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Home My WebLink About203-043 ') ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ;2 Q '3 - 0 !f- 3 Well History File Identifier Organizing (done) o T we-sided 11I11111I1111111111 ~can Needed ~ , RESCAN ~or Items: o Greyscale Items: DIGITAL DATA ~kettes.No~ o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: BY: ........-;: ""'\ Helen C Maria J o Other:: Date:~ 18'/0$ Isl wtP I - - , Date:6 I g OS /s/ Project Proofing Scanning Preparation ~~ x 30 = 10 + (;, = TOTAL PAGES (Count does not tJCIUd~ cover st eetj 1'\11.p Date:a Ig/OS- /s/ ,r~1 , I mp OL: BY: Helen ('"Maria) BY: Helen (Maria) Production Scanning Stage 1 Page Count from Scanned File: q S (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ,/ YES 'NO I '0 Helen~Maria ) Date: 5 I g os-- 151 111' BY: Stage 1 If NO in stage 1 page(s) discrepancies were found: YES NO Date: /s/ II III "' Date: Isl Quality Checked 1111111111111111111 BY: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: • • :- -1 MICROFILMED 03/01 /2008. DO NOT PLACE 0.~ . ~a~ ~,,- ~. ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc ~~ ConocoPhillips January 17, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 3S-08B Dear Commissioner: Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~~~~~ JAN 2 2 2ooe Alaska Oil & G$s Cpns. Conr~ml~~i®~ pnchora~e ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the ,j recent P&A operations on the Kuparuk well 3S-08B. If you have any questions regarding this matter, please contact me at 265-6830 or Guy Schwartz at 265-6598. Sincerely, ~ ~-~--~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling ~~~ JpN 2 ~ 2008 s:... _._ _.. RT/skad • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED JAN 2 2 ~.Q98 WELL COMPLETION OR RECOMPLETION REPOF~~kAR~~~,~~ ~amrn'ssi°~' 1a. Well Status: Oil ^ Gas Plugged ^ - Abandoned ~ 'Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development ^ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: December 6, 2007 ~ 12. Permit to Drill Number: 203-043 / 307-354 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: March 15, 2003 13. API Number: 50-103-20450-02 4a. Location of Well (Governmental Section): Surface: 2492' FNL, 954' FEL, Sec. 18, T12N, R8E, UM 7. Date TD Reached: March 16, 2003 ~ 14. Well Name and Number: 3S-08B ^ Top of Productive Horizon: 1855' FSL, 764' FWL, Sec. 17, T12N, R8E, UM 8. KB (ft above MSL): 56' RKB Ground (ft MSL): 28' MSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1938' FSL, 529' FWL, Sec. 17, T12N, R8E, UM 9. Plug Back Depth (MD + ND): 4663' MD / 2886' TVD Kuparuk Oil Pool ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 476305 ' y- 5993923 Zone- 4 10. Total Depth (MD + ND): 8815' MD / 6062' TVD 16. Property Designation: ADL 380107 TPI: x- 478024 y- 5992986 Zone- 4 Total Depth: x- 477789 y- 5993069 Zone- 4 11. SSSV Depth (MD + ND): none 17. Land Use Permit: 4624 18. Directional Survey: Yes ^ No ^/ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 1542' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): no new logs 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE N AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTI G RECORD PULLED 30" x 16" 62.5# B Surf. 108' Surf. 108' 42" 75 sx ArcticCRETE 9.625" 40# L-80 Surf. 4263' Surf. 2662' 12.25" 664 sx AS Lite, 391 sx LiteCRETE 7" 26# L-80 Surf. 8802' Surf. 6054' 8.5" 255 sx Class G w/GasBLOK CIBP @ 8417' CTMD and 4663' CTMD 23. Open to production or injection? Yes ^ No ^/ If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET none perforations plugged off 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED bridge plug @ 8417' 21.5 bbls of 15.8 Class G 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged and abandoned Date of Test Hours Tested Production for lest Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Cores} Acquired? Yes No ~ Sidewall Cores Acquired? Yes No Q If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~~ Q~,yt ~- t ~i,sL ~ NONE !Z.-G.p-~ (_. ~~ 3 1t~r~IFi~i~ Forrn 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~'~...j~ifw ~ :~ ~Dll~l ~-~i~~ ~~ /.z~ ~~~ ~.9 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes ^/ No If yes, list intervals and formations tested, Permafrost -Top surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1676' 1542' ~ needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk 8493.5' 5859' Base Kuparuk 8528' 5880' N/A Formation at total depth: Kuparuk C 30. LIST OF ATTACHMENTS Summary of Daily Operations 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6598 Printed Name Ran ma Title: Drilling Team Leader ~~~~~ ~ ~ Signature ~ ~, - hone 2.{~ j~(~ ~ ~ ~ Date INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. • 3S-08 Plug and Abandon Summary DATE Summary 12/1/07 TAG FILL @ 8508' RKB, EST 52' OF RATHOLE. PERFORM 30 MIN SBHP @ 8166' RKB=3148 PSI, 153 DEG. 15 MIN GRADIANT STOP MADE @ 8021' RKB. NOTE: TARGET DEPTH NOT REACHED, SAT DOWN HIGH IN TBG. 12/2/07 BREAK THROUGH OBSTRUCTION IN TBG. @ 8176' SLM (OBTAINED BALL OF ASPHAULTINES /PARAFFIN IN BAILER ). TAG TD @ 8567' SLM. BRUSH AND FLUSH TBG. TAG D-NIPPLE W/ 2.80 CENT. @ 8422' RKB. SET 2.75 CA-2 PLUG @ 8422' RKB. SET AVA CATCHER SUB ONTOP OF CA-2 PLUG @ 8422; RKB. PULLED GLV @ 4007' RKB AND SET DGLV. PULLED OV @ 8283' RKB AND LEFT POCKET OPEN FOR CIRC. OUT. 12/3/07 CIRCULATED 290 BBLS OF DIESEL DOWN TBG., UP IA, AND DOWN FLOWLINE. SET DGLV IN STA # 5 @ 8283' RKB. MIT TBG AND IA TO 2500 PSI. PULLED CATCHER SUB @ 8422' RKB. BAILED SMALL AMOUNT OF FILL OFF CA-2 PLUG @ 8422' RKB. RIGGED DOWN DUE TO POOR WEATHER CONDITIONS. 12/5/07 STANDBY WHILE RIG PREP IS BEING PERFORM. 12/5/07 PULLED CA-2 PLUG @ 8422' RKB. PERFORMED INJECTIVITY TEST: 1 BPM @ 1450 PSI AND 2 BPM @ 1900 PSI. READY FOR CTU. 12/6/07 MU AND RIH WITH A WEATHERFORD 2.80" OD CEMENT RETAINER AND SET RETAINER @ 8417' CTMD AFTER TAGGING AND CORRECTING COIL DEPTH OFF OF CAMCO D-NIPPLE @ 8422' CTMD.PUMP A TOTAL QF 21.5 bbl OF 15.8 CLASS G CEMENT BELOW RETAINER.AFTER SHUTING DOWN PUMP TO UNSTING FROM RETAINER AND LAY IN 1 _BBL OF CEMENT WE WAS UNABLE TO SHEAR OFF FROM RETAINER. AFTER DROPPING DISCONNECT BALL AND PUMPING 5 BBL AWAY THE STINGER SHEAR FROM RETAINER. POOH AND CHANGED BHA TO RECOVER DISCONNECT BALL AND TO WASH TUBING. 12/6/07 PRE-RIG WO, T-POT -PASSED, T-PPPOT -PASSED, IC-POT -PASSED, IC-PPPOT -PASSED, TBG & IC-LDS FUNCTION TEST -PASSED 12/6/07 TAGGED CEMENT RETAINER @ 8412' RKB AND DUMP BAILED ~ 5' CEMENT ON RETAINER. PULLED DV @ 8283' RKB. COMPLETE. 12/7/07 CMIT- T X IA -PASSED 12/7/07 CMIT- T X IA 1500 psi -passed ---__ 12/8/07 Complete rig acceptance checklist and accept rig. Rig up Tiger tank and berm same. Make up hardline to take returns from well. Pull BPV. Circulate out diesel & seawater from well. Set BPV. NU & ND. Test BOP's. BOLDS. Prep & pull on 3 1/2" tbg. Fish out dropped sledge hammer. 12/9/07 Attempt to pull tbg free. No-Go. Pick up 4" DP & rack back in derrick while wait on SWS E-line to jet cut tbg. RU & WLIH to cut tbg. RD SWS. Pull tbg hanger to floor. stand back 1000' of 3 1/2" tbg. Lay down 220 juts of tbg. i ~ 3S-08 Plug and Abandon Summary 12/9/07 RIH WITH 2.50" POWER CUTTER, TOOLS WOULD NOT FALL PAST 2310', POOH & ADD WEIGHT BARS AND ROLLERS. RUN BACK IN HOLE AND JET CUT 3.5" TUBING AT 8310' IN THE FIRST FULL JOINT ABOVE THE SLIDING SLEEVE. DOYON 141 ABLE TO PULL TUBING SUBSEQUENT TO CUT. Make up & run 6-1/8" bit & scraper to 4800' MD. Displace well with 9.0 ppg LSND mud. POOH. Rig up and test 7" lower rams to 250 / 5000 psi. Install WB. RILDS. 12/10/07 Repair pipe skate. Finish lay down tbg. MU 6 1/8" bit & scraper, TIH to 4800'. POOH, lay do tools. R~ up & run CIBP to set @ 4663 DPM. Release from CIBP. Test to 3000 PSI. Displace well with 9.0 PPG LSND. POOH. Lay down tools. Rig up and test 7" lower rams. 12/11/07 Run 5 1/2" Multi-string cutter to locate & cut 7" casing @ 4463' DPM. Attempt to circulate OA. Pressure held at 950 PSI, injecting 5 BBLS. POO .Pull 7" casing packoff at hanger. MU 7" Casing spear &packoff. Attempt to~ull casing free, with upweight to 350K. Casing not free downhole. Land hanger. Install WB. Make up cutter & RIH to IocatQ & cut at 4365'. No circulation obtained. POOH. Pull WB. MU spear assembly with packoff, pull on casing to 350K for 1-1/2 hurs. Casing pulled free. Pull hanger to rig floor. Displace well with 9.0 ppg mud to the OA, taking diesel returns to rockwasher. POOH lay down tools. Pull & lay down 7" csg. 12/12/07 Continue Lay down 7" casing. MU 3 1/2" stinger assembly, RIH & pump 700' f cement_pIu~POOH. Message Maunder, Thomas E (DOA) Page 1 of,2~ • ~ ~~ From: Schwartz, Guy L [Guy.L.SchwartzQa conocophiliips.com] Sent: Wednesday, December 05, 2007 10:36 AM To: Maunder, Thomas E (DOA} Subject: RE: 3S-08B P & A (203-043) Tom, Thanks for the response. We will leave about 5-10 ft of cement on top of the retainer. This will keep it out of packer and PBR allowing the rig to pull out of the tubirg without cutting the tubing. Guy Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.l. schwartz@conocophitlips.com -----Original Message----- From: Maunder, Thomas E (DOA) [mailtoaom.maunder@a{aska.gov] Sent: Wednesday, December 05, 2007 9:42 AM To: Schwartz, Guy L Subject: RE: 3S-08B P & A (203-043} Guy, The regulations are written to have both a mechanical device as well as cement. From our discussion I understand that coil will still be used to cement the present completion interval and that it is planned to leave some cement on top of the retainer, however your goal is to keep the TOC deep enough to allow the rig to pull out of the seal unit rather than cutting the tubing. Your plan will still effectively plug the present completion interval and is acceptable. Call or message with any questions. Tom Maunder, PE AOGCC From: Schwartz, Guy L [maitto:Guy.LSchwartz@conocophtltips.com] Sent: Wednesday, December 05, 2007 8:12 AM To: Maunder, Thomas E (DOA) Subject: 3S-086 P & A Tam, If you are around today t need to talk to you about this well. Was wanting to change slightly the cementing procedure. We have had major delays due to weather and are hind getting well prepped far the rig. Reading the regulations t was curious as to whether we have to leave 5f!' of cement on top of the retainer in a cased hole completion? tf we don't leave cement an tap of the retainer we can forgo the Eline rig up to cut the tubing and just putt out of the PBR seals when the rig gets there. The retainer is going to tae set in the tuning tail just below the 7" production packer. 12/5/2007 • 4'`- ~ ~ ~~ SARAH PAL/N, GOVERNOR O~ ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~15ERQA~'I011T COMl-iISSIOrIT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Guy Schwartz FAx (so7) 27sasa2 Wells Engineer Conoco Phillips Alaska Inc. PO Box 100360 Anchorage, Alaska 99510 ~~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 3S-08B ~~ Sundry Number: 307-354 Dear Mr. Schwartz: 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 day of November, 2007 Encl. Cl n /+PYP~~ C~~~ J1 ~ ~~~ RECEIVED STATE OF ALASKA /~~ C ~ ~ ~/ ALASKA OIL AND GAS CONSERVATION COMMISSION N~V 2 ~. ~Q~7 ~~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.2so Alaska Oi! & Gas Cons. Commission 1. Type of Request: Abandon Q Suspend ^ Operational Shutdown ^ Perforate ^ raQe^ Other ^ Alter casing ^ Repair well ^ Plug Perforations 0 Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 203-043 r 3. Address: Stratigraphic ~ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20450-02 , 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 Requires? Y2S ^ NO Q 3S-086 ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): d ADL 380107, ALK 4624 RKB 23.5' Kuparuk River Fie ld /Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8815' ~ 6062' ~ 8592' none none Casing Length Size MD ND Burst Collapse CONDUCTOR 108' 16" 108' 108' SURFACE 4241' 9-5/8" 4263' 2662' PRODUCTION g~~g~ ~~~ 8802 6053' Pertoration Depth MD (ft): Perforation Depth. TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8491'-8529' 5857'-5881' 3-1/2" L-80 8429' Packers and SSSV Type: Packers and SSSV MD (ft) Baker SAB-3 pkr ~ 8398' Camco'DS' nipple @ 495' 13: Aftachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed. Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 15. Es imated Date for 16. Well Status after proposed work: Commencing Operat December 1, 2007 Oil ^ Gas ^ Plugged Q Abandoned ^~ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true an rrect to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Name GU SCh Title: Wells Engineer Signature Phone 263-4820 Date !`' Cv "C7 Commission Use Onl Conditions of approval: Notif Commission so that a re resentative may witness Sund~ ~ r•+ ~ ~~ ) l y p . Plug Integrity `~,~j BOP Test ~ 7T ' Mechanical Integrity Test ^ Location Clearance ^ H "`r ''-.~ '- Other. .. ~ati.~.J~=~ r ~~-%~ ~t-E~~ F:, ,~~~ ,, ,~, k~r~ e) ~, ?DDi Subsequent Form Required: ~~~ APPROVED BY Approved by: C MISSIONER THE COM IS ION Date: ' ~ Form 10-403 Revised 06/2006 ~~ ~~ ~ U K I ~ 1 l\I A L Submit in Duplicate • • From: Guy Schwartz Date: 11-19-07 To: Tom Maunder (AOGCC) Subject: 3S-08B P & A (pre-sidetrack) The following is a summary of the reasons for abandoning existing wellbore and a brief review of the procedure we will follow to P & A the well. The original 3S-08 well was drilled in the southeastern area of the field and found thin pay (~10 feet) combined with a large amount of siderite cementation. Rather than attempt to complete and stimulate, the well was sidetracked back towards the main field as 3S-08A. This well had resulting sands that were thinner than expected (8 feel net pay actual vs. 20 feet expected), and reservoir quality lower than expected with high siderite percent. The decision was made to fallback another 500 feet to the northwest, targeting higher amplitude and associated improved reservoir quality. The 3S-08B bottomhole location did encounter thicker, higher quality sands (12 feet net pay actual vs. 20 feet net pay expected). The well initially came online at 1200 bopd. After nearly six months of production, a 48,000 pound proppant frac was pumped but did not noticeably improve liquid rates. The current production rate is 220 bopd and 1444 bwpd (87% watercut). The objective of the project is to drill a single horizontal rotary sidetrack lateral from the 3S-08B wellbore to develop C-sand reserves in the southeast side of the 3S drillsite. This horizontal lateral will be placed to the south of the 3S-08B and drilled in a south/southwest direction. The current 3S-08B completion, making 220 bopd, will not be retained. The plan to P & A the well includes setting a cement retainer in the 3 '/2" production tubing and pumping cement to the 7" casing to seal of perforations. The tubing will be cut above the production packer before the sidetrack rig arrives. Rig P & A operations include pulling the tubing and setting a CIBP in the 7" casing at about 4700'. The 7" casing will then be cut and pulled to allow a fullbore sidetrack to be done. Outline of P 8~ A Procedure (pre-rig): 1. Dummy off GLVs @ 4007' and 8283' and ..... MIT IA. 2. Verify drift and tag with Slickline /drift 3.5" tubing and liner for cement retainer. 3. RU Eline: RIH with 3.5" cement retainer. Set at depth of 8417' md. (pup jt below SAB packer) 4. Pressure Test retainer from surface to 2500 psi. 5. RIH with CTU and sting back into retainer ...Squeeze off perforations with Class G cement. ~~ vai,s~~.c~: ~~.. ~\ h~~ ~~~''" l 6. Pull out of retainer and lay in cement to 8367' (50' above retainer). ~~ 7. Wait 24 hrs for cement to set. Tag cement MIT tubing and IA.... have AOGCC ,~'~ witness present. 8. Jet cut tubing at 8300' and ..... • Rig P &A operations: 1. Pull 3 /2" production tubing 2. Set CIBP at 4700' (approx) 3. Cut and pull 7" casing. Message . Page 1 of 1 • Maunder, Thomas E (DOA) From: Schwartz, Guy L [Guy.L.Schwartz@conocophil6ps.com] Sent: Tuesday, November 27, 2007 2;33 PM To: Maunder, Thomas E (DOA) Subject: RE: 3S-08B (203-043} P&A Tom, The following rig operations will be done in addition to the pre-rig P & A operations. 1. Rig will pull existing 3 1/2" tubing 2. A Cast Iron bridge plug will be set in 7" casing at approx. 4700' and-rkb (the 9 5/8" shoe is at 4263' md) 3. The 7" casing will be cut at approx. 4600' and and pulled. 4. Cement plug well be pumped (from the 7" CIBP to just above the 9 5/8" shoe) and the well sidetracked to the new well location. Well to kick off through the cement plug at about 4500' md. Call me if additional information is needed Thanks, Guy Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy. 1. schwartz@conocoph i I li ps. com -----Original Message----- From: Maunder, Thomas E (DOA} [mailto:tom.maunder@alaska.gov] Sent: Tuesday, November 27, 2007 10:59 AM To: Schwartz, Guy L Subject: 3S-08B (203-043) P&A Guy, Following up on our conversation, could you provide some additional details on the upper abandonment for the casing cut. As discussed alt work occurring prior to actually drilling new hole is, by our convention, wi#hin the existing well (3S-08B). Look forward to your reply. Tom Maunder, PE AOGCC 11 /27/2007 • ~"~ ~~ ~~-~a~oPt~i~~~p~ ~-l~~~~, 1n~. _ 35=088_ ~'~~ KRU _ - - -- - _ _ API: 501U31U45UU2 Well T e: PROD TUBING _ SSSV T e: NIPPLE Ori Com letion: 3/20/2003 (0-8429, Annular Fluid: Last W/O: OD:3.500, Reference Lo RKB 23.49' Ref Lo Date: ID:2.992) i ..... r..... o~~ro rn. 00, G wvo Last Tag Date: 15/8/2007 I Casino String -ALL STRINGS SURFACE (0-4263, OD:9.625, wt:ao.oo) 'RODUCTION (0-6602, OD:7.000, Wk26.00) . , 3S-08B il T~: 5 i deg Coil ts4y4 ~ TD:~50 deg Ca) 8815 Descri ion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 108 108 62.50 H-40 WELDED SURFACE 9.625 0 4263 2662 40.00 L-80 BTCM PRODUCTION 7.000 0 8802 6054 26.00 L-80 BTCM I ubing Strang - I Ut11NG c VD i Wt I Gratle i _ Thread I Size i Top i Bottom i T 500 a J129 Jti 7',0 L r0 EUE:'~RD .Perforations Summary Interval TVD Zone Status Ft SPF Date T Comment 8491 - 8492 5857 - 5858 1 6 10/20/2003 RPERF 2.5" HSD, 60 deg phase, Powerflow Char es 8492 - 8506 5858 - 5866 C-4 14 12 10/20/2003 RPERF 2.5" HSD, 60 deg phase, Powertbw Char es 8506 - 8524 5866 - 5881 C_4 23 6 3/28/2003 IPERF 2 F" HSD P.1 Stimulations & Treatments Interval Date Type Comment S-t9I ^^-,,Oo I~ 30i~0U3 FRAr 4 Kx t ; 2n .Gas Lift PJI8fltife{s/N8iv8s St MD T TVD Man Mfr I Man Type V Mfr V Type V OD i Latch I Port TRO I Date Run VN l _~f 1 5 RK (1250 0 11/2R/ 006 5 82831 57291 CAMCO ~ MMG _ I _ ^ _ _ that lu s equi - -~P~_,_ ~ etc.) -.1_E_WEL_RY Gas lift MandrelNaNe 5 (8283.8284, SLEEVE-C (8335.8336, OD:4.500) Anchor Nipple (8397.8398, OD:4.730) PACKER (8398-8403, OD:5.956) NIP (8422-8423, OD:3.960) WLEG (8429-8430, OD:4.510) FRAC (8491-8506) Perf (8491-8506) Perf (8492-8529) BAKER I_ i- _: P . r` • • Date: 11 /27/2007 j To: Well File 3S-08B ~ 1/' From: Jane Williamson RE: KRt13 S-08j¢'B request ConocoPhillips requests approval to plug back 3S-08B to sidetrack to a location south of the current completion. The current completion makes 220 BOPD at 87% WC and has about 100-200 MSTB remaining reserves. In speaking with the Drill Site engineer, he indicated the new wellbore will be to the south to get away from the water injector, and will drain the same area as the old wellbore. I recommend approval of this sundry request. ioooo 5000 1000 a a ~ n O U_ d m O 100 50 Vltrlarg Forecast Paarr~etas Phase :Oil Case Name Case1 b :0.674801 Di 0.202Si3Ae. qi 213.032hd/d 6 :1031/2007 to 11/3D'2011 Fire) Rate 99.3199 td/d Curt Prod. 713.5ffi Mbd Cun Date 10'31/270'7 Relates 215.053 Mbd Rese~,es Date 11/,j0~1011 EUR 928.681 Mbd Forecast Ended BY :Rate DB Forecast Date :Nat Saed Resa~.eType Nate 10 _ _ _. .. ._ --- ~p3 (~ OS 06 07 OB 09 10 11 DATE r w~,v~c~+va~~,va~cwv a~ 102 ~~ ~ - i~ ~ \ /~~ %~ ~~ 10' 0 10 ,o 102 ~~ Oil Rate (CD) (Mhbl/d ) .~••• Total Liqud (Cil+rvgq (Mhbl/d) .y.~ Gas Rate (CD) (MMof/d ) Gas Iry' Rate (CD) (MMcNd ) tOs Voter Irtj RaAe(CD) (Mbbl/d) ~ cyaiProOilVlklls ~~ Gas /Oil Ratio (Mcdbd ) V~kter Cll (% ) Dais on Rod (M ) • 10~ ~ ~_ as ~ zooa DATE • c ~x; ~~~} 276m%3~2 ~~ ntai~ra~d in tnis fax is ra~fidentsai and/or prr~~~laya~9. ~'trrs f~smr ~a~ pale its ~~' me inf~rnra.r®n co revie4vesf i~itrai/y ~y only the individual na~Qd beto~rr. lr t'h° reader of th~~ ra notifaed that ~e ing'ended recipient or a sA~arssantativa of the intended recipient. yon era hereby any review, dissernfna#~on ar copying of thrs fax mr ttra irtfarrnati~r~ eon¢aina'd fierain is prcdtibits~. tf yov have received t'hi~ fax i,~ error. p/ease imaraediately notary tfie ,`nder by tsJepfrrsr~e and return tttas fax to the sender a` the above addr'ss. TF~ank yon. r~, Oate: ~ ~' 1 ~ ~ y teen . ~ ~--t ?home ~~ - gages (;nciurling e ~~~--~~- v GJ~ coyer sheet): Subject: tAessage ,' y0~ .~J ~.~~ r?~y~/g 3iE C'f'Z ~3C~3~ Jr "3'r3 3~^~y P~~O,~rr,s ~,v~:~ ~:, P~x_ olaasa pail for a,sista,~~e a. {90 T) T33-92~3- . WELL LOG TRANS MITT AL To: State of Alaska Alaska Oil and Gas Conservation Comrn. Attn. : Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 . November 14,2006 RE: MWD Formation Evaluation Logs: 3S-03, 3S-06, 3S-06A, 3S-08_3S-08A_3S-08B, 3S-14, 3S-15. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3S-03: dö3 -ODt I -d: ¡4f;/~d- Digital Log Images: 50-103-20458-00 SCANNED rEB 0 1 2007 3S-06: l>:rC- 803 -öS-"?- ~ L./L/Ci3 Digital Log Images: 50-103-20454-00 3S-06A: u:r:~ QO"3-D'tS''ð -tt l¿.jLI'd-1 Digital Log Images: 50-103-20454-01 3S-08 3S-08A 3S-08B: dD3 -Odd. I dó3 -0:5+ I 90'3 -043 Digital Log Im~ges: fÍ I '-/4.fé)6 ¡LILt Q(P ¡ I..{'-/ d-:¡' 50-103-20450-00,01,02 3S-14: U:r.~ dÓ~-d!O 'it IL.¡LI~O Digital Log Images: 50-103-20439-00 3S-15: db d - é;)5L.( -ti I'-/L/ ~t..¡ Digital Log Images: 50-103-20444-00 t 1 CD Rom 1 CD Rom 1 CD Rom 1 CD Rom 1 CD Rom 1 CD Rom Scblumbel'ger 12/19/06 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~ -¡'Jf'fl{> '" " .(Ut \] {L NO. 4077 Company: ,» Field: Date BL CD -~-"'''''''''' Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 003 -()<!3 Kuparuk Well Job# Color Log Description 1 R-03A (REDO) 11483497 INJECTION PROFILE 11/30/06 1 1 B-09 11483500 INJECTION PROFILE 12/03/06 1 3S-26 11538769 INJECTION PROFILE 12/10/06 1 1 F-04 11538770 INJECTION PROFILE 12/11/06 1 3S-08B 11538771 PRODUCTION PROFILE 12/12/06 1 3H-10B 11534187 PRODUCTION PROFILE 12/08/06 1 1J-136 11534188 US IT 12/10/06 1 2M-12 11534189 PRODUCTION PROFILE 12/11/06 1 1F-10 11534192 INJECTION PROFILE 12/12/06 1 1 Y -27 N/A PRODUCTION PROFILE 12/14/06 1 2Z-20 N/A SBHP SURVEY 12/15106 1 1 H-21 11551832 SBHP SURVEY 12/16/06 1 1 F-05 N/A INJECTION PROFILE 12/13/06 1 1 F-09 11548550 PRODUCTION PROFILE 12/14/06 1 3S-03 11551831 PRODUCTION PROFILE 12/15/06 1 3J-18 11548550 PRODUCTION PROFILE 12/16/06 1 1 H-14 11551835 SBHP SURVEY 12/18/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . <:onocÓÁ,illips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 7, 2006 ;t ::; Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 , t~ <163- D43 3~- o8ß Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, 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 November 18, 2003 and was previously reported to the Commission as follows. 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 top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 4 -5, 2006. 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 myself at 907-659-7043, if you have any questions. Sincerely, J ~f~ ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field Au ust 7,2006 Well Name Initial top Vol. of cement Final top of Cement top prD # of cement urn ed cement off date ft bbls ft Corrosion inhibitor/ sealant date 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 13, 2004 , ?jL"OÎ RE: MWD Formation Evaluation Logs 3S-08B, AK-MW-23 06056 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3S-08B: Digital Log Images 50-103-20450-02 .9D3~ 0 4ð 1 CD Rom (. l c.··' .. ---, .,/,- ') >~ ~g fJJr1 ~ ~~'\\ ('-- DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2030430 Well Name/No. KUPARUK RIV UNIT 35-088 Operator CONOCOPHILLlPS ALASKA INC )r1~J. ) f'I1t'V\ ;. ð c > API t4o. 50-103-20450-02-00 ---~------ MD 8815 --/- TVD 6062 /' Completion Date 3/28/2003 .,/ Completion Status 1-01L ------ REQUIRED INFORMATION ---- DATA INFORMATION Mud Log No Samples No Types Electric or Other Logs Run: GRlReslDens-Neutron Well Log Information: Log/ Data Digital Type Med/Frmt t:D (D i I I I :ED D ~ I Log L____________ Electr Dataset Number Name Directional Survey &rectional Survey Directional Survey ¿.Dit'éctional Survey Log Log Scale Media Run No 1 11711 c~~ ì~ 1.