Alter casing - Repair well- Change approved program- 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2063' FNL, 1503' FEL, Sec. 2, T11 N, R4E, UM At top of productive interval 1311' FSL, 2287' FWL, Sec. 2, T11N, R4E, UM At effective depth At tota I depth 1335'FNL, 1581' FEL, Sec. 11, T11N, R4E, UM 12. Present well condition summary //--.. Total depth: measured 7958 true vertical 7200 measured 7958 true vertical 7200 Effective depth: Casing Length Size Conductor 78' 16" Surface 2348' 9-5/8" Production 7911' 7" Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service - ----- Per APO ----- Per APD Plugs (measured) feet feet Cemented Pre installed 336 Sx AS III L & 228 Sx 15,8 class G 150 Sx 15,8 class G 4.5" 12.6#, L-80 ibtm @ 7767' MD Re-enter suspended well - Time extension - Stimulate - Variance - Perforate- 6. Datum elevation (DF or KB feet) F\KB 52 feet 7. Unit or Property name --- Other _X Annular Disposal Colville River Unit 8. Well number/, CO2-50 ,.- 9. Permit number I approval number ../ 2D.1'"64~'1..ð 't. - 04- q W GIr- . 10. API number 50-103-20415-00 -/' 11. Field / Pool Colville River Field / Alpine Oil Pool p0- '\ SR..~-\-\~"" ~~\ \ \ \-a b\è &-ì\\~ \\",-<ë\~ ~{ ~\\ ~'\S~~, "-^.\Jð Þ~~l L{ (":> ~ easured Depth True vertical Depth 114' ~ 2~~ ~9~ .-....'--""---. 7199') -~ RECEIVED ~948' 5 2002 AllllllOiI&GllConI.COnuniIiOn AncItorIge APR 13. Attachments Packers & sssv (type & measured depth) 7" Baker S3 Permanent Packer @ 7650' MD, Camco BAL-O SSSV @ 2004' MD Description summary of proposal - Detailed operations program - BOP sketch - Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic _X 14. Estimated date for commencing operation 15. Status of well classification as: May 10, 2002 16. If proposal was verbally approved Oil_x Name of approver Date approved Service - 17, I hereby certify that the foregoing is true and correct to the best of my knowledge, Signed /'1 ~!. ()tJ( Ch/P~ Title: Alpine Drilling Team Leader Gas- Suspended - Questions? Call Vem Johnson 265-6081 Date t( 1- (o~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval n~ . . Plug integrity - BOP Test - Location clearance - {" C7"- ¿~;.2.. -I c.-::L.j Mechanical Integrity Test - Subsequentform required 10- ~~ C)-\-~~,,~ ~ ~ ~~Q \ Onglnal Signed By , = ,/)j' Approved by order of the Commission Cammy Oechsli Taylor Commissioner Date J!j' ~ ? Fonn 10-403 Rev 06115/88 . - I'" I. :, ~ ~ !:.w- SUBMIT IN TRIPLICATE ) ') Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. CD2-50 b. The depth to the base of freshwater aquifers and There are no USDW aquifers in the Colville River permafrost, if present. Unit. Base of Permafrost = 1552' TVD (RKB) c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from. 15000 to 18000 mg/I. (Ref AOGCC Conservation Order No. 443, March 15, 1999) d. A list of all publicly recorded wells within one- See attached map indicating wells within 1/4 mile. quarter mile and all publicly recorded water There are no water wells within 1 mile. wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of Types of fluids can be mud, diesel, cement, and waste to be disposed of and the estimated density water. Maximum volume to be pumped is 35,000 of the waste slurry. bbls. f. An estimate of maximum anticipated pressure at Maximum anticipated pressure at casing shoe the outer casing shoe during annular disposal during disposal operations is 1911 psi. See operation and calculations showing how this attached calculation page. value was determined. g. Details that show the shoe of the outer casing is See attached cem.enting reports, LOT/FIT reports, set below the base of any freshwater aquifer and and casing reports. permafrost, if present, and cemented with sufficient cement to provide zone isolation. h. Details that show the inner and outer casing See attached casing summary sheet and calculation strings have sufficient strength in collapse and page. burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the Commission NA to confirm containment of drilling wastes. ') ) CD2-50Pressure Calculations for Annular Disposal DETAILS: ~ .... .... Q) "0 () 'U (t <U Q) () ..s:: ..s:: '(i) '(i) c.. Q. 0 0 0) 0 0 0 c: C'\I 0 '(jj C'\I co + + () t: t: ~ '(i) '(i) lC) c.. Q. ~ ..... ...... 0 0 ~ ø ø <U <U (!) (!) <=9-5/8" 36Ib/ft, J-55 BTC casing (if) 2385 ft MD (2395 ft TVD) Pburst == 3520 psi, C?'ÌJ 85%: Pburst8S% == 2992 psi '."""" .... .... "" .'tö'ë Z Z Estimated Top of Cement @ 7948 ft MD (7199 ft TVD) (7" csg x 8-1/2" Open hole annulus) t» c: :ë :J I- 0) ~ c: "';" 'ii) ~ <U () <=4-1/2" 12.6Ib/ft L-80 tubing to 7767 ft MD (planned) f-... L ~ <=7" 26 Ib/ft, L-80, BTC casing (4) 7948 ft MD (7199 ft TVD) P collapse == 5410 psi, (êg 85 <Y<): P collapse8S% == 4598 psi ~ ASSUMPTIONS: . M:aximum injection pressure, PApplied == 1500 psi . Maximum. density of injection fluid is 12.0 ppg. . Pore pressure at 9-5/8" casing shoe is 0.4525 psi/ft . Inj ecti on gas pressure is 0.1 psi/ft + 2000 psi header press ure CALCULA TIONS: Maximum pressure at 9-5/8" shoe: P max == PHydrostatic + P Applied - PFonnation Pmax == 12.0 (0.052) (2395)+1500 - 0.4525 (2395) Pmax = 1911 psi Maximum fluid density to burst 9-5/8" casing: Pburst8S% = PHydrostatic + P Applied - PFonnation 2992 = MWmax (0.052) (2395) + 1500 - 0.4525 (2395) MW max == 20.7 ppg Ma.ximum Fluid Density to Collapse 7" Casing: P collapse85% = PHydrostatic + P Applied - P Gas Gradient - PHeader 4598 = MWmax (0.052) (6855) + 1500 - (0.1) (6855) - 2000 MWmax = 16.2 ppg ') ) Casing Detail 9518" Surface Casing _PHILLIPS Alaska, Inc. . A Subsidiary of PHilLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 55 Doyon 19 RKB to LDS FMC Gen V Hanger 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Collar 9-518" 36# J-55 BTC Csg Davis Lynch Float Shoe 53 Jts Jts 1 to 2 2Jts 9- 5/8" shoe @ TO 12 1/4" Surface Hole RUN TOTAL 32 BOWSPRING CENTRALlZERS- 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #2) #14,16,18,20,22,24,26,28,30,32,34,36,38, 40,42,44,46,48,50,52 65 joints total in shed - 55 joints total to run Last 10 joints stay out # 56 thru # 65. Use Best-O-Life 2000 pipe dope Remarks: Up Wt - k On Wt - k Block Wt - 75 Well: CD2-50 Date: 3rl/2002 LENGTH 36.60 2.26 2265.08 1.64 77.64 1.77 2395.00 Supervisor: Don Mickey DEPTH TOPS 36.60 38.86 2303.94 2305.58 2383.22 2384.99 ) ') ~, Gm ~ 'RHILL,IP$,ÀLA$,~ IN~C., . 'C,é~e~ti:ngRfJP~'rt Legal Well Name: CO2-50 Common Well Name: CO2-50 Event Name: ROT - DRILLING Report #: Start: 1 3/4/2002 Spud Date: 3/5/2002 Report Date: 3/7/2002 End: I " I, I, . . I " ,',','., " ':, . ,,' ',',Ce~nt'Jpb,,':rype~,'J;>rin1aty ,. '", """,,', . .~~:"J~~_7=~:~i~~:~_~~~~:~:~~~i:l:T=.~~I~;'~;n~t;!~~~I:YZ=-~=~~-~;t~~~;':q~iry(l~==-~~0~~~'~~~Z¡~~:":I]~:~_:~~~;~-~~=~~~ Hole Size: 12.125 (in) Hole Size: Hole Size: Hole Size: TMD Set: 2,385 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 3/7/2002 sa Date: Date Set: BTM set: (ft) Csg Type: Surface Casing sa Type: Csg Type: Plug Date: Csg Size: 9.625 (in.) sa TMD: Plug Type: sa Date: Drilled Qut: Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Surface Casing Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jim Thompson Pipe Movement: Reciprocati ng --¡'~~-'~'-:--c--:,,.~~.~.:~:-:-:-:-,::,~r~:~:c:',..,.,-r~~--:-:7~~'~':~~~~-:;~'~':~~'-::~:~';'~:-:-7-:-'~:~~?~-~"7-~~-r~' ',~:-::'ë'r~':~~'7:~-: ':,:'~~-""~:~-:¡~~'7 '~;-: ,:.:,,":~.~ '~:':,,..,.-~..; ,'_. , ," . . ,PJPè':I\II~ve~~nt'" ".'. . . ,,'" .,1 ,I, ":', "':"II"¡I, "':.'"' "I J Rot Time Start:: Time End:: RPM: Rec Time Start: 18:30 Time End: 21 :00 SPM: Init Torque: (ft-Ibf) Stroke Length: 30.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 160 (Ibs) Max Torque: (ft-Ibf) Drag Down: 145 (Ibs) ""'7""""' r'fl""-ï"r-r-;",.... ,~",,,,,,,,,-,,,,,,,,,,-,,,:.,,,,,,._~.~ j""'11"'--"-".':,"".....,. .,......,.~~---.,.....:.~,.,..,.:.... "'rr~--"-'-:.''''''''''''''''''1'''''':''~':I"'r:T'''''''''''''''''''''~~'''''::"'':''''-r:''' rr~"""""""':~""':""""''''' :""""T""""""T""':r"'r"'" 7''''~~'''''-'''7''''"::'-'''''",:''''~~''''''~':n:-''''"'"':'''T''''1'':''~ ,', '"""':",:"'''''''~-r:.':-'1'''r'''F~-""'"'""T"'''''::''''''''-''''' ~"""T""~-"'1'7:;'''''' ~... """1'1'"..........,.... ::'..... ,'" ".' ", ',' . , '" ,,' '., "$tå9é:No,:,'10f;1",'., ,,' ,:,' """'r''.,,'' ',,', _~l.._~~.._~~~:~ -~.....~~~~-;~-~-_.......:~~~~;-~~.._,.:....:, -~---;~"'~"-~:'~~~:~_.L.~-:"""':;-_.~~;-_":.._-~~~_.~~:;~_.....~'~~~-~ _;~i.._'~~~~~;~~~~~~~;~~-~~~;--~......:~~~~~;--~--'.......:~~:~',;... _'1.._~~~_~.;:.._..:............::~ -~~;_...~.._~:- ~~~._.:.1.._.:........._~~;...L Type: Cement Casing Start Mix Cmt: 20:30 Disp Avg Rate: 7.00 (bbl/min) Returns: full ../" Volume Excess %: 64.00 Start Slurry Displ: 20:33 Disp Max Rate: 7.00 (bbl/min) Total Mud Lost: (bbl) ./" Meas. From: Start Displ: 21:25 Bump Plug: Y Cmt Vol to Surf: 120.00 (bbl) Time Circ Prior End Pumping: 22:00 Press Prior: 690 (psi) To Cementing: 1.50 End Pump Date: 3/7/2002 Press Bumped: 1,200 (psi) Ann Flow After: N Mud Circ Rate: 252 (gpm) Top Plug: Y Press Held: 5 (min) Mixing Method: Mud Circ Press: 300 (psi) Bottom Plug: Y Float Held: Y Density Meas By: , " ,,' " " "I ""', I ", , '" .:..._._-~~ ':"""__:__...':'...:._-,-..._..~,:- ._---~_. ~.:-..~-_...~'~ .~.:-~--_.:-;~-_:_..~.:...:.'2-~_:_,""~-- ~_",,:_,""~.:._.':"':__:~-~~'.~-_:__...':'_';--_._,""-~ ~-":,,,~:_,""~,.:..-: .~_":_';'~L.._~~---~~..';""-_._-~':"'_. --- Type: Spud Mud Density: 9.6 (ppg) Visc: 66 (s/qt) Bottom Hole Circulating Temperature: 68 eF) Displacement Fluid Type: Mud PVIYP: 14 (cp)/17 (lb/1ooft2) Gels 10 sec: 12 (lb/1ooft2) Gels 10 min: 18 (lb/1oofF) Bottom Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 178.00 (bbl) " , , Stag, l\Io~'1'Slurry No: 1 Qf 4 . . ~J...--.~~_....~-~..._..._...._....._.¡.I.....:_...o.-~-_....-------_._':"".¡.--.:......._--._:""'.Io_..-,--¡...._,.j"_._¡'.a._.IoL..-__~..._Ll_....._.....~.I...I...-.-_~...'_.-_----_.Io.L..--_..._.LI..~_",""---,,,.._..L..-_...o..-I..__.""""':_....._...._,.¡,¡L S lu rry Data Auid Type: FLUSH Slurry Interval: (ft) Water Source: To: (ft) Description: Biozan water wi nut plug Class: Cmt Vol: 40.0 (bbl) Density: 8.30 (ppg) Yield: (frisk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Auid Loss: (cc) Auid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (oF) (oF) Pressure (psi) (psi) (OF) Printed: 41312002 3:23:53 PM t;HI~~P$" r!T!I ,~ ) ) ,I , , PHI~LIÞ$'ÁLA~,KAI'Nè'. ,C:,èroerjti:n,g'Re'pØ'rt Legal Well Name: CO2-50 Common Well Name: CO2-50 Event Name: ROT - DRILLING Report #: Start: 1 3/4/2002 , , . . .. p~gé~of3 ' Spud Date: 3/5/2002 Report Date: 3/7/2002 End: " . I " ' ';,:., ' ., " , ' ' ' ",'Stag,~N():"1"~IUf.ry'~P:"20~'4 " ' '. '.' ',':, ,', " , ~,....'.:.~~~~-.¡....~~-~:"""_'~~.~---_~~....:l'~._---~ .-.:..._i'.,¡.~~-~,~~',,¡,~~--~~~,~~.~-~,,¡;~...L':"':~~~._":"'~-~~~~.:....w-:~~~~~~.,¡':-------'~.,¡.~---~~~~ll~.~~_.~-~~;~-,-,.,~~~.,¡.~..w-_--.....¡.~~~.. ....._~-J-~~ Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: To: (ft) Description: ARCO SPACER Class: Cmt Vol: 50.0 (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Temp (OF) (OF) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) II, ,I, : ',,', ,'I!,',"",I, ,',':,,',,! 1,1,," ,",1 "', I,. "I""" ,,", :1,,',1 I , ' "'" 'S~g~:N(J~,1,SJurrY,N~:30f41 ,"." " I ,', I " " ' ..:-_._.~--.¡ ~'-~'.~'_.~-- .¡ :"_~_.__L~~'~ :..--;..'ø '-_l_~~~'~_;"'R~~;.~_:LL '-__M'''_~ _~LL '_....~~.~_L ~~'_~~.~_L_~.. ~~~'-'~..~-~..~...:.~'~~~~-~~...~~~~L~ L! J..~~~_..L__~:..~~~~---~-~,: '_._...;..~,_..'~-~" J_'-~~_._~~-- ~.L..~~_:~"'~_.-<.'L! .1..-"': Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: eF) Slurry Data Fluid Type: LEAD Slurry Interval: 1,885.00 (ft)To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Description: ASLite /' Class: Cmt Vol: 284.0 (bbl) Density: 10.70 (ppg) Yield: 4.40 (fP/sk) Slurry Vol:336 (sk) Water Vol: (bbl) Other Vol: () Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp eF) (OF) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) ~~:=:=~~-=~~~~~~~;T~€~1~==_~~~~-=:~~-=~--=~:= Slurry Data Fluid Type: TAIL Description: I Class: G Slurry Interval: 2,385.00 (ft)To: 1,885.00 (ft) Cmt Vol: 48.0 (bbl) Density: 15.80 (ppg) Yield: 1.15 (fP/sk) Water Source: Slurry Vol:228 (sk) Water Vol: (bbl) Other Vol: () Test Data Thickening Time: Free Water: (%) Auid Loss: (cc) Auid Loss Pressure: eF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: (OF) Temp (oF) (OF) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Printed: 41312002 3:23:53 PM ) ) /PIi:.tLIPS' ,cø . . .. I " , PHr~LIÞS'AL~$,kAINè. . C:èh)enti:119 ,~ep~#:t . ,p~ge 3,of 3 '. Legal Well Name: CO2-50 Common Well Name: CO2-50 Event Name: ROT - DRILLING Report #: Start: 1 3/4/2002 Spud Date: 3/5/2002 Report Date: 3/7/2002 End: "--~-~----'-"-~7~~----~-~~~7""''"7-''~'~"':"7~~-~-~7'--~':.~:~-~-'?7'~~7'~'~-:~"7 .' . ciasittg:t~st., ,.. "'" ,:~h'o.Test"", ., '...., '". "Li~e'r'TQ'p'.'Test" .',., ' . ~..J._.i-~~,~~~........,..~.__..J"'~~~~--~~"_.M-_~~~'~""'''---~~~;~----~~_J.:~.~..i._~,--~~.~..;.....-~~~~.~~~.~':"..J'_~':'-~'~~..J'~""""_.'~-~;~"""'~~:~~J.~'~~~~.~"~""""--'~._-'..J.~----_~~_.:._L........--.:"""'~ Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 16.10 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N -';"~".'~,ï7':":""''''''~~'~:~'-7' ~~'~:"'-7'""""~.".-""-""~~~"~~'-":-:~':~"""7""'''~''~:-'''''r--"~'~":~~''''':'':'"''~':~::~~''~7'-~'~~;--: , , 'I ' I ' I ~,-~~~~_f:"_~~_i~c~..~~,-,-,,--~~,-~~~~~2''-''-~~'-~~:Lic,~ eBl Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: (ft) How Determined: TOe Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N .------.--.-.----. -..--.-..---..--.-. -"-'--'-'---"'--'-'-'--"----'-'---"'--'- Printed: 413/2002 3:23:53 PM ') I ) ?:ma. ÎtltLi~ , " " ~ ~ I P"UI~p~,'AI~S~~f~~~~ " ,,' . "'.I. . ,', ". ... ,'" " Da,ny~t'lbngf{~p~~" . ,'" , , , lJOBNUMBERIEVENTCODE 24HRSPROG "TMD ¡ND .IDFS REPTNO. ..fDATE CD2-50 ODR 257.0 2,395.0 2,391.0 2.00 3 3/712002 SUPERVISOR lRIG- NAME & NO~--- l'ELD NAME I ÕCS NO. --- AUTH MD _I DAIL V TANG JCUM. TANG '___I ,__, Don Mickey,___- ..-,-_. doyon1@pPC<?~.1.!L1~,_. .-- ~.!PJ~e 12,125.0 0.00 ,.-.--- .-,.-,____.9.:9.9_____.., CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTWIO MUD CUM INTANG WfMUD ._._---,,_..,--,._-,.--_.,..,_..._-,--~.__.._,.,-_.I~~!!.':1JL~qP'_IL_~_.__._---,---_._-----,_..,-_.__._---, ---__._...Qm.__._..__._-~._-,-------,---_..Q.:,QQ..-,----,_..-._._- 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD Finish BOP test - MU 8 .5" BHA - Drill 8.5" hole 3/612002 185 370 555 202 ~~~~¿~~~~~~~-~~~= -'.!?~!t~!!(r~~!',~.,.~-_.._~~,:.-_...,-l!!i\.l'~-':'~--'T~ ..~..-.,,~~~L-,-~:_I~!J.~p~:t~,"I' ...:~~~t.!~~Tj..,~ë":-~- _.~:.~...- -,~.._.:-L~~~~~I.j:'~"-:~-:1.P:g~--,--_. -'~.. ", f\I..,.~V,!~ :"Oa:sL~~ )~....'r1iF-,,'., F~I1~'$OL, '" :ÖI,Lf\'II~T ..,'.,,:.~~~dltJll,T.. , "IPh/p~" , ,fit(II¡If,', ,:,',',CI" .,.., ',"',ta'".' ,1:t~S,lIlVI~..." ~S,' 66 14/17 12/18 16.4/ I I 120.0 8.8/ / "tiA'Ã:'~o;'I---1-"- "-r~-:.-;---" 7'~-'-~~~:?",-,'-"-;:7-':"---'-ãHð~TjiQii~CONBi1ìQÑ¡-";~-.-': 7-:-C~~'.-:;--,~~:7~"-;-:-r'BitfiÏQ.~ :T-.'---' --.. :~~!:J§~~.~~~~~-~!~-~=__!~!!!~3~~==~=~~¡:¡~~~;~~~22:~=~iäí~~~~7cFt8!~=~~¡7~ -~!€~~Û~~~E~~=::,._.~'Z!~~~iN~i;~~:~=~ 21 150 145 150 7,ooOft-lbf 1,001.19 :':--'-~"::"~~'~'''''é''-'~;--'~''ïT~~~¡&f.tìpT'Ø~ ," ..,. '~~"~'_."-~-~~"'''N~'"jf$~' .. ': lE~G~ïf7~'~.7"~~;p~~'~-~'?~-~,'"~~i~D?~--,:'~~-:~ff¡íi~~;.~9()N~:'Ti~IF Bit MXC1 1 1.00 12.250 -'--'--~'---'-_'____M'_~_~'-'---- Navidrill MACH1C 1 28.82 12.125 XO 1 1.30 8.000 3.000 '-'---""--"-"--"-""'--'-'-'-"'---'-' .----....-.-.-...-.-.- -"'-'--"-'---""--'-'---"'----'-'---"'-'--'-'---,"'__'M"_'_'--""-'~-""----',-",_,_,_,- SNMDC 1 9.92 8.125 3.000 NMSTAB 1 5.63 8.000 2.875 .._.__...~_....._._~--_.._......._._..._,..._- ,_...,._._-_.-...._._...._._._-_._~-_._.._-_._.._.._.._--""'-""-"----"-"---'--"---"-"'-'----"----- SNMDC 1 9.40 8.125 3.000 MWD 1 30.30 8.000 1.920 '"'-"'---'-""'------'-" "'--'---'-,"'--'-'-'-"'--'---'-.'.-..'--'-".-..--'-'..-.. UBHO 1 3.27 8.000 3.000 NMDC 2 61.15 8.000 2.875 '.----'-.-.-'...-.--'-.-'-'-.-.--'---'...'----""-.--'...-.-- -.--....-.--.-.-....-.-- --'...----.-.--...-.--.-.--'...-.--'.-.--'...-.--'-.--.-.-.---.---....-.--.-.--....-.--...-..-.... NMSTAB 1 5.54 8.125 2.875 NMDC 1 31.07 8.000 2.875 -------.---- -.--------...--------..-------....-----.--...---- ----.---.. -.--------.---- XO 1 3.65 8.062 3.000 HWDP 3 88.34 5.000 3.000 '-.-----.-..'.-----.