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203-119
/Image F.bject Well History File Cc..~r 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. Q Q.3 - L L 1- Well History File Identifier Organizing (done) D Two-sided 11I111111I111111111 ~escan Needed I R)$CAN ¥Color Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, No/Type: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: BY: Helen (Maria ), D Other::, I Date: 7 0, os Isd1tF·0 1 111111 Date:....... h OS Isl ~ NOTES: Project Proofing BY: Helen\ Maria '") Scanning Preparation BY: HelerC Maria.) I x 30 = ~() + Ll- = TOTAL PAGES 3L/- (Count dods¡no~ include cover sheet)", Ai) Date:t=! ~ OS Isl r VI, Production Scanning Stage 1 Page Count from Scanned File: :3S II I (Count does include cover sheet) BY: Page Count Matches Number in Scanning Preparation: ¡"./YES NO Heie~Maria) Date:1/~ 06' Is! vv¡p If NO in stage 1 page(s) discrepancies were found: YES NO Stage 1 BY: Helen Maria Date: Isl III 1111111111I 11111 11I1111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned I BY: Helen Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 • • -:~.__ , MICROFILMED 03/01 /2008 DO NOT PLACE "" ~_ ;~.- '- .~. ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\C~rPgs_Inserts\Microfilm_Marker. doc ) (QJ ~fl\l'--r íè ~ ~. ~ ® l:ll6:. ~ "IJ!( !ß' / cQ) IJ J1-_ lb l:¿.J W ~W @ lüW / AI~ASKA OILAlWD GAS . CONSERVATION COlWlISSION / ) FRANK H. MURKOWSKI, GOVERNOR R. Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 333 w. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Oliktok Point State, #2 ConocoPhillips Alaska, Inc. Permit No: 203-119 Surface Location: 1669' FNL, 2334' FWL, SEC. 9, T13N, R9E, UM Bottomhole Location: 1880' FNL, 437' FEL, SEC. 33, TI4N, R9E, 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. . Well targest a fault block that has not been produced. H2S monitoring equipment will be functional at all times. Over-pressure not expected. Kuparuk reservoir pressure expected to be 10.1 ppg EMW; reservoir will be drilled with 10.5 ppg mud. Operations must be conducted in acçordance 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). Sincerely, ~ cG--e.L:.--,,-- Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this2.l day of June, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section WGI\-- ~lulut!J"$. ') STATE OF ALASKA ) ALASKA blL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1a. Type of work [X] Drill [] Redrill 1 b. Type of well [ ] Service [ ] Development Gas [X] Single Zone r J Re-Entry [ ] Deepen r J Exploratory [ J Stratigraphic Test [X] Development Oil 2. Name of Operator /J -LJ . //.. 5. Datum Elevation (OF or KB) 10. Field and Pool WINSTAR.P£TROlEUM, LLG. ... ( .P-tAcx::o r&(..,.( /Ir~ h. 38.8' OF (AMSL) 3. Address - /. /~. 6. Property Designation Kuparuk River Oil Pool 3111 C ST., SUITE 500, ANCHORAGE, ALASKA 79703 ADL 388584 4. Location of well at surface 7. Unit or Property Name 1669' FNL, 2334' FWL, Sec. 9, T13N, R9E, UM Oliktok Point State At top of productive interval 8. Well Number 2258' FNL, 525' FEL, Sec. 33, T14N, R9E, UM NO.Gt At total depth ~-;..o! -9. Approxil}Játe s d date Amount 1B80' FNL, 437' FEL, Sec. ~T14N, R9E, UM {7/10 $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Num~~es in property 15. Proposed depth (MD and TVD) 525' at top of productive interval At 870': 33' from Oliktok pt. St #1 1,~ J~ 13,334' MD, 7,089' TVD 16. To be completed for deviated wells 17. Anticipated pressure {se~,20 