(,_ C"v~ S£ {J,. 1\0/ 11!3 Voriflr.fiti?/1- ~ ('.... i C· LIS Verification Well Cores/Samples Information: Production 12 Blu Name Interval Start Stop Sent Received Current Status 1-01L UIC N Oirectional surverr::) (data taken from Logs Portion of Master Well Data Maint) Interval OH/ Start Stop CH Received Comments 6465 8815 Open 4/22/2003 6465 8815 Open 4/22/2003 MWD 6465 8815 Open 4/22/2003 MWD 6465 8815 Open 4/22/2003 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 3/19/2003, 4246 8784 Open 5/13/2003 4246 8784 Open 5/13/2003 4000 8515 Case 6/27/2003 CULLED Sample Set Number Comments ~ -- ,--'" Oaily History Received? QI N ~~N Formation Tops LY' ADDITIONAL INFORMATION Well Cored? ~ Chips Received? ~ Analysis ~ Received? ------- Comments: DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2030430 Well Name/No. KUPARUK RIV UNIT 3S-088 Operator CONOCOPHILLlPS ALASKA INC MD 8815 TVD 6062 Current Status 1-01L Completion Date 3/28/2003 Completion Status 1-01L ----- ------ ~------ - ----- ----- Compliance Reviewed By: ~ Date: API No. 50-103-20450-02-00 UIC N ;{ J t, ~ t- ~ ~?r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 290* 290 0 31710 37 5/19/2003 6/26/2003 38-24, 38-03, 38-19 0 0 0 0 0 0 0 0 0 -~~' 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAGD GINJ D WINJ D WDSPL D Sa. Sundry number: Sb. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation D or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 303-122 (h)(3) Other Commission approved substances (include descriptions in block 12) 4/28/2003 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 2003 / 2nd 31610 100 2003 / 3rd o o 2003 / 4th o o 2004/1st o o Total Ending Volume (bbls): 31610 100 290 32000 Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Pressure vs. Time D Step Rate Test D 11. Attach: * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~~ Signature: Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 203-043 38-088 50-103-20450-02 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ---- 37 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 7I'ß/0'7 Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 290* 290 0 31710 37 5/19/2003 6/26/2003 38-24, 38-03, 38-19 0 0 0 0 0 0 0 0 0 ~ 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GINJ D WINJ D WDSPL D Sa. Sundry number: Sb. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 303-122 (h)(3) Other Commission approved substances (include descriptions in block 12) 4/28/2003 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 2003 1 2nd 31610 100 2003 1 3rd o o 2003 14th o o 20041 1st o o Total Ending Volume (bbls): 290 32000 31610 100 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Pressure vs. Time D Step Rate Test D * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. \<...~. \ Lw.-...- \"'<.. &.... ... J) ~~,....... ~ ) Signature: Date: ~ r- l.) \.¿- ~,,__ L~hÁ Printed Name: Title: Form 10-423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 203-043 38-088 50-103-20450-02 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: --- 37 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 'r ((6/óY Phone Number: 'Us- 6-8 .3 D Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. <, ~ \~ ~~ '\...( ì ~JÞ_"''' 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation of Disposal 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 / 2nd 31610 100 2003 / 3rd 2003 / 4th 2004/1st Total Ending Volume (bbls): 31610 100 11. Attach: Disposal Performance Data: Other (Explain) 0 12. Remarks and Approved Substances Description(s): Pressure vs. Time 0 Signature: Printed Name: Form 10-423 Rev. 9/2003 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAGD GINJ 0 WINJ 0 WDSPL 0 5a. Sundry number: 5b. Sundry approval date: 303-122 (h)(3) Other Commission approved substances (include descriptions in block 12) 4/28/2003 Volume (bbls): Number of days disposal occurred 290* 290 o 31710 37 290 37 32000 Step Rate Test 0 Date: Title: ~.~ \e.-._ G:.-Ld INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 203~043 38-088 50-103-20450-02 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~/ 5/19/2003 6/26/2003 38-24, 38-03, 38-19 -.--' Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. { (è.-i,; (0'7'" Phone Number: Z6r 6"830 Submit in Duplicate 03-oc.-0 ~ 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 IC-190, IC-174, IC-178, IC-19 2003 2003 Puviaq #1 5063 100 0 5163 0 4731 9894 March April Puviaq I f 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-I7, 3S-06, 3S-16 2003 Hansen 1 47382 100 0 47482 0 67796 115278 January June 2003 Hansen, Hansen IA 2002 lC-19 31325 100 0 31425 0 0 31425 May 2003 June 2003 IC-184, IC-170, lC-172 3S-0SB 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-I9 Total Volumes into Annulifor 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-I9, CD2-41, CD2- 23 CD2-50 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 I D-l 03 lC-IS 32251 100 0 373 32724 Open, Freeze Protected June 2002 July 2002 1 C-l 04 ~ ',I ) ConocóP'hillips Mike Mooney ")' Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 December 10, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3S-088 (APD # 203-043) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation and perforating operations on the Kuparuk well 38-088. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, IItJf/I~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED DEC 1 6 2003 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL 1. Operations Performed: ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION Abandon REPORT OF SUNDRY WELL OPERATIONS D Suspend D Operation Shutdown D D Repair Well D Plug Perforations D D Pull Tubing D Perforate New Pool D Other 0 Perforate 0 Stimulate 0 Variance D Annular Disp. 0 D D Time Extension Alter Casing Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 23.5' Re-enter Suspended Well 5. Permit to Drill Number: 203-043 6. API Number: 50-1 03-20450-02 4. Current Well Status: Development 0 Stratigraphic D Exploratory Service D D 9. Well Name and Number: 3S-08B 8. Property Designation: ADL 380107 / ALK 4624 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field I Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION Perforation depth: measured 8815' feet true vertical 6062' feet measured 8515' feet true vertical 5872' feet Length Size MD 84' 16" 108' 4239' 9-5/8" 4263' 8778' 7" 8802' Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2662' 6053' Measured depth: 8491' - 8529' RECEIVED DEC I 6 2003 Alaska Oil & Gas Cons. Commission Anchorage true vertical depth: 5857' - 5881' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8429' MD. Packers & SSSV (type & measured depth) Baker SAB-3 parker pkr @ 8398' SSSV= NIP SSSV= 495' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 8491' - 8506' MD 48M# in formation, 10 ppa on perfs Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinq Pressure Tubinq Pressure Prior to well operation 819 1615 497 256 Subsequent to operation 797 1099 534 244 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ D WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Signature JU- )If, Form 10-404 R_L Title Phone Wells Group Team Leader Date I '-'¿ 1& it) "3 Prepared bv Sha on A'fs~p-Drake 263-4612 EgØ. ',~ ~OR'G1f\'At_, SUBMIT IN DUPLICATE TUBING (2~29. 00:3.500. 10:2.992) Anchor Nipple (8397-8398. 00:4.730) NIP (8422-8423, 00:3.960) FRAC (8491-8506) Perf (8491-8506) Perf (8492-8529) ) C()nQcOPhnUp$Ala,skª~.lnc. ] ::" ... J: i.II..'..:"· I 11'. " ~ ] ;1'1, ::.,~ .. . o·t : .' iìI :~ 0 I. II;' .' i ':" . !:; A, t .... i! ) KRU 35-088 Well Type: PROD Angle @ TS: 51 deg @ 8494 Orig Completion: 3/20/2003 Angle ~ TD: 50 deg ~ 8815 Last W/O: Rev Reason: GLV Port correction Ref Log Date: Last Update: 12/7/2003 TD: 8815 ftKB Max Hole Angle: 66 deg @ 2450 Size Top Bottom TVD Wt Grade Thread 7.000 27 8802 6054 26.00 L-80 BTCM 9.625 29 4263 2662 40.00 L-80 BTCM 16.000 29 108 108 62.50 H-40 WELDED Thread EUE8RD API: 501032045002 SSSV Type: NIPPLE Annular Fluid: Reference Log: RKB 23.49' Last Tag: 8515 Last Tag Date: 11/20/2003 Cäsing <Strir1g- ALL STRI NGS Description PRODUCTION SURFACE CONDUCTOR Tubing String,;, Size 3.500 Interval 8491 - 8492 TVD 5857 - 5858 8492 - 8506 5858 - 5866 Zone Status Ft SPF Date Type Comment 1 6 10/20/2003 RPERF 2.5" HSD, 60 deg phase, Powerflow Charges 14 12 10/20/2003 RPERF 2.5" HSD, 60 deg phase. Powerflow Charges 23 6 3/28/2003 IPERF 2.5" HSD PJ C-4 C-4 8506 - 8529 5866 - 5881 Stirnulations & Treatments Interval I Date I Type 8491 - 8506 10/30/2003 FRAC Gas Lift Mandrels/ValvEis St MD TVD Man Man Type Mfr 4007 2557 CAMCO 5687 3782 CAMCO 6572 4615 CAMCO 7487 5254 CAMCO 8283 5729 CAMCO 1 2 3 4 5 Depth 28 495 8335 8382 8397 PBR/SEAL Anchor Nipple PACKER BAKER PACKER SAB-3 EXTENSION BAKER MILLOUT EXTENSION NIP CAMCO 'D' NIPPLE W/2.75" NO GO PROFILE WLEG BAKER PUMPOUT SUB TTL TVD Type 28 HANGER 493 NIP 5760 SLEEVE-O 5789 5799 I 48K# 16/20 Comment V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BK-5 0.000 0 1 0/28/2003 DMY 1.0 BK-5 0.000 0 10/28/2003 DMY 1.0 BK-5 0.000 0 10/28/2003 DMY 1.0 BK-5 0.000 0 1 0/28/2003 OV 1.5 RK 0.313 0 11/20/2003 KBUG KBUG KBUG KBUG MMG Description FMC 3.5 GEN 5 TBG HANGER CAMCO 'DS' NIPPLE W/2.875" NO GO PROFILE BAKER CMU SLIDING SLEEVE W/CAMCO 2.813 NO GO PROFILE- OPEN BAKER PBR/80-40 SEAL ASSEMBLY KBH-22 ANCHOR TUBING SEAL NIPPLE ID 3.500 2.875 2.813 2.980 3.000 3.250 3.720 2.750 2.990 2.992 8398 5799 8403 5802 8422 5814 8429 5819 8430 5819 General" Notes Date Note 3/18/2003 TREE: FMC / GEN 5 / 5M TREE CAP CONNECTION: TO 5.75" ACME W/3.5" EUE8RD Date 10/18/03 10/20/03 10/26/03 10/27/03 10/28/03 10/29/03 10/30/03 10/31/03 11/01/03 11/05/03 ) 3S-08B Event History ) Comment DRIFT & TAG FILL, TAGGED FILL @ 8447' WLM (8519' RKB) ESTIMATED 101 OF FILL OVER BOTTOM PERFS. TAGGED BOTTOM @ 8511', DEEPEST POSSIBLE PERFORATION 8506' WTH THIS TOOLSTRING. PERFORATED: 8491' - 8506',6 SPF POWERFLOW, 60 DEG PHASING. [TAG, PERF] TAGGED FILL @ 8512' RKB, PRE-FRAC IN PROGRESS [TAG] PULLED 1" GLV'S @ 40071,5687',6572', 7487'RKB, SET 1" DV'S @ 4007',5687', 6572'RKB, PRE-FRAC IN PROGRESS [PT TBG-CSG] SET 1" DV @ 7487'RKB, SET 2.81" CA-2 PLUG IN CMU SLIDING SLEEVE @ 8335'RKB, PRE-FRAC IN PROGRESS [PT TBG-CSG] LOADED IA WI SW & DIESEL CAP. PT TBG & IA TO 3500#. GOOD TESTS. PULLED PLUG @ 83351 RKB. [PT TBG-CSG] PUMPED INITIAL C SAND FRAC. PLACED 48M# IN FORMATION, 10 PPA ON PERFS. SAW TSO AT 12 MINUTES INTO JOB. HAD NWBSO WHEN 10 PPA HIT PERFS. [FRAC-REFRAC] CLEANED TO HARD TAG AT 8589' CTM WI SW J313 AND 1-1/2# BIOZAN USING A 2" JETSWIRL NOZZLE (EST. 70' OF RATHOLE). WASH PASSES MADE ACROSS MANDRELS. WELL LEFT SHUT IN AND FREEZE PROTECTED TO 2500' WI DIESEL. TAGGED FRAC SAND IN TBG @ 8040' WLM. WORKED TO 8070' RKB. [TAG] CLEANED OUT FILL TO 8590' CTM WI SLICK SEAWATER (EST. 70' OF RATHOLE) & 1-1/2# BIOZAN USING A 2" JET-SWIRL NOZZLE. WELL FREEZE PROTECTED WI DIESEL TO 2500'. [FCO] Page 1 of 1 11/17/2003 Schlumberger NO. 2879 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 06/24/03 ---- Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Log Description Field: Date BL Color 05/07/03 1 OS/25/03 1 OS/24/03 1 05/10/03 1 05/14/03 1 05/09/03 1 05/08/03 1 05119/03 1 04/04/03 1 05/07/03 1 OS/23/03 1 Job # 3S-17A ~O-g--()(y~'SBHP SURVEY 35-06 .~(1~ -C&S 1- PERF RECORD W/SBHP & JEWELRY LOG 35-08B "!:Jo.~-nL.1-3 PROD PROFILE WITEMP SURVEY 35-23 ~Q? -ûtJ.t:) PRODUCTION PROFILE 1 H-17 I q d. .. I?XJ PRODUCTION PROFILE 2U-08 I~S-C~ \ SBHP SURVEY 1R-14 ì~l- IF? \ LDL 3F-01 ¡<;'S-Ð.d_Þ) PRODUCTION PROFILE 1D-103 :5)CC) 'm(O MEM PSP INJECTION PROFILE 3S-17A:iO~fi7:Ù 23351 5CMT 3S-06 ,~G -rr; T, 23353 SCMT SIGNE~C\ ~ ^(,-~,_~t.. ~~~ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk CD - >---- }~~~_E:(~E 1\/ED ~.j ;--' ["! ;"~~:::Jr:r~~ ::~~:~.~ ~.#_ .._·~-s ;.~"-."::.'~-~, . ~ .- , ~«i1;1~~~!~ ) \ ~ / a03~-ÒyJ3 //7/1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West ill Avenue, Suite 100 Anchorage, Alaska May 07, 2003 RE: MWD Fotmation Evaluation Logs 3S-08B, AK-MW-23 06056 1 LDWG fotmatted Disc with verification listing. ~I#: 50-103-20450-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO mE ATTENTION OF: Sperry-Sun Drilling Service Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: si4{J1~ RECEIVED MAY 13 2003 AJa~!t Q~i & ·G~' ''1 · ia ;:($ (..{~1 r;¡ ¡'~r'.r')"'" . A. .",. V.....:.'.Iµ.1~"l ";7~1u:mro~; .. ..- \':'. 'W ') ) STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged 0 Abandoned 0 Suspended 0 WAG 0 20AAC 25.105 20AAC 25.110 Gas U 1a. Well Status: Oil 0 1b. Well Class: Development 0 Exploratory 0 Service 0 Stratigraphic Test 0 12. Permit to Drill Number: WINJ 0 WDSPL 0 GINJ 0 2. Operator Name: íN<¡);'gf'P0iAlP!~~!0~S - .' .. .,1 .. 'I ~: ..~ ~~},':'<l ~:.; .' .'-' '~ 3..:..Z_a.:~?.:2 f Other 5. Date Comp., Susp., 213 Jp or Aband.: MarchX 2Ó03 6. Date Spudded: March 15, 2003 7. Date TD Reached: 203-043 13. API Number: 50-103-20450-02 14. Well Name and Number: ConocoPhillips Alaska, Inc. 3. Address: 1,¡'Ei'!'I"¡Œ ~ P. O. Box 100360, Anchorage, AK 99510-0360 .,::~~.~-;.r 4a. Location of Well (Governmental Section): Surface: 2492' FNL, 954' FEL, Sec. 18, T12N, R8E, UM At Top Productive Horizon: 3S-08B 15. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool March 16, 2003 8. KB Elevation (ft): RKB 23.5' 9. Plug Back Depth (MD + TVD): 8631' MD I 5944" TVD 10. T~al Depth (MD + TVD): Ø6z./ 16. Property Designation: BßJ~D/~VD .,ib ADL380107 11. Depth where SSSV set: ", 17. Land Use Permit: Land Nipple @ 495' feet MD ALK 4624 1855' FSL, 764' FWL, Sec. 17, T12N, R8E, UM Total Depth: 1938' FSL, 529' FWL, Sec. 17, T12N, R8E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 476305 y- TPI: x- 478024 y- Total Depth: x- 477789 y- 18. Directional Survey: Yes 0 NoD Zone-4 Zone-4 Zone- 4 5993924 5992986 5993069 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: '-r/w~~ - 1676' MD (p ,/910 ,. In j) qçs;-/ (' 7YD 21. Logs Run: G R/Res/Dens-Neutron 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 4263' Surface 8802' CEMENTING RECORD AMOUNT PULLED HOLE SIZE CASING SIZE WT. PER FT. 62.5# 40# 26# GRADE B L-80 L-80 75 sx ArcticCrete 42" 30"x16" 664 sx AS Lite, 391 sx LiteCrete 255 sx Class G w/GasBlok 12.25" 9.625" 8.5" 7" TUBING RECORD DEPTH SET (MD) 8430' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 24. SIZE PACKER SET (MD) 8398' 3.5" 8492' -8529' MD 5858' - 5881' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 29,2003 Gas Lift Oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF 4/11/2003 18 hou rs Test Period --> 1253 446 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF press. 254 psi 900 psi 24-Hour Rate -> 1338 1446 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). CHOKE SIZE 100% OIL GRAVITY - API (corr) GAS-OIL RATIO 356 W A TER-BBL 1 W A TER-BBL 1 not available Submit core chips; if none, state "none". RECEIVED APR 2 3 2003 Alaska Oil & Gas Cons. Commission Anchorage /J?~~~~"'<iJ'~'-:~ ~ ."...~..,..::¡":.~~'~: j~:.=~~~; ~;.~ .iJ!:"~: " ',' ",... (0. ',", .... ~ ", .. ..". ,.~ NONE ~~ C,~;TINUED ô'f{ttitN A L APR 3 0 ¡J}3 Submit in duplicate Form 10-407 Revised 2/2003 RBDMS BFl 28. ) 29. ) GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top Kuparuk Base Kuparuk 8493.5' 8528' 5859' 5880' Annulus left open - freeze protected with diesel. RECE\\lED ~PR 2 3 lGG3 , Comm\SS\on '\ & Gas Cons, Ma$~a 0\ ~nchotage 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Lowry 265-6869 Printed Na~ Ihoma8r Title: Signature \ -c - I \ ~one Kuparuk Drilling Team Leader Date 1.-/('¿l!Oj Prepared by Sharon AI/sup-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 a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 ORIGINAL ) ) Rig down & blow down ball mill & mud pits PJSM, Move Injection skid & Ball Mill away from Sub Module Move Sub Module off of 3S-22 and in front of 3S-08 Spot wellhead equip. & Herculite on 3S-08, Spot rig on 3S-08 Center rig over hole. Set matting boards and spot mud pits. Lay herculite and spot ball mill, injection skid and auxiliary equipment. Connected service lines and take on water in pits. Accepted Rig @ 0500 hours. Install valves on 4" Conductor outlets, NU riser, install burms around cellar, Ball mill and Injection skid. Take on spud mud. Install 16" divertor line and tunbuckles on stack. Address housekeeping issues in cellar, move BHA #1 xo's and stabs to rig floor. PJSM with Halliburton slickline operator. RU HES slickline for Qyro surveys. PU and stand back 3 flex collars - MU bha #1 moter set @ 1.5 degrees. Perform Divertor and Accumulator test - Chuck Scheve (AOGCC) waived witnessing tests. Fill conductor and check for leaks - pressure test mud lines to 3000 psi. Spud well @ 1730 hours, drill from 109' to 176'. Lost scribe mark - set back flex collars - scribe tools - RIH with flex colars. Gyro survey @ 87', MU Top drive and pump up MWD survey. Drill from 176' to 539', survey with MWD. (oa) AST=2.3 ART=1.6 450 gpm / 900 psi PUW / SOW / ROT WT = 50K. Torque on / off = 3K / 2K 12.00 DRILL DRLG SURFAC Drill 121/4" hole from 539' to 1474' (1395' tvd). ART=1.55 AST=6.65 460 gpm / 1000 psi 25-35K WOB PUW 90K SOW 75K ROT 80K Torque on/off 6K / 3K @ 80 RPM 9.00 DRILL DRLG SURFAC Drill from 1474' to 2044' (1742' tvd). ART =1.56 AST =4.6 460 gpm I 1050 psi PUW 90K SOW 70K ROT 85K (after sweep) Torque on/off 6-7k / 4K While backreaming prior to connection @ 1948' torque increased to 8-10k, PUW 95k SOW 65K. Slid from 1948' to 1917' while mixing 40 bbls .2 ppb Baralift sweep. Pumped sweep while rotating last 30' of stand - 85 rpm - increased rate from 460 gpm to 500 gpm. 0.50 DRILL CIRC SURFAC Pumped sweep around and circ to clean up hole. Observed increase in cuttings with pipe rotation, additional moderate increase with sweep back. Circulate untill cuttings began to reduce across shakers. 2.50 DRILL DRLG SURFAC Drill from 2044' to 2330' (1865 tvd). ART =.92 AST =.92 PUW 90K SOW 68k ROT 85K 504 gpm / 1300 psi Torque on/off 6-7k / 4K 12.00 DRILL DRLG SURFAC Drill from 2330' to 3185' (2216' tvd) ART=5.96 AST=1.09 550 gpm / 1950 psi PUW 100K SOW 75K ROT 80K Torque on/off 7K / 5K Had difficulty sliding from 2420' to 2475' do to sticky clays, average Legal Well Name: 3S-08 Common Well Name: 3S-08 Event Name: ROT - DRILLING Contractor Name: N1268@ppco.com Rig Name: Nabors 7ES Date ·From- To Hours Code Sub .. Phase Code 2/24/2003 18:00 - 20:00 2.00 MOVE MOVE MOVE 20:00 - 21 :30 1.50 MOVE MOVE MOVE 21 :30 - 23:00 1.50 MOVE MOVE MOVE 23:00 - 00:00 1.00 MOVE MOVE MOVE 2/25/2003 00:00 - 01 :00 1.00 MOVE POSN MOVE 01 :00 - 02:00 1.00 MOVE MOVE MOVE 02:00 - 05:00 3.00 MOVE MOVE MOVE 05:00 - 09:00 4.00 MOVE RURD RIGUP 09:00 - 11 :00 2.00 MOVE RURD RIGUP 11 :00 - 13:30 2.50 MOVE RURD RIGUP 13:30 - 13:45 0.25 MOVE SFTY RIGUP 13:45 - 14:00 0.25 MOVE RURD RIGUP 14:00 - 16:30 2.50 MOVE RURD RIGUP 16:30 - 17:00 0.50 MOVE RURD RIGUP 17:00 - 17:30 0.50 MOVE RURD RIG UP 17:30 - 18:45 1.25 DRILL DRLG SURFAC 18:45 - 19:00 0.25 DRILL DRLG SURFAC 19:00 - 19:45 0.75 DRILL SURV SURFAC 19:45 - 00:00 4.25 DRILL DRLG SURFAC 2/26/2003 00:00 - 12:00 12:00 - 21 :00 21 :00 - 21 :30 21 :30 - 00:00 2/27/2003 00:00 - 12:00 Start: 2/24/2003 Rig Release: Rig Number: Spud Date: 2/25/2003 End: Group: Description. of Operations Printed: 4/3/2003 9:40:39 AM ) ) ConocoPhillipsAlaska .Qpera~ionsSum maryRepört 12.00 DRILL DRLG SURFAC Rap 40 fph.Treated mud with BDF 263 and Con Det. Pumped 40 bbls 11.2 ppg sweep with 0.25 ppb Baralift @ 2542', observed moderate increase in cuttings with sweep back. 12.00 DRILL DRLG SURFAC Drill from 3185' to 4070' (2582' tvd). ART=8.0 AST=0.75 550 gpm I 2150 psi PUW 105K SOW 73K ROT 85K Torque onloff 9-1 OK 16-7K Pumped 40 bbls 0.25 ppb Baralift sweep @ 3470', observed strong increase in cuttings with sweep back. Pumped 40 bbls 0.25 ppb Baralift sweep @ 3560', observed moderate increase in cuttings with sweep back. 2.50 DRILL DRLG SURFAC Drill from 4070' to 4276' casing point (2667'''tvd). ART =1.67 AST =0 550 gpm 12150 psi PUW 120K SOW 80K ROT 85K Torque onloff 9K 17K @ 90 RPM 3.00 DRILL CIRC SURFAC Pumped 40 bbls sweep with 0.25 ppb Baralift, circ and cond mud 550 gpm 12100 psi, moderate increase in cuttings with sweep back. Pumped 35 bbls 12.8 ppg wt (3.3 ppg over mud wt) sweep with 0.25 ppb Baralift increased rate to 600 gpm I 2250 psi observed large increase in cuttings back with sweep. Both sweeps back @ gauge hole volumes. Circ untill shakers clean. Monitor well - static. POH from 4276' to 2044' mostly 5-15K over, tight spots @ 4100' and 4050' 35k, wiped clean. Began swabbing well on last stand pulled 2140' to 2044'. Actual time 0900 hrs. Had several interuptions pulling pipe due to trip tank unable to keep hole full. Trip tank continued to operate after keeping it completely full by refilling after each five stands pulled. Backream slowly from 2140' to 2044' 500 gpm 11500 psi 190 rpm moderate cuttings across shakers through 1.5 x BU. POH 1 0/20 K over from 1860' to 1700' , 0-5k over to 86'. Flow check well at HWDP, static. Lay down remainder of BHA, clear tools from rig floor. RU 9 5/8" slips, elevator,fiII up tool, long bails and GBR tongs. Held safety and opts meeting with crew. Mu 9 5/8" shoe track and circ to check floats, all joints 40#, L-80 BTC casing. PUW 100K SOW 70K. RIH, set down 20K @ 1790' (46 jts ran) Wash down from 1775' to 2006' - 308 gpm 1387 psi slight effort except for 1964' to 1966' - 30 min to wash 2'. PUW 105K SOW 70K. RIH to 4002' @ midnight (104) jts total - no problems. Run casing to 4235', MU landing joint and land casing in wellhead. Lay down fill up tool and MU cement head. Establish circ @ 3 bpm 1360 psi, staged pumps up to 8 bpm 1660 psi, Circ and cond mud for cementing - reduced wt. f/9.7ppg tJ 9.5 ppg, vis f/248 to 49, PV f/28 tJ 22, yp f/52 tJ 16. Final circ rate 8.0 bpm 1500 psi last 100 bbls pumped with nutplug marker. PJSM with all parties. 2.25 CEMENT PUMP SURFAC Line up to cementers - pumped 5 bbls of CW 100 - tested lines to 3000 psi. Pumped 45 bbls of CW 100 - dropped botton plug. Pumped 46 bbls of 10.5 ppg Mudpush XL with 2 gals of dye marker - 506 bbls of 10.8 ppg ASLite lead slurry and 156 bbls of 12.0 ppd Lite Crete tail slurry. 1.00 CEMENT DISP SURFAC Dropped top plug - dislpaced with 20 bbls of FW from cementers - switched to rig pups and displaced with 9.5 ppg mud - 279 bbls @ 8.0 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-08 3S-08 ROT - DRILLING N1268@ppco.com Nabors 7E8 Date From~ To Hours Sub . Code· Code Phase 2/27/2003 00:00 - 12:00 12:00 - 00:00 2/28/2003 00:00 - 02:30 02:30 - 05:30 05:30 - 05:45 0.25 DRILL OBSV SURFAC 05:45 - 08:00 2.25 DRILL TRIP SURFAC 08:00 - 09:00 1.00 RIGMNT OTHR SURFAC 09:00 - 09:45 0.75 DRILL REAM SURFAC 09:45 - 13:00 3.25 DRILL TRIP SURFAC 13:00 - 14:00 1.00 DRILL PULD SURFAC 14:00 - 15:30 1.50 CASE RURD SURFAC 15:30 - 15:45 0.25 CASE SFTY SURFAC 15:45 - 19:00 3.25 CASE RUNC SURFAC 19:00 - 20:30 1.50 CASE OTHR SURFAC 20:30 - 00:00 3.50 CASE RUNC SURFAC 3/1/2003 00:00 - 00:45 0.75 CASE RUNC SURFAC 00:45 - 01 :15 0.50 CEMENT PULD SURFAC 01:15 - 04:30 3.25 CEMENTCIRC SURFAC 04:30 - 06:45 06:45 - 07:45 Start: 2/24/2003 Rig Release: Rig Number: Spud Date: 2/25/2003 End: Group: Description of Operations Printed: 4/3/2003 9:40:39 AM ) ) 1.00 CEMENT DISP SURFAC bpm / 230 - 838 psi - 11 bbls @ 6.0 bpm / 675 psi - 8 bbls @ 4.0 bpm / 541 psi. Bumped plugs to 1100 psi - floats held - CI P @ 0730. Had good returns throughout with 160 bbls of 10.8 ppg cement returns to surface. Pipe hung up with 260 bbls of lead cement around shoe, unable to land hanger per plan - 3' high - FS @ 4263', FC @ 4182. Flush Conductor and flowline RD cement head. Held safety meeting in preparation for setting slips on casing. Disconnect dresser sleeve and cut 14 inches off of 20" riser to provide clearance for slip installation. PU surface stack - center pipe and install slips - set slips with 120K string wt. Rough cut 9 5/8" casing - set stack down and LD landing jt - casing hanger and cuttoff joint. ND 20" Diverer system and riser. Assist welder in cellar untill 9 5/8" transition nipple in place on casing. Clear casing equipment from rig floor - change out long bails to drilling bails - install 13 5/8" drip pan extension. Changing pump liners to 5". PU and stand back 45 joints of drill pipe, Actual time midnight. Loss of efficiency due to using mousehole by ironroughneck because of cooling transition nipple in cellar. PU and stand back 48 jts of 5" drill pipe. Installed casing head and tubing spool onto transition nipple while picking up drill pipe. PJSM - NU BOPE. NU BOPE and riser, tested M/M seal on wellhead to 1000 psi - 10 min. Test BOPE: Annular Preventer 250/3500 psi. Pipe and Blind rams, choke and kill line, manifold, TD, and floor safety valves 250/5000. **Tested choke manifold valves while NU BOP stack. John Crisp witnessed BOP and gas alarm tests. Lay down test plug and install wear bushing. Set in mousehole, pick up tools and clean up rig floor. PU and stand back 24 jts of drill pipe - LD 6 jts hwdp. MU BHA #3 - initialize tools. Shallow test tools - PJSM - load sources - RIH with Flex collars and hwdp. RIH -PU 108 joints of drill pipe, set down 10K @ 4134'. MU Top drive and wash down to 4156'. Circ and cond cement cotaminated mud - 450 gpm / 1050 psi / 60 rpm. Set back one stand - RU and test casing to 2500 psi - RD test manifold - blow down lines. Clean out cement, drill wiper plugs and float collar @ 4182', drill out cement to 4184'. Drill out cement from 4184' - shoe @ 4263', clean out rathole and drill 20' of new hole to 4296'. CBU, change well over to 8.9 ppg LSND mud 550 gpm / 1650 psi / 60 rpm RU and perform LOT = 17.9 ppg. RD, blow down lines. Drill from 4296' to 5011' (2977' tvd). ART =4.69 AST =0.23 PUW 145K SOW 60K ROT 90K 550 gpm / 1600 psi MWT =8.9 ECD=10.9 Torque on/off 1 OK / 9K Pumped 40 bbls 11.9 ppg sweep @ 4726', large increase in cuttings back with sweep. 