-.-.---.--. -.-....----.------.-.--.--- JARS 1 32.71 6.250 2.250 ---.--.-.-.--.-..--.-.--.---.-.-.-.---..---.-.-.---..--'-'-'---'---'-' -.---..--.-.-.---.- -.---..--.-.----..--.-.-.---..--..-.-.---.---.-.-.- HWDP 23 689.09 5.000 3.000 WELL NAME --.--...----.---,--..---.- -.-.---,,-.-.-.......-,....... -...-..--..--.-..---.----.-....-"...---- -,--...--------.. .----'.-.--.---'-....---'..- -----..-..-------....,...-------.-.,....------. ...----. ----..----..---.-...-.--------.,...- . ,,"'" ',' ':", , ,".,' , " "" ' ,''''''. , ' .:',"'.. ,'BITS,'....', ":", ","'.,.', ,':" , .. ,,'.,' ':'." ,,'<," ,', ".':, ": ~-riïtJ'JltUN~'~-'~Sízit~'.--~MÃÑÜF~-'~"'~TYP¡:'~-sëRÎÃLNct'~':'~~"~'Eif&O,t~Ã~~._'''-~'pËp~:itt~ïi'tN-~:-'~-,~~'¡4ö:R''~--'~ 11 12.250 HC MXC1 L33JX 10/12/12/18// 114.0 3/6/2oo22-4-wr-A-E-2-RG-TD ..-----..-.----..---..----. ..-----..----.---..-------...-..---.--..-------..-.-----..------.-. -----..-..----..-... ~~~=.=--===--=--=-:.~.~=~==~~_.~, --1tŒ..QP,~.~Tiq~S' ',-~~",~,-~:..,~.,~~~,--=~,._-~~,..=~~_.~~,.'~'" BIT I ftUN ,WOB, RPM. GPM'. PRSS$, ' P BIT HRS' ~4Hr OIST. 24Hr ROP CUM HRS CUM DEPTH CUM ROP ---"':------------------"":""'-------------"""---' --- --~-- . I -_.......-_~-_-:-~- 11 5/35 190 544 1,650 869 4.00 257.0 64.25 13.90 2,281.0 164.10 --.---.---.----.-.----- -.-____._0- MAKE OF PUMP Continental Emsco Continetal Emsco . SURVEY DATA T.V.O. rillS CUMEIW CUM SECTION: M.D. 2,166.49 -67.00 -66.47 27.74 2,330.18 2,261.86 -67.07 -67.05 27.52 .. ".,'PUM,P:IHYD'RAUUÖ])ATÅ' .STROKE (in) LINER (In~ SPM Q (gpm) 12.000 6.000 65 272.09 12.000 6.000 I 65 272.09 -"",,-'---,.---.....,---.- ,---~-, MD. INCL. AZIMUTH 2,170.36 0.380 265.150 2,265.73 0.320 262.290 INCL. AZIMUTH T.V.O.' HIS CUM 'Em CUM SECTtON 0.160 295.600 2,326.31 -67.05 -67.31 27.38 NO. 1 2 PRESS. (psI) TOTAL Q KILL SPM I PRESSURE 1,650 544.18 1,650 544.18 Printed: 41312002 3:38:25 PM ') ) (ÍmÜ."~ "I I' , ~" 'r CD2-50 I , . ,I' I . I I I I Ph~~Up~'\I~Sf<å;' ~ric., ",,' "Q~,iIYI~rilling,Rep~tf " ,",," IJOB NUMBER [EVENT CODE I24HRS PROG" , ITMD' ODR 257.0 2,395.0 1~391.0IDFS2.00 REPT;O. ID;~~2002 WELL NAME :~=:=---~""-l~==:I~.-~-,,~~_._~2~:L.~.~,,.2-:~C9~:~'~~J&~!?'rI!LI'ßM~=~"~~~''''''A".','":~L,,l~:--[:~:~C'.L.--=:'.=7~ ~~5>~~~~~-~HOUI\~_:~CÔ~,:~:.~_}~9E~I,.~~_~U$~--~A~~~,~,~~~~-~~~,~~~~~.~~~~~E~CRI~TI()N '.,' ,,' "I'" 00:00 05:00 5.00 DRILL P DRLG SURFAC D rill 1 2 1 14" h 0 I e f I 2 1 38' to 2 395' TV D 2 39 l' A DT 4 ART 4 --~9.Q._~.~g_.__._..Q~~--,-_!?_~~!:_~_.~._._.._-_._.._----,~~-~-~---_..._~~~~~~-~.!.~.~~_!.~-_.~~~.~~___~.I e a n 1 3 B P M 1_i.Q_Q..._p siR &,.~_._P',~P-~~.._-_. 05:30 08:00 2.50 DRILL P WIPR SURFAC Wi per t rip f I 2 395' to 1 096 ' - R I H to 2 300' - S a f ._---,---,----,-, .---------..---------..-.------.-..-----,----...---------.~-~y_.~._~-~-~-~_._,.!._~--~-~_._..!..?_-~~.~_?' ._.._---,_._--~.._- 08:00 09:00 1.00 DRILL P CIRC SURFAC C i r cui ate h 0 I e c I e a n 1 3 B P M 1 350 psi R & R pip e 09:00 11 :00 2.00 DRILL P TRIP SURFAC M 0 nit 0 r well (s tat i c) POOH to B H A - m 0 nit 0 r well (static) stand back HWDP PULD SURFAC L D 8" DC, Po n y coil a r, s y a b, M W D,m 0 tor, & bit - clean up floor -_!~~.~_..._~_?:g.9._-_..,_!:?Q-_._-~~'§~--~_.._,,-~,-,--,--,--,-_.._,-~~.~l?._-,-~~~~~C;:_!3_~,~..._~_P-_._~,.~--"".!~-~-,.~~,-~!.,,-~~,:_,--~..!,~,.J_r:!_~,_.,:,_,f,.~_~_~--,-_..-.-----.-..--, 15:00 18:00 3.00 CASE P RUNC SURFAC Run 9 5/8" 3 6 # J - 5 5 B T C cas i n 9 55 j t s. wI s hoe @ 2385' FC @ 2304' - Baker-Loc first 4 connecti ons - ran 32 bow spring cent. as per program PULD SURFAC L D fill up too I & I and i n 9 j 0 i n t - b low do w n top d r i ve - MU cement head & lines -_.~.~:,~-_._~.Q:gg-,,-_._~:_?_~__..,--2.~_~~~I.~._..__.._...._,--,,-~-~~,~.__..._~-~,.~.~~2_,~.L~.~,_~_!.~,!.!._,-~.._?_?..!!..~-~.~.~,_?._"-,_.!_~..r......_~-~-~_!._~~,..L~_.~-,_:_.-.~,~,.~.~,,--_._.._.,,--,-- 20:00 22:00 2.00 CEMENT P PUMP SURFAC C e men t 9 5/8" cas i n 9 - P u m P e d 40 b b I s b i 0 Z an s p acer wi nut plug - 5 bbls water - test lines to 25 00 psi.. Drop btm plug - 50 bbls Arco spacer @ 1 0.5 ppg - Lead slurry (ASL3) @ 10.7 ppg - observ ed nut plug @ shakers wI 257 bbls lead pumped - pumped down surge can - 280 bbls total lead vo I. - switched over & pump tail slurry - "G" @ 15.8 ppg - 48 bbls total vol. - Drop top plug wI 20 bb I water fl Dowell swithced to rig pumps & displac e wI 9.6 ppg mud 161 bbls - Bumped plug wi 120 0 psi - floats ~Id - CIP @ 2200 hrs. .. Full retur ns wI 120 bbls 10. 7ppg cement returns to surface 11:00 13:30 2.50 DRILL P 18:00 18:30 0.50 CEMENT P -~--_._,--_..~--_._._---_._-_._.- ---_._-_._,----_._.~_._._-- .---.-.---.-.----.----- '-'---'---'____.0_'._'_'---.-'-'-- 22:00 23:00 1.00 CEMENT P PULD SURFAC R D c e men the ad.. L Dca sin gel e vat 0 r s & I and i n 9 j 0 i n t ----.-, ---.----- ------ OTHR SURFAC Flu s h 20" s t a c k - Rem 0 v e d i v e r t e r Ii n e 23:00 00:00 1.00 DRILL P ------ ---.------- .---..------.--.-. ".---------"'---'---..'___.0 --.---.--------.-- -"---.--"'-----------""'-- 24 HR SUMMARY: Drill to 2395' - Wiper trip.. POOH - LD BHA - Run & cemt. 9 5/8" c~sing . , . PERSONNEL DATA . " . .' ---.,_._._-'-_..._--....-._...,-----_._.~-.,........_.._-"!-,,-,,,,----,-or----~~~---_._~-~_._._-.,---_.-..---_._-..,......._._-.......----......-_..._-.......__. 'COMPANY SERVICE'. NO. . HOURIS: COMPANY SERVICE' NO. HOURS Phillips 2 MI 2 Doyon 25 , Sperry Sun 3 ACI 5 Dowell 2 BHI 3 FMC 1 Fuel Water, Drilling . 'USÂ~[: . 1,835 940 . MATERïAL$).CONSUMPTION . "ONHANþ .. .""JTêN -5,962 . Water, Potable -3,220 '. '! '. ---- UNI,TS. "USÁ~E ' 90 "ONHAND -270 Printed: 41312002 3:38:25 PM ). ) ~. I~I'$~' ~' ~ , '. . ,."Þag~~,óf. ~, " ~hUI¡p$,Ålaåka~,Jnç~': , .l;)a,ily',Pt~ding~pþtt'., , ", ' JOBNUMBER[EVENTCODE 24'HRSPROG ' 'TMD JrvD "DFS' ODR 257.0 2,395.0 __2,391.0 2.00- , r ' DATE 3/7/2002 WELL NAME CD2-50 =:=~._~~,:~~~:~'~:~-=',~~~:~¡~~'.~-==:=-~~-~;,,2~YJ~~BI:~fr~'~Ä~~-=',~:~~=',=-~~=:=-==~¿~-~::.~-==,~~~._~ , ",,'1:YPE' ,NO.' ,. " " Ft&MAftK$ , ,,: ,". ' "1YÞE' , ':,NQ. ,., "'RI5I1r'1A~kS"" -.--1------ . . ., - I L ............-----..--.1..............-..""-'---....-1-1..-.........-.0..-- ., . I . \ ., . CD2-15 ---_."._-----~.!Q.~~ CD2-50 Printed: 41312002 3:38:25 PM Well Name: CD2-50 CASING TEST and FORMATION INTEGRITY TEST Date: 3/8/2002 Supervisor: Don Mickey Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/8",36#, J-55, BTC CSG Casing Setting Depth: 2,385' TMD Hole Depth: 2,415' TMD 2,381' TVD 2,411' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 30' EMW= Leak-off Press. + Mud Weight = 800 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,381' Used cement unit Ri¡:¡ pump used 3,000 psi 2.900 psi 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 )5i 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi - W 1,800 psi 0::: 1,700 psi - :> 1,600 psi - ~ 1,500 )51 " W 1,400 psi - 0::: 1,300 psi 0.. 1,200 )5' - 1.100 psi 1.000 psi -- 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 0 y ---- EMW for open hole section = 16.1 ppg ./' NO #2 Pump output = 0.0997 bps After review Fluid Pumped = 1.0 bbls Fluid Bled Back = 0.7 bbls ....... 111111111 . II !llLliy.LlliLLII Tì1~lll1llll1 . I I ¡ll~.¥~~;1 ¡ I i . -'--""-"";',,"õOO::-'=.'.-,,-;'~-"'Î I I I I 20 ~LEAK-OFF TEST ""CASING TEST --LOT SHUT IN TIME -Á-CASING TEST SHUT IN TIME - ~TlME LINE ! 30 STROKES 40 50 10 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA I i - ! MINUTES FOR lOT STROKES PRESSURE I I - 0 I 0 psi I ~-- ---- . --- ---~., .- - ---~ I I 1.0 I 30 Dsi I t=---:_~c~-_. --, I --- - ----t--~-~ ¡ i - 2.0 i- 60 psi i i i 3.0 : 80 psi i i--~---- -~- I - , ¡ -- i 4.0 120 psi i I --I 5.~ 250 psi j L_____--- -; --- ~~~ :', 360 psi 1 ! i 7.0 ¡ 460 psi ¡ r- I 8.0 ! 580 psi! 1-- : - I . t I---~_. . . - 1 - 9.0 - 1-- 6~~ es~ -~ : : 10.0 I 800 pSI: I -- - I I : 1-- ¡ 1--- --1 I I I I I ! --I i L ---_____--1 i I I I I I I . I I f------ --- i - - I I 1- 1 - i i I , I I ~:O"::::::: 1-0 --I I L_-==~-==-j........,....,...,...........i,......................,......,.. i i i i I SHU~N TIME i ~HUTIN PRESSU~ ~-i>.:-QJ11~!!- i - i - 800 ps~ ~ ¡ 1.0 mm I ! 760 PSI! ¡ 2.0 min ¡ ¡ 730 psi i L-~p f!1Ï!L t --- --- i 71~ psi J i 4.0 m~n ~ i 700 ps~ i I 5.0 mm : I 690 pSI I ¡--- -- . - I -ì - u . I : 6.0 mm : : 680 pSI I i 7 0 . i i 670 . ì J----' m~n I I pSI I i 8.0 m~n i i 660 pS! i I 9.0 mm I I 660 pSI I I ~o 0 . I I 66-0 . I ¡ . ...' mm ! ¡ PSI! 60 ~PHILLIPS Alaska, Inc. ~ A Subsid!al')' of PHILLIPS PETROLELM CCMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r I 0 stks - I 0 psi! J -= : ~ - - -4 ~-- I -- 2 _~!k~ 1- 15~p.!W ¡ I 4 stks i 310 psi; ¡ I 6 stks i 610 psi I f 8 stks 1 890 psi --1 i 10 stks I 1,060 psi I L~ . ----; 12 stks 11,~40~Si j I I 14stks I 1,450 psi ¡ [- I 16 stks i 1,6~0 psi J I 18 stks I 1,890 psi I t- - . ~c - I - -- - i i 20 stks ; 2,130 psi; ¡ I 22 stks i 2,390 psi i J:~ -P3 stks f - ),5ÕO - Psf-1 t. i - L -- j i I I I I I . I i i - i i t-- I 1---1 i~ . . -~ i i i i ~~!.~ ~ME I _n. _n__~_PR_~~~~~..E ; 0.0 mm I 2,500 psi I f 1.0 miF1 : - I 2,500 psi I i 2.0 min i i 2,500 psfl L 3.0 ~in i I 2,500_psi j i 4.9 r1]~n - i - -- i ~,!~O ps~ ~ ¡ 5.0 mm i i 2,500 pSI i ¡ 6.0 min ¡ ¡ 2,500 psi ¡ [ : 7.0 m~n f I 2,~_00 psiJ i 8.0 m~n I ~ 2,490 psi i I 9.0 mln I I 2,490 psi I t- - -.-;. I -~ I -- . 1 : 10.0 mm : : 2,490 pSI: r 15.0 m~n i i 2,480 psi i i- 20.0 _m~n i i 2,480 PS!~-~ I 25.0 mm I I 2,480 pSI I I 30 0 . I I 2 480 .-1 ¡ .' mm I!, PSI! ~ ~. NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Phillips Alaska, Inc. '} ) Casing Detail 1" Intermedíate C,asinQ Jt Number Num of Jts Jts 3 to 193 Jts1to2 Remarks: 191 Jts 2 Jts Up VVt = 270 COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKS to LDS FMC 11" X 7" Hanger 7" 26# L-80 STCM Csg 7" Davis Lynch Float Collar 7" 26# L-80 STCM Csg 7" Davis Lynch Float Shoe 8-1/2" TD 1 straight blade centralizer per jt # 1 thru # 17 # 137,138,139 every other joint # 141 -191. Total Centralizers (46) 200 joints in pipe shed - last 7 joints stay out Use Best-o-Life 2000 pipe dope On VVt:: 195 Block VVt= 75K Supervisor: David Burley Well: CO2-50 Date: :~/"6/2002 LENGTH 35.20 2.40 7824.19 1.40 83.18 1.70 DEPTH TOPS 35.20 37.60 7861.79 7863.19 7946.37 7948.07 7958.00 ) ) ~ 1';1';1 ~.. '..PHlL,LIÞS'A~AS,'~ .INq., .C,émenti:n9"ep~)rt ... .,P~g~1:oii Legal Well Name: CO2-50 Common Well Name: CO2-50 Event Name: ROT - DRILLING Report #: Start: 2 3/4/2002 Spud Date: 3/5/2002 Report Date: 3/16/2002 End: T=It~~ij:_3:"<"22~~~i~riË~~'~~~-3~=~i~=~~=DZ Hole Size: 8.500 (in) Hole Size: Hole Size: Hole Size: TMD Set: 7,948 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 3/13/2002 sa Date: Date Set: BTM set: (ft) Csg Type: Intermediate Casing/Li sa Type: Csg Type: Plug Date: Csg Size: 7.000 (in.) sa TMD: Plug Type: sa Date: Drilled Out: Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: OPEN HOLE Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jerry Cullpeper Pipe Movement: Reciprocating ~:-:~~".~'''-~--~~~~'''~:~~...~.~:~'-~~''.~';~~:~~.''~7-;~".~'~:~;'!~~"r~~~~~'~~'~"T~;':~::::!~.~:~~;~7:~~~t7';~::~:~"0~~~';-~7:?~~~~';~'~;'-~.',::', . . .. . '~iPè:,:IVIØve"m, ,ønt " "" ,', ,:,' ' I '," I Rot Time Start:: Time End:: RPM: Ree Time Start:03:30 Time End: 06:10 SPM: 1 Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 275,000 (Ibs) Drag Down: 195,000 (Ibs) '1,1 '~~'...,-~-rõ'""""""""::'~:"~~rTr"-"""""'.'"""'~"'~."'''~~?'i'''~''''~"''T'''~r~:'~'i~~~''~~'.,~':~--rI'"~-""-"''''''f''~~'7r''~-'-'.'~:'''''"r''''''''1''"~-:.,~ , ., . , . "., .'$täg~'NQ': '1,'0."fI1 . ". ", .. . '.,' .. I I I .' I" ,.,,1,. ", "'1"'1 "'I :"',1' I.., I I I I I, I I , ,I, I 'I I," ) I ._..:_-_.__:"'cC._-~-_._._-'--'C:.~.:_-_._~-;_._-~--_._~--''':.c...,.._._"--'_:._":_-_._-'-':._,:c__._-,,:,,c._~_:"-_._-,--,c,~.---'"".~-'--'C:._":.--'""._-'--''':._.:.__._';''''':'':_~---_._---''':- '-'c__..~--,..:.:.":c_-:"-7''-..---'--'--'c.._.c_- ,_._-,"'c.,.. Type: Cement Casing Start Mix Cmt: 05:12 Disp Avg Rate: 6.00 (bbl/min) Retums: 100 Volume Excess %: 50.00 Start Slurry Displ: 05:14 Disp Max Rate: 7.00 (bbl/min) Total Mud Lost: (bbl) Meas. From: 0 Start Displ: 05:23 Bump Plug: Y Cmt Vol to Surf: (bbl) Time Circ Prior End Pumping: 06:15 Press Prior: 800 (psi) To Cementing: 3.00 End Pump Date: 3/16/2002 Press Bumped: 1,800 (psi) Mud Circ Rate: 252 (gpm) Top Plug: Y Press Held: 2 (min) Mud Circ Press: 550 (psi) Bottom Plug: Y Float Held: Y Ann Flow After: N Mixing Method: Density Meas By: Densometor , :,', . ...' ..",'"..' .M~4D~~', "., ".".',..', ,',' --.--.......-...'--":.--...-...: ._~...._~-_....-...~--_.:._~._--..::_....._....,_.':'-"_;_"":'_'_"'__":'_"'':'_'M:''_--:'__':"_"''':''M:_-'':_'__''''':'''':'_~----'';'-:''_':'-''_:''..':'_.-:............:.-.._-_..._....:'.-~_.:...;._..:.- ._.:-.:-_._---...;._-_:_.;._":'...:....--":""_:_":'':''_.....,-~ Type: Non-Disp. LS Density: 9.9 (ppg) Vise: 45 (slqt) Bottom Hole Circulating Temperature: eF) Displacement Fluid Type: Brine PVIYP: 11 (cp)/16 (lb/100fF) Gels 10 see: 8 (lb/10Qft2) Gels 10min: 12 (lb/10Qft2) Bottom Hole Static Temperature: 159 eF) Density: 9.6 (ppg) Volume: 301.00 (bbl) ,SfageNo:1SlurryNo: l' Qf.3 , , "." " 1._""'--...~_Mi.--.",,"-I..~_.I._.,,--~-_oI._~_I..~_.Io-----_I..~_.I._._..~_.~_.-,,-..._.I.__---.l..._.I.....-.-._I.'M_'I.,"--~.. _.Io----_..~_.¡'_.--I...~_.I.__...._I..__I._-'---I..._.I._-----.._-.IoLI..-_.-"-I..~_.I... Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: To: (ft) Description: ARCO wash Class: Cmt Vol: 20.0 (bbl) Density: 8.30 (ppg) Yield: (fP/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Auid Loss: (cc) Auid Loss Pressure: Temperature: (OF) Temperature: CF) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: Temp (oF) eF) Pressure (psi) (psi) (OF) Printed: 4/312002 3:24:31 PM ) ) ~. ~. ~ ~, ,PHILL.IP$.ALA$,KA, INC. '. . . r I .', I .C,èmen~i"g ,aep()rt Legal Well Name: CD2-50 Common Well Name: CD2-50 Event Name: ROT - DRILLING 2 3/4/2002 Spud Date: 3/5/2002 Report Date: 3/16/2002 End: , "-~~~""'~~~""':~--""'T'T-7~~~~~, I " I-~'~~~~~'~""'--'~~~'~~~~-~~'-~ .', .. . ". ., ,',. ,'Sta~ð,,~o~,:1SlurrY'~O:2bf3"",.,. " ",' ... ... :':~._~~.c.:.._-~._~-,---~",_..........;__..:L_~_~,..:~~,-,":"_--,-..:_:~,~~---"-~~.~~-~c.:..:"::,:~,~-,-:..:_--~~.~":""_-_"':~"",.:.~..:--_:":~.,.:.__.,-...:L..:.~_."':"'::..._.,-~--~:_L~~__:":l.,.:.--:'_----~.,---:'~___i Slurry Data Fluid Type: ARCO Spacer Slurry Interval: (ft) To: (ft) Water Source: Report #: Start: Description: spacer Cmt Vol: 50.0 (bbl) Slurry Vol: (sk) Class: Density: 12.50 (ppg) Yield: (ft3/sk) Water Vol: (bbl) Other Vol: () Test Data Thickening Time: Free Water: (%) Fluid loss: (cc) Fluid loss Pressure: Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (oF) Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) , , . 1 , , . :! , ' , ,I , " " I ,I, I " : , !,," I, , ,~ I I I I I," ,I , , ',$tageNa:,.1,SIUr,yNo: 30f3 ", ,"',.'. ' , . ~-'~~~-~.t .~~_'~~.~aL.__IJ _....._~.~~~-_... ":.,,.~_.'_,~":'_"~_:__~._a~~I~ ~_.---N'-~~--~~---~~~__'~oL~'.~~~~'-~~'" ":_~'_.~N~~~~'~~~!~~:""~'; ~~.~'_:~N~'~~u '-~ ~'N.I~.~I_~_¡( ~;~~.~._~~~,¡ ~.....__,I_,._,~~¡ --~-,-~~:"'~~J~~~~~~.~I_.....:,¡ J~~~ S lu rry Data Fluid Type: TAil Description: G Slurry Interval: 7,948.00 (ft)To: 7,306.00 (ft) Cmt Vol: 31.0 (bbl) Water Source: Slurry Vol:150 (sk) Class: G Density: 15.80 (ppg) Yield: 1.15 (fP/sk) Water Vol: (bbl) Other Vol: () Test Data Thickening Time: Free Water: (%) Fluid loss: (cc) Fluid loss Pressure: Time Compressive Strength 1: Compressive Strength 2: Temp eF) eF) Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) -'~-~'~-(~".. "'""'7"-~ ~-~:....""""'7"-~ -,---.....'"""""7--; 7'"---'"" """"'7"- 1,----:",","" --;'"'-,-:~~~~-;-' -,,",,:~"7'"''''''''"'''"7-~'--(~~''''''''''-''''--~-~''''''-'--ì''''''~~~''''"""'''"7""""! 7'"~-~'-""'----~':--.""P ~:-"""~~~'-~"""':"""-~''''''--.~~,----~,--:--~'''''-~ ":-,----.... Cå~dng::T~,t Shoø:TJ!$t . , ILine'r'r~p'1e$t:" . . _J.-..;"~-' ,.J._~.-:"_""'--'--'':''''''~_.'_''''_-'';''''--'''':-'',,''''......J..~'......_-..__~'':'''-~_.'__........L-':':''''''''-'''':':'.'-';"---:'--':':"""'--':"_:""~,':""'-'-__,;..-"":"'I':"".'___""1.~"~~----'--"~__h""-'-_"':""'''''__':''''.............~'-,::...'_...!...._~~,.:.....':"'-':".'_2...-...z....:...,.I.o.~....!.:........~~,.:.....- Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N ---'-'1"---..---.----.-,....-- Tool: N Tool: N Log/Su r:'ey Evaluatio~ . Intèrpretatibn Summary , . , '--'-"""'-'---"--------'-"--""--'----",,,,,,-".