MC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 63 deg Maximum surface 2,260 ~g, At total depth (TVD) 18. Casing Program Setting Depth Size Specifications Top Bottom Casing Weight Grade Coupling Length MD TVD MD TVD 16" BO' 33' 33' 110' 110' 9~5/8" 40# L-80 BTC 6,942' 33' 33' .16,975' 4,177' 7" 26# L~80 STCM 13,301' 33' 33' /13,334' 7,089' [ J Multiple Zone 11. Type Bond (See 20 AAC 25.025) Statewide Number #59-52~180 3,700 psig Hole Quantity of Cement (include stage data) Grouted to surface Lead: 800 sx Arcticset, Tail: 550 sx LiteCRETE 270 sx Class G 12-114" 8-1/2" 19. To be completed for Redrìll, Re-entry, and Deepen'Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Plugs (measured) Junk (measured) Casing Length Size Cemented MD TVO Structural Conductor Surface Intermediate Production liner JUN 2 (; Z003 Perforation depth: measured true vertical I. 11:1, ,~,I A\as~(~& \Jj! (.~ 20. Attachments [ Xl Filing Fee [X] Property Plat [ ) BOP Sketch [ J Diverter Sketch [ X] Drilling Program [ Xl Drilling Fluid Program [X] Time vs Depth Plot [] Refraction Analysis [ ) Seabed Report [ ] 20AAC25.050 Req. Contact Engineer Name/Number: Bill Penrose (907)258-3446 Prepared By Name/Number: Bill Penrose (907)258-3446 21. I hereby certi~Jh,êt the foregoing is true and correct to the best of my know!edge Signed \, ~~~ \ \.,~ R. Thomas' r me Kuparuk Drilling Team Leader Commission Use Only Date 6 ('?-5" f<> ) Permit Number CJ IAPI Number ~ -ö,.,¡Q- 2.316/ _ 06 A?~r al DË 31 See cover letter .203 -II I ~ (....'.G-I ø ~ ~ ') for other requireme. nts Conditions of Approval: Samples Required: [ ] Yes I)(No ud 9 Required l J Yes ~o Hydrogen Sulfide Measures: [ ] Yes )4'No Directional Survey Req'd .MYes [ ] No Required Working Pressure for BOPE: [12M, [13M, [] 5M, [] 10M, [] 15M Other: 'T-eç t- ß o¡,) E tc 5"000 J> ç i . ~VC\.-, V'¿q~N J µ r øc../ r-~~fe- UC"L1 P 1V'JYor..~. ~~ A' 0 by order of ~ '~? Approved By / i _ 1:1 . ~ Commissioner the commission Date ()J . Form 10-401 Rev. 12~01-85 Submit In riplicate OR\G\NAL ,,;tJ: ,\·:)L.: -.-..-- 1<"1'1 " i<)"( , <~\~N (.j ) ) Oliktok Point State #2 Proposed Drilling Program /' " 1. MIRV Doyon 141. / 2. Install diverter system. /"" 3. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run LWD ' logging equipment with OR tool only. 4. Run and cement 9-5/8" 40#, L-80 BTC casing string to surface. Employ lightweight penTIafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surface. If cement does not circulate to surface, utilize port /' collar installed in casing to pump a second cement stage. Install and test BOPE to 5000 psi. Test casing to 2500 psi. 5. Drill out cement and 20' of new hole. PerfonTI LOT. 6. Drill 8-1/2" hole to contingent top-set casing point according to directional plan. Run LWD logging equipment with OR and resistivity. POOH and PIU neutron density tool, drill well to total depth according to directional plan, and run 7" 26# L-80 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-80 EVE 8rd-Mod completion assembly wi penTIanent packer and PBR. Set packer, shear out ofPBR, PIU tubing hanger, and land tubing. Pressure test tubing to 3500 psi. Pressure test 3 Yí" x 7" annulus to 3500 psi. Burst shear valve for freeze protect. 