12.00 DRILL DRLG INTRM1 Drill from 5011' to 6153' (3455' tvd) ART =7.29 AST =0.37 PUW 160K Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-08 3S-08 ROT - DRILLING N1268@ppco.com Nabors 7E8 Date From-To Hours Code cfciJe Phase 3/1/2003 06:45 - 07:45 07:45 - 08:45 1.00 CEMENT PULD SURFAC 08:45 - 09:15 0.50 CASE SFTY SURFAC 09:15 - 11 :30 2.25 CASE NUND SURFAC 11 :30 - 15:00 3.50 CASE OTHR SURFAC 15:00 - 16:30 1.50 CASE NUND SURFAC 16:30 - 17:30 1.00 CASE OTHR SURFAC 17:30 - 20:30 3.00 DRILL PULD SURFAC 20:30 - 22:30 2.00 DRILL PULD SURFAC 22:30 - 00:00 1.50 DRILL PULD SURFAC 3/2/2003 00:00 - 02:00 2.00 DRILL PULD SURFAC 02:00 - 02:15 0.25 WELCTL SFTY SURFAC 02:15 - 05:30 3.25 WELCTL NUND SURFAC 05:30 - 09:00 3.50 WELCTL BOPE SURFAC 09:00 - 09:30 0.50 DRILL PULD SURFAC 09:30 - 10:30 1.00 DRILL OTHR SURFAC 10:30 - 12:30 2.00 DRILL PULD SURFAC 12:30 - 15:30 3.00 DRILL PULD SURFAC 15:30 - 17:00 1.50 DRILL TRIP SURFAC 17:00 - 20:30 3.50 DRILL TRIP SURFAC 20:30 - 21 :00 0.50 CEMENT COUT SURFAC 21 :00 - 21 :30 0.50 CASE CIRC SURFAC 21 :30 - 23:00 1.50 CASE DEQT SURFAC 23:00 - 00:00 1.00 CEMENT DSHO SURFAC 3/3/2003 00:00 - 01 :00 1.00 CEMENT DSHO SURFAC 01 :00 - 02:00 1.00 DRILL CIRC SURFAC 02:00 - 03:00 1.00 CEMENT LOT SURFAC 03:00 - 12:00 9.00 DRILL DRLG INTRM1 12:00 - 00:00 Start: 2/24/2003 Rig Release: Rig Number: Spud Date: 2/25/2003 End: Group: Description of Operations Printed: 4/3/2003 9:40:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) ConocoPhillipsAlaska Page 401 12 Operations SUl11maryRepøtt 3S-08 3S-08 ROT - DRILLING N 1268@ ppco.com Nabors 7ES Date From '- To Hours Code ·îo~e Phase 3/3/2003 12:00 - 00:00 3/4/2003 00:00 - 17:15 17:15 - 17:45 17:45 - 00:00 Start: 2/24/2003 Rig Release: Rig Number: Spud Date: 2/25/2003 End: Group: Description ·01 Operations 12.00 DRILL DRLG INTRM1 SOW 64K ROT 95K 550 gpm 12100 psi MWT =9.0 ppg ECD=11.3 ppg Torque onloff 12K I 11 K Pumped 40 bbls sweeps, 3 ppg over MWT @ 5125',5583', and 6058'. Sweeps @ 5125' and 5583' had a large increase in cuttings back. Sweep @ 6058' had a moderate increase in cuttings with sweep back. 17.25 DRILL DRLG INTRM1 Drill, Slide & Survey Per Directional Plan from 6,153' to 7,675'MDI 4,082' TVD (1,552') ART 9.27 Hrs, AST .52 Hrs. 1 0-25K WOB, 115 Rpm's, 535 Gpm's, Off Btm Press 2,100 Psi, On Btm 2,250 Psi, Off Btm Torque 11.5K Ft#'s, On Btm 12K Ft#'s, Rot Wt 102K, PU Wt 185K, Dn Wt 70K, Ave BGG 80 Units, Pumped Wt'd Sweeps at 3 ppg over MW @ 6,438',7,010' with Large Amount of Cuttings Back, 70-80% Increase on Both Sweeps, Pumped Sweep @ 7,580' with 30% Increase in Cuttings 0.50 DRILL OTHR INTRM1 Shakers Blinding Off Due to EP Mud Lube, Worked Pipe, Reduced Circ Rate And Cleaned Off Shakers 6.25 DRILL DRLG INTRM1 Drill & Survey from 7,675' to 8,246' MD/4,326' TVD (571') ART 3.03 Hrs, -0- Hrs Sliding, 10-25K WOB, 100-115 Rpm's, 535 Gpm's, Off Btm Press 2,250 Psi, On Btm 2,350 Psi, Off Btm Torque 12.5K Ft#'s, On Btm 13K Ft#'s, Rot Wt 11 OK, PU Wt 185K, Dn Wt 75K, Ave Bgg 90 Units, Max Gas 170 Units, Pumped Wt'd Sweep at 3 ppg Over Mw @ 8,090' and had 70-80% Increase in Cuttings, Raised Mw from 9.3 ppg to 10.0 ppg per Mud Wt Up schedule Drill, Slide & Survey from 8,246' to 8,532' MD/4,440' TVD (286') ART 1.29 Hrs, AST .17 Hrs Repaired Epoch PVT Unit, Found Loose Conn on Back of Unit, Rebooted Computer Drill, Slide & Survey from 8,532' to 10,214' MDI 5,151' TVD (1,682') ART 8.36 Hrs, AST 1.15 Hrs 1 0-25K WOB 100 Rpm's, 540 Gpm, Off Btm Press 2,500 Psi, On Btm 2,850 Psi, Off Btm Torque 17K Ft#'s, On Btm 18K Ft#'s, Rot Wt 123K, PU Wt 220K, Dn Wt 80K, Ave BGG 100 Units, Pumped Wt'd Sweeps 3 ppg Over MW at 9,007' with 70-80% Increase in Cuttings and at 9,958' with 50% Increase in Cuttings, Began Raising MW to 10.6 ppg Per Wt Up Schedule 0.50 DRILL CIRC INTRM1 Circ and cond flocculated mud 550 gpm I 2950 psi I 115 rpm - mud out 200+ vis - treated mud with water, Carbonex and CF desco, large volume of cuttings across shakers for 15 min. final rate 550 gpm / 2625 psi. 4.00 DRILL DRLG INTRM1 Drill, Slide & Survey from 10,214' to 10,526' MDI 5,294' TVD (312') ART 1.88 Hrs, AST .53 Hrs, 15-25K WOB, 100 Rpm's, 529 Gpm, Off Btm Press 2,600 Psi, On Btm 2,750 Psi, Off Btm Torque 18K Ft#'s, On Btm 18.5K Ft#'s Rot WT 126K, PU Wt 240K, Dn Wt 80K, With 10.6 ppg Mud ECD Ave 12.2 ppg, BGG Ave 90 Units Drill, Slide & Survey from 10,526 to 10,716' MDI 5,395' TVD (190') ART .95 Hrs, AST .74 Hrs, Added 565 bbls of 11.9 ppg New Whole Mud to System While Drlg Ahead for Weighting Up System Circ Hole at Reduced Rate While Cleaning & Raising Shakers, Had a Large Amount of Cuttings Back with New Mud at Surface Drill, Slide & Survey from 10,716' to 11,384' MD/5,802' TVD (668'), ART 5.17 Hrs, AST 2.21 Hrs, 1 0-25K WOB, 100 Rpm's, 500 Gpm, Off Btm Press 2,650 Psi, On Btm 2,750 Psi, Off Btm torque 18.5K Ft#'s, On Btm 18.5K Ft#'s, Rot Wt 140K, PU Wt 250K, Dn Wt 95K, Ave BGG 60 Units, Max Gas 150 Units, Mud Wt after Adding New Mud 10.8 ppg, 3/5/2003 00:00 - 02:30 2.50 DRILL DRLG INTRM1 02:30 - 03:00 0.50 RIGMNT RGRP INTRM1 03:00 - 19:30 16.50 DRILL DRLG INTRM1 19:30 - 20:00 20:00 - 00:00 3/6/2003 00:00 - 03:00 3.00 DRILL DRLG INTRM1 03:00 - 03:30 0.50 DRILL CIRC INTRM1 03:30 - 14:30 11.00 DRILL DRLG INTRM1 Printed: 4/3/2003 9:40:39 AM ) ) ConocoPhillipsAlaska Page S of 12 . ·Operations Summary Report Legal Well Name: 38-08 Common Well Name: 38-08 Spud Date: 2/25/2003 Event Name: ROT - DRILLING 8tart: 2/24/2003 End: Contractor Name: N1268@ppco.com Rig Release: Group: Rig Name: Nabors 7ES Rig Number: Date Sub Phase Description of Operations Code 3/6/2003 03:30 - 14:30 11.00 DRILL DRLG INTRM1 Began Raising MW to 11.9 ppg per Mud Program, Began Circ Out Contaminated mud 14:30 - 18:00 3.50 DRILL CIRC INTRM1 Circ Out Contaminated Mud, Circ & Cond Mud to 11.9 ppg, Determined Barite Used for Wt Up Had Been Contaminated with Cement. Circ @ 500 Gpm's @ 2,600 Psi 18:00 - 19:15 1.25 DRILL DRLG INTRM1 Drill, Slide & Survey from 11,384' to 11,450' MD/5,849' TVD (66') ART .43 Hrs, AST .42 Hrs, 10-15K WOB, 100 Rpm's, 500 Gpms, Off Btm Press 2,650 Psi, on Btm 2,750 Psi, On & Off Btm Torque 19K Ft#'s, Rot Wt 140K, PU Wt 250K, Dn Wt 95K, Ave Bgg 60 Units, 11.9 ppg Mw with 13.23 ECD 19:15 - 20:30 1.25 DRILL CIRC INTRM1 Circ Btms Up & Cond Mud, Ave Bgg 60 Units, Max Gas 100 Units, Circ @ 500 Gpm 2,600 Psi, 115 Rpm's with 11.9 ppg Mud In & Out 20:30 - 00:00 3.50 DRI LL WIPR INTRM1 Monitored Well-Static, Began POOH Ave 275K PU Wt, Pulled 25K Over Drag At 10,720', Base of Morraine Sand, Back Reamed Thru Sand from 10,720' to 10,526', Cont POOH from 10,526' to 9,672' with 20K over Ave Drag 3/7/2003 00:00 - 05:30 5.50 DRILL WIPR INTRM1 Cont Wiping Hole to Shoe, Pulled 25K Over at 9,672', Backreamed Out F/9,672' to 9,578', Cont POOH to 4,251' with No Problems 05:30 - 07:00 1.50 RIGMNT RSRV INTRM1 Cut & Slip 106' of Drlg Line, Found Line to Have Broken Strands, Slip & Cut add 240' (346' Total) Drlg Line 07:00 - 08:00 1.00 RIGMNT RSRV INTRM1 Serviced Top Drive & Crown 08:00 - 11 :00 3.00 DRILL WIPR INTRM1 Est Circ Outside of Shoe at 4,300' to Calibrate Sperry Sun Tool, TIH to 8,628', Took Wt @ 6,754' Wiped Back Thru & Ck Ok, No Other Problems RIH 11 :00 - 11 :30 0.50 DRILL CIRC INTRM1 Est Circ & Circ Hole Prior to RIH to Btm, Circ @ 500 Gpm's, 2,500 Psi, 50 Rpm's, Rot Wt 125K with 15K Ft#'s Torque 11 :30 - 13:30 2.00 DRILL WIPR INTRM1 Cont TIH to Btm with No Problems 13:30 - 15:30 2.00 DRILL CIRC INTRM1 Pumped Barolift Sweep & Circ Hole Clean, Sweep Came Up on Calc Strokes, Circ @ 500 Gpm's, 2,800 Psi, Max Gas 740 Units @ Btms Up And Dropped Out in Several Min, Ave 60 Units Bgg 15:30 - 18:30 3.00 DRILL DRLG INTRM1 Drill 8 1/2" hole From 11,450' to 11,642' MD/5,986' TVD (192') ART 2.5 Hrs, AST -0-, Control Drilled Thru KUP "C" Sand @ 100'/Hr for Real Time Logs, 500 Gpm's, Off Btm Press 2,600 Psi, On Btm 2,800 Psi, Off Btm Torque 20K Ft#'s, On Btm 21 K Ft#'s, Rot Wt 145K, Pu Wt 70K, Dn Wt 95K, Ave 60 Units BGG, Max Gas From KUP sand 270 Units, Added 2 ppb LCM While drlg Thru Sand and Had Full Returns, Decision Made to Plugback and Sidetrack Well. 18:30 - 22:00 3.50 DRILL CIRC INTRM1 Backreamed Out of Hole While Circ 2 Btms Up from 11,642' to 10,420', Thru Morraine Sand, No Problems, Backreamed Out at 80 Rpm's, 450 Gpm, 2,100 Psi, 165K Up Wt, Ave 20 Units BGG and 20K Ft#'s Torque 22:00 - 00:00 2.00 DRILL TRIP INTRM1 Monitored Well-Static, Pumped Dry Job & POOH to 8,434' with No Problems 3/8/2003 00:00 - 03:45 3.75 DRILL TRIP INTRM1 Cont POOH From 8,434', Pumped Dry Job @ 8,326', Worked Thru Tight Spot @ 7,095' POOH to Shoe to 4,251', Monitored Well-Static 03:45 - 04:30 0.75 DRILL OTHR INTRM1 Attempt to Turn Kelly Hose to Move Out Of Derrickmans Way and Unable to Turn, Having to Swing Stand of Pipe Around Hose 04:30 - 07:00 2.50 DRILL TRIP INTRM1 POOH to BHA #2, LD 21 Jts of 5" DP 07:00 - 08:30 1.50 DRILL TRIP INTRM1 POOH & LD 17 Jts HWDP, Jars and 2 Flex Dc's, Cleaned Rig Floor 08:30 - 12:00 3.50 DRILL TRIP INTRM1 Held PJSM, Removed Radioactive Source, LD 1-Flex Dc, Download MWD and LD BHA 12:00 - 15:00 3.00 ABANDt\ PULD ABANDN RU GBR Tbg Tongs & Handling Tools, PU & MU 30 Jts of 31/2" 9.3# L-80 EUE Tbg for Cmt Stinger with Bull Nose Circ Sub 15:00 - 20:00 5.00 ABANDt\ TRIP ABANDN Tlh with 3 1/2" Tbg Stinger on 5" DP to 11,557', Est Circ & Washed 85' Printed: 4/3/2003 9:40:39 AM ) ') COl1ocoPhillips··Alaska OperaJi()l1s$umrnary R~port 5.00 ABANDr\ TRIP ABANDN to Btm, 11,642' with No Problems 3.00 ABANDr\ CIRC ABANDN Circ & Cond Mud for Setting Cmt Plug, Max Gas on Btms Up 380 Units with No Gas Cut, Circ Hole Clean with 11.8 ppg Mud at 500 Gpm, 1,700 Psi with 21 OK Pu Wt & 85K Dn Wt, Held PJSM on Setting Cmt Plug & Batch Mixed Cmt 1.00 CEMENT PUMP ABANDN RU Dowell, Pumped 5 bbls of 8.3 ppg CW 100, Found Low Torque Valve Leaking, Changed Out Same, Tested Lines to 3,500 Psi & Ck Ok, Pumped Add 5 bbls 8.3 ppg CW 100 Followed by 42 bbls, 203 sxs of Class G Cmt W / Add @ 15.8 ppg & 1.16 Yield, Pumped 1.5 bbls of CW 100 Behind, Turned Over to Rig And Displaced Cmt with 181 bbls of 11.8 ppg Mud to Balance Plug, CIP @ 24:00 Hrs Est T.O.C @ 11 ,200' POOH Slow from 11,642' to 10,765' after Setting Cmt Plug on Btm, Circ 100 bbls of 11.8 ppg Mud Down DP to Clear Same POOH 15 Stds Wet to 9,340', Pumped Dry Job, Blow DownTop Drive, Cant POOH to 5,156' Pumped & Spotted 12.8 ppg High Vis Pill from 5,156' to 4,870' POOH 3 Stds to 4,870' Circ & Cond Mud for Kick-Off Cmt Plug, At Btms Up Did Not See Any Weighted Pill, After Circ Hole Clean, MU Head Pin With TIH Valve and Cant Circ Hole While Dowell Batch Mixed Cmt, Circ @ 500 Gpm, Initial Pres 970 Psi, Final Press 920 Psi, Rot Pipe 15 Rpms with 5K Ft#'s Torque, 11.8 ppg Mud in & Out Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-08 3S-08 ROT - DRILLING N1268@ppco.com Nabors 7ES · Date Sub From-To Hours Code Code Phase 3/8/2003 15:00 - 20:00 20:00 - 23:00 23:00 - 00:00 3/9/2003 00:00 - 01 :00 1.00 CEMENTTRIP ABANDN 01 :00 - 04:45 3.75 ABANDr\ TRIP ABANDN 04:45 - 05:00 0.25 ABANDr\ CIRC ABANDN 05:00 - 05: 15 0.25 ABANDr\ TRIP ABANDN 05: 15 - 07:30 2.25 ABANDr\ CIRC ABANDN 07:30 - 08:15 Start: 2/24/2003 Rig Release: Rig Number: Spud Date: 2/25/2003 End: Group: Description of Operations 0.75 CEMENT PLUG ABANDN RU Dowell, Pumped 5 bbls 8.3 ppg CW1 00 Spacer, Press tested Lines to 3,500 Psi, Pumped 10 bbls Add CW100, Pumped 59 bbls, 328 SXS of Class G Cmt @ 17.0 ppg and 1.01 Yield with Add, Follow with 3 bbls CW100, Turned over to Rig Pump and Displaced Cement with 63 bbls of 11.8 ppg Mud to Balance Plug, CIP @ 08:00 Hrs, Est TOC @ 4,203' POOH slow with 7 Stds Dp to 4,203' Circ Btms Up, Had 60 bbls of Cmt Contaminated Mud Back at Btms Up, circ Clean at 580 Gpm, 1,070 Psi, 20 rpm's, 4K Ft#'s torque, St Wt 72K Pumped Dry Job, Blow Down Top Drive, POOH & Stood Back 7 Stds DP for 85 Stds in Derrick, POOH LD 84 jts 5" dp and 30 Jts of 31/2" Stinger 08:15 - 09:00 0.75 ABANDr\ TRIP ABANDN 09:00 - 09:30 0.50 ABANDr\ CIRC ABANDN 09:30 - 15:30 6.00 ABANDr\ TRIP ABANDN 15:30 - 16:00 0.50 ABANDr\ RURD ABANDN 16:00 - 16:30 0.50 WELCTL OTHR PROD 16:30 - 20:00 3.50 WELCTL BOPE PROD 20:00 - 20:30 0.50 WELCTL OTHR PROD 20:30 - 20:45 0.25 RIGMNT RGRP PROD 20:45 - 23:00 2.25 DRILL PULD PROD 23:00 - 23:15 0.25 DRILL SFTY PROD 23:15 - 00:00 0.75 DRILL PULD PROD 3/10/2003 00:00 - 01 :30 1.50 DRILL TRIP PROD 01 :30 - 03:30 2.00 DRILL TRIP PROD Note: John Spaulding with AOGCC Waived Witnessing of BOP Test, Sim-Op Tested Choke Manifold to 250 Psi Low & 5,000 Psi High While LD Dp & Tbg RD GBR Tbg Equip, Cleared Rig Floor and Turned Kelly Hose Pulled Wear Bushing RU & Tested BOPE, Tested Rams, Valves and 7" Test Jt to 250 Psi Low and 5,000 Psi High, Tested Annular to 250 Low & 5,000 Psi High, Good Test, RD Test Tools Installed Wear Bushing Changed Out Flow Riser/Bell Nipple PU & MU BHA #3, Orient BHA, Upload MWD & Surface Test Held Safety Mtg with Crew & Sperry Sun on Loading Radioactive Sources Loaded Radioactive Sources & Cant PU & RIH with BHA #3 to 373' Fin PU & MU BHA #3, PU 23 Jts 5" HWDP & Jars Cant TIH with BHA #3 and tagged TOC at 4,210' (Est TOC @ 4,203') Printed: 4/3/2003 9:40:39 AM ) ) cOnþcoP~illiþàAlaské1 Page70f 12 Operations· SumrnäryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-08 38-08 ROT - DRILLING N 1268 @ ppco.com Nabors 7ES Date From-To Sub Phase Code 3/10/2003 03:30 - 04:30 1.00 DRILL REAM PROD 04:30 - 12:00 7.50 DRILL DRLG PROD 12:00 - 18:45 6.75 DRILL DRLG PROD 18:45 - 19:00 0.25 DRILL CIRC PROD 19:00 - 00:00 5.00 DRILL DRLG PROD 3/11/2003 00:00 - 01 :00 1.00 RIGMNT RGRP PROD 01 :00 - 02:00 1.00 DRILL DRLG PROD 02:00 - 02: 15 0.25 RIGMNT RGRP PROD 02:15 - 07:45 5.50 DRILL DRLG PROD 07:45 - 08: 15 0.50 DRILL CIRC PROD 08:15 - 17:30 9.25 DRILL DRLG PROD 17:30 - 17:45 17:45 - 00:00 0.25 RIGMNT OTHR PROD 6.25 DRILL DRLG PROD 8tart: 2/24/2003 Rig Release: Rig Number: Spud Date: 2/25/2003 End: Group: Cleaned Out Med to Hard Cement from 4,210' to 4,300', Displaced 11.8 ppg Mud in Hole Over to New 8.9 LSND Mud While Cleaning Out Cmt, Circ at 500 Gpm's, 975 Psi. Drill, Slide & Survey Per Directional Plan from 4,300' to 4,957' MDI 3,108' TVD, ART 1.98 Hrs, AST 2.43 Hrs, 1 0-20K WOB, 100 Rpm's, 550 Gpm, Off Btm Press 1,625 Psi, On Btm 1,825 Psi, Off Btm torque 11 K Ft#'s, On Btm 12.5K Ft#'s, Rot Wt 100K, PU Wt, 158K, Dn Wt 70K, Ave BGG 15 Units, 9.2 ppg MW with 10.7 ECD, Pumped Weighted Sweep 3 ppg Over MW at 4,816', Had 70-80% Increase in Cuttings Drill, Slide & Survey from 4,957' to 5,579', ART 2.97 Hrs, AST 1.74, Raised Mw from 9.2 ppg to 9.6 ppg, Pumped Weighted Sweep 3 ppg Over MW at 5,140', Had 70-80% Increase in Cuttings, Pumped Weighted Sweep 3 ppg Over MW at 5,412', Had 30% Increase in Cuttings Fin Circ Btms Up After Backreaming Prior to Conn, Circ to Lower ECD, Lowered ECD from 12.8 to 11.0 ppg with 9.6 ppg MW Drill, Slide & Survey from 5,579' to 5,959' MDI 4,050' TVD, ART 1.02 Hrs, AST 1.85 Hrs, 10-25K WOB, 100 Rpm's, 550 Gpm, Off Btm Press 1,890 Psi, On Btm 2,070 Psi, Off Btm torque 13K Ft#'s, On Btm 13K, Rot Wt 123K, PU Wt 205K, Dn Wt 83K, Ave 20 Units BGG, 10.15 Mw In with 11.8 ECD, Replaced Swab on #1 Pump, Worked Pipe & Circ Hole at 250 Gpm, 650 Psi Drill, Slide & Survey Per Directional Plan from 5,959' to 6,054' TVD (95'), ART .2 Hrs, AST .5 Hrs Replaced Hose on Rod Oiler on #1 Mud Pump, Worked Pipe & Circ Hole Drill, Slide & Survey from 6,054' to 6,529' MDI 4,578' TVD (475') ART 1.19 Hrs, AST 1.89 Hrs, 10-20K WOB, 100 Rpm's, 550 Gpm, Off Btm Press 2,150 PSi, On Btm 2,250 PSi, OfflOn Btm torque 16K Ft#'s, Rot Wt 133K, PU Wt, 232K, Dn Wt 90K, 10.2 MW with 11.6 ECD, Top of Morraine Sand 7,380' MD, 5,243' TVD, Max Gas 700 Units, Ave Bgg 50 Units, Pumped Weighted Sweep at 3 ppg Over Mw at 6,083', Had 70-80% Increase in Cuttings, Sweep @ 6,510 Had 70-80% Increase Fin Circ Out Weighted Sweep Pumped at 6,510', ECD Went from 11.55 to 11.35, Max ECD 11.98 with 10.2 MW Drill, Slide & Survey from 6,529' to 7,478' MDI 5,320' TVD (949') ART 4.33 Hrs, AST 1.46 Hrs, 1 0-20K WOB, 100 Rpm's, 540 Gpm, Off Btm Press 2,370 PSi, On Btm 2,600 PSi, Off Btm torque 16.5K Ft#'s, On Btm 15.5K Ft#'s, Rot Wt 140K, PU Wt, 250K, Dn Wt 95K, 10.5 MW with 12.5 ECD, Max Gas 1,140 Units, Ave Bgg 120 Units, Pumped Weighted Sweep at 3 ppg Over Mw at 6,909' Had 30% Increase in Cuttings, Sweep @ 7,208' Had 70-80% Increase, Rig Off High Line Power @ Hrs 16:30 Hrs Put Rig Back On Highline Power, Rig OFF Highline for 1 1/4 hrs Drill, Slide & Survey from 7,478' to 7,954' MDI 5,689' TVD, (476'), ART 3.53 Hrs, AST .28, 10-20K WOB, 110 Rpm's, 520 Gpm, Off Btm Press 2,340 PSi, On Btm 2,770 Psi, Off Btm Torque 17K Ft#'s, On Btm 18K Ft#'s, Rot Wt 148K, PU Wt 265K, DN Wt 95K, Ave BGG 150 Units, Max Gas 990 Units, 11.3 ppg MW, ECD 13.2 ppg Top of HRZ 7,714' MDI 5,501' TVD, Base of HRZ 7,958' MDI 5,693' TVD, Pumped Weighted Sweep @ 7,477', Had 50% Increase in Cuttings Printed: 4/3/2003 9:40:39 AM ) ) QonocoPhillips Alaska OpèrationsSummary Report Drill from 7,954' to 8,145' MDI 5,843' TVD, (191') ART 1.4 Hrs AST -0-, 20-25K WOB, 110 Rpm's, 530 Gpm, Off Btm Press 2,350 Psi, On Btm 2,770 Psi, Off Btm Torque 17K Ft#'s, On Btm 18K Ft#'s, Rot 149K, PU 275K, Dn Wt 95K, Ave BGG 150 Units, Pumped Hi Vis Sweep with 50% Increase in Cuttings 2.50 DRILL CIRC PROD While Circ Hole for Wiper Trip had a Drop In DP Press, Checked Surface Lines and Cleaned Pump Screens with No Change, Init Circ Press @ 530 Gpm, 2,350 Psi, Final Press 1,850 Psi (500 Psi Drop) 4.00 DRILL TRIP PROD Began POOH Looking for Washout, Tigh Coming Off Btm, Pumped Out 10 Stds to Above Top of Morraine Sand @ 7,380', Cont POOH WIO Pumping & Found Washout on 14th Std Out, Washed out in Neck Area Below Box, LD Stand Circ Btms Up from 6,800', No Increase In Cuttings on Btms Up, Circ at 500 Gpm, 2,236 Psi, 120 Rpm's with 17.5K Ft#'s of Torque Cont POOH to Shoe, Had to Pump Thru Tight Spot at 6,674', Worked Back Thru with No Problems, No Other Problems POOH to Shoe, Cleaned Rig Floor after Wet Trip Monitored Well-Static, Serviced Rig & Top Drive Cut & Slip 108' of Drlg Line TIH to 8,049', Washed 96' to Btm, 8,145' with No Problems Pumped Hi Vis Sweep & Circ Hole Clean After Wiper Trip, Max Gas at Btms Up 1,330 Units and Fell Off in Less than 10 Min, Ave Bgg 100 Units, Had Little Change in Cuttings from Sweep Drill from 8,145' to 8,475' MDI 6,116 TVD (330') T.D., ART 2.98 Hrs, AST -0-, 15-25K WOB, 110-115 Rpm's, Control Drilled Thru KUP "C" @ 1 OO'IHr, Top of Sand 8,168' MD/5,862' TVD, Base of Sand at 8,187' MDI 5,878' TVD, 500 Gpm, Off Btm Press 2,200 psi, On Btm 2,400 psi, Off Btm Torque 22.5K Ft#'s, On Btm 22K Ft#'s, Max Gas from Sand 520 Units, Ave Bgg 125 Units, 11.3 ppg MW, ECD Ave 12.4, Max 12.8 ppg, Rot Wt 160K, Up Wt 300K, Dn Wt 95K, Decision Made to Abandon Lower Portion of Wellbore & Sidetrack 1.50 DRILL REAM PROD Pumped Hi Vis Sweep, Backreamed Out While Circ Out Sweep, Backreamed Out from 8,475' to 7,954', Circ at 500 Gpm, 2,300 Psi, 100 Rpm's with 20K Ft#'s Torque, Had 50% Increase in Cuttings Back from Sweep and Cleaned Up While Backreaming POOH from 7,954' to 6,149' with No Problems, Pumped Dry Job, & Cont POOH to BHA, No Problems on Trip Out Held PJSM with Sperry Sun on LD BHA & Radioactive Sources LD BHA & Removed Radioactive Sources, Downloaded MWD, LD 2 Flex Dc's, Cleaned Rig Floor RU GBR Tbg Tongs & Handling Tools, PU & MU 30 Jts of 31/2" 9.3# L-80 EUE Tbg for Cmt Stinger with Bull Nose Circ Sub TIH with 31/2" Stinger on 5" DP to 8,461', Washed 14' to Btm, 8,475' with No Problems Circ Btms Up Prior to Setting Abandonment Plug, Max Gas 200 Units at Btms Up, Ave 80 Units BGG, Circ at 500 Gpm, Initial Press 1,960 Psi, Final Press 1,880 Psi, Reciprocated Pipe, Up Wt 225K, Dn Wt 93K, Held PJSM with Dowell & Rig Crew, MU Head Pin & Cement Hose & Cont Circ While Batch Mixing Cement 0.75 CEMENT PLUG ABANDN RU Dowell, Pumped 5 bbls of 8.3 ppg CW 100,Tested Lines to 3,500 Psi & Ck Ok, Pumped Add 5 bbls 8.3 ppg CW 100 Followed by 48.5 bbls, 235 sxs of Class G Cmt WIAdd @ 15.8 ppg & 1.16 Yield, Pumped 1.5 bbls of CW 100 Behind, Ave 5 Bpm at 450 Psi, Turned Over to Rig Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3S-08 38-08 ROT - DRILLING N1268@ppco.com Nabors 7E8 3/12/2003 From -To Hours Code Sub Phase Code 00:00 - 02:30 2.50 DRILL DRLG PROD 02:30 - 05:00 05:00 - 09:00 09:00 - 09:30 0.50 DRILL CIRC PROD 09:30 - 12:00 2.50 DRILL WIPR PROD 12:00 - 13:00 1.00 RIGMNT RSRV PROD 13:00 - 14:00 1.00 RIGMNT RSRV PROD 14:00 - 16:00 2.00 DRILL WIPR PROD 16:00 - 18:00 2.00 DRILL CIRC PROD 18:00 - 22:30 4.50 DRILL DRLG PROD 22:30 - 00:00 3/13/2003 00:00 - 07:30 7.50 DRILL TRIP PROD 07:30 - 07:45 0.25 DRILL SFTY PROD 07:45 - 11 :30 3.75 DRILL TRIP PROD 11 :30 - 14:00 2.50 ABANDt\ PULD ABANDN 14:00 - 17:30 3.50 ABANDt\ TRIP ABANDN 17:30 - 20:15 2.75 ABANDt\ CIRC ABANDN 20:15 - 21 :00 Start: 2/24/2003 Rig Release: Rig Number: Spud Date: 2/25/2003 End: Group: Description of Operations Printed: 4/3/2003 9:40:39 AM ) ) GOnocoPhillipsAlaska Operations Summary Report Page 9 of 12 0.75 CEMENT PLUG ABANDN And Displaced Cmt with 125 bbls of 11.3 ppg Mud to Balance Plug, Displaced Cmt 420 Gpm, 1,400 Psi, Reciprocated Pipe During Job, CIP @ 20:50 Hrs Est T.O.C @ 7,968' POOH Slow 9 Stds to 7,603', 1st 5 Stds at 1 Std/2 Min, Circ Btms Up from 7,603', No Cmt Back at Btms Up, Pump and Spotted 35 bb112.3 ppg High Vis Pill from 7,603' to 7,300' POOH 3 Stds to 7,317' Circ & Cond Mud for Kick-Off Cmt Plug, At Btms Up Did Not See Any Weighted Pill, After Circ Hole Clean, MU Head Pin With Cmt Hose and Cont Circ Hole While Dowell Batch Mixed Cmt, Circ @ 425 Gpm, 900 Psi, Rot Pipe 10-15 Rpms with 15K Ft#'s Torque, 11.3 ppg Mud in & Out 0.75 CEMENT PLUG ABANDN RU Dowell, Pumped 5 bbls 8.3 ppg CW100 Spacer, Press tested Lines to 3,500 Psi, Pumped 10 bbls Add CW100, Pumped 57 bbls, 316 SXS of Class G Cmt @ 17.0 ppg and 1.00 Yield with Add, Follow with 3.5 bbls CW1 00, Turned over to Rig Pump and Displaced Cement with 102 bbls of 11.3 ppg Mud to Balance Plug, Reciprocated Pipe, CIP @ 00:45 3/14/03 Hrs, Est TOC @ 6,700' POOH Slow, 1st 6 Stds @ 1 std/3 min, POOH Total of 10 Stds to 6,369' Circ Btms Up at 6,369' At Btms up Had 30 bbls of Cmt Contaminated Mud Back, Circ Hole Clean with 11.3 MW In & Out ,Circ at 500 Gpm, 1,000 Psi Reciprocated & Rot Pipe Monitored Well-Static, Pumped Dry Job & POOH to 31/2" Stinger RU GBR Tbg Equip, POOH LD 30 Jts 3 1/2" 9.3# L-80 EUE 8 rd TBg Stinger, NOTE: Chuck Scheave with AOGCC Waived Witnessing of BOP Test, Sim-Op-Tested Choke Manifold on Trip Out of