~-'--'~-,.-....-',---'--'-""'--"--'-"'.'-'I"""--"~-'--',,~---,~-'---,....---.-;-_._.--""",---,,,,-'--.--,-,,--"-----.'-'1""'''--'---'''.'-'''''''---'.----. --'1"""-- .----- - - - -- ----..._-_...._--------_.._------~ -..--.----..-..--------...------,"-"---------..-- --,---------------"-"""---"--,.------,,,,-,,-------,,,----,,---,,,-,,-,,--"----------L....-..-..------...-..- CBl Run: N Under Pressure: (psi) Bond Quality: Get Run: Bond Quality: Temp Survey: N Hrs Prior to log: N Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator. Remedial Cementing Required: Number of Remedial Squeezes: N "Remarks Displaced cement with 30 bbls of FW from Dowell followed with 9.6 ppg brine (rig pu mps) at 6 bpm, increased rate to 7 bpm first 15 bbls of cement around shoe. Reciproc ated pipe until( last 15 bbls of displacement, full returns throughout. Printed: 41312002 3:24:31 PM ) (ím.'~.I~.'" I ' '.' , ~. ) ..' Pti~II~P"~I~Sl<a;...~nç: ., [)a,iJ'YDrl~lin9i~ep~tt ", , IJOBNUMBER.rEVENT~ODE 24HRSPROG . TMD niD 'IDFS . REPTN'O. DATE CD2-50 ODR 7,958.0 7,200.0 11.00 12 3/16/2002 SUPERVISOR tRIG NAME & NO. I FIELD NAME 10CS NO. AUTH MD I DAILY TANG I CUM. TANG -. .-.- Dave ê.~J1~Y..,_._- ..._.__._c!<?.Y9n1<WPPCC?~.~.19 .ð~!!~___.. .12,125.0 -.-, 0.00 ..- 0.00 CURRENT STATUS ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD CUM INT ANG WI MUD ._._._..._..._-,-_....---_..._...--':>.!~P~,~!:1.9.!~._~.~y.~_.~.9_Q.!f.S~g~J~~~..:_,-_.__._._........__._-_._..._..,-_.__._._..._...__.-~,_._..._..~_._-,_._..._.._-,--,_._.._...Q.lJ9. -...-...--.--,--_.9.:,QQ...-,-.-...-.,,--,-- 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD .-- Move rig to Nanuq #5 location and RU. 3/1612002 ,-----~§?J§.~3 -----j ,977,292 -'-"-'-- ~:~~£=~~:~;;~::l~~)~~~~~~--;:.o:=:== L~!t~!!(:~~U.._" :."~~,, -". ,.-l1!~l,_....,.-_.....,-:.._..._.-,~EJ.....:--J~!J.Ji~4IM"~l'~-L:t!~~!J-,---c-..,,~ "~:'~-',.~~"'r:"""t~~~~~I::J:...._..._-:-..9.::~,~-_..,-~ -.'~' ',." FV., '~VfV,~,;::~~$',.~ '!Vl1...Tf:ï~, F;C/1.$pl, , .,','. "C)',qw~r'\. ,,"%~I1~~~a,~, ., , ,',:PhfPNi.'" . ,"'~(~' ,",,: ,',C;'", ,(.:.."t;~,.,"I:I~~t ,'I"'IVIt: .,:..~S': 42 12/16 8/13 6.5/15.2 I I 115.0 10.21 I -..--..---..--- ..__._--.._-_.__.._.._-----~- ~~~~~~E~~£~fJ~~~~~~~?3E~~~~If~E:£::~~ _29..~- -Q~,QQ..--,,__!,:9.9___.~~~.§.~_....__._....._--_..._-_,_~~~9__.._.,!~!~,~~_..,B_~_~_._~_!_~...!~~,~..__!_~,,--~~,-~?.,,~~_._..._---,---,,-"'- 01:00 01 :30 0.50 CASE P CIRC INTRM1 C ire B U - 5 b P m - 560 psi - P U W 240 k SOW 1 90 k RUNC INTRM1 Run cas i n 9 - M u h a n 9 era n d L J - I and cas i n 9 wit h shoe @ 7948' - FC @ 7862'. Lay down fill up too I 03:00 03:30 0.50 CEMENT P PULD INTRM1 M U c e men the a d and b rea k c i r cui a t ion. .,~----,-_.-.,_..~._"_._--_.,_.. ....-.---....-.-.. _._---_._......_"---~..._....-..."_.,---_._......_._---_.,_....-.----..-.....----.---.--......------.--....- ..----..--.-....-....-----.-.....-.-----..-...-------..-..... 03:30 04:45 1.25 CEMENT P CIRC INTRM1 S tag e p u m p sup to 6 b pm, 550 psi r e c i pro cat e p i pe and condition mud. POW 270k - SOW 195k full returns throughout - PJSM. PUMP INTRM1 T est I i n est 0 3500 psi, P u m P e d 20 b b Iso fAr cow ash, 50 bbls of 12.5 ppg spacer and 31 bbls of 1 -------,--------,------- --,------ 5 . 8 p p 9 -_<:.~~-~_!:!.!-=-_..- ------,,----_. INTRM1 D i s P I ace d c e men t @ 6 b pm wit h 30 b b Iso f F Wan d 271 bbls of 9.6 ppg kcl brine, bumped plugs - f loats held. CIP @ 0615 hrs. Confirmed 9 5/8 X 7" annulus static. --------.-..-..----- -"--'-----'---'-"-------'---'-'-------'--.'''''--'.. ----.--......---..-- --.......--------...-.,..".------...--......----- ---"""-------'''''.'''''-------'''''''''''-------'---'-----------'''''- -,~~.._.P:ëg9__,_..2~9___..~5~~!'i!f._---_.._-,..E~-~,Q__._J~TRM1 R ~.~~-~-~,-~,~~-~..!:IJ._~-~-~~ and L D I ~ n din ~_..i.~!~~...:,--,----_._--, 07:00 08:00 1.00 CASEP DEQT INTRM1 Pull slim wear bushing, install and test packoff t .-----...-----..--...- -_._..._..__.._._...._~_..~ 00 0 p s..!..:---.-...-....----...-.-.---..-...-.. 08:00 10:00 2.00 DRILL P PULD INTRM1 L Dca sin 9 b a ¡Is - P U d rill i n 9 b a ¡Is - L D 5" h W d P f rom derrick. ____'_N._'_._-- SUSPEN R I H wit h 4 II d rill pip e t 0 5 3 0 0 I - P 0 H I a y d 0 w n d r i _...J.!......EiP e . -------- SUSPEN R I H wit h 4" d rill pip e,M U tub i n 9 h a n 9 e r I ins t a II TWC and land kill string @ 2334'. Test hanger se a I S ~.~~~~..-P_~ i . --------- ----------, SUSPEN C h a n get 0 p pip era m s t 0 4 1 12" X 7" - N D BOP s t ack - NU adapter flange and tree, test to 5000 ps i. Pull TWC. SUSPEN RUt 0 Do well and t est I i n est 0 2 000 psi I beg i n p u mping diesel for freeze protection. WELL NAME .'--'-"--'-"'-'-.-"'-'__'__N.___'N_".__'..'---"--' 01 :30 03:00 1.50 CASE P 04:45 05:30 0.75 CEMENT P -.--.--------..- 05:30 06:30 1.00 CEMENT P DISP -----..'-.------.--...-.--------.-.-------.--.----- 10:00 16:00 6.00 DRILL P 16:00 19:30 3.50 CMPL TN P OTHR ---------------- 19:30 23:00 3.50 CMPL TN P NUND 23:00 00:00 1.00 CMPL TN P FRZP Page'fof,2 ' -----,.,-,--.--.--...--.-.--.---.--'__'__M.__.__-.-"-'---.--.-.------..--.-.--..---..--.------. 24 HR SUMMARY: Run and cement 7" casing wi shoe @ 7948'. LD drill pipe - test casing to 3500 psi for 30 min. RIH - hang kill string @ 2236'. ND BOP's NU tree. Freeze protect to 2000'. Printed: 41312002 3:37:03 PM ) ) =') ~. ~' CD2-50 . Phillip6'AI~s~a;~nc~' , 'Qé,ilyQrIU'"Q ,r:tèpqtt, , ..'JOB NUMBER.EVeNT CODE 124'HRSPRÓG ]TMD ' OOR ---- 7,958.0 ,., '..'[ TVD DFS 7,200.0 11.00 ¡DATE 3/16/2002- WELL NAME =:~::~~~'.=-===~~-==~~:_~:_~~~,---:.-~~',==,-£g.B~1J2.&TA.,-:,--~._,:~~-==~:_~,~:-~~:L:-~~.~~-_.~=:-'~~,:Ä-== . . . "COMPAtf(. . .:$S~V.CI$. . NO; ,HOURS".,.~NlPANY'.' ,$ERVICE=-. .:, NO. " ,HOORS, -,,,,,,,,.'--'..I.,,-,--..................-.I..--.,--.-..J..-----.",,,,--.-,..J..-.......--.-...J.. . ",. ---------..........-""""""";---..-,oo-..---"---..I-_L-,- '__~_.""¡"",----""",-"",._--~""""",,,,-- _...........,.¡,...-- Phillips .--- -_._-_.,-----~_.. MI ---"--"'-'--------"'--------"- --~_.._------,.. Doyon 25 Sperry Sun 2 ACI 5 Dowell 2 -_._._-_._.~-~-_._._--,_._---_._.*--_._._----_._-_._.-----,...---.--..----....---..-...----....---.--*-..--....----.--..----...---.-------....---.-..------.--.---------.--- -----,...---. ........_- BHI 1 FMC 1 =~Z,==~,c-:~,~¿~=~:~~.==~.' .' .~:~=:~.~=:~=:~.=~~:~,=]1¡ï~ß~,~,~:tç~Ñ,~V.~TIg.N~~~i.=:~,~=~~~==~,~~~~==~,==:~S:~,:~'C"Z==~',,-~~~~.'=:=~~: .. .. '. '.,ITEM ' ,', ,0,,*11$' , . USAGE!. ' , ,ON 'HAND..," , . .I~M ',.,' ',' ,,.. U~tr$:""', USA:GG, ' . 'ONHANfj , . .-.......~_...-----,....:.........._..:..-._..._..._~-'".__... --"__""''''M-..I. I --"'--"-"~~"''''~-..I.............:.......-........:'.."""" .--...--"- .' '.' " ":''',...:''''-,.-,,~_...~...o.....-,,'~..._...L,....¡,'''''_''''''''M''''''.__'''- ~""'_""'''~''''''''.'''_'''--"'''''''''''''''''_._-'''~_''''':''_-'"---....:...-w...........:._-.... "",-"~¡,__"",~,,,-,,,._.,,:,,-"..."":.......- .!~~~-,,-_...--.._--,----_._..,.._--_._--_...,----_._._,--,.._-_..__.~_,.~1~P.._,_--.. ---- -26, 169 "--,_,,y'y~~er, Potabl<:,_,__..._------_.__..._------_..__..._-------,~_...--_!.~g-,-,_..._--_._-,_:~~-~~~.__._-, _~~!.,Drilling ..---"..._-,"-,-,,-------..,_. ~..,_J~~_..__....._----,_...:!..!?!..-¿.._"._- -".---. '---"'---"'-"---'- ---.- =~~=~:=~L~¡{~=~~~~l?i:f~=~~-=;~jI~==:I~~-~-:l~;f~~E_~~ CD2-15 1,953 CD2-50 Printed: 4I3l2OO2 3:37:03 PM CASING TEST and FORMATION INTEGRITY TEST Well Name: CD2-50 Date: 3/16/2002 Supervisor: David Burley Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/8" 36# J-55 BTC X 7" 26# l-80 BTMC Casing Setting Depth: Toe Hole Depth: 7,306' TMD 6,855' TVD 2,385' TMD 2,381' TVD Mud Weight: 9.9 ppg Length of Open Hole Section: 4,921' EMW = Leak-off Press. + Mud Weight 0.052 x TVD 591 psi 0.052 x 2,381' + 9.9 ppg = EMW for open hole section = 14.7 ppg ~ Used cement unit Ri~ pump used Pump output = bbls pumped Fluid Pumped = 9.0 bbls Fluid Bled Back = 0.0 bbls yes #2 800 psi I i I I I I I I I i . ......., .....1. !~~Edï~~~~i~q i I ¡ I i ; i i I I I I ~ i ! I ! i I ! ; 700 psi I I I I I I I I I I I 600 psi i i ~ ~Q I '''-.. ! ~'" ¡ "'--;...~~----..¿;,-~~, ! i -+-LEAK-OFF TEST ~CASING TEST .....ç~LOT SHUT IN TIME -.-CASING TEST SHUT IN TIME ~TlME LINE 500 psi w ~ :> ~ 400 psi - W ~ a.. . ' 300 psi 200 psi 100 psi 0 psi ,I 0 10 20 25 15 BARRELS NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds .~~l~l;œH~,~~!~!'l~~ LEAK-OFF DATA CASING TEST DATA 30 MINUTES MINUTES FOR FOR LOT BBLS PRESSURE CSG TEST 1-- I - 0 I - 5 psi I! . t ------- -- - ¡ - 0.5 I -25 psi -i í--- t--~~~ I - --------. ~~- --~. -t t-- L- i ___1.0 i - 71 pSI I. l :: i i 1.5 i 147 psi i [=: '-- - l -- 2.0 -= r--24-2 psi '1 r- 1- I 2.5 I 343 ps~ I i L_. - -- -; --- 3.Q ; ~ e!1 j J=- ---- ; i ! 3.5 i 545 psi I . , [------ -, 4.0 1- 5~_! psi ~ L i Ì-- I -~- 4.5 I -- 58_~ P-~-~ I I I : 5.0 I 576 pSI ~ I - -1 . . . I L . r---- I 5.5 i 576 Psi, : : --- I . '~L--- I [ - '6~O r--581 ~~i i L J : 6.5 '576 psi J ' , L -- 7.0 I 581 psi 1 t ¡ L-- I -- .,i I [ i I I I I I ii-I i i i ',----- i-I -1 t---= i I --- - ., . . , . I=-' -------- -- i _-L - - J i i L -- --- i -- -- i -~ --- i i SHUT IN llM~ f -- --- I I I : O.Omin I I ! , I t- 1.0 min r-- - 1"""""""''''''''''''''1''''''''''''''''''''''.''''''''1 r 2.0-rñiñ i ! SHUTlN llME I ~HUTIN PRESSUR.E L 3.0 min i ~-_O.p m~n i -- - i 58J-p-s~ J~ i 4.0 m~n i " 1.0 mln " , 520 psi ,;;.'iI' ! 5.0 mln I . 2 0 ., , 485 . . . 6 0 . , I . mm , 'PSI I' . mln i L}.O mJ!LJ - --i 47~ PSi! i 7.0 m~11 , i 4.0 m!n i " 464 ps~ I 8.0 m~n \ : 5.0 mm : , 454 PSI. 9.0 mln r 6.1Ymin ! - ! 449 psi ~ :--1 Õ~O mín ,-= i 7.0 mÎn i - i 439 psi 1 i 15.0 ~ñ J ~O m~n I I _434 PS! I f- 20.0 m~n i ~O mln , : 424 pSI: _: 25.0 mm I LJO.O min I ; 424 psi f L 30.0 min ! -I STROKES PRESSURE _° stk~LD~j J I - -- -- I -- --- ------I - i- i i - -~~---i ~ i I I I I !---~ , , i i i i , I -- T- -- "ì , , I - i i____- j I J , , i i - -- i : i SHUT IN PRESSURE 0 ps~ - ., i i I --1 i ì -4 I --- - -1 --¡ J i i I --- i i , i i i , i ---4---- i , I - i I i i ! _d NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ) ) ~"----""-.'-'-ë;;;t.~-bÿ-¡;;~;;¡-~-"-'----""'"'- Dat. ptottod: :S.-Apr-2002 Plat R_fllNnG8 I. IIWD <m-7SJ27"'>, ClKII'dlnotM ora I" foct ,...t4"""I1::4 liioi. 150. Trill V.tkol o.th. Ortl r.r.IW'I~ tlKB (1)oyQn 1D). ..I: -------------_._..'.'!'~:.-:::_----,-,-------"",.._" -_.._._..,,----,--_._-~,.._---,_..".~"-_.._-,"...._---~'"--"-'--'_._-.'-~--"""'-"-"-'---""--""'.~"-.---- ~HIÛ.IPÌ' ~." ~ .' Scnl~ 1 Inch" 1 00 It -,!~_!!_~_!l_!p S_---~_!_~,~.~-~_?_.__!_~~-~- Structure: CD#2 Well: SOPS 1 I field: Alpine Field Locaflon : North Slope. Alaska -.'-"'-'--'--'-"-'--."-------.'..-'---(---'-West"{ftt8t)-----..-... -....-.....--'-."."""." '~~,'~,'~,'~'~~.~.~~~~ ! ~-, .~ § ~ ..-----...-..$ 700 ~ 0 ~ -1~ ~ ~ m .~ . ó I -~ v 'Qb .. .. 10. ~ .~ \~. %:~ @ SURFACE CASING SHOE SEPARATION FROM CD2-50 CD2-50 X Y Surface Casing Shoe ASP 4 Coordinates: 371664.5 5974228.1 Distance Surface Surface csg. Cement Casing No. of Ann. Vol. from Object csg. Shoe X Shoe Y Wells Permit # Permit Date Report Tally LOT Source well **** Start Date End Date well. Coord. Coord. CD2-351O'" --- ---- x x 1 ---- ---- ------ 681 372312.31 5974017.68 CD2-24, CD2-33, CD2-42 301-140 6/1/2001 x x 2 CD2-33A, CD2-15 33992 6/112001 10/10/2001 613 371098.46 5973992.48 CD2-33 (+A&B), CD2- CD2-24 301-186 7/13/2001 x x 2 39, CD2-14, CD2-15 33999 7/1612001 10/912001 1146 370630.11 5974721.81 CD2-33 B"''' --- ------ x x 4 ---- ---- ----- 1547 370155.64 5973886.23 ---- CD2-39 301-281 10/9/2001 x x 2 CD2-15, CD2-47 27879 10/1012001 11/1212001 908 372350.61 5973633.17 CD2-45, CD2-47, CD2-14 301-288 10/9/2001 x x 2 CD2-32 31073 11/13/2001 3/512002 909 372202.47 5974960.87 CD2-15 301-308 11/6/2001 x x 2 CD2-15 10817 3/612002 3/1712002 1124 370832.00 5974984.02 CD2-47 301-322 12/3/2001 x x 2 CD2-34, CD2-26 27349 12/17/2001 112012002 1029 371231.72 5973294.19 CD2-45 301-345 12/13/2001 x x 2 CD2-49, CD2-17 22991 112012002 2/1912002 1163 372765.13 5973853.74 CD2-34 302-069 3/4/2002 x x 2 NA 253 371803.06 5974439.79 CD2-26 302-068 3/4/2002 x x 2 NA 353 371798.52 5974554.55 CD2-49 302-070 3/412002 x x 2 NA 443 371252.38 5974065.93 CD2-17 x x 2 NA 431 371774 5974645 CD2-32 x x 2 NA 376 371295.6 5974302.38 CO2-50 x x 2 NA 0 371664.5 5974228.1 . Distance in feet, between surface casing shoes, in the X-V plane .. CD2-35 was drilled from an ice pad in early 1998. The 9-5/8" x 7" annulus has not been permitted for annuluar disposal. ""'CD2-33 B was a delineation well with a window milled out of 9-5/8" casing at 3840' MD (3062' TVD), shoe depth shown indicates window depth. It has not been permitted for annular disposal. .... As of 20-Mar-02 ~ ') ) . Phillips Alaska, Inc. Post Office Box. 1.00360 Anchorage, Alaska 99510-0360 Telephone 907-276-1.21.5 April 3, 2002 Alaska Oil and Gas Conservation Commission 333 West 7tÌ1 Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundrv Approval for Annular Disposal of Drillin" Waste on well CD2-50 Dear Sir or M:adam: Phillips Alaska, Inc. hereby requests that CD2-50 be pennitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. CD-50 currently has intermediate casing"~et horizontally in the Alpine reservoir. It is planned to drill the 6-1/8" hole with mineral oil based mud in mid April. It is intended to begin annular injection on CD2-50 approximately May 10,2002../ Please find attached fonn 10-403 and other pertinent infonTIation as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intemlediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD2 pad and the lateral distance from the surface casing shoe. If you have any questions or require further information, please contact Vem Johnson at 265-6081, or Chip Alvord at 265-6120. ~ince ./. em Jonnson Drilling Engineer RECEIVED cc: CD2-50 Well File Chip Alvord Nancy Lambert Sharon Allsup-Drake ATO-868 Anadarko ATO-1530 APR 5 2002 Allllr8E1IG18Con1.~ AnctMIrae (~n 1 ('"\\ \1/\ l ,,--J f\ 1 ~J i i \j ;~ ') ) Note to File Well CO2-50 PTO 202-049 Sundry 302-121 Phillips Alaska, Inc. (PAl) requests approval for annular disposal in the subject well. This note analyzes information submitted by PAl and recommends approving PAl's request for annular disposal. Well CO2-50 is part of the Alpine development, and was drilled during spring 2002. 9-5/8" surface casing in CO2-50 was cemented with 284 bbls lead cement followed by 48 bbls tail cement, totaling about 133% excess cement relative to gauge wellbore. 120 bbls of lead cement circulated to surface during initial placement. Successful placement of such volumes of cement indicates that CO2-50's surface casing is adequately cemented. After drill-out to 30 feet below the 9-5/8" shoe, the formation supported a 16.1 ppg EMW leak off test. Applied pressure dropped 140 psi (from 800 psi) during a 10 minute observation. CO2-50 was then drilled to 7948 feet, where 7" production casing was run and cemented. An annular (9-5/8" x 7") injectivity test showed a pressure gradient of 14.7 ppg EMW referenced to the 9-5/8" casing shoe. Ouring this test, pressure response departed from linear at about 545 psi and reached a maximum of 591 psi. The pressure then stabilized between 591 psi and 581 psi. Shut in pressure varied between 520 psi and 424 psi over 10 minutes. Based upon information submitted, AOGCC recommends approval of Phillips' request for annular disposal in Well CO2-50 (PTO 202-029). Winton Aubert \¡.J~ 4"/2S/D2- Petroleum Engineerftt tJff) !.-\.( ~ ¥' ') ) ~~!Æ~E :} ~~!Æ~~~!Æ ALASKA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Vem Johnson Drilling Engineer Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510-0360 Re: Colville River Unit CD2-50 Phillips Alaska, Inc. Permit No: 202-049 Sur Loc: 2063' FNL, 1503' FEL, Sec. 2, TIIN, R4E, UM Btmhole Loc. 1335' FNL, 1581' FEL, Sec. 11, TIIN, R4E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name Colville River Unit CD2-50 PH50-103-20415-70 from records, data and logs acquired for well (name on permit). Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on CD-2 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the armular space of a single well or to use that well for disposal purposes for a period longer than one year. Permit No: 202-049 March 4,2002 Page 2 of2 Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (OJ~,,^-~>\~¿'Yt 1-ct-l Cammy Oè-Óhsli Taylor' Chair BY ORDER OF THE COMMISSION DATED this 4th day of March, 2002 jj cÆnc10sures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. _.n, .. ~ Type of Work RECEIVEof" 3 /1 STATE OF ALASKA FE B 2 1 2002 i+-iGA- 3 Mn ALASKA OIL AND GAS CONSERVATION COMMISSION' - PER M IT TO DR ILL Alaska Oil & Gas Coos. Commissiorn 20 AAC 25.005 Anchor~ 1 b Type of Well Exploratory Stratigraphic Test Development Oil X Service Development Gas Single Zone X Multiple Zone 5, Datum Elevation (OF or KB) 10, Field and Pool DF 52' feet Colville River Field 6. Property Designation Alpine Oil Pool ADL 380075 7. Unit or property Name \. ) ) 1a. Drill X Re-Entry Name of Operator Phillips Alaska, Inc. Address P. O. Box 100360, Anchorage, AK 99510-0360 Location of well at surface Redrill Deepen 2, 3. 4. 11. Type Bond (see 20 AAC 25.025) 2063' FNL, 1503' FEL, Sec.2, T11 N, R4E, UM At target (=7" casing point) Colville River Unit 8. Well number Statewide Number 1311' FSL, 2287' FWL, Sec. 2, T11 N, R4E, UM At total depth 1335' FNL, 1581' FEL, Sec. 11, T11 N, R4E, UM 12, Distance to nearest 13, Distance to nearest well Property line CD2-49 2063 FNL 380075 feet 7.2' at 400' MD 16. To be completed for deviated wells CD2-50/CD2-50 PB1 9, Approximate spud date #59-52-180 Amount Feet $200,000 15, Proposed depth (MD and TVD) 11125' MD ..25trcr- '13'7 ,6) 7252' TVD 17, Anticipated pressure (see 20 AAC 25.035(e)(2)) Maximum surface ....25'7'5" í psig At total depth (TVD) , 2. .:;~- 7 ~A feet 3/8/2002 14, Number of acres in property Kickoff depth 400 feet Maximum hole angle 90° 3258 at psig 7000' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 2361' 37' 37' 2398' 2394' 476 Sx Arcticset III L & 230 Sx Class G 8.5' 7' 26# L-80 BTC-M 8088' 37' 37' 8125' 7252' 135 Sx Class G N/A 4.5' 12.6# L-80 IBT mod 7735' 32' 32' 7767' 7165' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations, Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20, Attachments Filing fee X Property plat Drilling fluid program X Time vs depth plot BOP Sketch Refraction analysis Diverter Sketch Seabed report Drilling program X 20 AAC 25,050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _Avc- -[ ()¿( Drilling Team Leader Date 2-(2... , ( ð L Permit Number I /0, Z-62.. --6 "-(/ Conditions of approval Hydrogen sulfide measures Required working pressure for BOPE Title Commission Use Only I API n~mber ZD' /I~ - ^^ I Approval date .i?. L h ~ I See cover ~etter for 50- /ó ;3 - ï..;:) (....{...I ) ~ : \J ')\ Other requIrements Samples required Yes C~I Mud log r~qui e\j. Yes ~) Yes ~o,-) Directional survey required (è:.) No - 2M 3M 5M 10M 15M Other "3::DO ~<)' ~I."'\ ~'--' "" ~ ~ ~S -\- !5f!rvt ~ I Original Signed Ov (;ammy Oechsli Approved by Form 10-401 Rev, 7-24-89 Commissioner by order of the commission ''ÁLLJ h, .-"'1- Date ~) ~ (). Submi in tr~ate 0 .".... - -,> ~ .,tl I rl',: l;i i fvA- ) ) CD2-50 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) ,12-1/411 Hole /9-5/8' Event Conductor Broach Well Collision Gas Hydrates Running Sands and Gravel Abnormal Pressure in Surface Formations >2000' TVD Lost Circulation ,8-1/2' Hole /7' Event Abnormal Pressure in Surface Formations >2000' TVO Lost circulation Hole swabbing on trips Abnormal Reservoir Pressure Hydrogen Sulfide gas Casina Interval Risk Level Low medium Low Low Low Low Casina Interval Risk Level low Low Moderate low Low . M iti.,Qation StrateQY Monitor cellar continuously during interval. Gyro single shots, traveling cylinder diagrams Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Oiverter drills, increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries M itiqation Strateqy BOPE drills, Keep mud weight above 10.4 ppg. Check for flow during connections and if needed, increase mud weight. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted sweeps. Well control drills, increased mud weight. No mapped faults occur within 7001 of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, mud scavengers ,6-1/8' Hole / Horizontal Production Hole Event Risk Level Lost circulation Low Hole swabbing on trips Abnormal Reservoir Pressure Hydrogen Sulfide gas Moderate Medium ¡ Low M itiqation Strateqy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to T shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. / BOPE drills, Keep mud weight above 9.0 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, mud scavengers 0,......,,- '-':, " ;rj,u'¡'VA~ f ) Alpine: CD2-50PB1 (Pilot Hole) & CD2-50 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 20. ) Procedure / Install diverter. Move on Doyon 19. Function test diverter. Drill 12-)4 , hole to the surface casing point as per the ,directional plan. Run and cement 9-5/8' surface casing. Install and test BOPE to 5000 PS¡( Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. / Drill 8- Y2" hole to a point +/- 100' TVD below the base of the Alpine Sand (GR/RES/NEUT.,DENS/PWD). / Set a 500' cement plug #1 from TD to +/- 7458'. Set a 400' cement plug #2 from +/- 74581 to +/- 7058'./ r'/' ./ RIH with drilling assembly (DIR/GR/RES/PWD). Dress off plug #2. Kick off at +/- 7174' and drill sidetrack to intermediate casing point in the Alpine Reservoir. .,/ Run and cement T casing as per program, chase top plug with sufficient diesel for freeze protect. Top of cement + 500 feet MD above Alpine reservoir. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe Freeze protect casing annulus and casing. Install tubing hanger, install TWC. ND BOP, NU tree. RD and move off with Doyon 19. Drill surface and intermediate hole on other Alpine wells. 16. Move in and rig up with Doyon 19. BOPE test to 5000 psi. / 17. 18. / PU and RIH with 6-1/8' hole drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Displace well to mineral oil based mud (MOBM). 19. Drill 6-1/8' horizontal section to well TD. 21. Contingency' set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). 16. Condition mud and pull out of hole. 17. Run 4-%,12.6#, L-80 tubing with SSSV, GLM's, sliding sleeve, packer and landing nipple. Land hanger. 18. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20. Rig up slickline 21. Close sliding sleeve ~ i/G Ai.. 22. ) ) Drop ball and rod, set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 23. 24. RIH with slickline, open sliding sleeve. Circulate tubing and annulus to diesel. 25. Set BPV and secure well. Move rig off. Well Proximity Risks: Directional drilling / collision avoidance information as required by ~ ACC 25.050 (b) is provided in following attachments. CD2-49 will be the closest well to CO2-50, 7.2' at 400' MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 5.1' at 400' MD. / There are no high-risk events (e.g. over-pressures zones) anticipated. Drillinq Area Risks: Lost circulation: Faulting within the Alpine reservoir section is considered the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpinq Operations: Incidental fluids developed from drilling operations on well CD2-50 will be injected into a permitted annulus on CO2 pad or the class 2 disposal well on CD1 pad. The CD2-50 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD2-50 be permitted for annular pumping of fluids occurring ~ a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. /" Surface casing will be set below the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2394') + 1,500 psi = 2,994 psi = 1,081 psi Pore Pressure Therefore Differential = 2994' 1081 = 1913 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OR¡GIJVA~ ) ) t Wt Connection 850/0 of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8' 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi / T 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi v' DRILLING FLUID PROGRAM Density PV YP Funnel Viscosity Initial Gels 10 minute gels API Filtrate HPHT Fluid Loss at 160 PH Electrical Stability Oil/water ratio SPUD to Intermediate hole to T 9-5/8' surface casing casing point' 8 Y2' point' 12 1¡f . 8.8' 9.6 ppg / 20' 60 100' 200 Production Hole Section' 6 1/8' 9.6' 9.8 ppg / 10' 25 15' 25 8.5' 9.0 9.0' 10.0 9.2 ppg 15 -20 18 -25 NA 9-12 NA 4.0-5.5 NA +800Vts 80/20 4' 8 <18 NC' 10 cc / 30 min 4' 12 cc/30 min (drilling) Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at :t 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel/polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a 80/20 oil/water ratio M-I Versa-Pro mineral oil based drill-in fluid. The base fluid will consist of high flash point (>200 F) mineral oil with 25% by weight calcium chloride as the internal phase. Calcium carbonate bridging material will be added to minimize formation damage. ~,1/G Nt.. ') I Colville River Field CD2-50PH Pilot Hole - Prior to Sidetracking Updated 02/15/2002 RKB - GL = 37' ~ Wellhead ~, ~ 16" Conductor to 114' ~ 9-5/8" 36 ppf J-55 BTC ... Surface Casing @ 2398' MD 12394' TVD cemented to surface .,f 9.8 ppg drilling mud in hole > Plug #2 : 400' (7058' MD). 17 ppg to cover the HRZ when in place (HR7 top at +1-7283' MD/6825' TVD) Cement Plug Top of cement plug dressed oft to 7174' MD / 6728' TVO (+/- 27.3 inc.) Top Alpine Reservoir at 7704' MO / 7199' TVO V Top of Cement Plug #1 at +/- 7458' 500 ft R Pilot Hole TO at 7958' MO / 7425' TVO (+1- 27.3Q inc.) C ., .'G r V ., I.' 1-,- ') ) Colville River Field CD2-50 Production Well Completion Plan Updated 02/15/02 16" Conductor to 114' ~.",i 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 2000' TVD=2189' MD Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile Dual 1/4" x 0.049" sls control lines 9-5/8" 36 ppf J-55 BTC Surface Casing 2398' MD 12394' TVD cemented to surface WRDP-2 SSSV (2.125"ID) wi DB-6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap Tubing Supended with diesel to lowest GLM Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 2004' 2000" End thermal centralizers 2404' 2400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 3930 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Start thermal centralizers. 4667' 4500' (1 per joint) Camco KBG-2 GLM (3.909" ID) 6017' 5700' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 7440' 6954' 4-1/2" tubing joints (2) Baker CMD sliding sleeve with 3.813 'X' Profile 7550' 7036' 4-1/2" tubing joints (2) Baker S3 Packer 7650' 7101' 4-1/2" tubing joints (2) HES "XN" (3.725" ID)-60.72 inc 7755' 7159' 4-1/2" 10' pup joint WEG 7767' 7165' Camco KBG~2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch GL.J 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD Camco KBG-2 GLM (3.909" ID) at 5700' TVD for E Dummy with 1" BK~2 Latch GLJ Camco KBG-2 GLM (3.909" ID) 2 joints above sliding sleeve E Dummy with 1" BK-2 Latch Baker 4~1/2" CMD sliding sleeve with 3.813 'X' Profile set 2 joints S3 packer .,'-..., Baker S3 Packer at +1- 7650' '" >--"-'----'---~ Well TO at 11125' MD I 7252' TVD 4 "'..... ~ -..............----- .~ 7" 26 ppf L -80 BTC Mod Production Casing @ 8125' MD 17252' TVD @ 902 ~:. "a .\Þ- .-8...j ~LJ .GLJ TOC @ +1-7348' MD (500' MD above top Alpine C) Alpine C @ 7848' MO / 7199' TVO J ) Colville River Field CO2-50 Production Well Completion Plan Formation Isolation Contingency Options Updated 02/15/02 16" Conductor to 114' 4-1/2" Cameo BAL-O SSSV Nipple (3.812" 10), WROP-2 SSSV (2.25" 10) and OB-6 No-Go Lock (3.812" 00) with dual 1/4" x 0.049" s/s control line @ 2000' TVO 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2398' MO / 2394' TVO cemented to surface (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" 10) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBO) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVO to 2400' TVO (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBO) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-1 0 ECP (anchor) - Muleshoe / Entry Guide Camco KBG-2 GLM (3.909" ID) at 5700' TVD for E Dummy with 1" BK-2 Latch (C) Open Hole Bridge Plug Assembly ~ Baker Payzone ECP (cement inflated) -XO -Float Collar ~ 4-1/2" Float Shoe Camco KBG~2 GLM (3.909" ID) set 2 joints above the sliding sleeve E Dummy with 1" BK-2 Latch Baker 4-1/2" CMD sliding sleeve with 3.813 'X' Profile set 2 joints 53 packer Well TD at 11125' MD! 7252' TVD ',------ ....... . . '"" ''<.................., I ", 'Þ<1- - -; - - - .. - - ~ - - - - þq -ÞO ' ~ (\ .~ ~ ~ @ ~~~@>.: 7" 26 ppf L~80 BTC Mod Production Casing @ 8125' MO I 7252' TVO @ 902 ~ q I G ¡ 1\/;- } ) CD2-50 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well : Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (Ibs. I (psi) (psi) MDfTVD(ft) gal) 16 114/114 10.9 52 53 9 5/8 2398 I 2394 14.5 1081 1562 l' 8125 I 7252 16.0 3282 2557 N/A 11125 I 7252 16.0 3282 N/A . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from Ib./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP' (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point 1. ASP CALCULATIONS Drilling below conductor casing (16') ASP = [(FG x 0.052)' 0.1] D = [(10.9 x 0.052)' 0.1] x 114 = 53 psi OR ASP = FPP' (0.1 x D) = 1081 ' (0.1 x 2394') = 842 psi 2. Drilling below surface casing (9 5/8') ASP = [(FG x 0.052)' 0.1] D = [(14.5 x 0.052)' 0.1] x 2394= 1566 psi OR ASP = FPP' (0.1 x D) = 3282' (0.1 x 7252') = 2557 psi / 3. Drilling below intermediate casing (1') ASP = FPP' (0.1 x D) = 3282' (0.1 x 7252') = 2557 psi ORiGiJVA - ') Alpine~ CD2-50PB1 Cementing ReQuirements ') CD2-50PH Cement Plug #1 : 7958' MD to 7458' MD = 500'. Slurry: Cement with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. ,/ 500' X 0.3941 fefft X 1.15 (15% excess) = 226.6 fe => 196 Sx @ 1.16 ft3fsk CD2-50PH Cement Plug #2 : 7458' MD to 7058' MD = 400'. Cement with Class G + additives @ 17 ppg. Assume 15% excess on opeJ hole volume. Slurry: 400' X 0.3941 ft3fft X 1.15 (15% excess) = 181.3 ft3 => 182 Sx @ 1.00 fefsk Alpine, CD2-50 Well Cementing Requirements 9 5/8' Surface Casing run to 2398 MD /2394' TVD. Cement from 2398' MD to 18981 (500' of fill) with Class G + Adds @ 15.8 PPG, and from 18981 to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1556' MD). Lead slurry: System: Tail slurry: System: (1898'-1556') X 0.3132 fe/ft X 1.5 (50% excess) = 160.7 ft3 below permafrost 1556' X 0.3132 fefft X 4 (300% excess) = 1949.3 fe above permafrost T,I volume = 160.7 + 1949.3 == 2110.0 ft3 => 47~X @ 4.44 ft3fsk 476 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 fefsk, Class G + 30% 0053 thixotropic additive, 0.6% 0046 antifoamer, 1.5% 0079 extender, 1.5% S001 accelerator, 50% 0124 extender and 9% BWOW1 0044 freeze suppressant 500' X 0.3132 fe/ft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 fe/ft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 fefsk ,// 230 Sx Class G + 0.2% 0046 antifo.amer, 0.3% 0065 dispersant and 1 % S001 accelerator @ 15.8 PPG yielding 1.17 ft3fsk ./' 7' Intermediate Casing run to 8125 MD /7252' TVD ../ Cement from 8125' MO to +f- 7348' MO (minimum 500' MO above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (8125" 7348') X 0.1268 ft3fft X 1.4 (40% excess) = 137.9 fe annular volume 80' X 0.2148 fe/ft = 17.2 fe shoe joint volume Total volume == 137.9 + 17.2 = 155.1 fe => 135 Sx @ 1.15 fefsk / 135 Sx Class G + 0.2% 0046 antifoamer, 0.25% 0065 dispersant, O.~% 0800 retarder and 0.18% 0167 fluid loss additive @ 15.8 PPG yielding 1.15 ft3fsk 1 By Weight Of mix Water, all other additives are BWOCement C =','"G 'AA,- a ::0 --- ~ --- < ~ r-- Crected by bmicllOel For: V Johnson Dale platted: 12-Feb-2002 Plat Reference is CD2-50PB1 Versian#8. Coordinates Ofe in feet reference slot 650. Vert;col Depths are reference RKB (Doyon mi. BAKÐ1: HUGHES INTE() . -- --- - ---- ======= ----- Point Begin Nudge EOC West Sak Beg in l)rop EOo Bose Permafrost ----- Mo 400.00 700.00 1069,57 1200.00 1500,00 1555.84 2203.84 2397,84 2407.84 2600.00 2785.12 3509.81 3932.97 4182.79 5799.82 6355,72 7282.95 7492,26 7593.53 7663.30 7682.43 7703.81 7707.19 79~u8:JE2 C 40 9 5/8 Casing pt (-30 KOP C -- 20 EOC K-3 K-2 Albian-97 Albion -96 HRZ K-: LCU Miluveach A .Alpine 0 Alpine C Target TD Phillips Alaska, Ince Structure: CO#2 Field: Alpine Field Well: SOPB1 Location: Norlh Slope, ..:.. ~ ~ ;~..~, 'F"!.~~~~~\ -.., "~- .........u""""::,-~""'~"~ . --.__._..-._--------_........__m___.n____--._----------~- - _mm__n___---_----- n " .-------------..-------..----______n____-_____m______-..__-._--m.__m_m_____m___._._m--.--.__-_.__._---~-__.__.m-.-..