8. Set TWC and ND BOPE. Install and pressure test production tree. 9. Freeze protect. Secure well. Rig down and move out. /' 16" X 30" I insulated I conductor @ +/- ,125' I J TAM 9-5/B" Port Collar Std Grade BTC Threads ( +/- 1000 I MDITVD) Surface csg. 9-5/B" 40# L-BO BTC ( 6975' MD) A Sand Perfs (To be determined after logging) Production csg 7" 26 # L-BO STCM (+/- 13,334 MD ) ) ) J Oliktok Point State # 2 /" Proposed Completion Schematic Lonastrina Completion I I I T T I Ib dl ~~--R·~·' ,"=11 I I I ~ ~ ---. ~ ~ ~ 6' Handling pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing I _ I - - I Baker 3-1/2" WL Re-entry Guide w/ shear out sub. I I Tubing tail 50' above top planned perforation. ~ I ~ F ~ ~ I --I ~ ~ I I - œ L 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-BO EUEBRD pin down. Special Drift 2.91" 3-1/2" tbg Retrievable SSSV @ +/- 2500' I I ........ GLM Placement: Placement TBD Valves #1-4: 3-1/2" X 1" KBUG Valve #5: 3-1/2" X 1-1/2" 'MMG' GLM w/DCR Dump Kill Valve ( 3000 psi casing to tubing shear). 6' L-BO handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-BO, 9.3# EUE 8rd Mod TUbing 3-1/2" Baker'CMU' sliding sleeve w/2.B13" Camco No-Go profile, EUE8RD box X pin. 3-1/2" X 6' L-BO EUE8RD handling pups installed above. 1 Joint 3-1/2", L-BO, 9.3# EUE Brd Mod Tubing 6' Handling pup Joint 3-1/2", L-BO, 9.3# EUE Brd Mod Tubing Baker 'BO-40' PBR Baker 7" x 3-1/2" 'SAB-3' Permanent Packer set +/- 100' MD above top planned perf. Minimum ID through the packer 3.00" 3-1/2" Camco "D" Nipple with 2.75" ID No-Go profile TD @ 13,334 MD / 7089'TVD Bill Ponro.. 4/03 16.. X 30" ~ insulated ~ conductor @ +/- ,125' I ~ TAM 9-5/8" Port Collar Std Grade BTC Threads ( +/- 1000' MD/TVD) Surface csg. 9-5/8" 40# L-80 BTC ( 6975' MD) Production csg 7" 26 # L-80 STCM / (+/-12,500 MD ) A Sand Perfs (To be determined after logging) Production liner 3-1/2" 9.36 # L-80 SLHT (+/-13,334 MD ) ) ) Oliktok Point State # 2 // Proposed Completion Schematic Topset Case ~ ~ I I 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RD pin down. Special Drift 2.91" I I I I I ~ ~ ~~ ~ ~ ~ ~ ~ C' ~ I I 3-1/2" Camco "D,S" landingnipple with 2.875" 10 No-Go, set @+/- 500' MD ~ ~ ~ ~ I I 3-1/2" tbg Retrievable SSSV @ +/- 2500' ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I I GLM Placement: ~ ~ ~ ~ Placement TBD ~ ~ I I Valves #1-4: 3-1/2" X 1" KBUG ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Valve #5: 3-1/2" X 1-1/2" 'MMG' GLM w/DCR Dump Kill Valve ( 3000 psi casing to tubing shear). I I 6' L-80 handling pups installed on top and bottom of mandrel. I I I I 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing ~ ~ ~ ~ I B I ~ ~ 3-1/2" Baker'CMU' sliding sleeve w/ 2.813" Camco No-Go profile, EUE8RD I I box X pin. 3-1/2" X 6' L-80 EUE8RD handling pups installed above. ~ ~ I I 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing ~ ~ i ~~ I 5.125" X 3" Baker locator sub I·, '~~~~~. '.~ ~1/2" Baker GBH-22 casing seal assemblyw/ 12'stroke, 3-1/2" L-80 ~ 11 ~ EUE8RD box up ~ ~~~ ~ ~ i I I ~ TIner Assembly (run on drillpipe). 150' of liner overlap ~ I I ~ ~ I I L Baker 7" X 5" 'ZXP' Liner Top Isolation Packer with HR profile I I Baker 7" X 5" 'Flexlock' Liner Hanger I I Baker 20' Seal Bore Extention I I I I XO Sub, 5" Stub Acme box x 3-1/2" SLHT pin I I 3-1/2" 9.3# L-80 SLHT liner as needed i i I I 3-1/2" Baker Landing Collar J 1 jt 3·1/2" 9.3# L·80 SLHTtubin9 :1\1 3-1/2" Baker Float Collar I 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Shoe TO @ 13,334 MD / 7089'TVD Bill P.n.o.. 4/03 0.00 - \ -1000.00 - -2000.00 - -3000.00 -4000.00 - -5000.00 -6000.00 - ~ m æ -7000.00- J: ë. Q) c -8000.00 - -9000.00 - -10000.00 - -11000.00 - -12000.00 - -13000.00 -14000.00 / 2 MIRL Doyon' 41 3 ) Drill 12-1/4" 10le 4 ) Oliktok