Hole 0.25 WELCTL SFTY PROD Held PJSM on Testing BOP's 4.75 WELCTL BOPE PROD Pulled Wear Bushing, RU & Tested All Rams, Valves, and 7" Test Jt to 250 Psi Low, 5,000 Psi High, Tested Annular to 250 Low and 3,500 Psi High, Good Test, RD Test Tools, Installed Wear Bushing & Blow Down Kill & Choke Lines Started MU BHA #4 Orient and Upload MWD Changed Out Wash Pipe On Top Drive & Serviced Same Surface Tested MWD and Blow Down Top Drive Held PJSM with Sperry Sun on Loading Radioactive Sources Loaded Radioactive Sources & Fin PU & RIH with BHA #4 TIH with BHA #4 and Began Taking Wt @ 6,455' Est Circ at 500 Gpm, 2,450 Psi and 75 Rpms, Began Washing Down from 6,455', Tagged Hard Cmt At 6,470', (Calc TOC was @ 6,700' with 35% Excess, Calc Gauge Hole) Drilled Hard Cmt from 6,470' to 6,496' Began Sliding to Sidetrack Well, Slide Drilling from 6,496' to 6,515' with 500 Gpm, 2,450 Psi, with 25K WOB Slide Drilling to Sidetrack Well from 6,515' to 6,531', Well Sidetracked @ 6,531' Drill, Slide & Survey Per Directional Plan from 6,531' to 7,220' MD/5,093' (689') ART 4.12 Hrs, AST 4.24 Hrs, 20-25K WOB, 100 Rpm's, 500 Gpm, Off Btm Press, 2,250 PSi, On Btm 2,600 Psi, Off Btm & On Btm Torque 17K Ft#'s, Rot Wt 140K, PU Wt, 240K, Dn Wt 105K, 11.3 MW, 12.7 ECD, Pumped Sweeps Every 300' with 50-100% Increase in Cuttings 12.00 DRILL DRLG PROD Drill, Slide & Survey from 7,220' to 8,183' MD/5,668' (963') ART 6.08 Hrs, AST 2.96 Hrs, 20-25K WOB, 100 Rpm's, 500 Gpm, Off Btm Press, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-08 3S-08 ROT - DRILLING N1268@ppco.com Nabors 7ES . Date Sub From - To Hours Code Code . Phase 3/13/2003 20:15 - 21 :00 21 :00 - 21 :30 0.50 ABANDt\ TRIP ABANDN 21 :30 - 22:45 1.25 ABANDt\ CIRC ABANDN 22:45 - 23:00 0.25 ABANDt\ TRIP ABANDN 23:00 - 00:00 1.00 ABANDt\ CIRC ABANDN 3/14/2003 00:00 - 00:45 00:45 - 01 :30 0.75 ABANDt\ TRIP ABANDN 01 :30 - 02:45 1.25 ABANDt\ CIRC ABANDN 02:45 - 05:30 2.75 ABANDt\ TRIP ABANDN 05:30 - 08:00 2.50 ABANDt\ PULD ABANDN 08:00 - 08:15 08:15 - 13:00 13:00 - 15:30 2.50 DRILL TRIP PROD 15:30 - 17:30 2.00 RIGMNT RSRV PROD 17:30 - 18:00 0.50 DRILL TRIP PROD 18:00 - 18:15 0.25 DRILL SFTY PROD 18:15 - 19:00 0.75 DRILL TRIP PROD 19:00 - 22:00 3.00 DRILL TRIP PROD 22:00 - 22:45 0.75 DRILL REAM PROD 22:45 - 00:00 1.25 DRILL DRLG PROD 3/15/2003 00:00 - 00:45 0.75 DRILL DRLG PROD 00:45 - 12:00 11.25 DRILL DRLG PROD 12:00 - 00:00 Start: 2/24/2003 Rig Release: Rig Number: Spud Date: 2/25/2003 End: Group: Description of Operations Printed: 4/3/2003 9:40:39 AM .) ) ConocoPhillipsAlaska Oþ¢rationsSul11 rnary.. Repqrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/15/2003 3/16/2003 3S-08 3S-08 ROT - DRILLING N1268@ppco.com Nabors 7ES 12:00 - 00:00 . Sub. CÒde Phase 12.00 DRILL DRLG PROD 00:00 - 03:15 3.25 DRILL DRLG PROD 03:15 - 04:30 1.25 DRILL CIRC PROD 04:30 - 10:30 6.00 DRILL DRLG PROD 10:30 - 13:00 2.50 DRILL CIRC PROD 13:00 - 15:30 2.50 DRILL WIPR PROD 15:30 - 17:00 1.50 DRILL WIPR PROD 17:00 - 21 :30 4.50 DRILL CIRC PROD 21 :3Q - 00:00 2.50 DRILL WIPR PROD 3/17/2003 00:00 - 02:00 2.00 DRILL WIPR PROD 02:00 - 03:00 1.00 RIGMNT RSRV PROD 03:00 - 06:00 3.00 DRILL DRLG PROD 06:00 - 08:45 2.75 DRILL CIRC PROD 08:45 - 15:45 7.00 DRILL TRIP PROD 15:45 - 16:00 0.25 DRILL SFTY PROD 16:00 - 19:00 3.00 DRILL TRIP PROD 19:00 - 19:30 0.50 DRILL OTHR PROD 19:30 - 20:30 1.00 CASE RURD PROD Start: 2/24/2003 Rig Release: Rig Number: Spud Date: 2/25/2003 End: Group: Description of Operations 2,790 Psi, On Btm 2,350 Psi, Off Btm Torque 19K Ft#'s, On Btm Torque 18.5K Ft#'s, Rot Wt 145K, PU Wt, 255K, Dn Wt 98K, 11.3 MW, 12.8 ECD, Pumped Sweeps Every 300' with 30-50% Increase in Cuttings. Top Morraine Sand: 7,460' MDI 5,237' TVD, Max Gas 1,100 Units, Top HRZ, 7,890' MD/5,497' TVD, Base of HRZ, 8,175' MD/5,665' TVD, Max Gas in HRZ 1,400 Units Ave BGG 250 Units Dril8 1/2" Hole from 8,183' to 8,433' MDI 5,822 TVD (250'), ART 2.25 Hrs, AST -0-, 20-25K WOB, 100 Rpm's, 500 Gpm's, Off Btm Press 2,400Psi, On Btm 2,700 Psi, Off Btm Torque 19K Ft#'s, On Btm 17K Ft#'s, Rot WT 145K, Pu Wt, 285K, Dn WT 11 OK, Ave BGG 550 Units, Top of K-1 8,388' MDI 5,793' TVD, Max Gas 2,500 Units. 11.3 ppg MW ECD 12.8 ppg Pumped Weighted Hi Vis Sweep & Circ Hole to Lower ECD's, Had 30% Increase in Cuttings Back, Circ Hole Clean at 520 Gpm's 2,400 Psi, 110 Rpm's, ECD Before Sweep 12.8 After Sweep Out of Hole and Circ Clean 12.5 ppg, Ave Bgg 230 Units Drill from 8,433' to 8,815' MDI 6,062' TVD (382') T.D., ART 4.91 Hrs, AST -0-, Control Drilled KUp·"C" Sand @ 100'/Hr For Logs, 20-25K WOB, 100 Rpm's Top of KUP "C" at 8,496' MDI 5,860' TVD, Max Gas 4,800 Units, 11.3 ppg MW Gas Cut to 9.3 ppg, With 11.3 ppg MW at 485 Gpm, 2,475 Psi had 12.6 ECD and No Mud Loss, at TD Ave 150 Units BGG Rot WT 145K, PU Wt 285K, Dn Wt 11 OK, Off Btm Torque 19K Ft#'s, On Btm 19K Ft#'s. Circ Hi Vis Sweep Around and Circ Hole Clean, Circ at 500 Gpm at 2,500 Psi, 110 Rpm's, Circ 4X Btms Up & Circ Clean, Monitored Well-Static POOH Wet from 8,815' to 6,247', Above KOP, Pulled 25K Over at 7,980',7,711',7,236' and 6,836' Worked Back Thru Spots with No Problems Monitored Well-Static, TIH with No Problems or Fill Circ Hole, At Btms Up Had 5,328 Unit Gas with 2.0 ppg Gas Cut with 11.3 ppg MW, Circ and Raised MW to 11.6 ppg In & Out, Circ at 500 Gpm, 2,400 Psi and 110 Rpm's with 12.6 ECD and No Mud Loss, Ave BGG 60 Units, Monitored Well-Static Began Wiping Hole to Shoe, Pulled 10 Stds with No Problems, Pumped Dry Job and Cont POOH to 6,247' with No Problems Fin Wiping Hole to Shoe, Worked Thru Tight Spot @ 5,677', Went Back Thru & Ck OK, No Other Problems POOH Serviced Top Drive, Drawworks and Cleaned Rig Floor TIH, Washed 90' to Btm with No Problems Circ Btms Up, Max Gas 1,750 Units, Pumped Hi Vis Sweep & Circ Hole Clean, Circ at 500 Gpm's 2,550 Psi, 100 Rpm's, Circ 4X Btms Up, 11.6 ppg Mud with 12.4 ECD Spotted 40 bbl Steel Seal Pill on Btm Monitored Well, POOH 10 Stds with No Problem, Pumped Dry Job & Cont POOH to BHA with No Problems, Monitored Well at Shoe and at BHA-Static Held Safety Mtg with Sperry Sun on Radioactive Sources POOH & LD Radioactive Sources, Download MWD and LD BHA Pulled Wear Bushing RU GBR 7" Csg Equipment with Franks Fill Up Tool, Changed Out Elevator Bales Printed: 4/3/2003 9:40:39 AM ') ') ConocoPhilliþs Alaska· Operations Summary Report . Legal Well Name: 3S-08 Common Well Name: 38-08 Event Name: ROT - DRILLING Contractor Name: N1268@ppco.com Rig Name: Nabors 7E8 Date From- To Hours Code Sub Code 3/17/2003 20:30 - 20:45 0.25 CASE SFTY PROD 20:45 - 00:00 3.25 CASE RUNC PROD 3/18/2003 00:00 - 03:30 3.50 CASE RUNC PROD 03:30 - 04: 15 0.75 CASE CIRC PROD 04:15 - 05:30 1.25 CASE RUNC PROD 05:30 - 05:45 0.25 CASE CIRC PROD 05:45 - 07:15 1.50 CASE RUNC PROD 07:15 - 08:00 0.75 CASE CIRC PROD 08:00 - 09:00 1.00 CASE RUNC PROD 09:00 - 09: 15 0.25 CASE CIRC PROD 09:15 - 10:00 0.75 CASE RUNC PROD 10:00 - 10:45 0.75 CASE CIRC PROD 10:45 - 13:00 2.25 CASE RUNC PROD 13:00 - 14:30 1.50 CASE CIRC PROD 14:30 - 17:00 2.50 CASE OTHR PROD 17:00 - 20:00 3.00 CEMENT PUMP PROD Start: 2/24/2003 Rig Release: Rig Number: Spud Date: 2/25/2003 End: Group: 3/19/2003 20:00 - 20:30 20:30 - 21:15 21 :15 - 21 :30 21 :30 - 00:00 00:00 - 08:30 08:30 - 09:30 09:30 - 10:30 0.50 CEMENT PULD PROD 0.75 CASE DEQT PROD 0.25 CMPL TN SFTY PROD 2.50 CMPL TN RUNT PROD 8.50 CMPL TN RUNT PROD 1.00 CMPL TN DEQT PROD 1.00 DRILL LOT PROD 10:30 - 12:00 1.50 CMPL TN PCKR PROD 12:00 - 12:30 0.50 CMPL TN SOHO PROD Description of Operations· . Held PJSM with Rig & Csg Crew on Running 7" Csg Run 7" Csg, MU 7" Float Shoe, 4 Jts 7", 26#, L-80, BTC-Mod and Float Collar, Thread Locked Jts Below Fit Collar & Ck'd Floats, Cont RIH with 7" Csg to 1,460' with No Problems Ran 7" casing from 1460' to 4237'. CBU at 5 BPM. Ran 7" casing from 4237' to 5041'. Circulated 50 BBLs at 5 BPM. Ran 7" casing to 5890'. Circulated at 5 BPM. Ran 7" casing to 6736'. Circulated 50 BBLs at 5 BPM. Ran 7" casing to 7375'. Circulated at 5 BPM. Ran 7" casing to 8802'. CBU 460 units gas. Rigged down casing fill up tool and made up cement head. Broke circulation and pulled 400,000 casing stuck on bottom. Rig Dowell, Batch mix 30 bbls CW1 00 @ 8.3 ppg, 40 bbls MudPUSH @ 12.6 ppg, 255 sxs (52.6 bbls) @ 15.8 ppg GasBLOK w/ Class G + .030%BWOC B155, .300%BWOC D65, 2.000 gal/sk D600G, .200 gal/sk D47, Pump 10 bbls CW1 00, Test lines to 3500 psi, Pump 20 bbls CW100, Drop #1 btm plug, Reload head, Pump 40 bbls MudPUSH at rate of 5.5 bpm at 740 psi, Drop #2 btm plug, Pump 52.6 bbls cmt at rate of 6.0 bpm at 850 to 650 psi, Shut down, Flush lines to rig floor with seawater, Drop top plug, Dowell Displace first 310 bbls seawater at rate of 7.0 bpm at 1200 psi until 26 bbls cmt around shoe, Slowed rate to 3.0 bpm @ 1400 psi & bumped plug w/ total of 335.5.0 bbls seawater, Bumped plug wi 1900 psi, Bled back 2.5 bbls for a total of 333.0 total bbls displaced, CIP @ 1851 hrs 3/18/03, Had good circ. thru out job, Displaced entire job with Dowell. Casing stuck prior to start of cement job. Flushed stack and rigged down Dowell. Laid down landing joint and ran packoff. Tested packoff to 5000 psi. Prejob safety meeting. RIH with Completion string on 31/2" tubing to 1112'. Run 3-1/2",9.3#, L-80, EUE 8rd Completion string to 8429' PJSM, Rig & test 7" casing to 3500 psi f/ 30 min. -OK Perform injecttivity test on 7" x 9-5/8" annulus, EMW of 17.5 ppg using 11.6 ppg mud with 820 psi @ 9-5/8" shoe 4263' MD & 2662' TVD Drop Baker 2" packer setting ball. Will set SAB-3 packer @ 8398.21', Slowly pressure 3-1/2" tbg. to 2500 psi. Wait 5 min. Bleed pressure to zero. Slack off to 40K (20K on pkr) to comfirm packer set, then pressure tbg string to 3000 psi and hold 5 min. Bleed pressure to 1000 psi. PU to 175K (55K over) & PBR would not shear, Slack back off to 40K. Increase tbg. press to 1500 psi & PBR sheared. Check & tag locator w/ 15K. Pressure tbg to 4500 psi to shear ball seat - Not a very good indication of ball shearing out, attempt several times with same results, (Discussed with SL Wells Supervisor Chuck Fitzpatrick- Decided he could knock it out if ball not sheared). Bleed off all pressure. Pull jt. #267 out of hole (pulling 12' out of PBR). M/U 3-1/2" FMC tubing hanger on jt. # 266, Use jt. #267 as landing jt., RIH & land tubing w/ Printed: 4/3/2003 9:40:39 AM .) ) ·CÖnocoPhillips AIªska Operations ·.Surnmåry Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From- To 3S-08 3S-08 ROT - DRILLING N1268 @ ppco.com Nabors 7ES Hours Code . Sub. , Code Phase 3/19/2003 12:00 - 12:30 12:30 - 13:30 0.50 CMPL TN SOHO PROD 1.00 CMPL TN DEaT PROD 13:30 - 14:00 0.50 CMPL TN SOHO PROD 14:00 - 16:30 2.50 CMPL TN NUND PROD 16:30 - 18:30 2.00 CMPL TN NUND PROD 18:30 - 19:00 0.50 CMPL TN OTHR PROD 19:00 - 21:15 2.25 CMPL TN FRZP PROD 21:15-22:45 1.50 CMPL TN OTHR PROD 22:45 - 00:00 1.25 RIGMNT OTHR CMPL TN 3/20/2003 00:00 - 06:00 6.00 MOVE MOVE MOVE 06:00 - 07:45 1.75 MOVE MOVE MOVE 07:45 - 08:00 0.25 MOVE SFTY MOVE Start: Rig Release: Rig Number: Spud Date: 2/25/2003 End: Group: 2/24/2003 Description of Operations locator 2' above fully located in PBR, RILDS. Rig pumping lines Pressure 3-1/2" tubing to 3500 psi fl 15 min. Bleed pressure to 1500 psi. Pressure 3-1/2" x 7" annulus to 3500 psi f/15 min (Pressure on tubing increase to 2000 psi). Bleed tbg pressure to zero. (RP sheared w/1200 psi on tbg). Bleeding both sides to zero. All test were charted. Lay down landing joint, Install FMC BPV Nippled down BOP. Nippled up Xmas tree. Recovered BPV. Pumped freeze protection while rigging down in cellar and changing out saver sub on top drive. Rigged up FMC lubricator and set BPV. Held PJSM, Sliped and cut 109' of drilling line. Laid down excess DP 128 jts. Loaded pipe shed and secured well. PJ Safety meeting. Rig released to move to 3S-21. Printed: 4/3/2003 9:40:39 AM Date 03/26/03 03/27/03 03/28/03 04/01/03 04/02/03 ) ) 3S-0BB Event History Comment PULLED SOV, SET DV @ 8282' RKB. MITIA 3000 PSI, GOOD. MITT 3000 PSI, GOOD. UNABLE TO PASS SOS @ 8429' RKB. IN PROGRESS. [TAG, GLV, MIT] KNOCKED SOS OUT @ 8429' RKB. DRIFTED TBG W/22' X 2.5" HC DMY GUN TO 8566' RKB, EST. 37' BELOW TARGET PERF DEPTHS 8492'- 8529' RKB. [PERF] BHP AT 8511' BEFORE PERFORATING= 3519.2 PSIA WITH WHP= 1400 PSI. PERFORATED 8492' - 8529', 6 SPF PJ (PERFED 8499'-8529' WITH WHP= 100 PSI). SBHP AFTER PERFORATING AT 8511'= 3222.1 PSIA, TEMP= 157.5 DEGF AND SBHP AT 8311'= 3168.2 PSIA, TEMP= 151.5 DEGF. TAGGED FILL @ 8561' RKB EST. 32' RAT HOLE, HAVE SAMPLE OF FILL, SET 1/4" OV @ 8283' RKB, PULLED DV'S FROM STN 4,3, IN PROGRESS [GLV] SET GLV'S @ 4008',5685',6576',74861, RKB, BLED IA OWN F/725 - 200 PSI, GOOD COMPLETE [GLV] Page 1 of 1 4/21/2003 ) ) d03r-DC/3 , ~. 20-Apr-03 AOGCC Lori Taylor 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 3S-08 B Dear Lori Taylor Enclosed are two survey hard copies and one disk Tie-on Survey: 6,465.61' MD Window / Kickoff Survey: 6,496.00' MD (if applicable) Projected Survey: 8,815.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) , .' ,t..... ,\ ! F·:" ~ 'C. r" ~.,r ~\~ ...." \~.~(~::::i~~.} "'~.<"" Ii \, <.'U (1' ,\fH 2.:" ,. ,~)~. :~,,:,~~~.....~\ 1~:\~ytN;i ,j;. ;;; \";':..~:_~~":~::,<, , . Sperry-Sun Drilling Services Western North Slope ConocoPhillips Kuparuk 35 Pad 35-088 --' Job No. AKZZ2306056, Surveyed: 16 March, 2003 Survey Report 18 April, 2003 Your Ref: API 501032045002 Surface Coordinates: 5993923.52 N, 476305.45 E (70023'40.3069" N, 150011'34.0335" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~' Surface Coordinates relative to Project H Reference: 993923.52 N, 23694.55 W (Grid) Surface Coordinates relative to Structure: 80.05 N, 149.80 W (True) Kelly Bushing: 56. 30ft above Mean Sea Level Elevation relative to Project V Reference: 56.30ft Elevation relative to Structure: 0.20ft S5~ ·....,y-5LJr1 DR 1 L-L I, N G !:t EfFl"YIC;"E5s,$ A Halliburton Company Survey Ref: svy2002 Sperry-Sun Drilling Services Survey Report for Kuparuk 35 Pad - 35-088 Your Ref: AP/501032045002 Job No. AKZZ2306056, Surveyed: 16 March, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) 6465.61 31. 720 274.860 4468.87 4525.17 1444.61 S 3135.24 E 5992468.98 N 479436.09 E 3440.25 Tie On Point 6496.00 31.844 277.686 4494.70 4551.00 1442.86 S 3119.33E 5992470.78 N 479420.19 E 4.915 3424.70 Window Point 6531 .87 32.070 280.990 4525.14 4581.44 1439.78 S 3100.61 E 5992473.92 N 479401.48 E 4.915 3406.05 6563.34 32.610 282.700 4551.73 4608.03 1436.32 S 3084.13 E 5992477.43 N 479385.01 E 3.375 3389.39 6657.94 34.770 286.120 4630.44 4686.74 1423.23 S 3033.34 E 5992490.69 N 479334.26 E 3.038 3337.18 6754.10 37.570 286.680 4708.06 4764.36 1407.20 S 2978.90 E 5992506.89 N 479279.88 E 2.932 3280.54 - 6848.84 41.540 288.270 4781.10 4837.40 1389.05 S 2921.38 E 5992525.22 N 479222.42 E 4.324 3220.29 6944.08 44.600 289.220 4850.66 4906.96 1368.14 S 2859.81 E 5992546.32 N 479160.91 E 3.284 3155.27 7039.42 47.000 290.890 4917.13 4973.43 1344.68 S 2795.62 E 5992569.98 N 479096.79 E 2.813 3086.93 7132.79 48.510 291.220 4979.90 5036.20 1319.85 S 2731.12 E 5992595.02 N 479032.37 E 1.638 3017.83 7226.45 50.870 289.640 5040.49 5096.79 1294.94 S 2664.19 E 5992620.14 N 478965.52 E 2.829 2946.42 7321.22 53.690 289.800 5098.46 5154.76 1269.64 S 2593.63 E 5992645.66 N 478895.04 E 2.979 2871.46 7416.56 53.370 289.380 5155.13 5211.43 1243.94 S 2521.40 E 5992671.60 N 478822.89 E 0.488 2794.79 7511.96 52.860 289.800 5212.39 5268.69 1218.36 S 2449.51 E 5992697.41 N 478751.09 E 0.640 2718.49 7607.81 52.380 289.400 5270.59 5326.89 1192.80 S 2377.76 E 5992723.18 N 478679.42 E 0.601 2642.33 7702.42 51. 740 290.350 5328.76 5385.06 1167.44 S 2307.59 E 5992748.77 N 478609.33 E 1.041 2567.72 7797.40 53.290 290.320 5386.55 5442.85 1141.25 S 2236.92 E 5992775.18 N 478538.74 E 1.632 2492.35 7893.47 55.240 289.480 5442.66 5498.96 1114.72 S 2163.60 E 5992801.95 N 478465.51 E 2.150 2414.37 7988.24 54.600 289.230 5497.13 5553.43 1089.01 S 2090.43 E 5992827.89 N 478392.42 E 0.709 2336.82 8083.79 54.010 288.940 5552.88 5609.18 1063.64 S 2017.09 E 5992853.49 N 478319.16 E 0.665 2259.23 8179.62 53.290 288.760 5609.68 5665.98 1038.70 S 1944.05 E 5992878.66 N 478246.20 E 0.766 2182.07 8275.39 52.350 289.270 5667.55 5723.85 1013.84 S 1871.91 E 5992903.75 N 478174.14 E 1.069 2105.78 8370.77 51.820 289.880 5726.16 5782.46 988.63 S 1801.01 E 5992929.18 N 478103.32 E 0.751 2030.53 .~ 8466.74 51.450 289.770 5785.73 5842.03 963.11 S 1730.23 E 5992954.93 N 478032.62 E 0.396 1955.29 8562.08 51 .590 289.560 5845.05 5901.35 938.00 S 1659.95 E 5992980.27 N 477962.41 E 0.226 1880.65 8657.15 50.940 289.370 5904.54 5960.84 913.29 S 1590.03 E 5993005.20 N 477892.57 E 0.701 1806.50 8750.89 49.840 289.410 5964.30 6020.60 889.31 S 1521.90 E 5993029.39 N 477824.53 E 1.174 1734.28 8815.00 49.840 289.410 6005.65 6061.95 873.03 S 1475.69 E 5993045.82 N 477778.37 E 0.000 1685.29 Projected Survey 18 April, 2003 - 15:37 Page2of3 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-088 Your Ref: AP/501032045002 Job No. AKZZ2306056, Surveyed: 16 March, 2003 ConocoPhillips Western North Slope All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 3S-08. Northings and Eastings are relative to 3S-08. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 3S-08 and calculated along an Azimuth of 110.000° (True). Magnetic Declination at Surface is 25.174 O(26-Feb-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 8815.00ft., The Bottom Hole Displacement is 1714.60ft., in the Direction of 120.609° (True). ~ Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 6465.61 6496.00 8815.00 4525.17 4551.00 6061.95 1444.61 S 1442.86 S 873.03 S 3135.24 E 3119.33 E 1475.69 E Tie On Point Window Point Projected Survey Survey tool prooram for 35-088 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) -' 0.00 87.00 0.00 87.00 87.00 8815.00 87.00 Tolerable Gyro (3S-08) 6061.95 AK-6 BP _IFR-AK (3S-08) 18 April, 2003 - 15:37 Page 3 of 3 DrillQuest 3.03.02.005 Sperry..Sun Drilling Services Western North Slope ConocoPhillips Kuparuk 35 Pad 35-088 MWD '---------- Job No. AKMW2306056, Surveyed: 16 March, 2003 Survey Report 18 April, 2003 Your Ref: API 501032045002 Surface Coordinates: 5993923.52 N, 476305.45 E (70023'40.3069" N, 150011' 34.0335" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 --~-"õ"" Surface Coordinates relative to Project H Reference: 993923.52 N, 23694.55 W (Grid) Surface Coordinates relative to Structure: 80.05 H, 149.80 W (True) Kelly Bushing: 56.3Oft above Mean Sea Level Elevation relative to Project V Reference: 56.30ft Elevation relative to Structure: 0.20ft 5per--'''''Y-SUr-, DRILL.ING seRVIc:es A Halliburton Company Q) C) (jJ \ D ...c::.. Survey Ref: svy2014 CA Sperry-Sun Drilling Services Survey Report for Kuparuk 35 Pad - 3S-088 MWD Your Ref: AP1501032045002 Job No. AKMW2306056, Surveyed: 16 March, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6465.61 31.720 274.560 4468.97 4525.27 1431.448 3140.07 E 5992482.13 N 479440.97 E 3440.29 Tie On Point 6496.00 31.800 278.450 4494.81 4551.11 1429.638 3124.19 E 5992484.00 N 479425.09 E 6.742 3424.74 Window Point 6531.87 32.070 281.230 4525.26 4581.56 1426.38 8 3105.50 E 5992487.30 N 479406.41 E 4.168 3406.07 6563.34 32.610 281.060 4551.84 4608.14 1423.138 3088.98 E 5992490.60 N 479389.90 E 1.740 3389.43 6657.94 34.770 285.860 4630.57 4686.87 1410.878 3038.00 E 5992503.03 N 479338.96 E 3.623 3337.33 6754.10 37.570 286.230 4708.18 4764.48 1395.188 2983.4 7 E 5992518.89 N 479284.48 E 2.921 3280.72 ---..--/....... 6848.84 41.540 286.900 4781.22 4837.52 1377.968 2925.66 E 5992536.29 N 479226.72 E 4.214 3220.51 6944.08 44.600 287.490 4850.78 4907.08 1358.738 2863.53 E 5992555.72 N 479164.66 E 3.241 3155.56 7039.42 47.000 290.030 4917.25 4973.55 1336.728 2798.84 E 5992577.93 N 479100.04 E 3.159 3087.24 7132.79 48.510 291.650 4980.02 5036.32 1312.138 2734.25 E 5992602.73 N 479035.53 E 2.065 3018.13 7226.45 50.870 289.970 5040.61 5096.91 1286.778 2667.49 E 5992628.30 N 478968.85 E 2.867 2946.73 7321.22 53.690 290.290 5098.59 5154.89 1260.97 8 2597.12 E 5992654.32 N 478898.56 E 2.988 2871.77 7416.56 53.370 290.590 5155.26 5211.56 1234.20 8 2525.28 E 5992681.32 N 478826.80 E 0.420 2795.10 7511.96 52.860 291.070 5212.52 5268.82 1207.078 2453.96 E 5992708.68 N 478755.57 E 0.669 2718.81 7607.81 52.380 290.770 5270.71 5327.01 1179.878 2382.81 E 5992736.10 N 478684.51 E 0.559 2642.65 7702.42 51.740 290.790 5328.88 5385.18 1153.408 2313.05 E 5992762.80 N 478614.84 E 0.677 2568.04 7797.40 53.290 290.780 5386.68 5442.98 1126.65 S 2242.59 E 5992789.76 N 478544.46 E 1.632 2492.69 7893.47 55.240 290.240 5442.78 5499.08 1099.34 S 2169.56 E 5992817.31 N 478471.51 E 2.080 2414.71 7988.24 54.600 290.030 5497.25 5553.55 1072.64 S 2096.74 E 5992844.24 N 478398.78 E 0.699 2337.16 8083.79 54.010 289.970 5553.00 5609.30 1046.10 S 2023.82 E 5992871 .01 N 478325.95 E 0.620 2259.56 8179.62 53.290 289.240 5609.80 5666.10 1020.20 S 1951.12 E 5992897.14 N 478253.32 E 0.970 2182.38 8275.39 52.350 289.710 5667.67 5723.97 994.76 S 1879.18 E 5992922.81 N 478181.47 E 1.057 2106.08 8370.77 51.820 287.210 5726.29 5782.59 970.93 S 1807.81 E 5992946.86 N 478110.18 E 2.141 2030.87 8466.74 51 .450 288.750 5785.86 5842.16 947.71 S 1736.25 E 5992970.31 N 478038.68 E 1.316 1955.67 --" 8562.08 51.590 288.870 5845.18 5901.48 923.64 S 1665.60 E 5992994.60 N 477968.11 E 0.177 1881.05 8657.15 50.940 286.150 5904.68 5960.98 901.33 S 1594.89 E 5993017.14 N 477897.47 E 2.334 1806.98 8750.89 49.840 286.110 5964.44 6020.74 881.27 S 1525.52 E 5993037.42 N 477828.16 E 1.174 1734.93 8815.00 49.840 286.110 6005.79 6062.09 867.67 S 1478.44 E 5993051.17 N 477781.14 E 0.000 1686.04 Projected Survey 18 April, 2003 - 15:28 Page 2 of 3 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Kuparuk 38 Pad - 38-088 MWD Your Ref: API 501032045002 Job No. AKMW2306056, Surveyed: 16 March, 2003 ConocoPhillips Western North Slope All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 3S-08. Northings and Eastings are relative to 3S-08. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 3S-08 and calculated along an Azimuth of 110.000° (True). Magnetic Declination at Surface is 25.174°(26-Feb-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 8815.00ft., The Bottom Hole Displacement is 1714.25fl., in the Direction of 120.408° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 6465.61 6496.00 8815.00 4525.27 4551.11 6062.09 1431.44 S 1429.63 S 867.67 S 3140.07 E 3124.19 E 1478.44 E Tie On Point Window Point Projected Survey Survey too/prOgram for 35-088 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) --- 0.00 87.00 0.00 87.00 87.00 8815.00 87.00 Tolerable Gyro (3S-08 MWD) 6062.09 MWD Magnetic (3S-08 MWD) 18 April, 2003 - 15:28 Page 3 0£3 DrillQuest 3.03.02.005 ) Conoc6PhiUips ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Scott Lowry Phone (907) 265-6869 Fax: (907) 265-1535 Email: scott.l.lowry@conocophillips.com April 17, 2003 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well 3S-08B Dear Sir or Madam: Phillips Alaska, Inc. hereby requests that 3S-08B be pennitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on 3S-08B approximately May 10,2003. Please tind attached form 10-403 and other pertinent information 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. Production Casing Description 7. Production 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. Details on all wells within ~ Inile of 3S-08B at the surface casing shoe (N/ A) If you have any questions or require further information, please contact Scott Lowry at 265-6869, or Randy Thomas at 265-6830. Sincerely, ~. Scott Lowry Drilling Engineer I RECEIVED APR 1 7 Z003 cc: 3S-08B Well File Randy Thomas Sharon Allsup-Drake ATO-1576 A TO-1530 Alaska Oil & Gas Cons. Commission Anchorage ORIGINA~ ) ) 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown D D D D Repair well D D Perforate D D D Alter casing D D Abandon Suspend Plug Perforations Stimulate Change approved program Pull Tubing Perforate New Pool 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): 23.5' RKB 8. Property Designation: ADL 380107 I ALK 4624 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 8815' 6062' 8561' Casing Length Size Structural 4. Current Well Class: Development 0 Stratigraphic D Exploratory D Service D 9. Well Name and Number: 3S-088 J;/~~ Lhjzs ~q'Q5 Variance D Annu.a,r Dispos.0 Time Extension D Other D Re-enter Suspended Well D 5. Permit to Drill Number: 203-043 6. API Number: 50-103-20450-02 10. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): 5901' MD TVD Burst Perforation Depth TVD (ft): 5858' - 5881' Packers and SSSV MD (ft): packer @ 8398', nipple @ 495' 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D Conductor 841 30" X 16" Surface 42391 9.625" Intermediate Production 87781 7" Liner 108' 108' 4263' 2662' 8802' 6053' Perforation Depth MD (ft): 84921 - 85291 Packers and SSSV Type: Baker SAB-3 packer, Camco 'DS' nipple 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch D Tubing Size: 3.5" 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 5/10/2003 Date: Contact Printed Name R. Thomas \ '--~ \~ Title Kuparuk Drilling Team Leader Phone 265-6830 COMMISSION USE ONLY Signature Conditions of approval: Notify Commission so that a representative may witness Plug IntegrityD BOP Test D Mechanical Integrity Test D Location Clearance D Other: Subsequent Form Required: D;L \>t) ~ 'Q ~ 0- t"\ ~ \.J \ () \' '¿J \~ ~c;..C\ \ ~ P BY ORDER OF Approved by: ~ '--' Ú- ~ ~L t../L. COMMISSIONER THE COMMISSION Form 1 0-403 Revised 2/2003 nRIGINAL Collapse Tubing Grade: L-80 Tubing MD (ft): 8430' Service D Plugged D WINJ D Abandoned D WDSPL D Scott Lowry 265-6869 ..,. If? Ið "$ Date Sundry Number: ~'o3 - /d-d- f(CCCIVED APR 1 7 2003 Alaska Oil & Gas Cons. Commission Anchorage Date: y/2fJ/P) SUBMIT IN DUPLICATE ) ) NOTE TO FILE 35-088...203-043...303-122 Request for Annular Disposal Approval Summary ConocoPhillips (ConPPCo) has requested approval for annular disposal on the subject well. This is the 4th well on Drill Site 3S that ConPPCo has sought approval for annular disposal. They have submitted the required information. This document analyzes the information and recommends approving their request. Operational History 3S-088 is 5th development well on Drill Site 3S. This drill site is developing the Palm discovery. Offset Well Information NA-No offset wells were identified withing ~ mile of the surface casing shoe of 3S-08B. Well 35-088 Information The surface casing was set when the original wellbore was drilled in early March 2003. In the case of 3S-08, it is noted that over 160 bbls of cement were circulated. Based on spreadsheet calculations, gauge plus 111 % XS cement was left in the well. It is indicated that the surface casing is adequately cemented. The casing was successfully pressure tested prior to drillout. When tested, the formation did not leak off at about 17.9 ppg EMW. During the 10-minute observation period, the pressure dropped about 515 psi. The well was drilled into the Kuparuk reservoir and the· well was plugged back twice before the 7" casing string was set and cemented. On the injectivity test, the pressure builds steadily to about 800 psi when it sharply breaks and a stabilized injection pressure was developed between 820 and 780 psi. After pumping was stopped, a 180 psi drop was recorded after 1 minute with a stabilized pressure of about 420 psi being reached by the end of 5 minutes and holding for the remainder of the observation period. The pressure plots for 3S-08 are similar to those presented for the other wells, although the pump in pressure is one of the highest of any of the wells analyzed to date. Geologicallnformation This well lies within the Palm development area, which is located within the western margin of the Kuparuk River Unit as defined by the Eighth Expansion of the Unit Area approved by the Division of Oil and Gas on September 26, 2002. The Palm development area is also situated within the boundary of the Kuparuk River Unit aquifer exemption issued by the EPA. In well 3S-08, the base of the permafrost lies at approximately 1,550' TVD, and the West Sak Sands lie between approximately 2,000' and 2,460' TVD. The 9-5/8 inch casing shoe is set in the Colville Shale at 4,263 MD, more than 100' TVD below the base of the West Sak Sands. In the nearby Palm #1 exploratory well (renamed 3S-26), the Colville Shale is several thousand feet thick, and is composed of very soft to moderately firm claystone, mudstone and siltstone, with minor sand and rare conglomerate. In the M:\tommaunder\ Well Information\By Subject\Annular Disposal\030421_ 203-043--KRU _ 3S-08A _ AD.doc ) ) Geologic Considerations section of Note to File for well 3S-07, Bob Crandall notes that this disposal interval has low mechanical strength, and that the sands are minor, low permeability, low in volume, and frequently hydrocarbon-bearing. He also notes that the Colville Shale has a long track record of successfully receiving annular disposal in the Alpine, Meltwater, Tarn and Kuparuk River Unit areas. Recommendation Based on the presented information, we recommend that Conoco hillips' request for annular disposal in 3S-08B (203-0043) be approved. kð-W\~J' ~ Tom Maunder, PE Steve Davies Sr. Petroleum Engineer Petroleum Geologist M:\tommaunder\ Well Information\By Subject\Annular Disposal\030421_ 203-043--KRU _ 3S-08A_ AD.doc ) ) Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. b. The depth to the base of freshwater aquifers and permafrost, if presen 1. 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. d. A list of all publicly recorded wells within one- quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. 3S-08B No aquifers / Base Permafrost = +/- 1546' TVD RK.B A,1iA¡.~ ¡;e>i.4'k/_~~f tk:. ,RI¿¡¿ .4ß'i ttiey l:~<.rltf¡"~ :4~ ¡a-<-"l /~ ~¿j.t;:...4I7~~. "ß From the 9 5/8" shoe to the cement top all that is open is interbedded claystone, siltstone and shale with occasional minor non-hydrocarbon bearing sands. R~v,.¿·u.> ð AIltvD ~. /1?~1.~:~ ¿4~/r-4 þ/l ~\A"¡ '-/)"4 ~~G-r:t?f7.~ p3 o-(.....<-~..'--f-.!.. tiI¿1--:J-h:- ¿Vl7!'1 Þ-. ð~"ÝU4 ~ ~~_' . d c~~fcr.t,¡¿,. 0'>'Jdcl.:Sh>7-u£!/$I/Irh>-"<-. o r:'f4i'lb~.A .. (j /¿>..). See attached map indicating wells within 1/4 mile. There are no water wells within 1 mile. ()J<. ß e. Identify the types and maximum volume of Types of waste can be drilling mud, drilling waste to be disposed of and the estimated density cuttings, cement-contaminated drilling mud, of the waste slurry. completion fluids, diesel, formation fluids associated with the act of drilling a well, domestic waste water, and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. f. An estimate of maximum anticipated pressure at Maximum anticipated differential pressure at the outer casing shoe during annular disposal casing shoe during disposal operations is 1956 psi. operation and calculations showing how this See attached calculation page. value was determined. g. Details that show the shoe of the outer casing is See attached cementing 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 strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations. See attached casing summary sheet and calculation page. 1. Any additional data required by the Commission NA to confirm containment of drilling wastes. ') ') 3S-08B Pressure Calculations for Annular Disposal DET AILS: I- (I,) (¡) "'C co -0 (I,) co ..c (I,) ..c ïj) ïj) a.. 0 a.. 1.0 0 CV') 1.0 Q) ..-- CV') c: + ..-- ëi5 + co ~ E ü ëo "èij ëñ a.. a.. lô ..-- ...- ~ ..-- ..- ó ó ~ (/) (/) co co C9 C9 ........ ......... ....... ...... ......... Q) TOC c: :.ä :::¡ I-- ~ ~ Q) c: "èij co Ü t-.. - III L ~ ¢=9-5/8" 40 lb/ft, L-80 BrC casing @ 4263 ft MD (2662 ft TVD) Pburst = 5750 psi, @ 85%: Pburst85(% = 4888 psi Estimated Top of Cement @ 7692 ft MD (5379 ft TVD) (7" csg x 8-1/2" Open hole annulus) ¢:::3-l/2" 9.3 lb/ft L-80 tubing to 8430 ftMD I packer at 8398' MD ¢=7" 26 lb/ft, L-80, BTC casing @ 8802 ft MD (6053 ft TVD) Peollapse = 5410 psi, @ 85%: Peollapse85% = 4598 psi ASSUMPTIONS: · Maximum injection pressure, P Applied = 1500 psi · Maximum density of injection fluid is 12.0 ppg. · Pore pressure at 9-5/8" casing shoe is 0.4525 psi/ft · Injection gas pressure is 0.11 psi/ft + 1350 psi header pressure CALCULATIONS: Maximum pressure at 9-5/8" shoe: Pmax = PHydrostatie + P Applied - PFonnation Pmax = 12.0 (0.052) (2662)+ 1500 - 0.4525 (2662) Pmax = 1956 psi Maximum fluid density to burst 9-5/8" casing: Pburst85% = PHydrostatie + P Applied - PFom1ation 4888 = MWmax (0.052) (2662) + 1500 - 0.4525 (2662) MWmax = 33.2 ppg Maximum Fluid Density to Collapse 7" Casing: p eollapse85% = PHydrostatic + P Applied - P GasGradient - PHeader 4598 = MWmax (0.052) (5379) + 1500 - (0.11) (5379) - 1350 MWmax = 18.0 ppg TUBING (25-8429, 00:3.500, 10:2.992) Anchor Nipple (8397-8398, 00:4.730) PACKER (8398-8403, 00:5.956) NIP (8422-8423, 00:3.960) WLEG (8429-8430, 00:4.510) Perf (8492-8529) ) Con()coPhilupsAlaska:,..ln<;. [] I LJ Reference Log: RKB 23.49' Last Tag: 8561 Last Tag Date: 4/1/2003 Casing String - ALL STRINGS Description Size PRODUCTION 7.000 SURFACE 9.625 CONDUCTOR 16.000 Tubing String - TUBING Size I Top 3.500 25 Perforations Summary Interval I TVD I Zone I Status 1Ft SPF I Date I Type I Comment 8492 - 8529 5858 - 5881 C-4 37 6 3/28/2003 ¡PERF 2.5" HSD PJ Gas Lift Mandrels/Valves St MD TVD Man Man Mfr Type 1 4007 2557 CAMCO KBUG 2 5687 3781 CAMCO KBUG 3 6572 4615 CAMCO KBUG 4 7487 5254 CAMCO KBUG 5 8283 5728 CAMCO MMG Other ()Iugs, equip., etc: - JEWELRY Depth TVD Type 28 28 HANGER 495 493 NIP 8335 5760 SLEEVE-O 8382 5789 PBRlSEAL 8397 5799 Anchor Nipple PACKER BAKER PACKER SAB-3 EXTENSION BAKER MILLOUT EXTENSION NIP CAMCO '0' NIPPLE W/2.75" NO GO PROFILE WLEG BAKER PUMPOUT SUB TIL KRU 3S-08B API: 501032045002 SSSVType: NIPPLE Well Type: PROD Orig Completion: Last W/O: Annular Fluid: Ref Log Date: TO: 8815 ftKB Max Hole Angle: 66 deg @ 2450 Top 27 29 29 Bottom 8802 4263 108 Bottom 8429 TVD 5818 Wt 9.30 V Mfr V Type V OD Latch GLV GLV GLV GLV OV 1.0 1.0 1.0 1.0 1.5 35-088 Angle @ TS: 51 deg @ 8494 Angle @ TO: 50 deg @ Rev Reason: Tag, PERF, GLV design Last Update: 4/3/2003 TVD 6053 2662 108 Wt 26.00 40.00 62.50 Grade L-80 L-80 H-40 Thread BTCM BTCM WELDED I Grade I L-80 Thread EUE8RD BK-5 BK-5 BK-5 BK-5 RKP Port TRO Date Vlv Run Cmnt 0.125 1328 4/2/2003 0.156 1342 4/2/2003 0.188 1357 4/2/2003 0.250 1444 4/2/2003 0.250 0 4/1/2003 Description FMC 3.5 GEN 5 TBG HANGER CAMCO 'OS' NIPPLE W/2.875" NO GO PROFILE BAKER CMU SLIDING SLEEVE W/CAMCO 2.813 NO GO PROFILE - OPEN BAKER PBR/80-40 SEAL ASSEMBLY KBH-22 ANCHOR TUBING SEAL NIPPLE 8398 5799 8403 5802 8422 5814 8429 5818 8430 5819 General Notes Date Note 3/18/2003 TREE: FMC / GEN 5/5M TREE CAP CONNECTION: TO 5.75" ACME W/3.5" EUE8RD ID 3.500 2.875 2.813 2.980 3.000 3.250 3.720 2.750 2.990 2.992 ') ) Casing Detail 9 518" Surface Casinq øwPHILLlPS Alaska, Inc. :~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 1 to 2 2 Jts Nabors 7ES RT to Lnd Ring LID groove center(Load shoulder= 29.18') ****Casing Landed on slips**** 9-5/8" 40# L-80 BTC Csg Weatherford Model 402 Float Collar (00 10.64", 108.865") 9-5/8" 40# L-80 BTC Csg Weatherford Model 303 Float Shoe (00 10.64", 108.865") Jts 3 to 110 108 Jts Bottom of Shoe I TO 12 1/4" Surface Hole 9-5/8" Shoe @ 4263' MD 2,662' TVD 12-1/4" T.D. @ 4276' MD 2667' TVD RUN TOTAL 14 BOWSPRING CENTRALIZERS - 2 on jt.#1 (10' above Shoe on stop ring and over collar) 1 on Jt. #2 (On stop ring 10' below Float Collar) 1 per jt on Jt #3 - #13 (Total of 14 centralizers & 2 Stops) Total of 115 Jts. On tally Last 5 joints in shed stay out jts #111-#115 Total of 125 Jts. On location Use Best-a-Life 2000 pipe dope MU torque 8,400 ft/lb Remarks: Up Wt - 160k On Wt - 70k ConocoPhillips Alaska Casing Report Legal Well Name: 38-08 Common Well Name: 38-08 Event Name: ROT - DRILLING Report #: Start: 1 2/24/2003 General Information String Type: Surface Casing Hole TVD: 2,667.0 (ft) Ground Level: (ft) Circ Hours: 3.00 (hr) Permanent Datum: KB-Datum: CF Elevation: Mud Lost: Rotary Table 56.39 (ft) (ft) (bbl) Hole Size: Water TMD: Liner Overlap: KB to Cutoff: 12.250 (in) (ft) (ft) 28.63 (ft) Casing Flange I Wellhead Manufacturer: FMC Hanger Model: Actual TMD Set: 4,262.95 (ft) Model: Gen V Packoff Model: Integral Casing Detail Item Size Weight Grade Drift Threads JTS Length Top MU Torq. THD Manufacturer (in.) (Ib/ft) (in) (ft) (ft) (ft-lbf) Casing 9.625 40.00 L-80 8.679 BTC 108 4,153.26 28.63 N Float Collar 40.00 L-80 8.679 BTC 1.50 4,181.89 Y WEATHERFORD Casing 9.625 40.00 L-80 8.679 BTC 2 77.86 4,183.39 y Float Shoe 40.00 L-80 8.679 BTC 1.70 4,261.25 y WEATHERFORD 4,262.95 Non-Integral Casing Accessories Accessory Manufacturer Number Spacing (ft) Bowspring Centralizer Bowspring Centralizer Bowspring Centralizer WEATHERFORD WEATHERFORD WEATHERFORD 2 1 11 Remarks Average MU torque first 10 joints = 8400 ft-Ibs Thread locked shoe track [3 jts] Used Jet Lube Run -N- Seal pipe dope Page 1 of 2 Spud Date: 2/25/2003 Report Date: 3/2/2003 End: Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: 4,276.0 (ft) 125 (Ibs) 66.14 (0) 5.50 (days) -" Top Hub/Flange: (in) /5,000 (psi) BTM Hub/Flange: (in) 15,000 (psi) Model Condo Max OD MinlD Comp. Name (in) (in) \JEW 9.625 8.835 95/8" 40# L-80 \JEW 9.625 8.835 Float Collar \JEW 9.625 8.835 95/8" 40# L-80 \JEW 9.625 8.835 Float Shoe -'" Interval How Fixed Top (ft) Bottom (ft) 4,224.0 4,252.0 Stop Ring 4,192.0 4,192.0 Stop Ring 3,760.0 4,143.0 OverCollar Printed: 4/17/2003 9:30:48 AM ConocoPhillips Alaska Casing Report Legal Well Name: 38-08 Common Well Name: 38-08 Event Name: ROT - DRILLING Spud Date: 2/25/2003 Report Date: 3/2/2003 End: Report #: 8tart: 1 2/24/2003 Remarks Operational Detail: RU 9 5/8" slips, elevator,tiII up tool, long bails and GBR tongs. Held safety and opts meeting with crew. Mu 9 5/8" shoe track and circ to check floats, all joints 40#, L-80 BTC casing. RIH, set down 20K @ 1790' (46 jts ran) Wash down from 1775' to 2006' - 308 gpm /387 psi slight effort except for 1964' to 1966' - 30 min to wash 2'. PUW 105K SOW 70K. RIH to 4235', (104) jts total- no problems. MU landing joint and land casing in wellhead. Casing stuck 3' from landed in wellhead. Installed FMC slips and transition nipple. Page 2 of 2 ~ ~ Printed: 4/17/2003 9:30:48 AM ') ) .. . '. .. . . . . . : . . . . ... . . . . . .. . ..... .., . .... . .... .. . .. . . . ,". . . . . .. ... ..... ..Conoco~hilliPšAI~9~~.. ··...qerhentilig. .Repört Legal Well Name: 38-08 Common Well Name: 38-08 Event Name: ROT - DRILLING Hole Size: 12.250 (in) TMD Set: 4,263 (ft) Date Set: 3/1/2002 Csg Type: Surface Casing Csg Size: 9.625 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Report #: 8tart: 1 2/24/2003 Spud Date: 2/25/2003 Report Date: 3/2/2003 End: ," iC~rJ1ent Job Type: ~rirn~ry . ·.SqUeezeOpen Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Squéeze Casing' Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Jerry Culpepper Cmtd. Csg: Rot Time Start: : Rec Time Start:01 :30 Time End: : Time End: 06:50 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 20.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 160 (Ibs) Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Reciprocating . .. . i'ipeMo"ernent Max Torque: (ft-Ibf) Drag Down: 70 (Ibs) Type: Cement Casing Volume Excess %: 178.00 Meas. From: 160 Time Circ Prior To Cementing: 3.25 Mud Circ Rate: 336 (gpm) Mud Circ Press: 500 (psi) Start Mix Cmt: 04:55 Start Slurry Displ: 04:56 Start Displ: 06:39 End Pumping: 07:30 End Pump Date: 3/1/2003 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 7.80 (bbl/min) 8.00 (bbl/min) Y 541 (psi) 1,100 (psi) 2 (min) Y Type: Non-Disp. LS Density: 9.5 (ppg) Vise: 49 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 160.00 (bbl) Ann Flow After: N Mixing Method: recirc Density Meas By: densometer PV/yP: 22 (cp)/16 (lb/100ft2) Gels 10 sec: 5 (lb/100ft2) Gels 10 min: 8 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.5 (ppg) Volume: 298.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) To: (ft) Description: CW100 Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 4/17/2003 9:30:55 AM ) ) ... ·COnbêôRhilHps~Alaskâ. . . ... . .. .. .. ..... .... ...... . . .. . ... . . .. ". . . ... .. .. . Cerni!nti:ng.Repott Legal Well Name: 38-08 Common Well Name: 38-08 Event Name: ROT - DRILLING Report #: Start: 1 2/24/2003 Spud Date: 2/25/2003 Report Date: 3/2/2003 End: Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Slurry Data Fluid Type: LEAD Slurry Interval: 1,676.00 (ft}ro: (ft) Water Source: Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) ... . . . .. . ... ... . '. . . : ... . . .. . . ·StcageNo: 1Sh.írrYNo:3 of4 Description: ASLite Cmt Vol: 506.0 (bbl) Slurry Vol:664 (sk) Class:G Density: 10.70 (ppg) Yield: 4.28 (ft3/sk) Water Vol: 307.0 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: 19.39 (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Stage :No: 1 ~llIrryN():<30f. 4.. Additives D79 S001 D46 D65 D124 D53 D44 Concentration Units 1.50 %BWOC 1.50 %BWOC 0.60 %BWOC 0.50 %BWOC 43.10 %BWOC 30.00 %BWOC Stage No: 1 Slurry No: 4 of 4 Slurry Data Fluid Type: TAIL Description: LiteCRETE Slurry Interval: 4,263.00 (ft}ro: 1,676.00 (ft) Cmt Vol: 156.0 (bbl) Water Source: Slurry Vol:391 (sk) Test Data Thickening Time: 4.41 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) 9.00 %BWOW Class: G Density: 12.00 (ppg) Yield: 2.24 (frisk) Water Vol: 69.5 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: 7.45 (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 4/17/2003 9:30:55 AM ), 0) . . 0"" .... ... ...... . .. ... - . . . .. ..... ...... .. . .....". .", ::.::: . .... .,:".. ...... .. . :.. '. ", ConpcdPhilUpsÂlaska. Cel11enting·.A~p()ri . ..... .. .... 0"" ... . Páge$of3 Legal Well Name: 38-08 Common Well Name: 38-08 Event Name: ROT - DRILLING Report #: Start: 1 2/24/2003 8pud Date: 2/25/2003 Report Date: 3/2/2003 End: Slu~rY. ~o:.4of4 ... .~d~i~il'~S Trade Name . Typé Cöhbentrati.on 0.50 %BWOC 0.60 %BWOC 29.54 %BWOC 1.00 %BWOC 16.63 %BWOC D79 D46 D124 D65 D164 CéI!i;iI19Te$t . ... . . .. ..' ..... .. .. . ,.. "' . SI'1()eTesf. . Test Press: 2,500 (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 Tool: N Tool: N CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Line up to cementers - pumped 5 bbls of CW 100 - tested lines to 3000 psi. Pumped 45 bbls of CW 100 - dropped botton plug. Pumped 46 bbls of 10.5 ppg Mudpush XL with 2 gals of dye marker - 506 bbls of 10.8 ppg ASLite lead slurry and 156 bbls of 12.0 ppd Lite Crete tail slurry. Dropped top plug - dislpaced with 20 bbls of FW from cementers - switched to rig pups and displaced with 9.5 ppg mud - 279 bbls @ 8.0 bpm /230 - 838 psi - 11 bbls @ 6.0 bpm I 675 psi - 8 bbls @ 4.0 bpm / 541 psi. Bumped plugs to 1100 psi - floats held - CIP @ 0730. Had good returns throughout with 160 bbls of 10.8 ppg cement returns to surface. Pipe hung up with 260 bbls of lead cement around shoe, unable to land hanger per plan - 3' high - FS @ 4263', FC @ 4182. Printed: 4/17/2003 9:30:55 AM . , .... . .. ....... . . . :".".. .. :"" .... ;.". ": . '" .".. ... .,. .. ... . . .. .... ..:".... .:". ".':" ..... ";" ;. .. . Cpnþçø.Pliilli ~¡¡,.. ~1é1ska ..... . .... ...... ." .. ........ .... PtiUy.!Q:rilli r.gR~p()..t I JOB NUMBER ) EVENOTDCRODE 124 HRS PROG TMD I TVD I DFS 4,276.0 2,667.0 4.50 I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Nabors 7ES Kuparuk River 11,792.0 0 ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 2/27/2003 283,200 1 LEAKOFF AFE 10028567 I NEXT CASING 7.000 (in) @ 11,792.0 (ft) o ICUMCQSTI 0 PflMfCICa' . H2SLIME ES / 24 HR FORECAST MU bha #2, PU dp,test csg, drill cmt. PIT, drill 8 1/2" hole LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 2/28/2003 4,160.80 65.750 108.420 9.625 (in) @ 4,263.0 (ft) D~N~ITY(PP9) 9.50 'pp lecDI" I MUDDAT.AIÔAIL.Y COST 'I ,FV PVIYPGELSWLJHTHPF=CrtsoL 'OILIWAT %$a~dIM~TF:'h/pM 49 22/16 5/8 8.2/ 21 I /17.5 / ') WELL NAME SUPERVISOR David Burley CURRENT STATUS 3S-08 I RIG NAME & NO. N 1268 @ ppco.co Testing BOPE. FROM TO 00:00 00:45 00:45 01:15 01 :15 04:30 TROUBLE', ,SUB' RUNC PULD CIRC 04:30 06:45 CEMENT P 2.25 PUMP 06:45 07:45 CEMENT P 1.00 DISP 07:45 08:45 1.00 CEMENT P PULD 08:45 09:15 0.50 CASE T DH SFTY 09:15 11:30 2.25 CASE T DH NUND 11:30 15:00 3.50 CASE T DH OTHR 15:00 16:30 1.50 CASE P NUND 16:30 17:30 1.00 CASE T DH OTHR 17:30 20:30 3.00 DRILL P PULD 20:30 22:30 2.00 DRILL P PULD 22:30 00:00 1.50 DRILL T DH PULD } I REPT NO. I DATE 6 3/1/2003 I CUM. TANGO CUM INTANG WI MUD o CUM COST WI MUD 874,539 AUTH. LAST BOP PRES TEST dPERÄTI()~S$UMMÅRY PHAse DESCRIPTION SURFAC Run casing to 4235', MU landing joint and land casing in wellhead. SURFAC Lay down fill up tool and MU cement head. SURFAC Establish circ @ 3 bpm /360 psi, staged pumps up to 8 bpm / 660 psi, Circ and cond mud for cementing - reduced wt. f/ 9.7ppg t/ 9.5 ppg, vis f/ 248 to 49, PV fl 28 t/ 22, yp fl 52 t/ 16. Final circ rate 8.0 bpm / 500 psi last 100 bbls pumped with nutplug marker. PJSM with all parties. SURFAC Line up to cementers - pumped 5 bbls of CW 100 - tested lines to 3000 psi. Pumped 45 bbls of CW 100 - dropped botton plug. Pumped 46 bbls of 10.5 ppg Mudpush XL with 2 gals of dye marker - 506 bbls of 10.8 ppg AS Lite lead slurry and 156 bbls of 12.0 ppd Lite Crete tail slurry. SURFAC Dropped top plug - dislpaced with 20 bbls of FW from cementers - switched to rig pups and displaced with 9.5 ppg mud - 279 bbls @ 8.0 bpm /230 - 838 psi - 11 bbls @ 6.0 bpm / 675 psi - 8 bbls @ 4.0 bpm / 541 psi. Bumped plugs to 1100 psi - floats held - CIP @ 0730. Had good returns throughout with 160 bbls of 10.8 ppg cement returns to surface. Pipe hung up with 260 bbls of lead cement around shoe, unable to land hanger per plan - 3' high - FS @ 4263', FC @ 4182. SURFAC Flush Conductor and flowline RD cement head. SURFAC Held safety meeting in preparation for setting slips on casing. SURFAC Disconnect dresser sleeve and cut 14 inches off of 20" riser to provide clearance for slip installation. SURFAC PU surface stack - center pipe and install slips - set slips with 120K string wt. Rough cut 9 5/8" casing - set stack down and LD landing jt - casing hanger and cuttoff joint. SURFAC ND 20" Diverer system and riser. SURFAC Assist welder in cellar untill 9 5/8" transition nipple in place on casing. SURFAC Clear casing equipment from rig floor - change out long bails to drilling bails - install 13 5/8" drip pan extension. Changing pump liners to S". SURFAC PU and stand back 45 joints of drill pipe, Actual time midnight. SURFAC Loss of efficiency due to using mousehole by ironroughneck because of cooling transition nipple in cellar. 24 HR SUMMARY: Run casing, cond mud and cement 95/8" surface csg. casing stuck 3' high with FS @ 4263', FC @ 4182'. Lift stack, set slips and cut off casing. NU Divertor, weld on FMC transition nipple. Pick up drill pipe. Printed: 4/17/2003 9:31: 19 AM ) ) 3S-08 . . ". . . . . . . . ... . '" "... .. - . . ...." . .... . . .. . . ... ...."... o ..' ... .. ... .. .. .... .. .... ........ .. . .. . . . . . . .. ." . ...... ...... . .... :" . : .. :".:. :.,:" :.... '.: .:.." :.;":.' ......: ",. "., C()~oCÔÞl1il.lips,Alå$kå . ··l)åily[jriIIi119R~p()rt I JOB NUMBER I EVE~DC~DE 124 HRS PROG I T~~276.0 WELL NAME ITVD I DFS 2,667.0 4.50 I REPT ~O. I DATE 3/1/2003 ... PERSONNEL DATA NO. HOURS COMPANY 1 Sperry Sun 31 Baroid 5 APC . SERVICE ·····NO. · HOURS 4 2 2 Fuel Water, Drilling MATERIALSl CONSUMpTION ON HAND ··ITEM 10,642 Fuel (camp) 706 Water (Camp) RESERVOIR AND INTËRVALDÄTA ZÓNE-rOP ëi\SE 3S-08 730 3 750 Printed: 4/17/2003 9:31: 19 AM PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Nabors 7es Date: 3/2/2003 I Volume}'!put I Pump used: I #1 Mud Pump ¡... St k ~ . _roes T .., I Pumping down I annulus and DP. ~_ I Hole Depth 4,296 Ft-MD 2,674 Ft-TVD ...1 Well Name: 38-08 I Rig: Drilling Supervisor: David Burley Type of Test: I Casing Shoe T~st LOT/FIT Hole Size: 8-1/2" i ... RKB-CHF: 2615.0 Ft Casina Size and Description: Casina Test Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight: BlockslTop Drive Weight: Estimates for Test: Casing Shoe Depth 4,263 Ft-MD 2,662 Ft-TVD 9-5/8" 40#/Ft L-80 BTC 9.5 ppg 24.0 Lb/100 Ft2 2,500 psi 90,000 Lbs 26,000 Lbs 2.8 bbls ...1 Pressure IntearitvTest Mud Weight: 8.9 ppg Mud 10 min Gel: 5.0 Lb/100 Ft2 Rotating Weight: 92,000 Lbs BlockslTop Drive Weight: 26,000 Lbs Desired PIT EMW: 18.0 ppg Estimates for Test: 1260 psi 1.4 bbls EMW = Leak-off Pressure + Mud Weight = 1240 0.052 x TVD 0.052 x 2662 + 8.9 EMW at 4263 Ft-MD (2662 Ft-TVD) = 17.9 ppg 3000· -- 2500 - 2000 -- UJ ~ ::::> ~ 1 500 . UJ ~ a.. ---- 1 000 - 500 - o o 2 Barrels ~CASING TEST ~LEAK-OFF TEST Changed over to new 8.9 ppg L8ND mud after casing test. Comments: PIT 15 Second Shut-in Pressure, psi 1000 - Lost 35 psi during test, held = 98.6% of test pressure. .