--...... ==== PROF~LE COMMENT DATA Inc Dir ND North 0.00 222.00 400.00 0.00 6.00 222.00 699.45 -11.66 6.00 222.00 1067.00 -40.37 6.00 222.00 1196.71 -50.50 0.00 222.00 1496.17 -62.17 0.00 222.00 1552.00 -62,17 0.00 222.00 2200.00 -62.17 0.00 222.00 2394.00 -62.17 0.00 222.00 2404.00 -62.17 0.00 222.00 2596.16 -62.17 5.55 232.29 2781.00 -67.65 27.29 232.29 3471.95 -192.24 27.29 232.29 3848.00 -310.94 27.29 232.29 4070.00 -381.01 27.29 232.29 5507.00 -834.59 27.29 232.29 6001.00 -990.52 27.29 232.29 6825.00 -1250.62 27.29 232.29 7011.00 -1309.33 27.29 232.29 7101.00 -1337.73 27.29 232.29 7163.00 -1357.30 27.29 232.29 7180.00 -1362.67 27.29 232.29 7199.00 -1368.67 27.29 232.29 7202.00 -1369.61 --u- -______22~2u9______2 3 229_______~1_422~JQ___u_=_L4~Q:__1Q___. V. Sect 0.00 1 5.46 53.52 66.96 82.42 82.42 82.42 82.42 82.42 82.42 91.38 295.05 489.09 603.64 1345.14 1600.04 2025.23 2121.20 2167,64 2199.64 2208.41 2218.21 2219.76 --______2~:34_:_~~L8. ----- East 0.00 - í 0.50 -36.35 -45.4 7 -55.97 -55.97 -55.97 -55.97 -55.97 -55.97 -63.07 -224.19 -377.70 -468.32 -1054.93 -1256.59 ' -1592.96 -1668.88 -1705.62 -1730.93 -1737.87 -1745.63 -1746.85 __=J_B_~~QJ- ~ . u ~m'_m.__m-_-_-_.._u_um-mm.._- oeg/100j 0.001 2.00- 0.00: 0.001 2.001 0,001 O.OO¡ 0.001 0.00' 0.001 3.00! 3.001 O.OO! O.OO¡ O.OO¡ 0.001 0.001 0.001 0.00, 0.001 O.OO! 0.001 0.001 - -_____JL_QidJ "i,_~T' --- Plot Reference is CO2 -50 Ve~5¡on#8. Structure: CO#2 Field: Alpine Field Well: 50 ~ - ~ - - - -~_....... --- --- ..... ~ ---- (Æ~'~~S ~ ........ .u,""~~,::::.;-;.-¿-'-~ Phillips Alaska, Inc. Created by bmichoel For: V Johnson Dote plotted: 12-Feb-2002 Location: Norlh Slope, Coordinates are in feet reference slot 650. V~rt' col Depths ore referenc~ RKB (Doyon i'tii1i BAKIR ttUGHES I NT!::\) ==== RO F~ LE COMMENT DATA ==== -~ ----- Point ----- MD Inc Oi! TVO North East V. Sect Oeg/1 00 KOP - Sidetrack pt 7173,66 27,29 232,29 6727.88 -1219.96 -1553,31 343. 1 8 0.00 HRZ 7284.24 30.28 2 1 2.48 6825.00 -1259.09 -1588.43 361 .12 9.00 K-1 7515.26 43.20 184.68 7011.00 -1388.46 -1626.57 457,20 9.00 LCU 7649.65 52,74 174,63 710~.00 -1487.91 -1625.31 545.49 9.00 Miluveach A 7763.66 61.37 167.99 71 63.00 -1582.28 -1610.61 635,64 9.00 -"' Þ,lpine 0 7800.86 64.25 166.07 7180.00 -1614.51 -1 603.18 667.57 9.00 Alpine C 7847.72 67.91 1 63,78 7199.00 -1655.85 -1592.03 709.28 9.00 C) ::0 Target - CsgPt-EOC 8125.05 90.00 151.86 7252.00 -1905.46 -1489.12 977.92 9.00 ---- ~ TO - Csg pt 11125.37 90.00 151.86 7252.00 -4551 .13 -74.08 3978.24 0.00 --- <= ~ r-- ') For: V Johnson Phillips Alaska, Inc. Well: 50PB1 Structure: CO#2 Field: Alpine Field Coordincle~ ore in feet reference :slo~ #50. Vcrlical Depths ora reference RKB (Doyon 19). lmil1! BAKER HUGHB IN''I:(j 231.85 AZIMUTH 2220' (TO TARGET) ...Plane af Proposal... I ~\ $ . TRUE lacation : North Slope, I SURFACE LOCATION: I 2~~r F2~lt1 \~~3~Nl Begin Nudge Begin Or5&C EOO 1\ , Base Permafrost",¿4$' ~V - 0 9 5/8 CasiKö~t~( 'ý' C-20 EOC 'ì!\) - " '1; *,1<-3 * K-2 ~<\> 'Ç.¡~ ~. 'Ç.¡~"Älbian-97 '" Âlbian-96 KOP - Sidetrack PI (. HRZ HRZ K-1 LCU Miluvcoch A Alpine D AI~iDe C PilOT TO lOCATION: 1776' FSL, 1938' FWL SEC, 2, T11 N, R4.E ( K-1 50PS1 II< LCU II< ~il~X~OFih A \'Afplne't \~ I TARGET LOCATION: I 1311' FSL, 2287' FWL SEC, 2, T11 N, R4E Target - CsgPl-EOC ~ -? 'ôJ 6- ~ I TO LOCATION' I 1335' FNL, 1581' FEL SEC, 11, T11 N, K4E 2000 1750 1500 ŒJ TO - Csg Pt 1250 500 250 1000 750 <- West (feet) ') ~ - 250 - 500 - 750 - 1000 - 1250 - 1500 - 1750 (j) - ;1000 0 C -+ :r - 2250 r--. -+, CD CD -+ - 2500 '--' I V - 2750 - 3000 - 3250 - 3500 - 3750 - 4000 - 4250 - 4500 I 4750 250 c =rG, Nt,~ 0 - 400 - 800 1200- 1600 - 2000 - 2400 - ~ +- QJ 2800 - QJ '+- "-" ..c 3200 - +- 0. QJ 0 3600 - 0 U +- 4000 - L QJ > QJ 4400 - ::J L - I 4800 - V 5200 - 5600 - 6000 - 6400 - 6800 - /200 - 7600 - I .' 0,00 ", Begin Nudge '" 2,00 .. 4,00 " EOC ,. West Sak II Begin Drop If 4.00 " 2,00 " EOD 'f Bose Permafrost If C-40 .Jill 9 5/8 Casing C-30 'f KOP " 3,00 ~ 6.00 C-20 ,', 9,00 " 12.00 , 15.00 18,00 " 21.00 " 24,00 ~ 27.00 EOC \ ') Phillips Alaska, Inc. Structure: CD#2 Field: Alpine Field Well: 50PB1 Location: North Slope, DLS: 3,00 deg per 10° It 231.85 AZIMUTH 2220' (TO TARGET) ...Plane of Proposal'" Albian-97 " \ Albian-96 K-3 \ I'. K-2 @]] TANGENT ANGLE 27.29 DEG DLS: 9.00 de9 per 10O ft 400 400 800 Vertical Section (feet) -> 1200 1600 2000 2400 2800 3200 Azimuth 231.85 with reference 0.00 N, 0.00 E from slot #50 ') B.. BAKER HUGHU INTEl) (1 G.l~A~ C) ::a -,- c-- ~--l .:> &.r4!2----=--- ~ 2~ r-- -----.... +- Q) Q) - '---" ....c +- 0... Q) 0 0 U 7000 - +- L Q) > Q) ::J L f- I V Phillips Alaska, Inc. Crealed by bmichael For: V Johnson Dale plolted ; 12-Feb-2002 Plot Reference is CJ2 -50 Version#8. Structure: CO#2 Field: Alpine Field Well: 50 Location: Norlh Slope, Coordinates ore in fee: reference slot ISQ. Vertical Depths ore reference RK8 (Doyon ~ 9). ~i;¡ BAKER HUGtE5 INTt;;() 151.86 AZIMUTH 978' (TO TARGET) ***Plane of Proposal*,,* 6400 - \!} 6600 6800. Sidetrack Pt '-JRZ 7200 - TARGET ANGLE DLS: 9.00 deg per 100 ft 90 DEG K-1. 42.17 ,(-1 49.12 LeU Milu'Ieac~e~. 56'6541 18 MiluA'Ieoch A Alp'ne D:, tRine D Af~ine e. 79.98 ~I~e e Target - CsgPt-EOC orget ~ 7400 ,. I~Blr TO 7600 0 1000 1200 1400 1800 2000 2200 2400 2600 2800 3000 200 400 600 800 1600 Vert i c a I Sect ion (f e e t) - > Azimuth 151.86 with reference 0.00 N, 0.00 E from slot #50 3200 ~ ---- --- --- -~~- -- ---- ----- - - - - l~Hlii~~~{ ,~ ¡; ß¡~ -~~1; ~c: . ..;. 'J 3400 3600 3800 4000 ~ TO - Csg pt 4200 ~. -' 4400 4600 ) ) Phillips Alaska, Inc. ~ Plot Reference i~ CO2-50 Vor::lionHB. Structure: CD#2 Field: Alpine Field Well: 50 Location: North Slope, Coordinoto~ ore in feet reference slot H5Q, True Vortical Ddplh~ are reforence RKB (Doyon r!.:i. BMLs I"T~:O 330 '" 1000 : 3~o.///'~~O ........... < ~3.,.. 1. .0,""'2000", ,;~,;~,/" oJ 30~ <§J4J *1òð6 @ . />59 , ' * 3000 <5000 ",,//JI<' *",1 ~ n./ ,,/ --'"",,,,'2tj00 ,~1 000 :" 20 (§) * 3500 10 40 50 60 290 280 80 270 90 260 100 240 120 230 130 2~{O 190 180 140 ~ 150 ~ 160 .. 2000 170 '6 :..II \3 ~ æ 210 . 1500 200 ê@ @ Norrlal Plane Travelling Cylinder - Feel All depths shewn ore Measured depths o~ Reference Well C r, It'1 .~ "I! ~ L '.'j I L1 ¡ "~ )') .,. ') Phillips Alaska, Inc. CD#2 50PBl slot #50 Alpine Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref: CD2-50PBl Ve~'sion#8 Our ref: prop3678 License: Date printed: 12-Feb-2002 Date created: 22-0ct-1999 Last revised: 12-Feb-2002 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 16.811,w151 2 26.836 Slot Grid coordinates are N 5974293.878, E 371732.983 Slot local coordinates are 2062.81 S 1501.69 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North " " R ,J. ..I.;.~ ¡'~ .l ,.::~. L '" Ä:' ":1 i n I " j ... '.~~'d\;Jlil ') ) Phillips Alaska, Inc. PROP08AL LI8TING Page 1 CD#2, 50PS1 Your ref : CD2-50PS1 Version#8 Alpine Fie1d,North 8lope, Alaska Last revised: 12-Feb-2002 Measured Inclin Azimuth True Vert RECTANGULAR G RID C OORD8 GEOGRAPHIC Depth Degrees Degrees Depth COORDINATE8 Easting Northing COORDINATE8 0.00 0.00 0.00 0.00 O.OON O. OOE 371732.98 5974293.88 n70 20 16.81 w151 2 26.84 100.00 0.00 222.00 100.00 O.OON O. OOE 371732.98 5974293.88 n70 20 16.81 w151 2 26.84 200.00 0.00 222.00 200.00 O.OON O. OOE 371732.98 5974293.88 n70 20 16.81 w151 2 26.84 300.00 0.00 222.00 300.00 O.OON O.OOE 371732.98 5974293.88 n70 20 16.81 w151 2 26.84 400.00 0.00 222.00 400.00 O.OON O. OOE 371732.98 5974293.88 n70 20 16.81 w151 2 26.84 500.00 2.00 222.00 499.98 1. 308 1.17W 371731.79 5974292.60 n70 20 16.80 w151 2 26.87 600.00 4.00 222.00 599.84 5.198 4. 67W 371728.23 5974288.77 n70 20 16.76 w151 2 26. 97 700.00 6.00 222.00 699.45 11. 668 10 . 5 OW 371722.29 5974282.40 n70 20 16.70 w151 2 27.14 1000.00 6,00 222.00 997.81 34.978 31.4 8W 371700.92 5974259.45 n70 20 16.47 w151 2 27.76 1069.57 6.00 222.00 1067.00 40.378 36.35W 371695.96 5974254.13 n70 20 16.41 w151 2 27.90 1200.00 6.00 222.00 1196.71 50.508 45 . 47W 371686.67 5974244.16 n70 20 16.31 w151 2 28.16 1300.00 4.00 222,00 1296.33 56.988 51. 3 OW 371680.73 5974237.78 n70 20 16.25 w151 2 28.33 1400.00 2.00 222.00 1396.19 60.878 54.81W 371677.16 5974233.95 n70 20 16.21 w151 2 28.44 1500.00 0,00 222.00 1496.17 62.178 55 . 97W 371675.97 5974232.67 n70 20 16.20 w151 2 28.47 1555.84 0.00 222.00 1552.00 62.178 55. 97W 371675.97 5974232.67 n70 20 16.20 w151 2 28.47 2000.00 0.00 222.00 1996.16 62.178 55. 97W 371675.97 5974232.67 n70 20 16.20 w151 2 28.47 2203.84 0.00 222.00 2200.00 62.178 55. 97W 371675.97 5974232.67 n70 20 16.20 w151 2 28.47 2397.84 0.00 222.00 2394.00 62.178 55. 97W 371675.97 5974232.67 n70 20 16.20 w151 2 28.47 2407.84 0.00 222.00 2404.00 62.178 55. 97W 371675.97 5974232.67 n70 20 16.20 w151 2 28.47 2500.00 0.00 222.00 2496.16 62.178 55. 97W 371675.97 5974232.67 n70 20 16.20 w151 2 28.47 2600.00 0.00 222.00 2596.16 62.178 55. 97W 371675.97 5974232.67 n70 20 16.20 w151 2 28.47 2700.00 3.00 232.29 2696.12 63.778 58.04W 371673.87 5974231.11 n70 20 16.18 w151 2 28.53 2785.12 5.55 232.29 2781.00 67.658 63. 07W 371668.79 5974227.31 n70 20 16.15 w151 2 28. 68 2800.00 6.00 232.29 2795.80 68.578 64. 25W 371667.59 5974226.41 n70 20 16.14 w151 2 28.71 2900.00 9.00 232.29 2894.93 76.558 74.5 8W 371657.13 5974218.61 n70 20 16.06 w151 2 29.01 3000.00 12.00 232.29 2993.25 87.708 88.9 9W 371642.53 5974207.71 n70 20 15.95 w151 2 29.43 3100.00 15.00 232.29 3090.47 101. 978 107. 46W 371623.83 5974193.74 n70 20 15.81 w151 2 29. 97 3200.00 18.00 232.29 3186.34 119.348 129.92W 371601.07 5974176.76 n70 20 15.64 w151 2 30.63 3300.00 21. 00 232.29 3280.60 139.768 156.33W 371574.33 5974156.79 n70 20 15,44 w151 2 31. 40 3400.00 24.00 232.29 3372.97 163.178 186.60W 371543.67 5974133.90 n70 20 15.21 w151 2 32.28 3500.00 27.00 232.29 3463.22 189.508 220. 65W 371509.18 5974108.15 n70 20 14.95 w151 2 33.28 3509.81 27.29 232.29 3471.95 192.248 224.19W 371505.59 5974105.47 n70 20 1.4.92 w151 2 33.38 3932.97 27.29 232.29 3848.00 310.948 377.70W 371350.11 5973989.40 n70 20 13.75 w151 2 37,87 4000.00 27.29 232.29 3907.56 329.748 402.01.W 371325.48 5973971.01 n70 20 13.57 w151 2 38.58 4182.79 27.29 232.29 4070.00 381. 018 468. 32W 371258.32 5973920.87 n70 20 13.06 w151 2 40.51 4500.00 27.29 232.29 4351.90 469.998 583.40W 371141. 77 5973833.86 n70 20 12.19 w151 2 43.87 5000.00 27.29 232.29 4796.23 610.248 764. 78W 370958.06 5973696.70 n70 20 10.81 w151 2 49.17 5500.00 27.29 232.29 5240.56 750.498 946.16W 370774.35 5973559.55 n70 20 09.43 w151 2 54.46 5799.82 27,29 232.29 5507.00 834.598 1054.93W 370664.18 5973477.31 n70 20 08.60 w151 2 57. 64 6000.00 27.29 232.29 5684.89 890.748 1127. 55W 370590.63 5973422.40 n70 20 08.05 w151 2 59.76 6355.72 27.29 232.29 6001.00 990.528 1256.59W 370459.93 5973324.82 n70 20 07.07 w151. 3 03.53 6500.00 27.29 232.29 6129.22 1030.998 1308. 93W 370406.92 5973285.24 n70 20 06.67 w151 3 05.05 7000.00 27.29 232.29 6573.55 1171.258 1490.31W 370223.21 5973148.09 n70 20 05.29 w151 3 10.35 7173.67 27.29 232.29 6727.88 1219.968 1553.31W 370159.40 5973100.45 n70 20 04.81 w151 3 12.19 7282.95 27,29 232.29 6825.00 1250.628 1592.96W 370119.24 5973070.47 n70 20 04.51 w151 3 13.35 7492.26 27.29 232.29 7011.00 1309.338 1668.88W 370042.34 5973013.06 n70 20 03,93 w151 3 15.56 7500.00 27.29 232,29 7017,88 1311.508 1671 . 69W 370039,50 5973010.93 n70 20 03.91 w151 3 15. 65 7593.53 27.29 232.29 7101.00 1337.738 1705.62W 370005.13 5972985.28 n70 20 03,65 w151 3 16.64 7663.30 27.29 232.29 7163.00 1357.308 1730.93W 369979.50 5972966.14 n70 20 03.46 w151 3 17.37 7682.43 27.29 232.29 7180.00 1362.678 1737.87W 369972.47 5972960.89 n70 20 03.40 w151 3 17.58 All data in feet unless otherwise stated. Calculation uses minimwn curvature method. Coordinates from slot #50 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 2334.98 on azimuth 231. n degrees from ¡.¡ellhead. Total Dogleg for ¡.¡ellpath is 39.29 degrees. Vertical section is from ¡.¡ellhead on azimuth 231.85 degrees. Grid is alaska - Zone 4, Grid coordinates in FEET and computed using the Clad:e - 1866 spheroid Presented by Baker Hughes INTEQ 0 ..., ~ f'\ ~ ~\J J' }1 .~I ~!' .!C.~ i u j i t JL, L. ') ) Phillips Alaska, Inc. PROPOSAL LISTING Page 2 CD#2, 50PBl Your ref : CD2-50PBl Version#8 Alpine Field, North Slope, Alaska Last revised: 12-Feb-2002 Measured Inc1in Azimuth True Vert RECTANGULAR G RID C OORDS G E 0 GRAPHIC Depth Degrees Degrees Depth COORDINATES Easting Northing COO RDINATES 7703,81 27.29 232.29 7199.00 1368.67S 1745.63W 369964.61 5972955.03 n70 20 03.34 w151 3 17.80 7707.19 27.29 232.29 7202.00 1369.618 1746.85W 369963.37 5972954.10 n70 20 03.34 w151 3 17.84 7808.46 27.29 232.29 7292.00 1398.02S 1783.5 9W 369926.16 5972926.32 n70 20 03.06 w151 3 18.91 7958.46 27.29 232.29 7425.30 1440.10S 1838. 01W 369871. 05 5972885.18 n70 20 02.64 w151 3 20.50 All data in feet unless otherwise stated. Calculation uses minimum curvature method, Coordinates from slot #50 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 2334.98 on azimuth 231.92 degrees from \.¡ellhead, Total Dogleg for wellpath is 39.29 degrees. Vertical section is from wellhead on azimuth 231.85 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clar;:e - 1866 sp:,eroid Presented by Baker Hughes INTEQ 0: 'G!'~' l ' " ,J"~t!.. ) ) I Phillips Alaska, Inc. CD#2,50PBl Alpine Field, North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: CD2-50PBl Version#8 Last revised: 12-Feb-2002 Conunents in wellpath =:==============:c:==== MD TVD Rectangular Coords. Comment - - - - - - -- - - - - - - - - - -- - - - - - - - - - - - - - - -- - - - - - - - - -- - - - --- - - - - - - - - - - - - - -- -- - - -- - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - -- 400.00 400.00 O.OON O. OOE Begin Nudge 700.00 699.45 1l.66S 10.5 OW EOC 1069.57 1067.00 40.37 S 36.35W West Sak 1200.00 1196.71 50.50S 45. 47W Begin Drop 1500.00 1496.17 62. 17 S 55. 97W EOD 1555.84 1552.00 62. 17S 55. 97W Base Permafrost 2203,84 2200.00 62. 17S 55. 97W C-40 2397.84 2394.00 62.17S 55. 97W 9 5/8" Casing pt 2407.84 2404.00 62. 17S 55. 97W C-30 2600.00 2596.16 62. 17 S 55. 97W KOP 2785.12 2781.00 67. 65S 63. 07W C-20 3509.81 3471.95 192.24S 224.19W EOC 3932.97 3848.00 310.94S 377. 70W K-3 4182.79 4070.00 381. 01S 468.32W K-2 5799.82 5507.00 834.598 1054. 93W Albian-97 6355.72 6001.00 990.528 1256.59W Albian-96 7282.95 6825.00 1250.628 1592.96W HRZ 7492.26 7011.00 1309.338 1668. 88W K-l 7593.53 7101.00 1337.738 1705.62W LCU 7663.30 7163.00 1357.308 1730.93W Miluveach A 7682.43 7180.00 1362.678 1737.87W Alpine D 7703.81 7199.00 1368.678 1745.63W Alpine C 7707.19 7202.00 1369.618 1746.85W Target 7958.46 7425.30 1440.108 1838. 01W TD NO Targets associated with this wellpath OHiuiiVAL ì Phillips Alaska, Inc. CD#2 50 slot #50 Alpine Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref: CD2-50 VersioniJ8 Our ref: prop4442 License: Date printed: 12-Feb-2002 Date created: 31-Jan-2001 Last revised: 8-Feb-2002 Field is centred on n70 20 37.100,w15C1 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 16.81l,w151 2 26.836 Slot Grid coordinates are N 5974293.878, E 371732.983 Slot local coordinates are 2062.81 S 1501.69 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) (, 'L' . ' '",: .'. "'\' '.. \ U I , j \"l 4 3 'J i"~ " ) Phillips Alaska, Inc. PROP05AL LI5TING Page 1 CD#2,50 Your ref : CD2-50 Version#8 Alpine Field, North 51ope, Alaska Last revised: 8-Feb-2002 Measured Inclin Azimuth True Vert RECTANGULAR G RID C OORD5 G E 0 GRAPHIC Depth Degrees Degrees Depth COORDINATE5 Easting Northing COO RDINATE5 0.00 0.00 0.00 0.00 O.OON O. OOE 371732,98 5974293.88 n70 20 16.81 w151 2 26.84 100.00 0.00 222.00 100.00 O.OON O. OOE 371732.98 5974293.88 n70 20 16.81 w151 2 26.84 200.00 0.00 222.00 200.00 O. OON O.OOE 371732.98 5974293.88 n70 20 16.81 w151 2 26.84 300.00 0.00 222.00 300.00 O.OON O. OOE 371732.98 5974293.88 n70 20 16.81 w151 2 26.84 400.00 0.00 222.00 400.00 O. DON O. ODE 371732.98 5974293.88 n70 20 16.81 w151 2 26.84 500.00 2.00 222.00 499.98 1. 305 1.17W 371731. 79 5974292.60 n70 20 16.80 w151 2 26.87 600.00 4.00 222.00 599.84 5.195 4. 67W 371728,23 5974288.77 n70 20 16.76 w151 2 26. 97 700.00 6.00 222.00 699.45 11.665 10 . 5 OW 371722.29 5974282.40 n70 20 16.70 w151 2 27.14 1000.00 6.00 222.00 997.81 34.975 31. 48W 371700,92 5974259.45 n70 20 16.47 w151 2 27.76 1200.00 6.00 222.00 1196.71 50.505 45. 47W 371686,67 5974244.16 n70 20 16.31 w151 2 28.16 1300.00 4.00 222.00 1296.33 56.985 51. 3 OW 371680,73 5974237.78 n70 20 16.25 w151 2 28.33 1400.00 2.00 222.00 1396.19 60.875 54 . 