Pt. State #2 Rur and cmt 9-5/8" csg N/U BOPE, Corduct LOT , nun :mj C1'" csg Comploto Well J 5 8 9 10 11 12 13 14 15 16 17 18 19 Day 6 7 ) ) ConocoPhillips Alaska, Inc. Drilling Fluid Program, Pressure Calculations, and Drilling Area Risks Oliktok Point State #2 Drillin2 Fluid Properties: Density Funnel Vis YP PV 10 Second Gel 10 Minute Gel pH API Filtrate % Solids 12-1/4" Hole Section Surface to Base Permafrost (45' to 1,902'MD) 8.5 - 9.4 150 - 200 30 - 60 8 - 22 1 0 - 30 25 - 55 8-9 8 - 15 5-8 Drillin2 Fluid System: 12-1/4" Hole Section Base Permafrost to Csg pt. (1,902' - 6,975'MD) <9.4 65 - 150 20 - 40 1 5 - 30 10 - 25 20 - 40 8-9 <8 5 - 11 8-1/2" Hole Section Surface Csg pt to TD (6,975' - 13'J.34",..,3. D) 9.0-~ 40 - 55 ... 5 - 26 6 - 25 3-7 6 - 14 9 - 10 <6 4 - 12 Specifications of the drilling fluid system for Doyon Rig 141 are on file with the Commission. BOP System and Diverter: Specifications for the blowout prevention equipment, including diverter, for Doyon Rig /' 141 are on file with the Commission. Maximum Anticipated Surface Pressure: The maximum anticipated surface pressure (MASP) for this well will be the lesser of the fOnTIation pore pressure (less a full gas column to the surface) at TD or the fOnTIation fracture pressure at the last casing shoe (less a full gas column to the surface). Based on offset well data, the highest fOnTIation pressure expected in the final hole section is 3,700 psi at the well's TD of 7,089' TVD (or 0.522 psi/ft). Documented fracture gradient data for this area indicates that the fracture gradient at 4,177'TVD (the 9-5/8" surface casing shoe) is a minimum of 0.650 psi/ft (12.5 ppg). Complete evacuation of the wellbore, except for a 0.11 psi/ft gas gradient, is assumed. , ') 8-1/2" hole section MASP (pore pressure) MASP (fin breakdown) -""'~-) ,/-,,,,.,,~/ (7,089 ft)(0.522 - 0.11) =42.22Y6si _, (4,177 ft)(0.650 - 0.11) =~ p~i /' Therefore, MASP in the 8-1/2" open hole section is 2,256 psi and the 5,000psi BOPE /' system to be used will be adequate. Well Proximity Risk: The nearest wellbore to that of the Oliktok Point State #2 is the Oliktok Point State #1. OPS #2 will pass 33' from OPS #1 at a depth of 870'MD. Drillin2 Area Risks: See attached Drilling Hazard Summary. Disposal of Muds and Cuttin2s: Surficial gravels drilled up in the shallow part of the well will be processed through the drilling rig's rock washer and retained on location in cuttings bins. They will then be tested and beneficially re-used as road/pad fill material within the Kuparuk River Unit. The remainder of the drill cuttings will be processed in the rig's ball mill, blended with waste mud and injected down designated Class II disposal we1l3R-l1. ) ') OLIKTOK POINT STATE #2 DRILLING HAZARDS SUMMARY 12-1/4" Hole / 9-5/8" Casine Interval EVENT Broach of Conductor Gas Hydrates Gravel/Sand Sloughing to 500' Hole Swabbing/Tight Hole on Trips Possible thaw bulb/water flow Lost Circulation 8-1/2" Hole / 7" Casine Interval Event Shale stability in HRZ, K-l, and Miluveach High ECD and swabbing with higher MW's required Barite Sag Differential Sticking Abnormal Reservoir Pressure Lost Circulation RISK LEVEL Low Low Moderate Moderate Low Low Risk Level Low Moderate Low Moderate Moderate Moderate Mitieation Strateey Monitor cellar continuously during interval. If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, additions of Lecithin. Increase mud weight/viscosity, High viscosity sweeps. Monitor fill on connections Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), pumping out of hole as needed. Watch return viscosity for signs of thinning. Increased mud weight/viscosity as needed. Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM /' Mitieation Strateey 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. Oliktok Point State #2 Casin2 Properties and Desi2n Casing Performance Properties Internal Collapse Tensile Strength Size Weight Yield Resistance Joint Body TVD MD Design Safety Factor* (in.) (lb/ft) Grad~ Cnxn fuill fuill (1,OOOlbs) (ft RKB) (ft RKB) T B C / / 9-5/8 40 L-80 BTC 5,750 3,090 979 916 4,177 6,975 3.82 2.55 1.95 ",.- 7 26 L-80 BTCM 7,240 5,410 667 604 7,089 13,334 2.05 3.20 1.86 * T ensile design safety factors are calculated using pipe weight less buoyancy. Burst design safety factor for 7" casing is calculated using Maximum Anticipated Surface Pressure. Collapse design safety factors are calculated assuming complete evacuation of the casing. Casing Setting Depth Rationale 9-5/8" 6,500' RKB, MD Surface casing to provide an anchor for BOP equipment and sufficient fracture gradient until the reservoir is reached. Production casing to provide hole stability and pressure containment for production operations. - ~ 7" 11,147' RKB, MD * -+- XFRMR UGHT POlE- * ~ UGHT POLE-* ~ I I I I I ... @ @ 5 6 7 8 9 1) 1112 C-08 j.-- I ~-~ a~"-~-L_--'L-_ I aoO PlUNG CH. Y-¡ aDD I I a ---r @ @ ... @ ... @ @ ... ... @ · 22 ;6141j 25171313 2J21 ESD ..00 -i0- TEST SEPERA TOR l-07 (f) w LAUNafER ..00 Z ] E-04 a . ~ "ETH TANK, PlUNG ONlY ~ I ~ ~ PIGGING PROOH~!g --~, "~T RESERVE PIT ~-( OLIKTOK ROAD r . " APPROVAl: DATE: DRA'MNG NO. REV. CUST DATE RE\1S1~S BYQI(£~ ~/ "\ " LEGEND / @ EXISTING PRODUCER ... EXISTING IN.£CTOR I ABANDONED CONDUCTOR 150' SCALE: 1" = "-.-I / " ; --~ Drill Site 3R Plot Plan CADD NO. SHEET: REV: Rig: Doyon 141 Location: Wildcat Client: Winstar Revision Date: 6/19/2003 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 16",62.6# casing at 120' MD < Sase of Permafrost at 1,985' MD (1,770' TVD) < Top of Tail at 4,195' MD < Top of West Sak at 4,695' MD < 95/8",40.0# casing in 12 1/4" OH TD at 6,975' MD (4,177' TVD) Mark of Schlumberger ) ) Schlulbl.gør Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 300% excess in the permafrost and 40% excess below the permafrost. The top of the tail slurry is designed to be 500' above the West Sak formation. Lead Slurry Minimum pump time: 280 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.28 ft3/sk 91.6ft3 2336.5 ft3 969 ft3 3397.1 ft3 793.7 sks 0.7632 ft3/ft x (120') x 1.00 (no excess) = 0.3132 ft31ft x (1985' - 120') x 4.00 (300% excess) = 0.3132 ft31ft x (4195' -1985') x 1.40 (40% excess) = 91.6 ft3 + 2336.5 ft3+ 969 ft3 = 3397.1 ft3 I 4.~~k = Round up ~~SkS Have 280 ~ of addItIOnal Lead on locatIon for Top Out stage, If necessary. Tail Slurry Minimum pump time: 190 min. (pump time plus 90 min.) LiteCRETE @ 12.0 ppg - 2.28 ft3/sk 1219 ft3 34.1 ft3 1253.1 ft3 549.6 sks 0.3132 ft31ft x (6975' - 4195') x 1.40 (40% excess) = 0.4257 ft31ft x 80' (Shoe Joint) = 1219 ft3 + 3~'1 ft3- 1253.1 ft31 2.2 I = Round up t 5 sks BHST = 93 -; Estimated BHCT = 87°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHED.ULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 7 50 7.1 7.1 Drop Bottom Plug 5.0 12.1 MudPUSH XL 7 50 7.1 19.2 Lead Slurry 7 610 87.1 106.3 Tail Slurry 7 223 31.9 138.2 Drop Top Plug 5.0 143.2 Displacement 9 508 56.4 199.6 Slow Rate 3 15 5.0 204.6 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.2 ppg MudPUSH* XL, Pv? 17-21, Ty ? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ) ) Winstar Oliktok Pt. State #2 Schlumb8Pg8P CemCADE Preliminary Job Design 7" Production Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: Wildcat Client: Winstar Revision Date: 6/19/2003 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Volume Calculations and Cement Systems Volumes are based on 75% excess. Tail slurry is designed for 800' MD above target - (1334' MD annular length). Tail Slurry Minimum thickening time: 190 min. (Pump time plus 90 min.) 15.8 ppg Class G + 2.0 gps D600G + 0.02% B155 + 0.3% D65 + 0.2 gps D47 + 1/4# per Sack D29 - 1.16 ft3/sk Previous Csg. < 95/8",40.0# casing at 6,975' MO 0.1268ft3/ft x 1334' x 1.75 (75% excess) = 0.2148 ft31ft x 80' (Shoe Joint) = 296.0 ft3 + 17.2 ft3,~ 313.2 ft3/1.1f¿6i~S'2' Round up t ~..5 BHST = 168° " Estimated BHCT = 129°F. (BHST calculated using a gradient of 2. 6°F/1 00 ft. below the permafrost) 296.0 ft3 17.2 ft3 313.2 ft3 270.0 sks PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 6 30 5.0 5.0 Drop Bottom Plug 5.0 10.0 MudPUSH XL 6 40 6.7 16.7 Tail Slurry 6 56 9.3 26.0 Drop Top Plug 5.0 31.0 < Top of Tail at Displacement 6 487 81.2 112.2 Slow Rate 3 20 6.7 118.9 12,000' MO MUD REMOVAL < 7",26.0# casing in 8 1/2" OH Recommended Mud Properties: 10.6 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* XL, Pv? 19-22, Ty ? 22-29 TO at 13,334' MO (7,089' TVO) Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ConocoPhillips Alaska, Inc. Created by bmichael For: B Penrose Date platted: 19-t.4ay-2D03 Plat Reference i. Oliktak pt 5t 2 VerslJ1. Coordinate. are in feet reference .Iat 18. True Vertical Depth. are reference RKB(DayanHI41). iii. IIfILs Structure : Pad 3R Well: 8 ~ ConocoPhillips Field : Kuparuk River Unit Location: North Slope, Alaska INTF.Q ~ = c::=:= = PROF~LE COMM NT DATA ==== ----- Point ----- MO Inc Oir TVO No rt h East V. Sect Oeg/100 KOP 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 Build/Turn 3/100 749.99 10.00 40.00 747.46 33.34 27.98 38.95 2.00 B/ Permafrost 1902.38 43.48 15.65 1764.00 506.22 204.67 540.01 /3.00 EOC 2548.44 62.75 12.95 2149.99 1004.90 330.23 1054.22 3.00 Top West Sak 51 0 1 .40 62.75 12.95 3319.00 3216.71 839.01 3323.69 0.00 Base West Sak 6979.51 62.75 12.95 4179.00 4843.86 1213.30 4993.26 0.00 - 9 5/8 Csg pt 7079.51 62.75 12.95 4224.79 4930.50 1233.23 5082.16 0.00 Top Kuparuk 12591.57 62.75 12.95 6748.80 9706.01 2331.74 9982.16 0.00 Target-LCU/Top A 12897.29 62.75 12.95 6888.79 9970.88 2392.67 10253.94 0.00 Base Kuparuk 13148.45 62.75 12.95 7003.80 10188.48 2442.73 1 0477.21 0.00 TO - Casing pt. 13334.08 62.75 12.95 7088.80 10349.30 2479.72 10642.23 0.00 Created by bmichoe' For: B Penrose Dote plotted : 19-Moy-2003 Plot Reference i. Oliktak pt 5\ 2 Ve"I1. Coordinates ore in feet reference slot lB. True Vertical Depth. ore reference RK8(DoyonI141). .. ... 0 - 600 - 1200 - 1800 - ,--... +- Q) Q) 2400 - '+- ~ ..r: +- 3000 - 0.. Q) 0 0 3600 - Ü :;:: L Q) 4200 - > Q) :J 4800 - L l- I V 5400 - 6000 - 6600 - 7200 - 7800 600 INTF.Q a RKB Elevation: 38.8' KOP Build/Turn 3/100 TANGENT ANGLE 62.75 DEG ConocoPhillips Alaska, Inc. Structure : Pad 3R Well: 8 ~ ConocoPhillips ~M "- Azimuth 13.49 with reference 0.00 N, 0.00 E from slot #8 Vertical Section (feet) -> Field : Kuparuk River Unit Location North Slope, Alaska 13.49 AZIMUTH 10253' (TO TARGET) ***Plane of Proposal*** <f TRUE Top West Sak Base West Sak 9 5/8 Csg pt Top Kuparuk Target-LCU/Tap A Base Kuparuk ~ TO - Casing pt. o 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 C",atad by bmichoal For: B Penrose Data plottad : 19-Moy-2DDJ Plot Rafa",nca is Ollktok pt 5t 2 Va",#'. Coordinates are in feet refcrcncCl :slot (18. Trus Varticol Depth. ora ",fa",nca RKB(Doyon#141). .