~ If· .~...." t J,~ 4 0 5 10 15 20 25 30 Shut-In time, Minutes o PIT Point Volume/Stroke I 0.0577 Bbls/Strk I ~ I i Casing Test Pumping Shut-in Strks psi Min psi o 0 0 2560 4 102 1 2560 8 247 2 2560 12 416 3 2550 16 574 4 2550 20 730 5 2540 24 849 6 2540 28 974 7 2540 32 1108 8 2540 36 1270 9 2540 40 1401 10 2530 44 1570 15 2530 48 1748 20 2530 52 1920 25 2525 56 2104 30 2525 60 2295 64 2480 66 2560 I'" Pump Rate: 9.0 Strk/min ... o 75 148 231 321 412 504 594 669 733 788 851 908 972 1031 1091 1146 1210 1240 Volume Bled Back _l::SblS Pressure Integrity Test Pumping Strks psi o 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 35 Shut-in Min psi o 1150 0.25 1000 0.5 780 1 675 1.5 610 2 600 2.5 580 3 575 3.5 560 4 560 4.5 550 5 540 5.5 535 6 530 6.5 525 7 520 7.5 520 8 520 8.5 515 9 515 9.5 515 10 515 ~ ~ Volume Bled Back tsbls ) ') Casing Detail 7" Intermediate Casiny Well: Date: ConocoPhillips Alaska Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH Jts 1 to 4 NABORS 7ES RKB to LOS FMC 11" X 7" Hanger 204 Jts 7" 26# L-80 BTCM Csg 7" Weatherford Sure-Seal Model 402 Float Collar 4 Jts 7" 26# L-80 BTCM Csg 7" Weatherford Sure-Seal Model 303 Float Shoe 25.79 3.43 8602.15 1.30 168.02 1.48 Jts 5 to 208 TD of 8-1/2" hole @ 8815' MD 6062' TVD 7" Shoe @ 8802' MD 6054' TVD Total Centralizers 1- 7" Bow cent.! stop rings 3'-5' above FS jt # 1 & 3'-5' below FC on jt # 4 Bowspring centralizer over collar on joints #2 , #3 and #5 thru #28 7" x 8-3/8" Centering guide on every jt. From #110 thru #114 (Total of 5) 7" x 8-3/8" Centering guide on every 3rd Jt. # 198, 201,204,207. (Total of 4) Totals: 29 Bowspring, 9 centering guides, 2 Stop collars Total of 301 jts.on location Total of 208 jts. Ran in hole Total out: 93 jts. Remarks: Up Wt = 260K Use "Run-N-Seal" pipe dope Drifted to 6.151" MU Torque 7,200 ft/lb On Wt = 90K Block Wt= 30K ConocoPhillips Alaska Casing Report Legal Well Name: 38-08 Common Well Name: 38-08 Event Name: ROT - DRILLING Report #: 8tart: 2 2/24/2003 General Information String Type: Production Casing Hole TVD: 6,054.0 (ft) Ground Level: (ft) Circ Hours: 3.00 (hr) Permanent Datum: KB-Datum: CF Elevation: Mud Lost: Hole Size: Water TMD: Liner Overlap: KB to Cutoff: 8.500 (in) (ft) (ft) 25.79 (ft) Rotary Table 56.39 (ft) (ft) (bbl) Casing Flange I Wellhead Manufacturer: FMC Hanger Model: Actual TMD Set: 8,802.17 (ft) Model: Gen V Packoff Model: Item Integral Casing Detail Size Weight Grade Drift Threads JTS Length Top MU Torq. THD Manufacturer (in.) (Ib/ft) (in) (ft) (ft) (ft-Ibf) 7.000 6.151 1 3.43 25.79 7.000 26.00 6.151 204 8,602.15 29.22 7.000 1 1.30 8,631.37 7.000 26.00 6.151 4 168.02 8,632.67 7.000 1 1.48 8,800.69 Non-Integral Casing Accessories Casing Hanger Casing Float Collar Casing Float Shoe Accessory Manufacturer Number Spacing (ft) Bowspring Centralizer Centering Guides Centering Guides WEATHERFORD WEATHERFORD WEATHERFORD 29 5 4 Page 1 of 1 Spud Date: 2/25/2003 Report Date: 3/18/2003 End: Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: 8,802.0 (ft) (Ibs) 67.58 (0) 21.50 (days) "-' Top Hub/Flange: (in) 15,000 (psi) BTM Hub/Flange: (in) 15,000 (psi) Model Condo Max OD Min 10 Comp. Name (in) (in) - Interval How Fixed Top (ft) 8,800.0 4,263.0 106.0 Bottom (ft) 7,696.0 OverCollar 4,063.0 Floating 500.0 Floating Ran 208 joints 7",26#, L-80, BTCM, Landed shoe @ 8802.17', Float collar @ 8631.37', Ran casing 50/60 ft/min. from surface to 9-5/8" shoe @ 4263' and 30/40 ft/min. from shoe to T.D., Circulated 50 bbls mud every 20 joints & circulated btm's up every 35 joints, did not lose any mud while circulating, Pipe stuck on btm. after making up Dowell cmt. head. Printed: 4/17/2003 9:30:36 AM ) ') .. . . '" .. . . .... . ... ...". .... .... ........ ... '" .. . ...... . ...... ...... ...... ........ .. ..... . .... .. . ..... ......... .. . . ....... .. ..,. ..... . .... ... . ... .... . . :.. . :..: .." :": :":": .... . . :n.. "'. .. ":: '" .... .... ..... .... ............. ...... . . .. .. .. . . .. . :Con~??~hilliP~~lask* .···Cel1ienti rj9Fl~pôrt Legal Well Name: 38-08 Common Well Name: 38-08 Event Name: ROT - DRILLING Report #: Start: 6 2/24/2003 Spud Date: 2/25/2003 Report Date: 3/18/2003 End: Hole Size: TMD Set: Date Set: Csg Type: Csg Size: .. ..... '" . ...... .. .·ç~ri1~nt HQb OI"ypé: Prlm~~y SqÜeeiëÖpen HÓle .. . Hole Size: sa TMD: (ft) sa Date: sa Type: SCflJëaže Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cmtd. Csg: Production Casing Cement Co: Dowell Schlumberger Cmtd. Csg: Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Cementer: Pipe Movement: Stuck prior cmt . . .. .... . .. .". .: .:. ........... ........ :", . .", .I'jp~ rJlOV~nientl·· · ... Rot Time Start: : Ree Time Start: : Time End: Time End: RPM: SPM: Init Torque: Stroke Length: (ft-Ibf) (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Max Torque: (ft-Ibf) Drag Down: (Ibs) Type: Cement Casing Start Mix Cmt: Disp Avg Rate: (bbl/min) Returns: Volume Excess %: 75.00 Start Slurry Displ: Disp Max Rate: (bbl/min) Total Mud Lost: (bbl) Meas. From: Start Displ: Bump Plug: Y Cmt Vol to Surf: (bbl) Time Circ Prior End Pumping: Press Prior: 1,400 (psi) To Cementing: 4.00 End Pump Date: Press Bumped: 1,900 (psi) Ann Flow After: N Mud Circ Rate: 210 (gpm) Top Plug: Y Press Held: 5 (min) Mixing Method: Mud Circ Press: 800 (psi) Bottom Plug: Y Float Held: Y Density Meas By: Type: Non-Disp. LS Density: 11.6 (ppg) Visc: 48 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Seawater PVNP: 21 (cp)/21 (lb/100ft2) Gels 10 sec: 6 (lb/100ft2) Gels 10 min: 10 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 8.4 (ppg) Volume: 333.00 (bbl) Stage No: 1 Slurry No: 1 of3 Slurry Data Fluid Type: FLUSH Description: CW100 Slurry Interval: 4,599.00 (ftJT'o: 5,926.00 (ft) Cmt Vol: (bbl) Water Source: Slurry Vol: (sk) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol:30 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 4/17/2003 9:31:10 AM ) ) .. . ." .. ..... ."' 0""·.· ... ."..".......... ....... CQn()cbÞhillipSAI~~kél··. .. ",. .. .. . ... ..... ... .. . ... . ..... . "... .... .. ...... ......""0· ... Çementing. Flepørt Legal Well Name: 38-08 Common Well Name: 3S-08 Event Name: ROT - DRILLING Report #: Start: 6 2/24/2003 Spud Date: 2/25/2003 Report Date: 3/18/2003 End: . . ~t~geNo:1~lurrYNó:2of3 Slurry Data Fluid Type: FLUSH Description: MUDPUSH XL Class: Slurry Interval: 5,926.00 (ft)To: 7,696.00 (ft) Cmt Vol: (bbl) Density: 12.40 (ppg) Yield: (frIsk) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Slurry Data Fluid Type: TAIL Description: GasBlock Slurry Interval: 7,696.00 (ftVo: 8,802.00 (ft) Cmt Vol: 52.6 (bbl) Water Source: Slurry Vol:255 (sk) Class: G Density: 15.80 (ppg) Yield: 1.17 (frIsk) Water Vol: 31.3 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: 5.17 (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) B155 065 047 0600 Concentration 0.03 %BWOC 0.30 %BWOC 0.20 G P S 2.00 G P S Printed: 4/17/2003 9:31: 1 0 AM ) ) P~g~.3Öf .~ . . .. .. ....... ........ :.:.... .' .. .:."..:. . .. ".. .. . . . ..... ·C6nQCqÞhil/ip$..AI.a.skÇ1 . .. ..... ... ... .... . .... ".' . . ". ..". . ..".: : ".. ... .. .. .. ..... .. .... ... . Ø~rneöting: Ffeþort .... . Legal Well Name: 3S-08 Common Well Name: 3S-08 Event Name: ROT - DRILLING Report #: Start: 6 2/24/2003 Spud Date: 2/25/2003 Report Date: 3/18/2003 End: .·~~~ir1gTest . ·.$h()eTest. . l.iner ,.~þT~~~ . T est Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: .l.oQt~lJrv~Y iEVªh;'at~ón· CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Rig Dowell, Batch mix 30 bbls CW100 @ 8.3 ppg, 40 bbls MudPUSH @ 12.6 ppg, 255 sxs (52.6 bbls) @ 15.8 ppg GasBLOK wI Class G + .030%BWQC B155, .300%BWOC D65, 2.000 gal/sk D600G, .200 gal/sk D47, Pump 10 bbls CW100, Test lines to 3500 psi, Pump 20 bbls CW100, Drop #1 btm plug, Reload head, Pump 40 bbls MudPUSH at rate of 5.5 bpm at 740 psi, Drop #2 btm plug, Pump 52.6 bbls cmt at rate of 6.0 bpm at 850 to 650 psi, Shut down, Flush lines to rig floor with seawater, Drop top plug, Dowell Displace first 310 bbls seawater at rate of 7.0 bpm at 1200 psi until 26 bbls cmt around shoe, Slowed rate to 3.0 bpm @ 1400 psi & bumped plug wI total of 335.5.0 bbls seawater, Bumped plug wI 1900 psi, Bled back 2.5 bbls for a total of 333.0 total bbls displaced, CIP @ 1851 hrs 3/18/03, Had good circ. thru out job, Displaced entire job with Dowell. Casing stuck prior to start of cement job. Printed: 4/17/2003 9:31: 1 0 AM ) ') '" ... ..": :... . ".:':: ." ." '.: ...... ... .., .. : .. . . . . . . '. . . . . .. ... . : . .. ... .. . . . . ..' . .. . .. .. ..... ..... . .... . ..... ..... . .. . '. ... .... "." .". . Cc:>nøCò~hillips,Alaska . ··PaUY[jrUU.,S fleþc>tt ........ WELL NAME I JOB NUMBER I EVE~DC~DE 124 HRS PROG I REPT NO. I DATE 23 3/18/2003 I CUM. TANGO CUM INTANG WI MUD o CUM COST WI MUD 3,152,865 3S-08 SUPERVISOR I RIG NAME & NO. Mike Thornton/Larry Hill N1268@ppco.CO CURRENT STATUS Running Completion on 31/2" tubing 215 of 266 in hole.. 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Fin Running 31/2" Comp, test casing, set packer, ND BOP. 3/16/2003 321,183 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 17.83 10028567 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 3/16/2003 8,815.00 49.840 289.410 9.625 (in) @ 4,263.0 (ft) 7.000 (in) @ 8,817.0 (ft) 3/14/2003 DE:NSITY(ppg) 8.40 Ipp ECD INlUDDATADJ\ILYCpST 0 ICUMCO~tl 0 FV .PVNPGELS : WUHTHP ¡::Cfl"~~OL ()IL/W AT >%$andIMBT Ph/pM Pf/Mf . CI Ca H~SLIIV'.E ES 27 / I I I / / I TMD I TVD I DFS 8,815.0 6,062.0 21.50 I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Nabors 7ES Kuparuk River 11,792.0 0 ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD o AUTH. .. EUTIRUN. 3RR/ , BITS·'. . TYPE: '. . SERIAL NO. .JETSOFfTFA . HCM-605 7101484 15/15/14/14/14/ . . , " , ! DEPTH IN DATE IN . I·Ó;D·L~e~G·O~R 7,000.0 3/14/20030-0------ BIT OPERATIONS GPMLPAEssfpBIT HRs··1 24HrDIS,. I 24HrROplclJMHRSlcUMDEPt~lcUMR()P OPERATIONS SUMMARY TROUBLE SUB PHASE DESCRIPTION RUNC PROD Ran 7" casing from 1460' to 4237'. CIRC PROD CBU at 5 BPM. RUNC PROD Ran 7" casing from 4237' to 5041'. CIRC PROD Circulated 50 BBLs at 5 BPM. RUNC PROD Ran 7" casing to 5890'. CIRC PROD Circulated at 5 BPM. RUNC PROD Ran 7" casing to 6736'. CIRC PROD Circulated 50 BBLs at 5 BPM. RUNC PROD Ran 7" casing to 7375'. CIRC PROD Circulated at 5 BPM. RUNC PROD Ran 7" casing to 8802'. CI RC PROD CBU 460 units gas. OTHR PROD Rigged down casing fill up tool and made up cement head. Broke circulation and pulled 400,000 casing stuck on bottom. 3.00 CEMENT P PUMP PROD Rig Dowell, Batch mix 30 bbls CW100 @ 8.3 ppg, 40 bbls MudPUSH @ 12.6 ppg, 255 SXS (52.6 bbls) @ 15.8 ppg GasBLOK w/ Class G + .030%BWOC B155, .300%BWOC D65, 2.000 gal/sk D600G, .200 gal/sk D47, Pump 10 bbls CW100, Test lines to 3500 psi, Pump 20 bbls CW100, Drop #1 btm plug, Reload head, Pump 40 bbls MudPUSH at rate of 5.5 bpm at 740 psi, Drop #2 btm plug, Pump 52.6 bbls cmt at rate of 6.0 bpm at 850 to 650 psi, Shut down, Flush lines to rig floor with seawater, Drop top plug, Dowell Displace first 310 bbls seawater at rate of 7.0 bpm at 1200 psi until 26 bbls cmt around shoe, Slowed rate to 3.0 bpm @ 1400 psi & bumped plug wi total of 335.5.0 bbls seawater, Bumped plug w/1900 psi, Bled back 2.5 bbls for a total of 333.0 total bbls displaced, CIP @ 1851 hrs 3/18/03, Had good circ. thru out job, Displaced entire job with Dowell. Casing stuck prior to start of cement job. 0.50 CEMENT P PULD PROD Flushed stack and rigged down Dowell. 0.75 CASE P DEOT PROD Laid down landing joint and ran packott. Tested packott to 5000 psi. 0.25 CMPL TN P SFTY PROD Prejob safety meeting. FROM TO . HOURS . ·.CODE 00:00 03:30 3.50 CASE P 03:30 04:15 0.75 CASE P 04:15 05:30 1.25 CASE P 05:30 05:45 0.25 CASE P 05:45 07:15 1.50 CASE P 07:15 08:00 0.75 CASE P 08:00 09:00 1.00 CASE P 09:00 09:15 0.25 CASE P 09:15 10:00 0.75 CASE P 10:00 10:45 0.75 CASE P 10:45 13:00 2.25 CASE P 13:00 14:30 1.50 CASE P 14:30 17:00 2.50 CASE P 17:00 20:00 20:00 20:30 20:30 21:15 21 :15 21 :30 Printed: 4/17/2003 9:31 :53 AM ) -~) 3S-08 .. ..-.. . .. .. .. .. .. . ... .. . '" . . . .. .. .. . . . .. . . '" .. . . ". ....... .., ... ... .", ..... . . ... ....... . . . .. ". . . . ;"; ..... ... L .. ......... . ....... ""' . . . .. .. . : ,: : ....:. :....... ..........",. . '. ::.:." . . . .",.. .. ¡. p()íjºçt>Ph~1I ipS,· Alaska '" .. .. .. .. . . . . . . . . ..-. .. . . ... .. . . . .... .. ¡P~ily :[)r~Ui...g.a~port . I JOB NUMBER I EVENOTDCRODE 124 HRS PROG I TMD 8,815-.0 WELL NAME FROM· 21:30 OPERATIONS·SUMMARY . PHASE OES.CRIPTION ... . PROD RIH with Completion string on 31/2" tubing to 1112'. 24 HR SUMMARY: Finished Running 7" Csg to 8,802', Cemented casing, RIH with Completion string. . . .. . .' PERSONNEL DATA ......~()~ ...... . HÓUFlS. C()MPA~Y 2 Baroid 30 APC 5 GBR 4 . HOURS..·· Fuel Water, Drilling MAtERIALS/CONSUMPTION..·· . . ON HAND '.. ·ITEIVI· 13,475 Fuel (camp) 485 Water (Camp) RESERVOIR ÄNDINTERVALDAtA ZONE . . TOP . eAse 775 2.5 700 35-08 Printed: 4/17/2003 9:31:53 AM Well Name: Drilling Supervisor: 38-08 B I Rig: Mike Thornton PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Nabors 7ES I Date: 3/19/2003 Pump used: #1 Mud Pump . Type of Test: Annulus Leak Off Test for Disposal Adequacy Hole Size: IS-1/2" . · Casing Shoe Depth RKB-CHF: 27.0 Ft 4,263 Ft-MD 2,662 Ft- TVD Casina Size and Description: 9-5/S" 40#/Ft L-SO BTC Chanaes for Annular AdeQuacv Test Enter outer casing shoe test results in comments Casing Description references outer casing string. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing 00 at right. ~ Pumping down annulus. Hole Depth 7,696 Ft-MD 5,384 Ft-TVD Pressure IntearitvTest Mud Weight: 11.6 ppg Inner casing 00: 7.0 In. Desired PIT EMW: Estimates for Test: 17.8 ppg 858 psi 0.6 bbls ¡. I· EMW = Leak-off Pressure + Mud Weight = 820 0.052 x TVD 0.052 x 2662 + 11.6 EMW at 4263 Ft-MD (2662 Ft-TVD) = 17.5 PIT 15 Second Shut-in Pressure, psi 700 1000 -- ~....-.......... f t ~ \ -~ '\ 8 < '- uJ 0::: ::::> ~ 500 - uJ 0::: a.. o. o 2 4 5 6 0 5 10 15 20 25 30 Shut-In time, Minutes o PIT Point Barrels .....CASING TEST -+-LEAK-OFF TEST Comments: I Volume Input Volume/Stroke Pump Rate: ! Strokes ... 0.0585 Bbls/Strk ... 8.0j Strkfmin .. Casing Test Pressure Integrity Test Pum ing Shut-in Pumping Shut-in Strks si Min si Strks psi Min psi 0 0 0 0 780 1 4 250 0.25 700 2 8 375 0.5 650 3 12 430 1 600 4 16 510 1.5 55 5 20 600 2 51 \)-" 6 24 660 2.5 500 7 28 710 3 480 8 32 780 3.5 475 9 36 820 4 450 10 40 830 4.5 440 15 44 820 5 430 20 48 820 5.5 425 25 52 820 6 425 30 56 810 6.5 410 60 810 7 410 64 800 7.5 410 68 800 8 400 72 800 8.5 400 76 800 9 400 80 790 9.5 400 84 790 10 4C 88 780 ~ 92 780 96 780 i~- I \... Volume Bled Back _Bbls Volume Pumped 5.6 Bbls Volume Bled Back 0.8 -Sbls ANTI-COLLISION SETIlNGS COMPA", DETAILS WEU.P Alli DETAILS WEILDEfAILS :S-:un: +SI-S tEl-W Sonhing fulOlg urirude- Longitudo Slot PI:,¡¡: 3S·03 30.06 -149.32 5993923.52 476.J05.45 70' 23·.()J07}; 150' 11'3-U!33W KiA -1320 -1240 -1033 -827 --620 -413 -207 -0 270 -207 -413 --620 -827 -1033 -1240 -1320 1/4 Mile Radius of 3S-08 ... 9-5/8" Csg Pt (@ 4263'MD /2662' TVD) Interpolation Method:MD Interval: 2.00 Depth Range From: 4265.00 To: 4275.00 Maximum Range: 1??oo.00 Reference: Definitive Survey P~S:J:2InÇ. Kuparuk - Q;]cu!>tion Memod: Minhrum Cur,.= ~:~~ ~%~~PlIDe mot Surf=-: Ðlipiical + 0.<ing W =in;: Memod: RuI>s Based 3S-03 (Rig Sur",}» Par",,! Wcl4>a1h: 3S-03PB2 (Rig SurvO») T¡' on MD: 6465.61 o Rig: RKB = 55.8" MSL 55.3Oft Rd. Daum: V_S~ûon Origin ~~ ~~VD Ang]< +:s'J-s 119.70' 0.00 0.00 0.00 lJ}() 1240 I I I F\ \ 90 \ l ~~~ ~J .~... 821 103.5 IT4u 180 l.EU Reference Azimuth Angle [deg] vs Centre to Centre Separation [ft] From Colour o 500 750 1000 1500 2000 2500 3000 3500 4500 5500 6500 7500 8500 9500 11500 13500 15500 ToMD 500 750 1000 1500 2000 2500 3000 3500 4500 5500 6500 7500 8500 9500 11500 13500 15500 17500 -~ --~ @i%irç tiÚ 1: fn.¡ II lb ) ~¡ç\(® ~ ~ ~y ~ l.b~J J Lr~\ ._L.:Jlf ~ ciû J\\ If=L.. ) A1tASIiA OIL AND GAS CONSERVATION COMMISSION / / l l / f / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Unit 3S-08B ConocoPhillips Alaska, Inc. Permit No: 203-043 Surface Location: 2492' FNL, 954' FEL, See, 18, TI2N, R8E, UM Bottomhole Location: 1934' FSL, 514' FWL, Sec. 17, TI2N, R8E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). ïe; ~L Randy Ruedrich ~ Commissioner BY ORDER OF THE COMMISSION DATED this /c¡1by of March, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section y..¡,GA- 3/ r1IZ-(Jo'3 ) STATE OF ALASKA ) . ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 1a. Type of work: Drill ~ Redrill U Re-entry DDeepen D 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2492'FNL,954'FEL,Sec.18,T12N,R8E,UM At top of productive interval 1835' FSL, 740' FWL, Sec. 17, T12N, R8E, UM At total depth 1934' FSL, 514' FWL, Sec. 17, T12N, R8E, UM 12. Distance to nearest property line 13. Distance to nearest well 1934' at TD 3S-07 I 2291' @ 5750' 16. To be completed for deviated wells Kickoff depth: 7000 MD 18. Casing program size 20 AAC 25.005 1 b. Type of well. Exploratory U Stratigraphic Test Service D Development Gas D Single Zone 5. Datum elevation (DF or KB) RKB = 28' U D Development Oil ~ Multiple Zone D 10. Field and Pool Kuparuk River Field Kuparuk River Oil Pool feet 6. Property Designation ADL 380107 ALK 4624 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) Kuparuk River Unit Statewide 8. Well number / Number 3S-08B #59-52-180 9. Approximate spud date Amount March 13, 2003 .-/" $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2448 8817' MD 16026' TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 2460 psig /Át total depth (TVD) 3104 psig Setting Depth Maximum hole angle 55.5° Hole Casing Weight Specifications Grade Coupling Top Length MD TVD MD Bottom TVD Quantity of Cement (include stage data) 8.5" 7" 26# L-80 BTCM 8789' 28' 28' 8817' 6026' 240 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 8475 feet true vertical 6116 feet Effective Depth: measured 6700 feet true vertical 4189 feet Casing Length Size Cemented Conductor 80' 16" 75 sx ArcticCrete Surface 4235' 9.625" 664 sx ASLite, 391 sx LiteCrete Plugs (measured) cement plug #1: 8475' - 7968' Cement plug #2: 7300' - 6700' Junk (measured) Measured depth True Vertical depth 108' 108' 4263' 2662' RECEIVED Perforation depth: measured none MAR 1 ;, 2003 A,~OI&GasGonss liOmlDiSSlOn ~ AIIIDage true vertical none 20. Attachments Filing fee 0 Property Plat D BOP Sketch D Diverter Sketch D Drilling program 0 Drilling fluid program 0Time vs depth plot Qefraction analysis D Seabed report D 20 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Scott Lowry 265-6869 Signed .Å. {. ~ t.r- tZ_ít-hJ~4~ R. Thomas Title: Kuparuk Drilling Team Leader Date S j l4-l 0 ~ PrAnflrArl hv Rhflmn AIJ.c;lIn-nrflkA Commission Use Only Permit Number / /~ API number. I Approval date 3 Î¡a~see cover letter 2...03-D,....:::;:; 50- /D3- .2Dc..¡.SÖ-ð2-- I/0 for other requirements Conditions of approval Samples required D Yes ~ No Mud log required I Yes LX1 No Hydrogen sulfide measures D Yes ~ No Directional survey required ~ Yes D No Required working pressure for BOPE D2M; D 3M; D 5M; D 10M; D D Other:",e;t 1;:'PE fc SDCC I)'L At)t>t"\?V~ reta.-vi~·d ~,,.- ~+~-fH.Jv+e. by order of Original Signed By Kandy Kuedrich Form 10-401 Rev. 12/1/85· C '~l~ '~VA , ¡ U ,; I ' .. \/u b~J C,.6l.-~ ") p t-o~ V Cl~ . ~f 9 ) 0 '3 f7P t-Olj~( ~ II ")/2-CO"3 Submit iJtf~tt; ;.S /;q. ~ft., Date Approved by Commissioner the commission j(~- conocóPhiUips \) Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com March 13, 2003 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Sundry Approval to plug back well 3S-08A I Application for Permit to Drill Sidetrack well,3S-088 \~.~.~'I:'I""""."'. . Dear Commissioner: ConocoPhillips Alaska, Inc. hereby files this Application for Sundry Approval to plug back well 3S-08A. Scott Lowry spoke with Winton Aubert on 3-13-03 to obtain.)(erbal approval to proceed with operations. A permit application for the sidetrack, 3S-088, is included with this application. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Scott Lowry at 265-6869. Sincerely, A--L ~ ~r- 12..-r-tÞMJ\<) Randy Thomas GKA Drilling Team Leader ) APpjr"~,iO, n for Permit to Drill, We1l3S-088 1 Revision No.O Saved: 13-Mar-03 Permit It - Kuparuk Well 35-088 Application for Permit to Drill Document MoximizE We-II \!gIUE; Table of Contents 1. Well Name ......... .... ........... ... ....... ... ...... ...... ... ...... .... ...... ............. .... .... ... ... .....'. ....... ..... 2 Requirements of 20 AAC 25.005 (f)... ................. ........................... ........ ............ ................. ....... ...... ....... 2 2. Location Sum mary . ..... ... .... ... ........... .... ..... ..... ... ...... ....... .......... .... .... ...... ...... ........ .... 2 Requirements of 20 AAC 25.005(c)(2) ........................................ ......... ....... ........ .................... ............... 2 Requirements of 20 AAC 25.050(b)....... ................... ................... .......... .............. ...................... ...... ....... 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ..................... ....... ............ ............. ........... ............... ............. ....... 3 4. Dri II i ng Hazards Information ..... ..... ..... ............... ... ......... ...... ............. ....... ...... ..... .... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .... ................ .................................. ..... .......................... ............. 3 6. Casi ng and Cementi ng Program .... ....... .... .............. ....... ........ ........ ... ... ...... .... ......... 4 Requirements of 20 AAC 25.005(c)(6) ..... ......... ...... ........ ............................... ............. .... ....................... 4 7. Diverter System Information ..................... ........ ...... ....... .............. ........ ...... ............. 4 Requirements of 20 AAC 25.005(c)(7) ................... ................ ............................. ........... ............ ............ 4 8. Dri II i ng FI uid Program ...... ..... ............. .... ... ........ ... ..... .... .... ..... ........ ... .............. ..... ... 4 Requirements of 20 AAC 25.005(c)(B) ............... ...... .............................................. ........ ........................ 4 9. Abnormally Pressured Formation Information...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ............................. ...... ......................... ......... ..... ........................ 5 10. Seismic Analysis.... .... ....... ....... ............... ......... ....... .... ..... ....... ...... ....... ... .... ........ ..... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bondi ng ..... ..... .... ........ ... .... ............. ..... ........ ...... ........... ............ ........... 5 Requirements of 20 AAC 25.005 (c)(12) ................................. ............... ......... .......... ................. ............ 5 13. Proposed Drilling Program .....................................................................................5 O r,n, " ,"\ 'A r~ ì ~, ¡ 1 ~ I~t ,- 38-088 PERMIT IT. DOC Page 1 of 7 Printed: 13-Mar-03 ) Applin8,~on for Permit to Drill, We1l3S-08B J Revision No.O Saved: 13-Mar-03 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ....................................................... ........ ................. ................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan.. ........... ........ ....... ...... ................... .......... .............. ......... ...... ................... 6 Attachment 2 Drilling Hazards....................................................................... ................. .....6 Attachment 3 Well Schematic............................ .................................... .......................... ....6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be Identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well witl7 multiple well branche~ each branch must similatly be Identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to tIle well by tl7e commission The sidetrack well for which this application is submitted will be designated as 3S-08B. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An applic<'1tion for a Permit to Onll must be accompanied by eaä, o( the following item~ except for an item already on tìle with the commission and Identified in the application: (2) a plat identifylÌ7g the plvperty and the property's owners and showing (A)the coordinates ol the ptvposed location of the well at the surface? at the top of each oþjective formation and at total depth, referenced to governmental section line!:>"". (8) the coordinates of tl7e proposed location of the well at the surface, referenced to the state plane coordinate sy!:>tem f'Or thl" state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) tile proposed depth of the well at the top of each objective (ormation and at total deptl7; Location at Surface NGS Coordinates Northings: 5,993,923 I 2492' FNL,' 954' FEL,; Sec 18, T12N, R8E, UM RKB Elevation Eastings: 476,305 Pad Elevation 56.1' AMSL 28.0' AMSL Location at Top of Productive Interval (Kuparuk "C" Sand) NGS Coordinates Northings: 5,992,965 1835' FSL, 740' FWL, Sec 17, T12N, R8E, UM Eastings: 478,000 Measured Depth, RKB.· Total Vertical Depth, RKB.· Total Vertical Depth, 55.' 8517' 5856' 5800' Location at Total Depth 11934' FSL, 514' FWL, NGS Coordinates Northings: 5,993,065 Eastings.· 477,774 Sec 17, T12N, R8E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 8817' 6026' 5970' and (D) other information requked by 20 MC 25.050(b); Requirements of 20 AAC 25. 050 (b) If a well is to be intentionally deviated, the application for a PermIt to Onll (Form 10-401) must (1) 1Ì7c1ude a plat, drawn to a sUItable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well,· Please see Attachment 1: Directional Plan lJ~ l~ ¡ ~ III ' rI 11U' jUÞ~~ 3$-088 PERMIT IT. DOC Page 2 of 7 Printed: 13-Mar-03 ) APPlir~.·on for Permit to Drill, We1l3S-08B J Revision No.O Saved: 13-Mar-03 ðnd (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells~ to the extent that those names are known or discoverable in public record~ and show that each named operator has been fumi!J'f1ed a copy of the application by certified mail· or (S) :,-tate that the applicant is the only affeäed owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Perrmt to Drill must be accompanied by each of the following Item~ except for an Item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (SOPE) as required by 20 MC 25.03~ 20 AAC 25.03(i or 20 AAC 25,03~ as appllcable/' Please reference 80P schematics on file for Nabors 7E5. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by eaL17 of the following Items~ except for an Item already on file with the commis..sion and identified in the application: (4) infO/mation on drilling hazards, ineluding (A) the mðximum downhole pressvre that may be encoul7terect cnteria used to determine it and maximum potential surface pressure based on a methane gradient; A pressure build-up test performed on Palm lA (35-26) in 4/01 indicated a reservoir pressure in the Kuparuk C sand of 3597 psi at 5830' tvd, 0.62 psi/ft or 11.9 ppg EMW (equivalent mud weight). Due to pressure depletion, the predicted ~rvoir pressure for 35-088 sidetrack is predicted at 3130 psi at 5856' tvd, 0.53 psi/ft or 10.3 ppg EMW. The maximum potential surface pressure (MP5P) while drilling 35-088 sidetrack is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at 5856' tvd: MP5P =(5856 ft)*{0.53 - 0.11 psi/ft) = 2460 psi /' (8) data Of} potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of 1]OIe problems such as abnormally geo-pressured strata, lost circulation zone!:>~ and zones that have a propensity tar differential sticking/ Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Dr/II must be accompanied by each of the following items/ except for an item already on file with the commission and Identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); A procedure is on file with the commission for performing LOT's. For 35-088, the 9 5/8" surface casing shoe has been tested to 17.9 ppg EMW on 3/3/03. J n ;í ¡~ L~ ~A . ,11 U ¡ j~ . ~ 35-088 PERMIT IT. DOC Page 3 of 7 Printed: 13-Mar-03 App¡r"'~lon for Permit to Drill, We1l3S-08B , Revision No.O Saved: 13-Mar-03 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a PermIt to Drill must be accompanied by each of the followíng item5~ except for an item already on file with the commíssion and identified in the applic<1tion: (6) a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner; pre- perforated liner;. or screen ta be lì7stallect' Casin~ and Cementin~ Pro~ram Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD 00 (in) (in) (/blft) Grade Connection (ft) (ft) (ft) Cement Program 30 X 16 42 62.5 H-40 Welded 80 28 / 28 108 / 108 9 cy High Early Insulated 9-5/8 12-1/4 40 L-80 BTC 4235' 28'/28' 4263'/2662' Cemented to surface as per APD 203-022 7 8-1/2 26 L-80 . BTC-MJd 8789' 28'/28' 8817'/6026' 240 sx 15.8 ppg 'G' w/ /' add. Planned TOC= 7717' 3-1/2 9.3 L-80 EUE 8rd 8389' 28' / 28' 8417'/5799' SAB- 3 packer set at Mod 8417' MD. If 7" casing must be top-set above the Kuparuk C sand, 6 1/8" hole would be drilled to total depth and a 3 V2" 9.3 ppf L-80 SLHT production liner will be cemented across the productive interval. ~ 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following Items¡ except for an item already on file with the commission and Identified in the applk..-ation: (7) a diagram and de.s-cliption of the diverter system as required by 20 MC 25.03~ unle5"s this requirement is waived by the c:vmmission under 20 AAC 25.035(17)(2)/ Please reference diverter schematic on file for Nabors 7ES. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following itemS¡, except for an item already on file wIth the commis.sion and identified in the application: (8) a drilling fluid program" inc!udli7g a diagram and description of the drilling flUId system" as required by 20 MC 25.033; Drilling will be done using mud systems having the following properties: Production Hole mud properties initial C40 Top Morraine Top HRZ Kuparuk Density (ppg) 8.9 10.2 10.6 10.8 11.3 ~ Funnel Viscosity 40-55 42-55 42-58 42-58 42-58 (seconds) Yield Point 11-15 20-25 20-25 20-25 20-25 (cP) Plastic Viscostiy 6-12 8-15 8-16 8-18 15-25 (lb1100 sf) 10 second Gel 2-5 3-6 3-6 4-7 4-8 Strength (lb1100 sf) 10 minute Gel 4-10 7-10 7-112 7-12 8-16 Strength (lb1100 sf) pH 9-9.5 9-9.5 9-9.5 9-9.5 9-9.5 API Filtrate(cc) <6 <6 <6 <4 <4 Solids (%) 6-11 9-14 1 0-15 1 0-15 15-19 ,. JJ ~!" f'~IJ A I . I' \,;! i J \i, f~' :¡. 3S-08B PERMIT IT. DOC Page 4 of 7 Printed: 13-Mar-03 ) APPIif'l'on for Permit to Drill, We1l3S-08B Revision No.O Saved: 13-Mar-03 Diagram of Nabors 7ES Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a PermIt to Drill must be accompanied by ead7 of the following item5~ except for an item already on file with the commission and identified in the application: (9) for an exploratOlY or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f}; N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An applk:ation fvr a Pem7lt to Drill must be accompanied by each of the following item:,~ except for an item already on file with the commission and identified in tile application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analy!:;is as required by 20 AAC 25.061(a); NI A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill mu.<it be accompanied by each of the following items, except for an item already on file wIth tlu? commi::.-sion and identified in the application: (1.1) for a well drilled from an off!..,17ore platfor¡n mobile bottom-founded structure, jack-üp rig, or floating drilling vessel, an analy.r;is of seabed conditions as required by 20 AAC 25:061(b); N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on fì/e wIth the commis!:Jion and identified li7 the application: (12) eVldenæ showing thl~t the requirements of 20 MC 25. 025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill mu.r;t be accompanied by each of the following items, except fvr an item already on file with the cvmmission and Identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. Drill off cement plug and sidetrack well with a planned kick-off point of 7000' MD. 2. Drill S-1/2" hole to total depth according to directional plan. Run LWD logging equipment Wit~ GR, resistivity, and density-neutron. Run 7" 26# L-SO BTCM casing to surface and cement. Note: If significant hydrocarbon zones are present above the Kuparuk C sand, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 7. Run 3-1/2" 9.3#, L-SO Srd EUE Srd-Mod completion assembly wI SAB-3 permanent packer and PBR. Set packer 100' above top planned perf~ation, shear out of PBR, P/U tubing hanger, and land tubing. Pressure test tubing to 3500 psi. Pressure test 3 112" x 7" annulus to 3500 psi. Burst shear valve for freeze protect. S. Set TWC and ND BOPE. Install and pressure test production tree. 9. Freeze protect. Secure well. Rig down and move out. 10. Handover well to Operations Personnel. C r"; ~ .l': ".O¡ '~A r ~ I ~I ~ ,Ii J.I.!! i ~. "J .... .;.¡, . .~ § , \~'I I j,! . 1.- 3$-088 PERMIT IT. DOC Page 5 of 7 Printed: 13-Mar-03 ) Appli"'\~on for Permit to Drill, We1l3S-088 J Revision No.O Saved: 13-Mar-03 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the (vllowing Items~ except for an item already or¡ file with file commission and identified in the appllÒltion: (14) a general description of how the operator plans to dispose ol drillli7g mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25. 080 lor an annular disposal operation in the wel/./ Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 35 pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 35 pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit 35-08B for annular pumping of fluids occurring as a result of future drilling operations on 35 pad. ---" 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. J J~r:II'i~ A , I" l~ ì n , ~ ..~ ". .:t1 I i I ~ ".~ J ."~ 1. 3$-088 PERMIT IT. ODe Page 6 of 7 Printed: 13-Mar-03 ---- Sperry-Sun Drilling Services _ <J ::t:J ConocoPhilli North S Kuparu 3 - G~J ~ -...~ ~r~ :::: :t~ r-- Proposal Report 13 March, 2003 Your Ref: Per Planning Session (Wed pm 3-12-03) Surface Coordinates: 5993923.49 N, 476305.43 E (70023'40.3066" N, 150011' 34.0341" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 - Kelly Bushing: 55. 80ft above Mean Sea Level c=q-tø.........,y-ca ,., DRI-LLING SERVICES A Hamburton Company Proposal Ref: pro 1997 ') 0) .~ ConocoPhi 11ips ConocoPhillips Alaska, Inc. North Slope, Alaska Palm (3S Pad) 35-08 B (wp01) ,±; ,~ sper-ar-y-su·r, C'R I L. L-.1N G S EAVIt:'""es A Halliburton Company Reference is True North Well: Horizontal Coordinates: R.:,r .':':ljt..1 Ç':,:. ~lrl.ll.:.::. A.:I :'1.".:1,..0:.- I:¡~I .:..:' :.j, ~¡;I,I..: ." ':: ;.1 1,·,W:"~ 3$,08 Plan ~\'ð-(I N~Q ~«.o ~~ Current Well Properties R KB ElevaUon : NorU, Reference: Units: 5993923.49 N, 476305.43 E 80.02 N, 149.82 W 70'; 23' 40.3066" N, 209' 48' 25.9659" E 2492' FNL & 954' FEL, SEC. 18· T12N· R8E 55.8011 above Mean Sea Level True Norlh Feet (US) 500 I 1000 I 1500 I 2000 I 2500 I 3000 I Scale: 1 inch = 500ft 3500 I -750 - 1'ARGII'1': 3S-08/J 5855.80' TV/), 953.1 l' S,1697.60' E - -750 (/ 0> c: :.c t o Z 9-5/8" Csg PI. 4276.00' MD 2666.93' '['VD (/ 0> c: :.c t o Z -1250 - - -1250 ;: o o L() II ~ -1750- End Dir, Start Sail @ 55,5° : 7437,34ft MD, 5243,96ft TVD . !~ \\\\ .. ~'ò<j:>' 3S-08A (Rig Surveys) TARGET (3S-08B) : 8517.47ft MD, 5855,80ft TVD (1835' FSL & 740' FWL, Sec 17-T12N-R8E) à) -¡¡¡ o (/ Sidetrack Point... Kick off of Cmt Plug @ 5.0o/100ft in 8-1/2" Hole: 7000.00ft MD. 4947.04ft TVD ;t::: o o L() II - -1750 ~ I 500 I 1000 I 1500 à) -¡¡¡ o (/ Scale: 1 inch = 500ft I 2000 Eastings I 2500 I 3000 I 3500 1250 I 1750 I 2250 I 2750 I 3250 I 3750 I 4750 - Sidetrack Point ... Kick off of Cmt Plug @ 5.00/100ft in 8-1/2" Hole: 7000.00ft MD, 4947.04ft TVD 6?~1Î() - 4750 m ~ ~ ~ ä. Q) o ëii C,) :e Q) > 5750 ~ ! End Dir, Start Sail @ 55.5° : ;> 7437.34ft MD, 5243.96ft TVD~ ~~oo '0"", 2í """, ''Vo, #' Ii' / /' . vrfJ;j . ./~ '~~ 0,"" '''0 .~8s.--0-_'_-'- ."-' -'.'--'-" -,.}?~ .------.,-, -- ,-~ ".o~ . ~r/ 7" Csg PI 8~«a<"" . ~GET (3S'OB~ :~.470 MD, 5555.BOO TVD :;1~:;~: ~~D (1835' FSL & 740' FWL, Sec 17-T12N-R8E) Proposed BHL @ 8817.47ft MD, 6025.73ft TVD (1934' FSL & 514' FWL, Sec. 17-T12N-R8E) m ~ ... ~- 5250 ~ ~ ä. Q) o ëii C,) :e Q) > ~ 5750 ! 5250 - ;t::: o o L() II .r::. <J .5;; à) ro <J (/ 6250 - ;t::: o o L() 11 .r::. o - 6250 ,5;; I 1250 I 1750 I 2250 I 2750 I 3250 I 3750 à) -¡¡¡ o (/ Scale: 1 inch = 500ft DrillQuest 3.03.02.002 ) j Il~ If.~, 1,~ l " . U ,~;I/"~: ~ ConocoPhillips Alaska, Inc. 38-088 (wp01) ~ MD Inc Azim. SSTVD TVD N/S EIW Y X DLS v.s. Com ment a (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) (ft) -~t:J 7000.00 39.20 273.59 4891.24 4947.04 1393.15 S 2819.28 E 5992521.41 N 479120.28 E 1.33 3125.74 Sidetrack off of Cmt Plug @ 5.00/1001t in 8-1/2" Hole ~~ 7431.77 55.27 293.51 5185.00 5240.80 1312.878 2516.81 E 5992602.65 N 478818.06 E 5.00 2814.05 Top Morraine !::~~J 7437.34 55.50 293.71 5188.16 5243.96 1311.038 2512.61 E 5992604.50 N 478813.87 E 5.00 2809.48 End Dir; 8tart 8ail 7881.93 55.50 293.71 5440.00 5495.80 1163.718 2177.14E 5992752.89 N 478478.87 E 0.00 2443.86 Top HRZ ~.,.~ 8190.87 55.50 293.71 5615.00 5670.80 1061.34 8 1944.03 E 5992856.00 N 478246.09 E 0.00 2189.79 Base HRZ ~' ..¡;:a ,~ 8400.96 55.50 293.71 5734.00 5789.80 991.72 8 1785.52 E 5992926.11 N 478087.79 E 0.00 2017.03 K-1 ~ 8517.47 55.50 293.71 5800.00 5855.80 953.11 S 1697.60 E 5992965.00 N 478000.00 E 0.00 1921.21 TARGET (3S-088) r- 8521.00 55.50 293.71 5802.00 5857.80 951.94 8 1694.94 E 5992966.18 N 477997.34 E 0.00 1918.30 Kuparuk 8556.31 55.50 293.71 5822.00 5877.80 940.24 8 1668.29 E 5992977.96 N 477970.74 E 0.00 1889.27 Miluveach 8817.47 55.50 293.71 5969.93 6025.73 853.71 8 1471.24 E 5993065.13 N 477773.95 E 0.00 1674.50 Proposed BHL -- Sperry-Sun Drilling Services Proposal Report for 3S-08 Plan Your Ref: Per Planning Session (Wed pm 3-12-03) Revised: 13 March, 2003 ConocoPhil/ips Western North Slope Global Coordinates Northings East" (ft) Local Coordinates Northings Eastings (ft) (ft) Vertical Depth (ft) Sub-Sea Depth (ft) Measured Depth (ft) Comment Azim. Incl. 3S-08 (Rig Surveys) 4005.43 E 476305.21 E 476305.17 E 476306.58 E 476309.32 E 0.00 N 0.08 N 0.96 S 5.91 S 14.95 S 0.00 -0.24 0.09 3.12 8.81 0.00 100.00 199.99 299.85 399.39 0.000 257.158 171.622 162.374 161.289 -55.80 44.20 144.19 244.05 343.59 0.00 100.00 200.00 300.00 400.00 0.000 0.191 1.254 4.494 6.542 0.191 1.254 3.262 2.050 --- 5993895.68 N 5993879.06 N 5993859.68 N 5993838.68 N 5993815.56 N 476314.66 E 476321.94 E 476332.17 E 476347.13 E 476366.95 E 2.867 2.262 2.608 3.117 3.033 18.26 30.83 47.11 68.40 94.98 442.61 540.94 638.50 735.11 830.34 156.018 154.824 148.11 0 141 .608 136.934 500.00 600.00 700.00 800.00 900.00 9.318 11 .570 13.729 16.355 19.036 C) ~ ~~~ ~--~ ·L" rA~ ~ -:) 5993791.37 N 5993767.27 N 5993743.47 N 5993719.58 N 5993694.04 N 476390.86 E 476418.69 E 476453.65 E 476495.30 E 476543.63 E 131.85 S 155.86 S 179.55 S 203.31 S 228.70 S 85.85 E 113.75E 148.79 E 190.51 E 238.92 E 1.739 3.797 4.225 4.280 4.846 125.77 160.20 201.23 248.56 302.73 ~~¡~~ii:~~~~~:~~ C1iì79j2:~?C- 1335.12 133.686 127.261 121.187 118.614.. 1113.. ª~g;-.?, ~"""-. ~, 1000.00 1100.00 1200.00 1300.00 1400.00 20.388 23.341 26.700 30.798 35.548 --.? ><~.- -. '" :~ r- 5993667.19 N 5993638.86 N 5993609.99 N 5993580.05 N 5993548.26 N 476598.64 E 476658.72 E 476724.59 E 476796.14 E 476873.06 E 255.37 S 283.51 S 312.17 S 341.88 S 373.43 S 294.02 E 354.19 E 420.15 E 491.80 E 568.82 E 4.561 3.438 5.609 4.757 6.185 363.63 429.79 501.58 579.07 662.23 1500.00 39.947,?' --1J4'.&Z6.=:·- 1600.00 43.38Ft~:R. f~~~' -.. 1700.00';/. :-~.59·~:;( r:'·2.26~'-" 1800.00'_;-: -';5$~c$4T:" -112.616 1900.00,: :59;531 ".eJ 12.501 1414.16 1488.89 1558.32 1621.39 1676.73 1358.36 1433.09 1502.52 1565.59 1620.93 5993512.05 N 5993474.94 N 5993438.26 N 5993403.82 N 5993368.56 N 476954.19 E 477035.64 E 477117.44 E 477201.41 E 477285.54 E 750.88 840.12 929.55 1020.25 1111.38 2000.00 - 2100.00 2200.00 2300.00 2400.00 409.38 S 446.23 S 482.65 S 516.83 S 551.82 S 650.06 E 731.63 E 813.54 E 897.62 E 981.86 E 5.133 1.149 1 .447 1.522 0.917 1666.73 1711.33 1755.63 1797.60 1838.58 1722.53 1767.13 1 811 .43 1853.40 1894.38 114.562 114.159 113.165 112.217 111 .278 64.332 63.242 64.380 65.637 65.965 -~ 5993337.71 N 5993307.63 N 5993277.62 N 5993251 .73 N 5993228.48 N 477371.56 E 477457.76 E 477543.97 E 477631.19 E 477719.17 E 1067.98 E 1154.28 E 1240.58 E 1327.88 E 1415.94E 2.113 0.331 1 .439 2.502 0.093 1202.76 1294.05 1385.32 1476.12 1566.72 582.39 S 612.21 S 641.94 S 667.55 S 690.52 S 1934.96 1975.75 2016.58 2058.06 2099.51 1879.16 1919.95 1960.78 2002.26 2043.71 65.999 65.961 65.651 65.507 65.455 108.965 109.325 107.784 105.041 104.956 2500.00 2600.00 2700.00 2800.00 2900.00 Dril/Quest 3.03.02.002 13 March, 2003 - 12:33 Page2of7 C) =0 ---.- Ç) ----~ :-:~~ ::r-;: r-- Western North Slope Measured Depth (ft) 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 4000.00 4100.00 4200.00 4276.00 4279.85 Incl. 65.728 65.957 65.738 65.123 65.376 65.828 65.727 65.329 65.835 65.659 65.537 65.788 65.806 65.914 65.920 3S-08A (Rig Surveys) Azim. 105.274 106.683 106.132 107.106 108.373 107.889 107.437 108.026 106.988 106.717 107.293 108.653 108.367 108.265 108.260 Sub-Sea Depth (ft) 2085.12 2126.01 2166.87 2208.42 2250.34 2291.63 2332.62 2374.17 2415.41 2456.45 Vertical Depth (ft) 2140.92 2181.81 2222.67 2264.22 2306.14 2347.43 2388.42 2429.97 2471.21 2512.25 2497.89 2553.69, 2539.01 259~~~1 ~ 2580.05-a63~æ5 ~~ ~ ~t%~"ê"(r1{+;~C~ . . 4300.00 64.584.c"; i:1.08~5Þ,9o_.- .14 4400.0p, 58.4:?~' 1Q9.72(),·' 2669.08 4500.00/, '>~.545;:" 199.61'15' 2725.02 4600. OO>:4~H205" 109.998 2787.64 4700.00' :;45:'146'110.992 2855.22 4800.00 4900.00 5000.00 5100.00 5200.00 5300.00 5400.00 5500.00 5600.00 5700.00 42.080 37.903 33.406 28.635 23.428 19.563 17.185 16.613 13.915 1 0.798 13 March, 2003 - 12:33 111.880 112.638 113.595 116.445 120.406 123.938 128.493 130.147 134.931 147.789 2927.17 3003.71 3084.92 3170.56 3260.33 3353.50 3448.46 3544.21 3640.59 3738.28 _·u 2676.94 2724.88 2780.82 2843.44 2911.02 2982.97 3059.51 3140.72 3226.36 3316.13 3409.30 3504.26 3600.01 3696.39 3794.08 Sperry-Sun Drilling Services Proposal Report for 35-08 Plan Your Ref: Per Planning Session (Wed pm 3-12-03) Revised: 13 March, 2003 Local Coordinates Northings Eastings (ft) (ft) 714.40 8 739.298 765.39 8 791.21 8 818.87 8 1068.83 8 1097.848 1125.678 1151.998 1177.708 1203.22 8 1227.468 1250.41 8 1271.858 1292.80 8 1312.138 1330.56 8 1348.96 8 1366.798 1383.188 2374.12 E 2460.67 E 2547.16 E 2613.00 E 2616.34 E 2633.70 E 2716.46 E 2794.50 E 2867.86 E 2936.91 E 3001.48 E 3061.05 E 3114.66 E 3161.55E 3200.20 E 3230.90 E 3256.23 E 3278.42 E 3298.19 E 3311.77 E Page 3 of7 Global Coordinates Northings East" (ft) 070.11 N 993042.27 N 5993014.09 N 5992986.52 N 5992959.83 N 5992933.32 N 5992904.45 N 5992875.27 N 5992853.27 N 5992852.15 N 5992846.32 N 5992817.04 N 5992788.97 N 5992762.42 N 5992736.48 N 5992710.76 N 5992686.33 N 5992663.21 N 5992641.63 N 5992620.55 N 5992601.12 N 5992582.62 N 5992564.14 N 5992546.25 N 5992529.82 N 478242.00 E 478328.86 E 478415.34 E 478502.17 E 478589.36 E 478676.43 E 478762.88 E 478849.28 E 478915.05 E 478918.39 E 478935.73 E 479018.40 E 479096.35 E 479169.62 E 479238.59 E 479303.08 E 479362.58 E 479416.11 E 479462.94 E 479501.52 E 479532.15 E 479557.43 E 479579.56 E 479599.27 E 479612.80 E 0.631 0.425 0.668 1.072 0.304 0.538 1.264 0.261 0.188 0.188 6.780 6.242 4.880 4.350 3.535 3.717 4.206 4.531 4.990 5.487 4.074 2.777 0.747 2.975 4.140 ConocoPhillips Comment 1657.43 1748.44 1839.55 1930.34 2021.05 2112.08 2203.22 2294.11 2385.12 2476.17 - 2567.03 2658.14 2749.30 2818.63 9-5/8" Csg Pt 2822.14 2840.43 2928.12 3010.97 3088.91 3162.59 3231.99 3296.26 3354.49 3405.88 3449.37 - 3484.83 3514.94 3542.08 3566.75 3585.12 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for 35-08 Plan Your Ref: Per Planning Session (Wed pm 3-12-03) Revised: 13 March, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Easti,n Comment (ft) (ft) (ft) (ft) (ft) (ft) 5800.00 8.388 170.280 3836.90 3892.70 1398.31 8 3596.16 5900.00 7.521 210.051 3936.01 3991.81 1411 .22 8 3598.66 6000.00 9.776 248.843 4034.94 4090.74 1419.91 8 3591.07 6100.00 13.909 265.258 4132.82 4188.62 1423.87 8 3573.69 6200.00 18.422 270.355 4228.85 4284.65 1424.62 8 3547.84 6300.00 23.168 271.314 4322.33 4378.13 489.18 N 479522.47 E 4.759 3514.36 --- 6400.00 28.228 272.964 4412.43 4468.23 '992490.78 N 479479.20 E 5.110 3473.20 6500.00 33.664 274.797 4498.20 4554.00 5992494.77 N 479428.01 E 5.517 3423.77 6600,00 37.912 274.852 4578.86 4634.66 5992499.86 N 479369.17 E 4.248 3366.78 C) 6700.00 39.075 274.940 4656.85 4712.65 5992505.48 N 479306.83 E 1.164 3306.34 ::~-] 6800.00 38.814 274.603 4734.55 4790.35 2943.15 E 5992510.94 N 479244.12 E 0.336 3245.59 ~....~-,~ 6900.00 38.171 274.925 4812.79 486~~69 2881.08 E 5992516.13 N 479182.07 E 0.673 3185.56 ø='-..,-.... 7000.00 39.202 273.592 4891 .24 4947,04 2819.28 E 5992521.41 N 479120.28 E 1.326 3125.74 8idetrack Point ... Kick off of Gmt Plug 'L:.J --'-'~-.. - --:;--"., @ 5.00/100ft in 8-1/2" Hole: 7000.00ft ~.- MD, 4947.04ft TVD "~~ ~ 3S-088 (wp01) r- 7100.00 42.588 219;'?17 "'~&f 4966.84 5022.64 1385.758 2754.29 E 5992529.02 N 479055.32 E 5.000 3062.14 7200.00 46.216?r' ;g~4'.;1:~~., 5038.30 5094.10 1371.508 2685.85 E 5992543.48 N 478986.92 E 5.000 2992.95 7300.00, 50.d3Ö~ ¿øa.4$',: r-!:'" 5105.05 5160.85 1350.52 S 2614.46 E 5992564.69 N 478915.59 E 5.000 2918.69 7400.0Ö,," <~.989;Ji; ,?~2.36~H 5166.61 5222.41 1322.96 8 2540.66 E 5992592.48 N 478841.89 E 5.000 2839.92 7431.77',' SS~271";{ 293.511 5185.00 5240.80 1312.878 2516.81 E 5992602.65 N 478818.06 E 5.000 2814.05 Top Morraine 7437.34> 55.497 293.709 5188.16 5243.96 1311.03 S 2512.61 E 5992604.50 N 478813.87 E 5.000 2809.48 End Dir, Start 8ail @ 55.5° : 7437 MD, 5243.96ft TVD ~ 7500.00 55.497 293.709 5223.66 5279.46 1290.27 8 2465.33 E 5992625.41 N 478766.65 E 0.000 2757.95 7600.00 55.497 293.709 5280.30 5336.10 1257.138 2389.87 E 5992658.79 N 478691.31 E 0.000 2675.71 7700.00 55.497 293.709 5336.95 5392.75 1223.99 8 2314.42 E 5992692.17 N 478615.96 E 0.000 2593.47 7800.00 55.497 293.709 5393.59 5449.39 1190.86 S 2238.96 E 5992725.54 N 478540.61 E 0.000 2511.23 7881.93 55.497 293.709 5440.00 5495.80 1163.718 2177.14 E 5992752.89 N 478478.87 E 0.000 2443.86 Top H RZ 7900.00 55.497 293.709 5450.24 5506.04 1157.728 2163.51 E 5992758.92 N 478465.26 E 0.000 2429.00 8000.00 55.497 293.709 5506.88 5562.68 1124.598 2088.05 E 5992792.29 N 478389.91 E 0.000 2346.76 8100.00 55.497 293.709 5563.53 5619.33 1091.458 2012.60 E 5992825.67 N 478314.56 E 0.000 2264.52 8190.87 55.497 293.709 5615.00 5670.80 1061.348 1944.03 E 5992856.00 N 478246.09 E 0.000 2189.79 Base H RZ 13 March, 2003 - 12:33 Page 4 of7 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for 35-08 Plan Your Ref: Per Planning Session (Wed pm 3-12-03) Revised: 13 March, 2003 Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Easti (ft) (ft) (ft) (ft) (ft) (ft) 8200.00 55.497 293.709 5620.17 5675.97 1058.31 S 5992859.04 N 8300.00 55.497 293.709 5676.81 5732.61 1025.18 S 599289 .42 N 8400.00 55.497 293.709 5733.46 5789.26 992.04 S 59 N 8400.96 55.497 293.709 5734.00 5789.80 991.72 S ~>5 '. .'" N 8500.00 55.497 293.709 5790.10 5845.90 958.90 S .- ;5992959. rtN 8517.47 55.497 293.709 5800.00 5855.80 953.11 S 5992965.00 N 478000.00 E ~~~~?c 2182.29 2100.05 2017.81 2017.03 K-1 1935.57 0.000 1921.21 C) 8521.00 55.497 293.709 5802.00 1694.94 E 5992966.18 N 477997.34 E 0.000 8556.31 55.497 293.709 5822.00 1668.29 E 5992977.96 N 477970.74 E 0.000 ::0 8600.00 55.497 293.709 5846.75 1635.33 E 5992992.54 N 477937.82 E 0.000 ~"_I~ 8700.00 55.497 293.709 5903.39 1559.87 E 5993025.92 N 477862.47 E 0.000 ~) 8800.00 55.497 293.709 859.49 S 1484.42 E 5993059.30 N 477787.12 E 0.000 ~-:"·oJ _..,.~ 8817.47 55.497 293.709 853.71 S 1471.24 E 5993065.13 N 477773.95 E 0.000 .c:=::.. ""'''''''-. . - '.-, ~ ~.,.