81W 371677,16 5974233.95 n70 20 16.21 w151 2 28.44 1500.00 0.00 222.00 1496.16 62.175 55. 97W 371675,97 5974232.67 n70 20 16.20 w151 2 28.47 2000.00 0.00 222.00 1996.16 62.17 S 55. 97W 371675,97 5974232.67 n70 20 16.20 w151 2 28.47 2500.00 0.00 222.00 2496.16 62.175 55. 97W 371675.97 5974232.67 n70 20 16.20 w151 2 28.47 2600.00 0.00 222.00 2596.16 62.175 55. 97W 371675,97 5974232.67 n70 20 16.20 w151 2 28.47 2700.00 3.00 232.29 2696.12 63.775 58. 05W 371673.87 5974231.11 n70 20 16.18 w151 2 28.53 2800.00 6.00 232.29 2795.80 68.575 64. 25W 371667,59 5974226.41 n70 20 16.14 w151 2 28.71 2900.00 9.00 232.29 2894.93 76.555 74.5 8W 371657.13 5974218.61 n70 20 16.06 w151 2 29.01 3000.00 12.00 232.29 2993.25 87.705 88.9 9W 371642.53 5974207.71 n70 20 15.95 w151 2 29.43 3100.00 15.00 232.29 3090.47 101. 975 107. 46W 371623.83 5974193.74 n70 20 15.81 w151 2 29. 97 3200.00 18.00 232.29 3186.34 119.355 129.92W 371601. 07 5974176.76 n70 20 15.64 w151 2 30. 63 3300.00 21. 00 232.29 3280.60 139.765 156.33W 371574.33 5974156.79 n70 20 15.44 w151 2 31. 40 3400.00 24.00 232.29 3372.97 163.175 186.60W 371543.67 5974133.90 n70 20 15.21 w151 2 32.28 3500.00 27.00 232.29 3463.22 189.505 220.65W 371509.18 5974108.15 n70 20 14.95 w151 2 33.28 3509.82 27.29 232.29 3471.96 192.245 224.19W 371505.59 5974105.47 n70 20 14.92 w151 2 33.38 4000.00 27.29 232.29 3907.56 329.745 402.02W 371325.48 5973971.01 n70 20 13.57 w151 2 38.58 4500.00 27.29 232.29 4351. 90 469.995 583. 40W 371141. 77 5973833.86 n70 20 12.19 w151 2 43.87 5000.00 27.29 232.29 4796.23 610.245 764, 78W 370958.06 5973696.70 n70 20 10.81 w151 2 49.17 5500.00 27.29 232.29 5240.56 750.495 946. 16W 370774.35 5973559.55 n70 20 09.43 w151 2 54.46 6000.00 27.29 232.29 5684.89 890.755 1127. 55W 370590.63 5973422.39 n70 20 08.05 w151 2 59.76 6500.00 27.29 232.29 6129.22 1031. ODS 1308. 93W 370406.92 5973285.24 n70 20 06.67 w151 3 05.05 7000.00 27.29 232.29 6573.55 1171.255 1490.31W 370223.21 5973148.08 n70 20 05.29 w151 3 10.35 7173.66 27.29 232.29 6727.88 1219.965 1553. 31W 370159.40 5973100.45 n70 20 04.81 w151 3 12.19 7200.00 27.74 227.25 6751.24 1227.825 1562.59W 370149.99 5973092,75 n70 20 04.73 w151 3 12.46 7284.24 30.28 212.48 6825.00 1259.095 1588.43W 370123,63 5973061.92 n70 20 04.42 w151 3 13.21 7300.00 30.93 209.99 6838.56 1265.955 1592. 59W 370119.36 5973055.13 n70 20 04.36 w151 3 13.34 7400,00 35.96 196,40 6922.10 1316.485 1613. 76W 370097,33 5973004.98 n70 20 03.86 w151 3 13.95 7500.00 42.17 186.03 6999.78 1378.165 1625. 61W 370084.45 5972943.51 n70 20 03.25 w151 3 14.30 7515.26 43.20 184 . 68 7011. 00 1388.465 1626.57W 370083.31 5972 933.23 n70 20 03.15 w151 3 14.33 7600.00 49.12 178.00 7069.71 1449.46S 1627. 82W 370081.03 5972872.26 n70 20 02.55 w151 3 14.36 7649.65 52,74 174 . 63 7101. 00 1487.915 1625. 31W 370082.89 5972833.78 n70 20 02.17 w151 3 14.29 7700.00 56.51 171.54 7130.15 1528.655 1620.34W 370087,16 5972792.96 n70 20 01.77 w151 3 14.14 7763.66 61,37 167. 99 7163.00 1582.285 1610. 61W 370095.98 5972739.18 n70 20 01. 24 w151 3 13.86 7800.00 64.18 166.11 7179.62 1613.765 1603. 37W 370102.69 5972707.59 n70 20 00.94 w151 3 13. 65 7800.86 64.25 166.07 7180.00 1614.515 1603.18W 370102..87 5972706,83 n70 20 00.93 w151 3 13.64 7847.72 67.91 163.78 7199.00 1655.855 1592.03W 370113.32 5972665,31 n70 20 00.52 w151 3 13,31 7900.00 72.03 161.36 7216.91 1702.705 1577.31W 370127.24 5972618.22 n70 20 00.06 w151 3 12.88 8000.00 79.98 157.02 7241.09 1793.285 1542.82W 370160.20 5972527.08 n70 19 59.17 w151 3 11. 88 8100,00 87.99 152.88 7251. 56 1883.275 1500.73W 370200.75 5972436.40 n70 19 58.28 w151 3 10.65 All data in feet unless otherwise stated. Calculation uses minimum curvature method, Coordinates from slot #50 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 4551. 76 on azimuth 180.93 degrees from wellhead. Total Dogleg for wellpath is 124.92 degrees. Vertical section is from N 0.00 E 0.00 on az~muth 151.86 degrees. Grid is alaska - Zone .:f. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ~ f"'''', .,"\ ~,~ , 11 L .,y 'I " ~' ii, \: /'1 '# f'l ~J J d ~ r'~ ) ') Phillips Alaska, Inc. PROPOSAL LISTING Page 2 CD#2, 50 Your ref : CD2-50 Version#8 Alpine Field, North Slope, Alaska Last revised: 8-Feb-2002 Measured Inclin Azimuth True Vert RECTANGULAR G RID C OORDS G E 0 GRAPHIC Depth Degrees Degrees Depth COORDINATES Easting Northing COO RDINATES 8125.05 90.00 151.86 7252.00 1905.468 1489.12W 370211. 99 5972414.02 n70 19 58.07 w151 3 10.31 8125.07 90.00 151.86 7252.00 1905.488 1489.11W 370212.00 5972414.00 n70 19 58.07 w151 3 10.31 8500.00 90.00 151.86 7252.00 2236.098 1312. 28W 370383.20 5972080.47 n70 19 54.82 w151 3 05.14 9000.00 90.00 151. 86 7252.00 2676.998 1076.46W 370611.51 5971635.69 n70 19 50.48 w151 2 58.25 9500.00 90.00 151.86 7252.00 3117.898 840.65W 370839.82 5971190.90 n70 19 46.14 w151 2 51. 36 10000.00 90.00 151.86 7252.00 3558.795 604.83W 371068.13 5970746.12 n70 19 41.81 w151 2 44.47 10500.00 90.00 151. 86 7252,00 3999. 68S 369.02W 371296.43 5970301.33 n70 19 37.47 w151 2 37.58 11000.00 90.00 151.86 7252.00 4440.585 133.20W 371524.74 5969856.55 n70 19 33.14 w151 2 30.70 11125.37 90.00 151.86 7252.00 4551.135 74. 08W 371581. 99 5969745.02 n70 19 32.05 w151 2 28. 97 11125.39 90.00 151. 86 7252.00 4551.155 74. 07W 371582.00 5969745.00 n70 19 32.05 w151 2 28, 97 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #50 and TVD from RK9 (Doyon 19) (5:.00 Ft above mean sea level). Bottom hole distance is 4551.76 on azimuth 180.93 degrees from wellhead. Total Dogleg for wellpath is 124.92 degrees. Vertical section is from N 0,00 E 0.00 on a:imuth 151.86 degrees, Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clar~:e - 1866 spheroid Presented by Baker Hughes INTEQ ( 11GINAL ) ') Phillips Alaska, Inc. CD#2,50 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: CD2-50 Version#8 Last revised: 8-Feb-2002 Comments in wellpath ::::::::===::::>::::::::===:=:::::::::::::::::::::::::::::::::::: MD Rectangular Coords. Comment TVD - - - - - - -- - - - - - - - - - - - - - - -- - - - -- - - - - - - - - - - - - - - -- - - - - -- - - - - - - - - -- - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 7173.66 6727.88 1219.96S 1553.31W KOP - Sidetrack pt 7284.24 6825.00 1259. 09S 1588. 43W HRZ 7515.26 7011.00 1388. 46S 1626.57W K-1 7649.65 7101.00 1487. 91S 1625.31W LCU 7763.66 7163.00 1582. 28S 1610.61W Miluveach A 7800.86 7180.00 1614, 51S 1603.18W Alpine D 7847.72 7199.00 1655.858 1592.03W Alpine C 8125.05 7252.00 1905.46S 1489.12W Target - CsgPt-EOC 8125.07 7252.00 1905, 48S 1489.11W CD2 Tgt 51 Heel 27-Sep-99 11125.37 7252.00 4551.13S 74. 08W TD - Csg pt 11125.39 7252.00 4551.15S 74. 07W CD2 Tgt 51 Toe 27-Sep-99 Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing - - - - - - -- - - - - - - - - - - - - - - - - - - - -- - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - -- - - -- - - - -- - - - - - - - - - -- - - - -- - - - - - - - - - - - - -- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE 8125.07 7252.00 O.OOE 2397.84 2394.00 1905.48S 62.17S 1489.11W 7" Casing 55.97W 9 5/8" Casing Targets associated with this wellpath =================:;;::==;0:::=;;::;==:::::====:;;;=====;:;: Target name Geographic Location T,V.D. Rectangular Coordinates Revised - - - - - - - - - - - - - - - - - - - - - - -- - - - -- - - - - - - - - - - - - - - -- - - - - -- - - - - - - - - -- - - - -- - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- CD2 Tgt51 Heel 27-Se 370212.000,5972414.000,0.0000 7252.00 CD2 Tgt51 Toe 27-Sep 371582,000,5969745.000,0.0000 7252.00 1905.48S 4551.15S 1489.11W 15-Qct-1997 74.07W 15-Qct-1997 \w.' ¡¡ IÎ a ,",4 ~ ~ ~" ~ J." ) ') Phillips Alaska, Inc. CD#2 50 slot #50 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref: CD2-50 Version#8 Our ref: prop4442 License: Date printed: 12-Feb-2002 Date created: 31-Jan-2001 Last revised: 8-Feb-2002 Field is centred on n70 20 37, 100,w150 51 37.53 Structure is centred on n70 20 37,100,w151 1 42.976 Slot location is n70 20 16.8ll,w151 2 26.836 Slot Grid coordinates are N 5974293.878, E 371732.983 Slot local coordinates are 2062.81 S 1501. 69 W proj ection type: alaska - Zone 4, Spher'oid: C1ar'ke - 1866 Obj ect wellpa th MWD <0 - 9ll3'>,,39PB1,CD#2 MWD <8371 - 12651'>,,39,CD#2 MWD <6701 - 8755'>,,34,CD#2 MWD <0-7562'>, ,34PB1,CD#2 MWD w/IFR <0 - 14580'>,,47,CD#2 MWD <0-11874'>,,49,CD#2 MWD <485 - 719'>,,26PB1,CD#2 Composite Survey <0-490' >, ,2 6PB2, CD#2 MWD <0-11238'>,,26,CD#2 MWD w/IFR <3794 - 13078'>,,33B,CD#2 MWD w/IFR <0 - 21464' >,,33, CD#2 MWD W!IFR <6007 - 15355' >, , 33A, CD#2 MWD w/IFR <0-???'>,,45,CD#2 MWD <8480 - 13138'>,,42,CD#2 MWD <0-9507'>,,42PH,CD#2 MWD <0-10054' >, ,24 PH, CD#2 MWD <8715 - 14301'>,,24,CD#2 MWD <0-12278' >, , 15 PB1, CD#2 MWD <11806 - 13776'>,,15 PB2,CD#2 MWD <13450 - 14161 '>" 15,CD#2 MWD <0-11056'>,,14,CD#2 PMSS <0-11984'>,,35,CD#2 MWD <0-???'>,,17,CD#2 PMSS <0-7170'>"Neve #l,Neve #1 PMSS <1876-9940'>, ,AlplA,A1pine #1 PMSS <0-3161' >, ,Alpl,Alpine #1 PMSS <1868-8850' >"Alp1B, Alpine #1 Reference North is True North Closest approach with 3-D Minimum Distance method Last revised Distance M. D . Diverging from M. D. 12-Sep-2001 99.5 550.0 11125.4 1-0ct-2001 99.5 550.0 11125.4 15-Jan-2002 159.9 100.0 9140.0 26-Dec-2001 159.9 100.0 1680.0 8-Feb-2002 27.8 450.0 10640.0 4-Feb-2002 7.2 400.0 11080.0 7-Jan-2002 232.2 512.5 512.5 8-Jan-2002 231.3 487.5 487,5 6-Feb-2002 239.8 200.0 10560.0 18-Sep-2001 169.1 450.0 450.0 18-Sep-2001 169.1 450.0 450.0 19-Aug-2001 169.1 450.0 450.0 26-Nov-2001 49.6 462.5 9620.0 2-Jul-2001 79.2 425.0 11125.4 27-May-2001 79.2 425.0 1412.5 18-Jun-2001 259.5 400.0 400.0 26-Jun~2001 259.5 400,0 400.0 30-0ct-2001 349.7 100.0 100.0 30-0ct-2001 349.7 100.0 100.0 30-0ct-2001 349.7 100.0 100.0 2-0ct-2001 359.6 400.0 400.0 30-Nov-2001 147.4 487.5 9720.0 12-Feb-2002 330.1 100.0 2560.0 16-Dec-1999 4552.1 11125.4 11125.4 21-Sep-1999 3035.8 3660.0 3660.0 21-Sep-19994139.9 0.0 10480.0 21-Sep-1999 4139.9 0.0 11125.4 J ~¡GINl4L ) ) Phillips Alaska, Inc. CD#2 50 slot #50 Alpine Field North Slope, Alaska 3-D M I N I MUM D I S TAN C E C LEA RAN C ERE paR T INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref: CD2-50 Version#8 Our ref: prop4442 License: Date printed: 12-Feb-2002 Date created: 31-Jan-2001 Last revised: 8~Feb-2002 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 16.811,w151 2 26.836 Slot Grid coordinates are N 5974293.878, E 371732.983 Slot local coordinates are 2062.81 S 1501.69 W Pt'ojection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is lirrlÌ ted to clearances less than 2000 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. Object wellpath DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g, 487.4* MWD <0 - 9113'>,,39PB1,CD#2 MWD <8371 - 12651'>,,39,CDJI2 CD2-34 Version#9" 34, CD#2 MWD <6701 - 8755'>,,34,CD#2 MWD <0-7562'>,,34PB1,CD#2 CD2-29 Version#3,,29,CD#2 MWD w/IFR <0 - 14580' >" 47, CD#2 MWD <0-11874'>,,49,CD#2 CD2-48 Version#3" 4 8, CD#2 CD2-51 Vers#6" 51, CD#2 CD2-53 Vers#5" 53,CD#2 MWD <485 - 719' >" 26PB1, CD#2 Composite Survey <0-490'>,,26PB2,CD#2 MWD <0-11238'>,,26,CD#2 CD2-31 Vers#5" 31, CD#2 MWD w/IFR <3794 - 13078'>,,33B,CD#2 MWD w/IFR <0 - 21464' >" 33, CD#2 MWD W/IFR <6007 - 15355'>, ,33A,CD!!2 CD2-25 Version#3" 25, CD#2 CD2-30 Vers#5" 30,CD#2 CD2-41 Vers#5" 41,CD#2 MWD w/IFR <O-???' >,,45, CD#2 MWD <8480 - 13138'>,,42,CD#2 MWD <0-9507' >, , 42 PH, CD#2 MWD <0-10054'>,,24PH,CD#2 MWD <8715 - 14301'>,,24,CD#2 MWD <0-12278'>,,15 PB1,CD#2 MWD <11806 - 13776'>,,15 PB2,CD#2 MWO <13450 - 14161' >,,15, CD#2 MWD <0-11056'>" 14,CD#2 CD2-35A Version#3" 35, CD#2 PMSS <0-11984' >" 35, CO#2 CD2-16 Version#5" 16,CO#2 CD2-23 Vers#8, ,23,CD#2 CD2-13 Version!i3" 13,CO#2 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 12-Sep-2001 )95.9( 562.5 11125.4 1-0ct-2001 )95.9( 562.5 11125.4 26-Dec-2001 )156.4( 475.0 11125.4 15-Jan-2002 )159.3( 100.0 9280.0 26-Dec-2001 )159.3( 100.0 1920.0 9-Apr-2001 )207.7( 425.0 425.0 8-Feb-2002 ) 24.4 ( 462.5 10840,0 4-Feb-2002 )5.1! 400.0 11125.4 9-Apr-2001 )17.7( 425.0 11125.4 9-Apr-2001 )8.8( 300.0 11125.4 9-Apr-2001 )29.0( 300.0 11125.4 7-Jan-2002 )228.7( 525.0 525.0 8-Jan-2002 ) 228.7 ( 487.5 487.5 6-Feb-2002 )238.8( 200.0 11125.4 9-Apr-2001 )187.7! 425.0 1520.0 18-Sep-2001 )165.7( 487.5 5300.0 18-Sep-2001 ) 165.7 ( 487.5 487.5 19-Aug-2001 )165.7( 487,5 487.5 3-Jan-2002 )242.8( 625.0 2700.0 8~Jun-2001 )197.7( 425.0 425,0 9-Apr-2001 )87.7( 425.0 11125.4 26-Nov-2001 )46,0( 487.5 10360,0 2-Jul-2001 )77.0! 450.0 11125,4 27~May-2001 )77.0! 450.0 1425.0 18-Jun-2001 )257.4( 412.5 412.5 26-Jun-2001 )257.4( 412.5 412.5 30-0ct-2001 )348.3( 400.0 400.0 30-0ct-2001 )348.3( 400.0 400.0 30-0ct-2001 )348.3( 400.0 400,0 2-0ct-2001 )357.5( 425.0 425.0 30-Nov-2001 H063.4! 11125.4 11125.4 30-Nov-2001 )144.7( 525.0 10340.0 9-Apr-2001 1338.0( t,12.5 t,12.5 14-Mar-2001 )267."7( 425.0 ';25.0 9-Apr-2001 1368,0( .:12.5 412.5 Ol1ìuu'H¡L ) CD2-19 Vers#4" 19,CD#2 CD2-18 Vers#4" 18,CD#2 CD2-56 Version#2" 56, CD#2 CD2-52 Vers#5" 52(CD#2 CD2-58 Vers#3" 58,CD#2 CD2-57 Vers#3" 57 ,CD#2 CD2-28 Vers#6" 28, CD#2 CD2-54 Vers#5,,54,CD#2 CD2-37PBl Version#4" 37PB1, CD#2 CD2-46 Version#5 ( , 46, CD#2 CD2-55 Vers#3" 55, CD#2 CD2-40 Version#3" 40, CD#2 CD2-22 Version#3" 22, CD#2 CD2-38 Version#3" 38, CD#2 CD2-5 Version#5" 5, CD#2 CD2-8 Vers#4" 8, CD#2 CD2-7 Version#3" 7 ,CD#2 CD2-10 Version#3" 10, CD#2 CD2-9 Vers#4" 9(CD#2 CD2-20 Version#5(, 20, CD#2 CD2-12 Version#3" 12, CD#2 CD2-44 Vers#4" 4 4, CD#2 CD2-43 Leg#l Vers#2(,43,CD#2 CD2-17 Version#4" 1 7, CD#2 MWD <O-???' >,,17 (CD#2 CD2-32 Version#8 ( , 32, CD#2 PMSS <0-7170'>"Neve #l,Neve #1 PMSS <1876-9940'>"AlplA,Alpine #1 PMSS <0-3161'>"Alpl,Alpine #1 PMSS <1868-8850'>( ,AlplB,Alpine #1 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 12-Jul-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 19-Jun-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 14-Mar-2001 9-Apr-2001 9-Apr-2001 8-May-2001 31-Jan-2002 12-Feb-2002 6-Feb-2002 16-Dec-1999 21-Sep-1999 21-Sep-1999 21-Sep-1999 ) 307.7 ( ) 318.3 ( ) 58.8 ( ) 14 . 9 ( ) 79.0 ( ) 68.5 ( ) 218.4 ( ) 38.8 ( ) lÒ5. 7 ( ) 37.7 ( ) 48.9 ( ) 93.4 ( ) 278.3 ( ) 117.1 ( ) 448.5 ( ) 418.6 ( 1428.5 ( 1398.6 ( ) 408.3 ( 1297.7 ( 1377.7 ( ) 55.6 ( ) 58.7 ( ) 327,9 ( ) 328.7 ( ) 177.5 ( )4393.2( )2915.9( )4138.6( )4138.6( 425.0 400.0 300.0 587.5 300.0 400.0 300.0 300.0 1540.0 425.0 300.0 637.5 400.0 437.5 300.0 300.0 300.0 300.0 300.0 425.0 425.0 475.0 860.0 425.0 450.0 425.0 11125.4 3780.0 437.5 437.5 11125.4 400.0 11125.4 11125.4 11125.4 11125.4 300.0 10280.0 11125.4 11125.4 10440.0 11125,4 2622,2 11125.4 300.0 300.0 300.0 2520.0 8560.0 425.0 2560.0 9480.0 860.0 2611.1 2580.0 1840.0 11125.4 3820.0 10720.0 11125.4 ) ~ ~,:". ........: ::" L ..Hi(;iirvJ4 ~GA- '-sJdlo~ ) ) Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 20, 2002 RECEIVED Alaska Oil and Gas Conservation Commissi-on 333 West ¡th Avenue, Suite 100 Anchorage, Alaska 99501 FEB 2 1. 2002 Re: Application for Permit to Drill CD2-50 (& CD2-50PB1) Alaska Oil & Gas Cons. Commission Anchorage Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD2 drilling pad. The intended spud date for this well is March ß'; 2002. It is intended that Doyon Rig 19 be used to drill the well. 5 The CD2-50 pilot hole will be drilled through to the base of the Alpine Sand at +/-27° inclination. This will allow evaluation of the reservoir interval. It will then be plugged back and sidetracked to enable a horizontal penetration of the Alpine reservoir. After setting 711 intermediate casing, it is planned to temporarily halt drilling, in order to batch drill to intermediate casing point. This will facilitate drilling with mineral oil based mud on the production interval of three producers. Doyon 19 will return to CD2-50 after setting intermediate casing on two other Alpine producers. At the end of the work program, the well will be closed in awaiting completion of well work and facilities work that will allow the well to be put on production. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: . Form 1 0-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). A proposed drilling program, including a request for approval of annular pumping operations. A drilling fluids program summary. Proposed pilot hole schematic. Proposed completion diagram. Proposed completion diagram with open hole isolation options. Pressure information as required by 20 ACC 25.035 (d)(2). CD2-50 Cementing Requirements. . . . . . . . . 1. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 0 ¡'I/ ,-d í .'r! L ~ '1 ~ -) ) If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~'~¿- Vern Johnson Drilling Engineer Attachments cc: CO2-50 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin e-mail: ATO 1530 A TO 868 A TO 848 ATO 844 Anadarko - Houston Kuukpik Corporation Tommy_Thompson @ anadarko.com RECE\VEO ffB 2 1 2002- , ka OU & Gas Coos. Commission A\as Anchorage 0 II ,I"Ì¡ 1/ Ù-, L ) .'.-' P AY .§4~ T~6~:tK~~KA 6~D~~Eo:e ..~~~W1>!,rH*:vè~þ~;:sÜlt~'lP9 7~:-4261839 . . . ":',, " . ,,',:"" ~G 11'1:1 $S:..> A<L.::....i! ,::e::;J? A FIR .LL. [:-;"" ölff!t..,<;) t\, I ~çJ~t¡J~l~7â~!i~9;~;i#i6 oe91:~7 9 ,'.;: "',' " ' . " /:FEBRUARY).i12/2002 .. .:..~, ...:. BANK=ØN£.. - BANK ONE, NA . 0710 Chic~go, IL Payable throJugh. . . . Reþub lie Bank & Trust Company . TRACE NLJMBER: D ;;)-SØ /ŒDd- 4.O.. ..' .....:.:.....:.f.. .".:.1$... .:.... J 11120 S,¡ ¡. . :é~IJ.CTLYi***¡~*****~ 1()()t)OLLARS .. AND>tJO Cß;NTS$:¡;*******, ()C1~OO .~............ . Qc....,...".........:..'.......:.:....... -..,....~....,..., .....~.................~ 0;"'.. C I:U8,.:1110..L. 2.\;.2.1: 0 g g 7 5 ? g nl ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMJTT AL LETTER .~ . ~ WELL NAME (Jet.{. (2)2--- Su \- C7:; 2 -,SêJPf/ CHECK 1 STANDARD LEITER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) \./.. Vi' DEVELOPMENT REDRlLL Pll.,OT HOLE ~~" /"'" V/' EXPLORA TION ANNULAR DISPOSAL L-)NO INJECTION WELL ANNULAR DISPOSAL <--J YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL' "CLUE" The permit is for a new wellbore segment of existing weD --'--' Permit No, ,API No. - " Production should continue to be reported as a function of the original API number stated above. . . In accordance with 2,0 AAC 25.005(1), all records, data and logs acquired for the pilot bole must be clearly , differentiated in both name (name on per~ plus PH) and API number (50 e.9'80) from records, data and logs acquired for well (na,me on permit). , Annular disposal has not been requested. . . Annular Disposal, of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. '. . ANNULUS /' . V YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved . subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. /VV-cl j}' ~f Áo/<'- 5-1-d -kx:.l- 4--- /I-~üv~ Lelk- A é'j¿~l WELL PERMIT CHECKLIST COMPANY ßi/{/,S WELLNAM: rlV2.- S-n ,FIELD&POOL /;!..¿;ì/OD tfNITCLASS J:)r:V IO/L-- ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . . N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N AP~ DATE 12. Permit can be issued without administrative approval.. . . . . N ~ r.) 3,. ¡ . ~2-- 13. Can permit be approved before 15-day wait.. . . . . . . . . . VN ENGINEERING 14. Conductor string provided.. . . . . . . . . . . . . . . . . . 82 N ~t @J ¡ lif' TV D . 15. Surface casing protects all known USDWs. . . . . . . Y N '....1 . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . ~ N A~r~li--l ~C i. ~r' . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y ~ rv...-1f}..{.~ GU--1.....VLU.~ ~s p.9<;":vl . 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . .. . . . . . , . N f)o~ I~ 21. If a re-drill, has a 10-403 for abandonment been approved. . . ~~/A " 22.. Ade. quate well bore separation proposed.. . . . . . . . . . . . N Clo Ç...('<;;.. t cvPf yO~ t.... = 7 t Z.@"oo'M/). 23. If diverter required, does it meet regulations. . . . . . . . . . N ( I 24. Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . (j2 N +-. t 26. BOPE press rating appropriate; test to 5000 psig. tt N 1YJ1lt::.. UIi, 4-etS .= 3'soo r'~. Ms.p '~2.SS 7 P CA.' I 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . éfJ N J 28. Work will occur without operation shutdown. . . . . . . . . . . J1J N. 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . ~ á" ~. /2..e(c:nu . 30. Permit can be issued wlo hydrogen sulfide measures. . . . . f{) N 31. Data presented on potential overpressure zones. . . . . .. 4/rf~' 32. Seismic analysis of shallow gas zones. . . . . . . . . . . .. AI.,.! ~--N APP!\. DAtE 33. Seabed condition survey (if off-shore). . . . . . . . . . . .. iv A ¥-N--- Þ '1' /. () z.- 34. Contact name/phone for weekly progress reports [exploratory onIY!;¡K---'N ANNULAR DISPOSAL 35. With proper cementing records. this plan £) (A) will contain waste in a suitable receiving zone; . . . . . . . c;;r N (B) . will not contaminate freshwater; or cause drilling waste. ., (2 N to surface; (C) W. ill not im. pair mechanical i. nte. g, rit,y of the well used for disposal;@,N (D) ,will not damage producing formation or impair recovery from a (J! N pool; and /.J (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. lY N GEOLOGY: 'ENGINE'ERING: UIC/Annular: COMMISSION: ~:;~:> ::G~ '>{ I APPR DA TJ: V#';A- ~ 1,101- ~3/1 GEOLOGY APPR DATE \¡$ilr 5 J tt 0 L, PROGRAM: Exp - Dev .J(Redrll - Serv - Wellbore seg - Ann. disposal para req - GEOLAREA B 1D UNIT# (? ç¡~_3~.,{) ON/OFF SHORE 6/7 l Teh, + f he~ç. f0 o.¡ f/,/(A¿. /1- r------ NY7V- ,,~h¿c:..,r?4M t/ ( \ Q.i\ M ~, ~ '¡,.~<;A. \ >«'\ <..,)(/:"'> -\- '\ \ '-'- \ J Commentsllnstructions: COT DTsJ/o~¡Ó 7- JMH G:\geology\templates\checklist.doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Permitting Process. but is part of the history file. , To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ) ) Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Oct 07 15:29:09 2002 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/07 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Tape Header Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/07 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22042 R. KRELL D. MICKEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services CO2-50 PB1 501032041570 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 07-0CT-02 2 llN 4E 2063 1503 52.43 15.90 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 16.000 114.0 8.500 9.625 2385.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. aOd-o'i9 I 1/ fšL{ ) ') 4. MWD RUN 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); COMPENSATED NEUTRON POROSITY (CNP); STABILIZED LITHO- DENSITY (SLD); AND PRESSURE WHILE DRILLING (PWD). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER MEG KREMER (PPCO) DISCUSSION OF REQUIREMENTS 9/26/01. MWD DATA ARE CONSIDERED PDC. 6. MWD RUN 2 REPRESENTS WELL CD2-50 PB1 WITH API#: 50-103-20415-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7927'MD/7434'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 8.5" MUD WEIGHT: 9.5 - 9.7 PPG MUD SALINITY: 400 PPM CHLORIDES FORMATION WATER SALINITY: 25,000 FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ PPM CHLORIDES File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/07 Maximum Physical Record. .65535 File Type............... .LO Previous File Name... ... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE NCNT FCNT NPHI 1 clipped curves; all bit runs merged. .5000 START DEPTH 2290.5 2290.5 2291.0 STOP DEPTH 7822.5 7822.5 7822.0 DRHO RHOB PEF FET RPD RPM RPS RPX GR Rap $ 2300.0 2300.0 2300.0 2347.0 2347.0 2347.0 2347.0 2347.0 2354.5 2395.0 7831.5 7831.5 7831. 5 7878.5 7878.5 7878.5 7878.5 7878.5 7886.5 7927.0 ) # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 2 2290.5 MERGE BASE 7927.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..... ...... ... ....0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point....... .... ...Undefined Frame Spacing.............. ...... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units......... . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 Name Service unit DEPT FT Rap MWD FT/H GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR NPHI MWD PU-S FCNT MWD CNTS NCNT MWD CNTS RHOB MWD G/CM DRHO MWD G/CM PEF MWD BARN Min 2290.5 0.44 42.11 0.25 0.25 0.25 0.25 0.18 10.55 402 2032 1. 27 -0.79 1. 49 Max 7927 501.13 435.44 1606 2000 1844.89 2000 47.29 78.74 1404 4107 2.93 0.34 13 .23 Mean 5108.75 208.845 113.494 4.6535 4.78327 5.56998 6.54968 0.857482 45.727 577.157 2632.22 2.40678 0.066788 3.00897 First Reading For Entire File........ ..2290.5 Last Reading For Entire File... ....... .7927 Nsam 11274 11065 11065 11064 11064 11064 11064 11064 11063 11065 11065 10934 10934 11064 First Reading 2290.5 2395 2354.5 2347 2347 2347 2347 2347 2291 2290.5 2290.5 2300 2300 2300 Last Reading 7927 7927 7886.5 7878.5 7878.5 7878.5 7878.5 7878.5 7822 7822.5 7822.5 7831.5 7831.5 7831.5 File Trailer Service name. .......... ..STSLIB.OOl Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation.. .... .02/10/07 Maximum Physical Record. .65535 File Type........... .... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/07 Maximum Physical Record. .65535 File Type.... ..,........ .LO Previous File Name... ... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI DRHO RHOB PEF FET RPD RPM RPS RPX GR ROP $ 2 ) header data for each bit run in separate files. 2 .5000 START DEPTH 2290.5 2290.5 2291.0 2300.0 2300.0 2300.0 2347.0 2347.0 2347.0 2347.0 2347.0 2354.5 2395.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ # STOP DEPTH 7822.5 7822.5 7822.0 7831.5 7831. 5 7831. 5 7878.5 7878.5 7878.5 7878.5 7878.5 7886.5 7927 . 0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS ll-MAR-02 Insite 66.37 Memory 7927.0 2291.0 7927.0 .2 27.6 TOOL NUMBER PB02350HWRG6 PB02350HWRG6 PB02350HWRG6 PB02350HWRG6 8.500 2385.0 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 9.60 41. 0 9.4 400 4.8 .770 .460 .900 .750 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.............. ....0 Data Specification Block Type.....O Logging Direction........... ..... . Down Optical log depth units.......... .Feet Data Reference Point. ............ .Undefined Frame Spacing....... ............ ..60 .1IN Max frames per record........... ..Undefined Absent value.. ................... .-999 Depth Units............... . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 Name Service Unit DEPT FT Rap MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR NPHI MWD020 PU-S FCNT MWD020 CNTS NCNT MWD020 CNTS RHOB MWD020 G/CM DRHO MWD020 G/CM PEF MWD020 BARN Min 2290.5 0.44 42.11 0.25 0.25 0.25 0.25 0.18 10.55 402 2032 1.27 -0.79 1. 49 Mean 5108.75 208.845 113.494 4.6535 4.78327 5.56998 6.54968 0.857482 45.727 577.157 2632.22 2.40678 0.066788 3.00897 Nsam 11274 11065 11065 11064 11064 11064 11064 11064 11063 11065 11065 10934 10934 11064 Max 7927 501.13 435.44 1606 2000 1844.89 2000 47.29 78.74 1404 4107 2.93 0.34 13.23 First Reading For Entire File... ...... .2290.5 Last Reading For Entire File.......... .7927 File Trailer 78.0 134.0 70.0 70.0 First Reading 2290.5 2395 2354.5 2347 2347 2347 2347 2347 2291 2290.5 2290.5 2300 2300 2300 ) Last Reading 7927 7927 7886.5 7878.5 7878.5 7878.5 7878.5 7878.5 7822 7822.5 7822.5 7831.5 7831.5 7831.5 ) ) Service name......... ... .STSLIB.002 Service Sub Level Name... Version Number...... ... ..1.0.0 Date of Generation..... ..02/10/07 Maximum Physical Record..65535 File Type.... ....,...... .LO Next File Name.......... .STSLIB.003 Physical EOF Tape Trailer Service name. ........... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/07 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.... ..01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/07 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ........... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Oct 09 07:01:11 2002 Reel Header Service name......... ... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/09 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Tape Header Service name......... ... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/09 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22042 R. KRELL D. MICKEY JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 AK-MW-22042 R. KRELL D. MICKEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 12.250 8.500 6.125 # REMARKS: Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services CO2-50 501032041500 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 08-0CT-02 MWD RUN 4 AK-MW-22042 M. HANIK D. BURLEY MWD RUN 5 AK-MW-22042 R. KRELL D. MICKEY 2 11N 4E 2063 1503 52.43 15.90 CASING SIZE (IN) 16.000 9.625 7.000 DRILLERS DEPTH (FT) 114.0 2385.0 7909.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. ¿;¡oa-o~9 III «3 ) THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL KICKED OFF FROM A CEMENT PLUG IN THE CO2-50 PBl WELLBORE AT 6820'MD/6428'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 5. MWD RUNS 2,4-6 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE WHILE DRILLING (PWD). 6. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER MEG KREMER (PPCO) DISCUSSION OF REQUIREMENTS 9/26/01. MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 2,4-6 REPRESENT WELL CO2-50 WITH API#: 50-103-20415-00. THIS WELL REACHED A TOTAL DEPTH (TO) OF 11624'MD/7242'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation.. ..,. .02/10/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR Rap $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 2347.0 2347.0 2347.0 2347.0 2347.0 2354.5 2395.0 STOP DEPTH 11543.5 11543.5 11543.5 11543.5 11543.5 11582.5 11623.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO 2 4 5 6 MERGE TOP 2347.0 6820.0 7958.0 9554.0 MERGE BASE 6820.0 7958.0 9554.0 11623.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing................... ..60 .1IN Max frames per record........... ..Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2347 11623.5 6985.25 18554 2347 11623.5 Rap MWD FT/H 0.03 346.69 150.544 18458 2395 11623.5 GR MWD API 39.4 458.1 90.4814 18457 2354.5 11582.5 RPX MWD OHMM 0.25 1606 10.5391 18394 2347 11543.5 RPS MWD OHMM 0.25 2000 10.0689 18394 2347 11543.5 RPM MWD OHMM 0.25 1844.89 10.5 18394 2347 11543.5 RPD MWD OHMM 0.25 2000 11.7206 18394 2347 11543.5 FET MWD HOUR 0.18 1012.58 4.96385 18394 2347 11543.5 First Reading For Entire File......... .2347 Last Reading For Entire File.......... .11623.5 File Trailer Service name........... ..STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/09 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name. .......... ..STSLIB.002 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation...... .02/10/09 Maximum Physical Record. .65535 File Type................ La Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD 2 header data for each bit run in separate files. 2 .5000 Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM RPD FET GR ROP $ START DEPTH 2347.0 2347.0 2347.0 2347.0 2347.0 2354.5 2395.0 STOP DEPTH 6820.0 6820.0 6820.0 6820.0 6820.0 6820.0 6819.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... .............0 Data Specification Block Type.....O Logging Direction................ .Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing........... ..,..... ..60 .1IN Max frames per record............ .Undefined Absent value............... ... ... .-999 Depth Units.... . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 ll-MAR-02 Insite 66.37 Memory 6820.0 2290.0 6820.0 .2 27.6 TOOL NUMBER PB02350HWRG6 PB02350HWRG6 8.500 2385.0 LSND 9.60 41.0 9.4 400 4.8 .770 .460 .900 .750 78.0 134.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel ) DEPT FT 4 1 68 0 1 Rap MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2347 6820 4583.5 8947 2347 6820 Rap MWD020 FT/H 0.47 346.69 222.18 8850 2395 6819.5 GR MWD020 API 49.14 193.25 109.735 8932 2354.5 6820 RPX MWD020 OHMM 0.25 1606 4.76604 8947 2347 6820 RPS MWD020 OHMM 0.25 2000 4.9128 8947 2347 6820 RPM MWD020 OHMM 0.25 1844.89 5.88081 8947 2347 6820 RPD MWD020 OHMM 0.25 2000 7.10463 8947 2347 6820 FET MWD020 HOUR 0.18 47.29 0.935465 8947 2347 6820 First Reading For Entire File...... ... .2347 Last Reading For Entire File....... ... .6820 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...02/10/09 Maximum Physical Record..65535 File Type. ......""'" ..LO Next File Name.... ..... ..STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/09 Maximum Physical Record. .65535 File Type........ ....... .LO Previous File Name...... .STSLIB.002 Conunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP RPS FET RPD RPX GR RPM $ 3 header data for each bit run in separate files. 4 .5000 START DEPTH 6820.0 6820.5 6820.5 6820.5 6820.5 6820.5 6820.5 STOP DEPTH 7958.0 7923.0 7923.0 7923.0 7923.0 7931. 0 7923.