£ INTEQ ^ 6000- I ,-.., CD 5400- Q) '+- '--" ..!: +- !.... o Z 1 0600 - 10200 - 9600 - 9000 - 8400 - 7600 - 7200 - 6600 - 4600 - 4200 - 3600 - 3000 - 2400 - 1600 - 1200 - 600 - ) ConocoPhillips Alaska, Inc. ..../ ConocoPhillips ~,~ Structure : Pad 3R Well : 8 Field: Kuparuk River Unit Location: North Slope. Alaska TD LOCATION: 1880' FNL, 437' FEL SEC. 33, T14N, R9E TD - Casing pt. Base Kuparuk Target-LCU/Top A Top Kuparuk TARGET LOCATION: 2258' FNL, 525' FEL SEC. 33, T14N, R9E 13.49 AZIMUTH 10253' (TO TARGET) ***Plane of Proposal*** <f TRUE o SURFACE LOCATION: 1669' FNL, 2334' FWL SEC. 9, T13N, R9E 600 600 600 1200 1600 2400 3000 3600 4200 4600 5400 6000 East (feet) -> ) ConocoPhillips Alaska, Inc. Pad 3R 8 slot #8 Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License Oliktok pt St 2 Vers#l prop355 Date printed Date created Last revised 16-May-2003 10-Dec-1991 16-May-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 30 8.305,w149 51 1.222 Slot location is n70 29 51.898,w149 49 52.391 Slot Grid coordinates are N 6031694.240, E 520639.120 Slot local coordinates are 1667.87 S 2338.27 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North All data is in feet unless otherwise stated. Coordinates from slot #8 and TVD from RKB(Doyon#141) (38.80 Ft above mean sea level). Bottom hole distance is 10642.23 on azimuth 13.47 degrees from wellhead. Total Dogleg for wellpath is 63.95 degrees. Vertical section is from wellhead on azimuth 13.49 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ 7678.36 8122.84 8567.32 9011. 80 9456.28 5455.96 5900.44 6344.92 6789.40 7233.88 4122.52 4567.00 4993.26 Base West Sak 5011. 48 5082.16 9 5/8" Csg pt 2344.59 2789.07 3233.55 3323.69 Top West Sak 3678.04 925.01 1011.44 1054.22 EOC 1455.63 1900.11 540.01 B/ Permafrost 608.91 683.05 760.59 841. 32 295.92 350.23 408.85 471.62 538.37 93.81 124.58 160.28 200.82 246.07 19.11 31.56 38.95 Build/Turn 3/100 47.36 68.04 0.00 0.00 KOP 0.39 3.51 9.76 Vert Sect PROPOSAL LISTING Page 1 Your ref : Oliktok pt St 2 Vers#l Last revised : 16-May-2003 ) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 3.00 3.00 0.00 0.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 2.00 2.00 2.00 3.00 3.00 0.00 0.00 2.00 2.00 2.00 Dogleg Deg/100ft 1815.26 E 1914.91 E 2014.56 E 2114.20 E 2213.85 E 1317.03 E 1416.68 E 1516.33 E 1615.97 E 1715.62 E 1018.09 E 1117.74 E 1213.30 E 1217.39 E 1233.23 E 619.51 E 719.16 E 818.80 E 839.01 E 918.45 E 300.71 E 320.58 E 330.23 E 420.22 E 519.86 E 204.67 E 222.97 E 242.04 E 261. 39 E 280.97 E 133.58 E 150.50 E 167.94 E 185.87 E 204.23 E 58.50 E 72.11 E 86.46 E 101.52 E 11 7.24 E 13.73 E 22.67 E 27.98 E 33.66 E 45.67 E 0.00 E 0.00 E 0.28 E 2.52 E 7.01 E 7460.74 N 7893.93 N 8327.11N 8760.30 N 9193.49 N 5294.80 N 5727.99 N 6161.18 N 6594.36 N 7027.55 N 3995.24 N 4428.43 N 4843.86 N 4861. 