-'" r-- 1918.30 1889.27 1853.34 1771.10 ConocoPhillips Comment TARGET (3S-08B) : 8517.47ft MD7' 5855.80ft TVD (1835' FSL & 740' FW! Sec 17-T12N-R8E) Target - 3S-08B, 100.00 Radius., Current Target Kuparuk Miluveach 1688.86 1674.50 Proposed BHL @ 8817.47ft MD, 6025.73ft TVD (1934' FSL & 514' FW¡ Sec. 17- T12N-R8E) 7in Casing All data is inF:eet (U S SÙr'J6~8unì~~\;W1erw¡~e stated. Directions and coordinates are relative to True North. Vertical dept~iât_e rt':1 O1hlJEt 10 35· 08 Nünr'lng~ and Eastings are relative to 3S-08. Global Northlbgs'~øEasMgs are relative to NAD27 Alaska State Planes, Zone 4. , .- c, ..- __ '--.-'--"'--',' ."-.,. . -.'. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Sectidr{¡s from 3S-08 and calculated along an Azimuth of 110.000° (True). Magnetic Declination at Surface is 25.1600(12-Mar-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 8817.47f1., The Bottom Hole Displacement is 1700.99f1., in the Direction of 120.125° (True). The Along Hole Displacement is 5624.71 ft, the Planned Tortuosity is 2.875°/1 OOft and the Directional Difficulty Index is 5.8. 13 March, 2003 - 12:33 PageS of7 - DrillQuest 3.03.02.002 Western North Slope Comments Measured Depth (ft) Sperry-Sun Drilling Services Proposal Report for 3S-08 Plan Your Ref: Per Planning Session (Wed pm 3-12-03) Revised: 13 March, 2003 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 7000.00 7437.34 8517.47 8817.47 4947.04 5243.96 5855.80 6025.73 CJ :J_J Formation Tops ~~-........~ r. .,.~...,. ~J ~,~-~ -"'0 . J ~.=- ~ r-- Formati on Plane (Below Well Origin) Sub-Sea Dip Up-Dip (ft) Angle Dirn. 1393.15 S 1311.03 S 953.11 S 853.71 S P r o,J . Measured Depth"._ (fOB:;. ~;::- ',::.- '.; - . 5185.00 5440.00 5615.00 5734.00. 5802.00( ., 0.000 0.000 0.000/ . 0.000' 9.060i .. g.;gg~~:{~~?ii;;~~~.: ~~ '~a$"1~~Œ 5822.00':,·· ·Ò.öÖO> 0.000 13 March, 2003 - 12:33 8556.31 2819.28 E 2512.61 E 1697.60 E 1471.24 E Comment -- ConocoPhillips Sidetrack Point... ' End Dir, S1éUf~1 . 5 T ARGE1SIss:~) :~~1 t; Proposedj3Hh' 8817)~7f @ in 8-1/2" Hole: 7000.00ft MD, 4947.04ft TVD MD, 5243.96ft TVD ,5855.80ft TVD (1835' FSL & 740' FWL, See 17-T12N-R8E) 0, 6025.73ft TVD (1934' FSL & 514' FWL, 8ee. 17-T12N-R8E) Poi n t etration ea Depth (ft) '':'-; 5240.80 5495.80 5670.80 5789.80 5857.80 5185.00 5440.00 5615.00 5734.00 5802.00 5877.80 5822.00 Northings (ft) Eastings (ft) Formation Name 1312.878 2516.81 E Top Morraine 1163.718 2177.14E Top HRZ 1061.348 1944.03 E Base H RZ 991.728 1785.52 E K-1 951.948 1694.94 E Kuparuk 940.24 8 1668.29 E M iluveaeh Page6of7 DrillQuest 3.03.02.002 CJ Western North Slope CasinQ details Fr om Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> 4276.00 2666.93 <Surface> <Surface> <Run-TO> <Run-TO> -.cc~o -!'~ Targets associated with this welloath (-, --- 'c- "'" :.....;..~...-- r- Target Name 3S-088 13 March, 2003 - 12:33 Sperry-Sun Drilling Services Proposal Report for 35-08 Plan Your Ref: Per Planning Session (Wed pm 3-12-03) Revised: 13 March, 2003 Casing Detail 9-5/8" Csg Pt 7in Casing Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Target Shape Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Radius: Target Thickness: 5855.80 953.11 S 1697.60 E 5800.00 5992965.00 N 478000.00 E 70023' 30.9301" N 150010'44.3164" W Circle 100.00ft 20.00ft Page 70f7 ConocoPhillips -- Target Type Current Target DriJ/Quest 3.03.02.002 C~mpabY: '. . Field: '. ..;. ". . 'Reference Site.: ,RefeJ.'el1ce Well:.: . Reference W~Upath:. ) ) SPERRY_SUN HES Anticollision Report I ". I , ' , " ' ' ' , ,'.' , ' , ' . ~ Phillips' Alaské\: Inc. . ~ÜpårukRive~ Unit K,uþaruk 3S.Pad Plan: 35-08 . Plan:3S~08B . NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 7000.00 to 8817.37 ft Maximum Radius: 10000.00 ft Survey Program for Definitive Wellpath Date: 3/12/2003 Validated: No Planned From To Survey ft ft 87.00 4279.85 4373.15 7000.00 7000.00 8817.37 Casing Points ~Q ',: ,. ·ft' 4276.00 8817.37 Summary 1'VD 'tt' . 2666.93 6025.75 3S-08 (Rig) (4) 3S-08A (Rig Surveys) (5) Planned: 3S-088 (wp01) V2 Diáartet~r", ..' H~leSiie····. I.~å~e I . ·.:'i.n . .. ;"ìn 9.625 12.250 95/8" 7.000 8.500 7" ,..".... ',',: "" ,," , .",' ", I,' '. I. I., ',',., , .,' .,1 <.-:~.\---'--~;;-.-'-~-" .··.··()ff:set W ellþ~th ...._-~- ~_~_~.~u_.~~~~'~.._>.·. . Sit~...,»,ell .......... ..' .~~It~a~. Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad 3S-07 3S-09 3S-10 3S-14 3S-15 3S-16 3S-18 Plan: 3S-01 Plan: 3S-06 Plan: 3S-06 Plan: 3S-08 Plan: 3S-08 Plan: 3S-17 Plan: 3S-17 Plan: 3S-19 Plan: 3S-19 Plan: 3S-20 3S-07 V5 3S-09 V2 3S-10 V6 3S-14 V2 3S-15 V4 3S-16 V4 3S-18 V4 Plan 3S-01 V2 Plan: 3S Plan: 3S-06 V2 Plan: 3 Plan: 3S-06F V2 Plan: 3S-08 (Rig Surveys) V6 3S-08A (Rig Surveys) V Plan: 3S-17 V1 Plan: 3 Plan: 3S-17F V1 Plan: Plan 3S-19F V2 Plan: 3 Plan: 3S-19 V1 Plan: 3 Plan: 3S-20 V1 Plan: 3 3/13/2003 ' Tillle:· 13:40;50 " '. ."'<' ...........'<. C~~ordinate(NE)Reference: Well:.Plan¡3$·08,Tr~e North' V ~rtical (ryo) :Re~e~elU~e: fU<~~Ei5:8i,~S~ 5,5:8.'. .. Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Version: 2 Toolcode Tool Name MWD MWD MWD MWD - Standard MWD - Standard MWD - Standard ,'. Ref~reòc¿' Offset. , Ctr-Çtr N;o~Go .. AlI~W~Þle' .', W~~ning. ..., ··.MI> ." MD . Í)i~t4n~e ' t\.r~* . . D~Yiåti~tl .' ·ff· :>dt, H. fL ft 8798.91 5750.00 2291.27 235.26 2082.90 Pass: Major Risk 7873.39 4200.00 4007.12 226.15 3824.22 Pass: Major Risk 8488.86 4050.00 4238.09 208.88 4076.24 Pass: Major Risk 8781.62 2800.00 4306.26 210.92 4208.05 Pass: Major Risk 8457.07 2100.00 4891.64 214.97 4807.67 Pass: Major Risk 8788.29 3250.00 3355.35 193.49 3281.43 Pass: Major Risk 8757.31 2300.00 4722.76 218.09 4645.67 Pass: Major Risk Out of range Out of range Out of range Out of range 7000.00 7000.00 0.00 0.87 -0.65 FAIL: No Errors 8785.06 2300.00 4878.00 224.10 4798.19 Pass: Major Risk 8785.06 2300.00 4878.00 225.65 4798.10 Pass: Major Risk 8397.96 1850.00 5038.90 214.04 4964.10 Pass: Major Risk 8397.96 1850.00 5038.90 214.04 4964.10 Pass: Major Risk 8799.17 2950.00 4443.60 214.24 4330.70 Pass: Major Risk o fi ~; i ì \J l~ ... '- ToMD 7000 7100 7200 7300 7400 7500 7700 7900 8100 8300 8500 8700 8900 8920 8940 8960 8980 9000 Colour ~ - 90 (3S-08A (Rig Su~ys From o 7000 7100 7200 7300 7400 7500 7700 7900 8100 8300 8500 8700 8900 8920 8940 8960 8980 CO~1P A'<Y DErAIlS WElLPATHDErAllS P~s Alaska Inc. PIm: 3S-08B Fn~~ ParemWellpa1h: 3S-08A (Rig Surveys) T~on:MD: 7000.00 Caku1aiion MèIDod: Minirrnm CUC'iature. E~E 5~J'~~!' RtL!}'¡~, 1'<7ES Rl(B,= 55KMSL 55.S9ft Warnj¡¡g ~f<lhod: Ruh Based V.Section o~ :k'!?J ~~'D A'lgl<. -fNJ-S 1l0.00' 0.00 0.00 0.00 0 22. ANTI-COLLISION SETITNGS 50.00 8817.37 Plan: 3S-08B (wpOl Interval: To: Reference: Interpolation Method:MD Depth Range From: 7000.00 Maximum Range: 1??oo.00 Slot ~A Longnud, 150' I ßI.033W L:.titud 10'23'40.307N WEU.DETAlLS );onrung E.1stin 5993923. 416305. +F1·W ·1·19. tS/· 80.06 Sw-r Plan: 3S.os 270- -22.1 -20.0 -15.0 -10.0 -20.0 -22.1 -10.0 -0 -5.0 -15.0 -5.0 ToMD 7000 7100 7200 7300 7400 7500 7700 7900 8100 8300 8500 8700 8900 8920 8940 8960 8980 9000 Colour - 90 From o 7000 7100 7200 7300 7400 7500 7700 7900 8100 8300 8500 8700 8900 8920 8940 8960 8980 Tool MWD SURVEY PROGRAM SurveylPlan Planned: 3S-08B (wpOl) V2 Depth To 8817.37 Fm Dept 7000.00 o 210 200 ~ ~~ ~ ~ \ \ 270 -210 -200 -150 -100 -100 -150 <:::) -.,.--. __ '_70 ~-c,... ø~ ~~- ""'.- --~ f~~-:!{) -0 18if-I. 38-08 B (wpOl) Approved Plan Target (8B- 3S VSe<: 2809.63 1921.38 1674.68 TFace 0.00 49.55 0.00 0.00 DLeg 0.00 5.00 0.00 0.00 +FJ-W 2819.33 2512.75 1697.73 1471.37 200 lRJ10 SECfION DE[ AIlS +N/-S -1393.17 -1311.10 -953.27 -853.89 TVD 4947.04 5243.89 5855.80 6025.75 Azi 273.59 293.70 293.70 293.70 1 39.20 55.49 55.49 55.49 MD 7000.00 7437.22 8517.37 8817.37 Sec -200 -210 Centre to Centre Separation [10ft/in] [deg] vs Azimuth (1FO+AZI) Travelling Cylinder Centre Separation [100ft/in] [deg] vs Centre to Azimuth (TFO+AZI Travelling Cylinde ) ) 35-088 Drillina Hazards Summary 8-1/2" Hole / 7" Casing Interval Event Shale stability in HRZ, K-l, and Miluveach High ECD and swabbing with higher MW's required Risk Level Low Moderate Barite Saq Differential Sticking Low Moderate Abnormal Reservoir Pressure Moderate Lost Circulation Moderate M iti~ation Strate~y Control with higher MW and proper drilling practices. Condition mud prior to trips. Monitor ECD's with PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Good drilling practices as documented in well plan. Periodic wiper trips. Do not leave pipe static for extended period of time. Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. ~. 35-088 Drilling Hazards Summary. doc prepared by Scott Lowry 3/13/03 O r'¡ ¡1t'1 f ··"i~ 1 ..~ . I ". J ! . '. ".1 ".¡ , , , f~.,~ I ~ . }: ,OI:Ð Page 1 of 1 ·;KRU - 35-088 5idetrac. ..)Producer/ Proposed Completion Schematic Single Completion wI Jet Pump Contingency 16"x30" insulated conductor @ +1- 109' MD I I I I I I I I I I I I I I I I I I Surface csg. I 9-5/8"40# L-80 ~ BTC (4263' MD I 2662' TVD) Cemented to surface C Sand Perts (to be done after rig moves off) Production csg. 7" 26# L -80 STCM (+1- 8817' MD) I I I I I I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ...J :::::~ - .. ~ J ~ - i '"-"\~. ~ ~ ~ ~ ~ ~ ~ ~ J q~~~~ [I ~ i ~ ~ ~ i ~ ~ ~ i ~ i ~ i ~ I ~ g ~ ~ ~ ~ ! ~ ~ ~ ~ ~.... ~- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~:~: r -""-' - i.-- r-=- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ) ~ ConocoPhiUips i ~ I I I ~ L..... 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RD pin down. Special Drift 2.91" 3-1/2", L-80, 9.3# EUE8RD Spaceout Pups as Required. Special Drift 2.91" 3-112" Cameo DS Landing Nipple with 2.875" ID No-Go profile set@ +1- 500' MD. GLM Placement: Valves #1-4: 3-%" x 1" KSUG Place gas-lift mandrels at the following depths: TVD Approximate MD 2550' 3992' 3725' 5682' 4580' 6630' 5175 7325' Valve #5: 3-1/2" x 1-1/2" 'MMG' GLM wI DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Baker 'CMU' sliding sleeve wI 2.813" Camco No-Go profile, EUE8RD box x pin. 3-1/2" x 6' L-80 EUE8RD handling pups installed above 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PSR. Baker 7" x 3-1/2" 'SA B-3' Permanent Packer set +1- 100' MD above top planned perf. Minimum ID through the packer 3.00". 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Cameo 'D' nipple wI 2.75" No-Go profile. 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Saker 3-1/2" WL Re-entry Guide wI shear out sub. Tubing tail 50' above top planned perforation. TD@ 8817' MD 16026' TVD (300' MD below base of pay) Scott L Lowry 03/13/03 O¡, · ; ! i j ~. _~ r~~ I: 0 :¡ .. .. 0 0 .. ~ ~ I: 2 .. 8 0 0 0 0 ~ 2 7 2 5 7/1' .. 0 j 2 ---- .Þ· -./~>:J;m~__ (>,~;1// ç '."-,- "'< MEr<J10 ._.____._____ ~. / ~.... CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars .,., 200 White Clay Center Dr.. N"Hark. DE 19111 .-.....-.e. . .~_ //ct-) ~~1)ðLLARS 6J /cP.-- <¡¿.u.--V'-¿'./!::f-:..C~ ..X-:' J..£rS $ í 0,:-- f ¡ -.' ~~~~~6~'~~r--=/ /~ 1~~~. ?;~ ~L/~/(/~ if /1-C:::/.~; _.~~ ~ f l /~.J #J -. :> lt1--/ c/!/t r! j 2J!}(J .~/ 62-14/311 DATE~. . S. K. ALLSUP-DRAKE PHILLIPS PETROLEUM COMPANY 700 G ST. ATO 1530 ANCHORAGE AK 99501 1032 ~ ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME 1::£ tf 3-5 - eBB 203-û~~ PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dum ber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates 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. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. '~þ ~t?MttpH~~ysi COMPANY ConocoPhillips FIELD & POOL 490100 - Kuparuk River, Kuparuk River WELL NAME Initial ClassfType KRU 3S-088 DEV /1-0IL ADMINISTRATION 1. Permit fee attached ................................................................................................... 2. Lease number appropriate ... ....................................................................................... 3. Unique well name and number ................................................................................... 4. Well located in a defined pool..................................................................................... 5. Well located proper distance from drilling unit boundary ...... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... 6. Well located proper distance from other wells... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... .. 7. Sufficient acreage available in drilling unit ...................................................................... 8. If deviated, is well bore plat included .............................................................................. 9. Operator only affected party........................................................................................ 10. Operator has appropriate bond in force... ...... ......... ... ............... ...... ...... ... ... ... ......... ...... 11. Permit can be issued without conservation order... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ..... 12. Permit can be issued without administrative approval...... ...... ...... ...... ...... ...... ... ...... ........ 13. Can permit be approved before 15-day wait ............ ... ...... ......... ... ... ...... ... ...... ...... ...... ... 14. Well located within area and strata authorized by Injection Order # 15. All wells within 1/4 mile area of review identified...... .................. ......... ... ...... ... ...... ...... ... 16. Pre-produced injector: duration of pre-production less than 3 months... ... ... ... ... ... ... ... ... ... .. 17. ACM P Finding of Consistency has been issued for this project......... ... ... ... ...... ...... ........... ENGINEERING 18. Conductor string provided......................................................................................... 19. Surface casing protects all known USDWs ................................................................... 20. CMT vol adequate to circulate on conductor & surf csg ................................................... 21. CMT vol adequate to tie-in long string to surf csg ... ... ... ... ... ... ... ... ... ... ... ... ... '" ... ... ... ... .... 22. CMT will cover all known productive horizons...... ... ... ...... ...... ...... ... ...... ...... ...... ......... ... 23. Casing designs adequate for C, T, B & permafrost............ ...... ... ............... ............ ......... 24. Adequate tankage or reserve pit... ...... ...... ...... ... ......... ......... ... ...... ......... ......... ...... ...... 25. If a re-drill, has a 10-403 for abandonment been approved... ...... ...... ...... ... ... ............ ....... 26. Adequate wellbore separation proposed ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... .... 27. If diverter required, does it meet regulations................................................................. 28. Drilling fluid program schematic & equip list adequate... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... . APPR DATE 29. BOPEs, do they meet regulation ...... ......... ...... ...... ......... ......... ......... ...... ............ ........ WGA 3/17/2003 30. BOPE press rating appropriate; test to ...................... 5000 psig ...... minimum.......... We;, J:r- 31. Choke manifold complies w/API RP-53 (May 84) .......................................................... 32. Work will occur without operation shutdown ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... '" 33. Is presence of H2S gas probable ...... .................. ......... ..................... .................. ........ (For Service Well Only) 34. Mechanical condition of wells within AOR verified ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... .... APPR DATE SFD 3/17/2003 (For Service Well Only) (For Service Well Only) (For Service Well Only) GEOLOGY 35. 36. APPR DATE 37. 38. SFD 3/17/2003 39. Permit can be issued w/o hydrogen sulfide measures ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ..... Data presented on potential overpressure zones ... ... ... ... ... ... ... ... ... ... ... ...... ... ... ... ... ... ..... Seismic analysis of shallow gas zones ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... Seabed condition survey (if off-shore) ......... ............ ........................ ............ ...... .......... Contact name/phone for weekly progress reports [exploratory only] ...... ...... ............... ..... GEOLOGY: ENGINEERING: RES. ENGINEERING: COMMISSION: RPC: WGA: X RR: 63//)' ~3 DTS: 03'} J ~l>-3' sp:r~J MJW: SFD: SFD TEM: JDH: PROGRAM Exploratory (EXP) GEOL AREA 890 Development (DEV) ~ Redrill UNIT No. 011160 Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes NA Not Applicable NA Not Applicable NA Not Applicable NA Not Applicable NA Not Applicable Yes Re-drill of pre-existing well. SFD NA Not Applicable No Possible AD. Yes Yes Yes Nabors 7ES. Yes NA Not Applicable Yes Max MW 11.3 ppg. Yes Yes MSP 2460 psi. Yes Yes No NA Not Applicable Service (SER) Well bore seg ON/OFF SHORE On Annular disposal para req ( ( Yes Yes Expected reservoir pressure gradient is 0.53 psi/ft. Mitigation measures are discussed in Drilling Hazards Summary. NA Not Applicable NA Not Applicable NA Not Applicable Operations were verbally approved by WGA on 3/13/03. Commentsl/nstructions ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation. information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ) ) Ó]03-õY-3 //7// Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu May 01 08:26:49 2003 Reel Header Service name............ .LISTPE Date.................... .03/05/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.. . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.................... .03/05/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 3S-08B 501032045002 Conoco Phillips Alaska, Inc. Sperry-Sun Drilling Services 01-MAY-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 MW0002306056 P. SMITH M. THORNTON MWD RUN 4 MW0002306056 P. ROGER M. THORNTON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 18 12N 8E 2492 954 MSL 0) 56.30 27.70 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 4263.0 ) ') 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS EFFECTED BY KICKING OFF FROM A CEMENT PLUG AT ABOUT 6496'MD / 4551'TVD IN THE 3S-08A WELLBORE . 4. MWD RUN 1 WAS DIRECTIONAL ONLY. NO DATA ARE INCLUDED IN THIS PRESENTATION. 5. MWD RUNS 3 AND 4 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS) i ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4) ¡STABILIZED LITHO-DENSITY (SLD) i AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). 6. MWD DATA ARE CONSIDERED PDC PER E-MAIL AUTHORIZATION FROM THE GKA GEOSCIENCE GROUP. 7. MWD RUNS 3 AND 4 REPRESENT WELL 3S-08B WITH API# 50-103-20450-02. THIS WELL REACHED A TOTAL DEPTH OF 8815' MD / 6062' TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL- DERIVED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA 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 = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: ') ) HOLE SIZE: ACAL-DERIVED (8.5" BIT) MUD WEIGHT: 11.3 PPG MUD SALINITY: 350 PPM CHLORIDES FORMATION WATER SALINITY: 25,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/01 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR NPHI NCNT FCNT RPX RPS RPM RPD FET RHOB DRHO PEF ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 4246.5 4250.0 4250.0 4250.0 4260.0 4260.0 4260.0 4260.0 4260.0 4267.5 4267.5 4267.5 4276.5 STOP DEPTH 8784.0 8728.0 8728.5 8728.5 8776.0 8776.0 8776.0 8776.0 8776.0 8741.0 8741.0 8741.0 8815.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ # REMARKS: BIT RUN NO 3 4 MERGED MAIN PASS. $ MERGE TOP 4246.5 6496.5 MERGE BASE 6496.0 8815.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined ) ) Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4246.5 8815 6530.75 9138 4246.5 8815 ROP MWD FT/H 0 388.3 141.307 9078 4276.5 8815 GR MWD API 51.53 441.28 119.923 9076 4246.5 8784 RPX MWD OHMM 0.52 1732.76 4.42387 9033 4260 8776 RPS MWD OHMM 0.58 1733.44 4.36685 9033 4260 8776 RPM MWD OHMM 0.19 2000 5.75089 9033 4260 8776 RPD MWD OHMM 0.04 2000 5.94229 9033 4260 8776 FET MWD HOUR 0.18 242.43 1.49896 9033 4260 8776 NPHI MWD PU-S 13.05 48.1 32.6536 8957 4250 8728 FCNT MWD CNTS 610.99 2949.86 1008.14 8958 4250 8728.5 NCNT MWD CNTS 112885 208160 138597 8958 4250 8728.5 RHOB MWD G/CM 1.827 3.239 2.35589 8948 4267.5 8741 DRHO MWD G/CM -0.1 0.664 0.0887022 8948 4267.5 8741 PEF MWD BARN 1.69 10.8 3.84454 8948 4267.5 8741 First Reading For Entire File......... .4246.5 Last Reading For Entire File.......... .8815 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/01 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...... .03/05/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR NCNT FCNT NPHI RPD FET RPM RPS RPX PEF DRHO RHOB ROP $ ) 2 ) header data for each bit run in separate files. 3 .5000 START DEPTH 4246.5 4250.0 4250.0 4250.0 4260.0 4260.0 4260.0 4260.0 4260.0 4267.5 4267.5 4267.5 4276.5 # 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 SLD CTN $ # STOP DEPTH 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON 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: # 12-MAR-03 Insite 66.37 Memory 6496.0 4263.0 6496.0 7.5 59.7 TOOL NUMBER 164580 145654 039307 105918 8.500 4263.0 LSND 11.30 47.0 9.0 350 3.7 2.050 1.170 1.350 3.100 71.0 129.0 71.0 71.0 ) 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 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF service Unit FT MWD030 FT/H MWD030 API MWD030 OHMM MWD030 OHMM MWD030 OHMM MWD030 OHMM MWD030 HOUR MWD030 PU-S MWD030 CNTS MWD030 CNTS MWD030 G/CM MWD030 G/CM MWD030 BARN Mean 5371.25 159.524 112.276 4.2766 4.25567 6.88244 6.93078 2.43 35.5735 887.734 133158 2.26875 0.0961083 3.00925 Min 4246.5 6.99 52.67 0.52 0.58 0.19 0.04 0.18 14.9 610.99 112885 1.827 -0.063 1.69 Max 6496 388.3 171.71 1732.76 1733.44 2000 2000 242.43 48.1 2387.51 188835 2.779 0.664 9.43 First Reading For Entire File......... .4246.5 Last Reading For Entire File.......... .6496 File Trailer Service name............ .STSLIB.002 Nsam 4500 4440 4500 4473 4473 4473 4473 4473 4493 4493 4493 4458 4458 4458 ) First Reading 4246.5 4276.5 4246.5 4260 4260 4260 4260 4260 4250 4250 4250 4267.5 4267.5 4267.5 Last Reading 6496 6496 6496 6496 6496 6496 6496 6496 6496 6496 6496 6496 6496 6496 ) " Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/01 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...... .03/05/01 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM PEF ROP GR RPS RPD FET NPHI FCNT NCNT RHOB DRHO RPX $ 3 ) header data for each bit run in separate files. 4 .5000 START DEPTH 6496.5 6496.5 6496.5 6496.5 6496.5 6496.5 6496.5 6496.5 6496.5 6496.5 6496.5 6496.5 6496.5 # 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 SLD CTN STOP DEPTH 8776.0 8741.0 8815.0 8784.0 8776.0 8776.0 8776.0 8728.0 8728.5 8728.5 8741.0 8741.0 8776.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON 16-MAR-03 Insite 66.37 Memory 8815.0 6496.0 8815.0 32.6 55.2 TOOL NUMBER 164580 145654 039307 105918 ) / $ # 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.....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 \ } 8.500 4263.0 LSND 11.30 53.0 9.8 350 3.6 2.200 1.140 1.900 3.100 72.0 145.0 72.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP 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 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6496.5 8815 7655.75 4638 6496.5 8815 ROP MWD040 FT/H 0 250.61 123.868 4638 6496.5 8815 GR MWD040 API 51.53 441.28 127.444 4576 6496.5 8784 ) } RPX MWD040 OHMM 1.27 109.54 4.56834 4560 6496.5 8776 RPS MWD040 OHMM 1.33 90.33 4.47591 4560 6496.5 8776 RPM MWD040 OHMM 1.42 87.73 4.64093 4560 6496.5 8776 RPD MWD040 OHMM 1.5 118.25 4.97266 4560 6496.5 8776 FET MWD040 HOUR 0.19 2.07 0.585684 4560 6496.5 8776 NPHI MWD040 PU-S 13.05 43.69 29.7146 4464 6496.5 8728 FCNT MWD040 CNTS 793.69 2949.86 1129.31 4465 6496.5 8728.5 NCNT MWD040 CNTS 121826 208160 144069 4465 6496.5 8728.5 RHOB MWD040 G/CM 2.265 3.239 2.4424 4490 6496.5 8741 DRHO MWD040 G/CM -0.1 0.436 0.0813488 4490 6496.5 8741 PEF MWD040 BARN 2.37 10.8 4.67389 4490 6496.5 8741 First Reading For Entire File......... .6496.5 Last Reading For Entire File.......... .8815 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/01 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/05/01 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. . . . . . . . . . . . . . . . . . . . .03/05/01 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