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): 14-MAR-02 Insite 66.37 Memory 7958.0 6820.0 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.. ...0 Logging Direction............. ... . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing... ................. .60 .1IN Max frames per record......... ... .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O ) 7958.0 23.4 79.8 TOOL NUMBER PB02350HWRG6 PB02350HWRG6 8.500 2385.0 LSND 9.60 40.0 9.9 400 6.4 .870 .430 .700 1.100 66.0 142.0 66.0 66.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6820 7958 7389 2277 6820 7958 Rap MWD040 FT/H 1 229.63 62.6596 2277 6820 7958 GR MWD040 API 48.58 458.1 131.364 2222 6820.5 7931 RPX MWD040 OHMM 1. 22 15.03 4.60651 2206 6820.5 7923 RPS MWD040 OHMM 1. 25 16.74 4.80226 2206 6820.5 7923 RPM MWD040 OHMM 1. 26 17.37 4.98298 2206 6820.5 7923 RPD MWD040 OHMM 1. 29 17.21 4.95302 2206 6820.5 7923 FET MWD040 HOUR 0.29 74.15 0.884642 2206 6820.5 7923 First Reading For Entire File......... .6820 Last Reading For Entire File.......... .7958 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/09 Maximum Physical Record. .65535 File Type. ....... ....... .LO Next File Name... ..."" .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/09 Maximum Physical Record. .65535 File Type. ....... ....... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPX RPS RPD RPM GR ROP $ 4 ) header data for each bit run in separate files. 5 .5000 START DEPTH 7923.5 7923.5 7923.5 7923.5 7923.5 7931. 5 7958.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 9517.5 9517.5 9517.5 9517.5 9517.5 9510.0 9554.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): 27-APR-02 Insite 66.37 Memory 9554.0 7958.0 9554.0 88.1 90.7 TOOL NUMBER PBOO088HWM4 PBOO088HWM4 6.125 7909.0 Oil Based 8.70 88.0 .0 38500 4.0 ) ) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .000 .000 .0 160.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units...... .....Feet Data Reference Point............. .Undefined Frame Spacing..................... 60 .1IN Max frames per record............ .Undefined Absent value.................. ... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7923.5 9554 8738.75 3262 7923.5 9554 Rap MWD050 FT/H 0.37 141.38 81. 8915 3192 7958.5 9554 GR MWD050 API 41.43 98.69 54.4264 3158 7931.5 9510 RPX MWD050 OHMM 0.77 27.06 22.1415 3189 7923.5 9517.5 RPS MWD050 OHMM 1.18 23.74 20.3488 3189 7923.5 9517.5 RPM MWD050 OHMM 1.2 119.58 20.193 3189 7923.5 9517 . 5 RPD MWD050 OHMM 1. 88 1548.34 22.9136 3189 7923.5 9517.5 FET MWD050 HOUR 0.35 1012.58 24.2146 3189 7923.5 9517.5 First Reading For Entire File......... .7923.5 Last Reading For Entire File......... ..9554 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..02/10/09 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name..... ...... ..STSLIB.005 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .02/10/09 Maximum Physical Record. .65535 File Type.. ............ ..LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 5 header data for each bit run in separate files. 6 .5000 START DEPTH 9510.5 9518.0 9518.0 9518.0 9518.0 9518.0 9554.5 STOP DEPTH 11582.5 11543.5 11543.5 11543.5 11543.5 11543.5 11623.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. . . . . . . . . . . . . . . . . .0 Data Specification Block Type. ....0 Logging Direction................ .Down Optical log depth units......... ..Feet Data Reference Point....... .... ...Undefined 29-APR-02 Insite 66.37 Memory 11624.0 9554.0 11624.0 88.4 91. 2 TOOL NUMBER PBOO088HWM4 PBOO088HWM4 6.125 7909.0 Oil Based 8.70 82.0 .0 39000 4.4 .000 .000 .000 .000 .0 163.0 .0 .0 ) ) Frame Spacing.............. .... ...60 .1IN Max frames per record.... ...... ...Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9510.5 11623.5 10567 4227 9510.5 11623.5 ROP MWD060 FT/H 0.03 232.47 98.6632 4139 9554.5 11623.5 GR MWD060 API 39.4 70.08 54.5448 4145 9510.5 11582.5 RPX MWD060 OHMM 9.82 28.17 17.385 4052 9518 11543.5 RPS MWD060 OHMM 9.48 24.69 16.2306 4052 9518 11543.5 RPM MWD060 OHMM 9.31 23.87 16.0742 4052 9518 11543.5 RPD MWD060 OHMM 9.79 25.12 16.7884 4052 9518 11543.5 FET MWD060 HOUR 0.3 20.37 0.928815 4052 9518 11543.5 First Reading For Entire File......... .9510.5 Last Reading For Entire File......... ..11623.5 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/09 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/09 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/09 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ) **** REEL HEADER **** LDWG 02/07/28 AWS 01 **** TAPE HEADER **** LDWG 02/07/29 01 *** LIS COMMENT RECORD *** ) LDWG File Version 1.000 Extract File: LISTAPE.HED ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! TAPE HEADER ALPINE UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: MWD RUN 1 1 D. BARBA D. MICKEY MSL 0) CD2-50PBl 501032041570 Phillips Alaska, Inc. BAKER HUGHES INTEQ 29-JUL-02 MWD RUN 2 2 IIN 4E 52.00 OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) 42.000 16.000 9.625 12.250 8.500 MWD RUN 3 DRILLERS DEPTH (FT) 114.0 2385.0 2395.0 7927.0 dOd-OY'1 PER PHILLIPS ALASKA INSTRUCTIONS, THE GAMMA RAY CURVE ) ) FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. SURFACE LOCATION: 2063' FNL 1503' FEL LOG MEASURED FROM D.F. AT 52.0 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: 1) BAKER HUGHES INTEQ RUN 1 UTILIZED A TRIPLE COMBO SUITE (ORD, CCN, MPR) FROM 2395 TO 7927' MD (2391 - 7434' TVD). REMARKS: 1) 9.625 INCH CASING DEP - LOGGER: 2385' MD (2381'TVD) 9.625 INCH CASING DEP - DRILLER: 2385' MD (2381'TVD) 2) THE GAMMA RAY HOT SPOTS FROM 2395 TO 7927' MD (2395 7434' TVD) WERE DUE TO THE STAT'IONARY SPERRY SUN NEUTRON SOURCE WHILE MAKING CONNECTIONS AND TAKING SURVEYS. 3) THE INTERVAL FROM 7818 TO 7927' MD (7334 - 7434'TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET AT TD. $ Tape Subfile: 1 63 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE001.HED 1 clipped curves; all bit runs merged. .5000 START DEPTH 2385.0 STOP DEPTH 7818.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 2385.0 MERGE BASE 7818.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. ) ) $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT cd250 5.xtf 150 Phillips Alaska, Inc. CD2-50PBl Alpine North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RAD RAD RACLM 0.0 RPD RPD RPCLM 0.0 RAS RAS RACHM 0.0 RPS RPS RPCHM 0.0 NPHI NPHI NPCKSM 0.0 RHOB RHOB BDCM 0.0 DRHO DRHO DRHM 0.0 PEF PEF DPEM 0.0 CALN CALN CALM 0.0 MTEM MTEM TCDM 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 56 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 18 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RAD MWD 68 1 OHMM 4 4 3 RPD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPS MWD 68 1 OHMM 4 4 6 NPHI MWD 68 1 PU-S 4 4 7 RHOB MWD 68 1 G/C3 4 4 8 DRHO MWD 68 1 G/C3 4 4 9 PEF MWD 68 1 BN/E 4 4 10 CALN MWD 68 1 IN 4 4 ) 11 MTEM MWD 68 1 DEGF 4 4 12 ROP MWD 68 1 FPHR 4 4 13 FET MWD 68 1 HR 4 4 ------- 52 Total Data Records: 616 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 2385.000000 7927.000000 0.500000 **** FILE TRAILER **** Tape Subfile: 2 664 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 Extract File: FILEOll.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 ) log header data for each bit run in separate files. 1 .2500 START DEPTH 2383.0 STOP DEPTH 7818.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD BOTTOM) TOOL TYPE DIRECTIONAL NEUTRON DENSITY ll-MAR-02 n/a 6.75 TC MEMORY 7927.0 2383.0 7818.0 0 .0 .0 TOOL NUMBER CCN 17625 ORD 10022 ) MPR GRAM $ MULT. PROP. RESIST. GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # ) MPR 17846 SRIG 5332 8.500 2385.0 FW Polymer 9.50 .0 .0 400 .0 .000 .000 .000 .000 130.0 .0 .0 .0 SANDSTONE .00 .000 .0 0 BIT RUN 1. GR/MPR/cCN/oRD. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) DRHM - DENSITY CORRECTION (G/CC) BDCM - BULK DENSITY COMPENSATED (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/e) NPCK - NEUTRON POROSITY (SANDSTONE PU) CALM - BOREHOLE CALIPER (IN) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT cd250.xtf 150 Phillips Alaska, Inc. CD2-50PBl Alpine North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 ) ) RACL RACL RACLM 0.0 RPCL RPCL RPCLM 0.0 RACH RACH RACHM 0.0 RPCH RPCH RPCHM 0.0 NPCK NPCK NPCKSM 0.0 BDCM BDCM BDCM 0.0 DPEM DPEM DPEM 0.0 DRHM DRHM DRHM 0.0 CALM CALM CALM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 56 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 18 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RACL MWD 68 1 OHMM 4 4 3 RPCL MWD 68 1 OHMM 4 4 4 RACH MWD 68 1 OHMM 4 4 5 RPCH MWD 68 1 OHMM 4 4 6 NPCK MWD 68 1 PU-S 4 4 7 BDCM MWD 68 1 G/C3 4 4 8 DPEM MWD 68 1 BN/E 4 4 9 DRHM MWD 68 1 G/C3 4 4 10 CALM MWD 68 1 IN 4 4 11 ROPS MWD 68 1 FPHR 4 4 12 RPTH MWD 68 1 MINS 4 4 13 TCDM MWD 68 1 DEGF 4 4 ------- 52 Total Data Records: 1233 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 2383.000000 7927.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 3 1332 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes ) **** TAPE TRAILER **** LDWG 02/07/29 01 **** REEL TRAILER **** LDWG 02/07/28 AWS 01 Tape Subfile: 4 Minimum record length: Maximum record length: ) 2 records... 132 bytes 132 bytes I. Ib ) 15/29/011 G.D.1 J.Z. I C.A.1 PER A01004ACS 15 14/13/041 AG I BD I C.A. I PER K03074ACS 4LL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.2, T 11 N R 4 E' U.M. (WELL Y' K' LAT.(N) LONG.(W) SEINE CFI nwnpnnN D2-1 5.974.781-09 371 6 1.81 151' 2 28.574 577 562 8.7 15.9 CD2 -2 5,974,770.84 371 682.85 151' 02 28.539 15 7 15 1 7 CD2 -3 5 974 761.44 371 684.74 70' 20 1.401 151' 02 28.507 1597 1560 8.7 15.9- 0O2-4 5 974 7 1.48 371 685.60 70' 20 21.303 151' 02 28.4 1606' 1 59 1 CD2 -5 5.974.741.17 71 685.60 151' 02 28.443 1617 155 .7 8 .9 15.9 CD2 -6 5,974,731.13 371 686.73 70' 20 2 .103 151' 02 28.406 1627 1556 8.7 15.9 CD2 -7 51' 02 28.35 CD2 -8 151' 2 28.337 CD2 -9 5,974,701.48 371 690.14 7 ' 20 20. 2 151' 02 28.291 1656 1552 8.7 15.9 D2-10 5,974,691.64 3 691.07 1511 02 259 1666 551 8.7 5.9 CD2 -11 5.974.681.62 371 69 .02 151' 02 28.226 167B' 15 0 8.7 9 CD2 -12 5 ' 0 28.1 CD2 -13 5,974,661.90 371 694.26 ' 02 8151 696 548 8.7 is CD2 -14 5.974.652.12 371 695.50 151' 02 28.110 17 15 8 - 1 CD2 -15 5,974,641.66 371 696.24 151' 02 28.083 17 15 B. 15 9 CD2 -16 5.974.631.95 371 697.39 51' 02 8.044 726 1544 8.7 15.9 CD2 -17 t).9/4.622.10 371 698.48 151' 02 28.008 1736 15 8_7 15.9 CD2 -18 151' 02 27.976 CD2 -19 51' 02 7.939 CD2 -20 5.974.592.18 371 715.9 01.77 70' 20 9.739 151' 02 27.897 1765 1539 8.7 15.9 CD2 -21 5.974.582.28 371 702.51 70' 20 19.642" 151' 02 27.870 1775 1538 8.7 15.9 CD2 -22 5.97 572.39 1 371 704.15 70' 20 19.5 151' 02 27.817 1785 1536 8.7 15.9 CD2 -23 t).9/4.b62.21 371 704.52 70' 20 19.445" 151' 0 27.8 17 1536 1 8.7 15.9 CD2 -24 5.974.552.30 371 705.92 0' 20 9.348 151' 02 27.756 1805 1534 1 8.7 15.9 CD2 -25 5.974.542.33 371 706.81 -371.707.80 70' 20 19 2 0 151' 02 27.725 _T81 �5 1533 8.7 15.9 CD2 -26 5 974 532.34 70' 19.15 151 02 27.6 1825 1532 8.7 15.9 CD2 -27 5,974,522.31 522.31 371 709.10 70' 2 19.053" 151' OT 27.8 1835 1531 8.7 15.9 CD2 -28 5,974,512.60 371 709.87 70' 20P 18.9 151' 02 27.620 1844 1530 8.8 15.9 D2-29 0,914,502,63 26 5' 02 27,575" 55 8 8 15.9 CD2 -30 97 492. 371.7 2.00 51' 02 27,548- 865 1527' 8.8 15.9 CO2 -315 974 482.74 371 713.04 70' 20 18.665 151' 02 27.513 1875 1526 CD2 -32 5 974 472.57 371 714.18 70' 20 8.565 51' 02 27.474- 1885 1525 15.9 CD2 -33 5.974.463.34 371 715.28 70' 20 18.475 _f51' 02 27.438 1894 1523 CD2 -34 5.974.452.65 371 716.13 70' 20 8.370 151' 02 27.407 1905 1522 8. .9 CD2 -35 5.974.442.90 371 717.49 0' 20 18.274 1 02 27. 1915 1521 CD2 -36 5.974.433.20 371 718.42 70' 20 8.179 151' 02 27.331 1924 1520 8.7 15.9 CO2 -37 5.974.423.05 371 719.40 70' 20 18. 9 ' 02 27.2 1934 1519 8.7 .9 CD2 -38 5.974.413.52 371 720.66 70' 20 17.986 151' 02 27.256 1944 1517 9 CD2 -39 5.974.403.28 371 721.83 70' 20 5 151' 02 27.216 1954 1516 8.7 CD2 -40 371 722.68 151' 02 27.18 1964 8.7 15.9 CD2 -41 b.974,383.33 371.723.84 70' 20' 17.689"151' 02 27.148 97 8.7 15.9 CD2 -42 5,974,373.69 371 724.77 ' 20 17 151' 02 27.116 1984 1513 8.7 15.9 CD2 -43 5,974,363.45 371 725.60 70' 17.494" 151' 02 27.087 1994 1512 8.7 15.9 CD2 -44 5,974,353.42 371 726.94 ' 20 17. 151' 02 27.042 2004 1510 8.6 15.9 CD2 -45 5,974,344.11 371 728.07 ' 20 7.30 151' 02 27. 005 2013 1509 8.6 15.9 'C 2_A6 974333.52 371 729.06 151' 02 26.971 02 508 8.6 15.9 CD2 -47 5,974.323.53 371 730.13 7 ' 20 7.102 151' 02 26.934 2034 1506 8.6 15.9 CD2-48 5,974,313.77 371 731.19 70' 20 7.006 151' 02 6.898 2043 1505 B.6 15.9 CD2 -49 5.974.303.80 371 732.05 70' 20 16.9p8" 151' 02 26.868 2053 1504 8.5 15.9 CD2 -50 597429364 371 733.00 70' 20 16.811 15 26.83 2063 1503 8.5 15.9 CD2 -51 5 9 .88 4.28 70' 20 18.713 1 02 26. 2 5 8.5 5 CD2 -52 5,974,274.18 371 .735.18 151' 02 26.762 2083 501 8.5 15.9 CD2 -53 5,974,264.07 371 736.31 1 70' 20 16.518 151 02 26.724" 2093 1499 8.5 15.9 CD2 -54 5.974.254.19 371 737.50 1 70' 20 16.421 151' 02 26.684 2103 1498 8.5 15.9 CD2 -55 5,974,244.05 371 738.44 1 70' 2 16.322 151' 02 26.652 2113 1497 8.5 15.9 CO2 -56 5 974 234.27 371 739.42 70' 26 151' 26.616 2123 1496 8.5 15.9 CD2 -57 5 974 224.26 371 740.55 0' 20 6 151' 02 26.580 2133 1494 8.5 15.9 D2-58 5,974,214.18 371 741.60 1 70' 20 16.029 151' 02 26.544 2143 1493 8.5 15.9 D2-59 51' 02 26 544im CD2 -60 5,974,194.47 371 743.77 70' 20 15.835 151' 02 26.471 2162 1491 8.5 15.9 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 27. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) 3. • INDICATES DATA PER LOUNSBURY AS -BUILT. ALPINE MODULE:CD20 UNIT: CD ConocoPhillips ALPINE PROJECT CD -2 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 01-02-05-1 05-27-01 CE-CD20-121 2 OF 3 5 CZ I DB I C.A. I ISSUED PER K07041ACS 12 14/21/08 I CZ I GD I C.A. I UPDATED PER K080010ACS IALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.2, T 11 N, R 4 E, U.M. WELL Y' X' SEC.LINE 0/S EXIST LAT(N) LONG(W) FSI FFI enin DAn CD2 -461 CD2 -462 D2-463 D2-464 D2-465 D2-466 CD2 -467 CD2 -468 D2-469 CD2 -470 CD2 -471 D2-72 CD2 -73. CD2 -74 D2-75 CD2 -x76 D2 -x77 CD2 -x78 5,973,927.48 5,973,925.28 5 973 923.32 5 973 921.12 5 973 919.18 5 973 916.76 5 973 915.01 5 973 912.62 5 973 910.54 5 973 908.62 5 973 906.37 5 973 904.22 5 973 902.15 5,973,899.86 5,973,897.83 5,793,895.84 5,973,893.62 5 973 891.66 1 511 501.61 1 511 481.66 1,511,461.85 1,511.442.08 1 511 422.01 1 511 402.40 1 511 382.20 1 511 362.41 1 511 342.61 1,511,322.72 1,51 302.77 1 511 282.90 1 511 262.95 1 511 243.06 1 511 223.26 1 511 203.39 1 511 183.28 1 511 163.81 70' 70' 70' 70' 70' 70' 70' 70' 70' 70' 70' 70' 70' 70' 70' 70' 70' 70' 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 14.465 14.440 14.417 14.392 14.370 14.343 14.322 14.295 14.271 14.249 14.224 14.199 14.175 14.150 14.126 14.103 14.078 14.055 151' 151' 151' 151' - 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 45.814 -o246.395 46.973 47.549 48.134 48.706 '0249.295 49.872 50.449 51.029 51.610 52.189 52.771 53.351 53.928 54.507 55.094 55.661 3099 3096 3094 3091 3089 3086 3084 3081 3079 3077 3074 3072 3069 3067 3064 3062 3059 3057 1765 1785 1805 1825 1845 1864 1884 1904 1924 1944 1964 1984 2003 2023 2043 2063 2083 2103 8.3 8.3 8.3 8.3 7:8 7.8 7.9 7.9 8.0 8.0 6.1 8.1 8.2 8.3 8.4 8.4 8.4 8.4 15.7 15.7 15.7 15.7 15.7 15.7 15.7 15.6 15.6 15.6 15.6 15.6 15.6 15.6 15.6 15.6 15.6 15.6 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4. NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) KU �' ALPINE MODULE:CD20 UNIT: QNK ConocoPhilli„''S ALPINE PROJECT Alaska, Inc. QANNIK WELL CONDUCTORS AS -BUILT LOCATIONS CADD FILE N0. DRAWING N0: PART: REV: 07-02-18-1 4/2/07 CE-CD20-139 2 DF 3 2 R V DATE BY CK I APP I DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 4/18/07 CZ DB C.A. I ISSUED PER K07041ACS 2 4/21/08 CZ GD C.A. UPDATED PER K080010ACS CD2 6 �G CD2 ACCESS ROAD S HPN�F LOCATION OF PIN THIS SURVEY ECT m DRILL ITE CD- Ti o Z o ALPINE SATELLITE DEVELOPMENT VICINITY MAP NOT TO SCALE e � -0 6� 9 ASPC Q N PLANT A 06'03'45' a f l � uw CD-2 Yfi — U PADw Y i 59 p I K �p1 � • W i 0 QANNIK�' ,a CONDUCTORS cT>P.I 689588986"se888i;$ DESIGN SHOULDER OANNIK PAD LEGEND: KU U KPI K OPROPOSED CONDUCTOR LCMFue • EXISTING CONDUCTOR °aeewnni wobq., raw c°m.,eonsnimo A11 �e Survey Office ALPINE MODULE:CD20 UNIT:QNK ConocePhilll S I� ALPINE PROJECT QANNIK WELL CONDUCTORS Alaska, Inc. AS—BUILT LOCATIONS CADD FILE NO. 07-02-18-1 4/1/07 DRAWING NO: CE—CD20-139 PART: 1 OF 3 REV: 2