62 N 4930.50 N 2262.49 N 2695.68 N 3128.87 N 3216.71 N 3562.05 N 879.11 N 963.22 N 1004.90 N 1396.12 N 1829.31 N 506.22 N 572.69N 644.36 N 719.46 N 797.78 N 272.27N 324.06 N 380.16 N 440.41 N 504.65 N 82.43 N 110.81N 144.09 N 182.16 N 224.93 N 16.36 N 27.02 N 33.34 N 40.63 N 59.01 N 0.00 N 0.00 N 0.33 N 3.01 N 8.35 N R E C TAN G U L A R COO R DIN ATE S 5562.10 5791.06 6020.01 6248.96 6477.92 4417.34 4646.29 4875.24 5104.20 5333.15 3730.48 3959.43 4179.00 4188.38 4224.79 2814.66 3043.62 3272.57 3319.00 3501.52 2076.98 2127.26 2149.99 2356.76 2585.71 1764.00 1833.09 1900.16 1963.27 2022.27 1445.37 1529.21 1610.12 1687.88 1762.27 990.51 1085.41 1178.60 1269.83 1358.83 599.13 698.15 747.46 796.60 894.15 0.00 250.00 300.00 399.93 499.68 12.95 12.95 12.95 12.95 12.95 12.95 12.95 12.95 12.95 12.95 12.95 12.95 12.95 12.95 12.95 12.95 12.95 12.95 12.95 12.95 13 .46 13 .12 12.95 12.95 12.95 15.65 15.14 14.67 14.24 13.84 18.54 17.67 16.91 16.25 15.67 27.04 24.39 22.40 20.84 19.59 40.00 40.00 40.00 36.18 30.72 0.00 0.00 39.99 40.00 40.00 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 58.32 61.30 62.75 62.75 62.75 43.48 46.39 49.37 52.35 55.33 31.54 34.50 37.47 40.44 43.41 16.91 19.80 22.71 25.64 28.58 7.00 9.00 10.00 11.32 14.08 0.00 0.00 1. åo 3.00 5.00 10000.00 10500.00 11000.00 11500.00 12000.00 7500.00 8000.00 8500.00 9000.00 9500.00 6000.00 6500.00 6979.51 7000.00 7079.51 4000.00 4500.00 5000.00 5101.40 5500.00 2400.00 2500.00 2548.44 3000.00 3500.00 1902.38 2000.00 2100.00 2200.00 2300.00 1500.00 1600.00 1700.00 1800.00 1900.00 1000.00 1100.00 1200.00 1300.00 1400.00 600.00 700.00 749.99 800.00 900.00 0.00 250.00 300.00 400.00 500.00 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth ConocoPhillips Alaska, Inc. Pad 3R,8 Kuparuk River Unit, North Slope, Alaska ) All data is in feet unless otherwise stated. Coordinates from slot #8 and TVD from RKB(Doyon#141) (38.80 Ft above mean sea level). Bottom hole distance is 10642.23 on azimuth 13.47 degrees from wellhead. Total Dogleg for wellpath is 63.95 degrees. Vertical section is from wellhead on azimuth 13.49 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 3R,8 Your ref : Oliktok pt St 2 Vers#l Kuparuk River Unit,North Slope, Alaska Last revised : 16-May-2003 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect 12500.00 62.75 12.95 6706.87 9626.67 N 2313 .49 E 0.00 9900.76 12591.57 62.75 12.95 6748.80 9706.01 N 2331.74 E 0.00 9982.16 Top Kuparuk 12897.29 62.75 12.95 6888.79 9970.88 N 2392.67 E 0.00 10253.94 Target-LCU/Top A 12897.31 62.75 12.95 6888.80 9970.89 N 2392.67 E 0.00 10253.96 OliktokPtSt#2 Rvsd 15-May-03 13000.00 62.75 12.95 6935.82 10059.86 N 2413 .14 E 0.00 10345.24 13148.45 62.75 12.95 7003.80 10188.48 N 2442.73 E 0.00 10477.21 Base Kuparuk 13334.08 62.75 12.95 7088.80 10349.30 N 2479.72 E 0.00 10642.23 TD - Casing Pt. ) ) 2392.67E 16-May-2003 9970.89N OliktokPtSt#2 Rvsd 1 523007.000,6041670.000,0.0000 6888.80 ----------------------------------------------------------------------------------------------------------- Revised Rectangular Coordinates T.V.D. Geographic Location Target name ------------------------------------- ------------------------------------- Targets associated with this wellpath 1228.71E 9 5/8" Csg 2479.72E 7" Casing 4910.83N 10349.30N 4214.39 7088.80 O.OOE 7056.80 O.OOE 13365.00 O.OON O.OON 0.00 0.00 0.00 0.00 ----------------------------------------------------------------------------------------------------------- 250.00 250.00 0.00 N 0.00 E KOP 749.99 747.46 33.34 N 27.98 E Build/Turn 3/100 1902.38 1764.00 506.22 N 204.67 E B/ Permafrost 2548.44 2149.99 1004.90 N 330.23 E EOC 5101. 40 3319.00 3216.71 N 839.01 E Top West Sak 6979.51 4179.00 4843.86 N 1213.30 E Base West Sak 7079.51 4224.79 4930.50 N 1233.23 E 9 5/8" Csg pt 12591.57 6748.80 9706.01 N 2331.74 E Top Kuparuk 12897.29 6888.79 9970.88 N 2392.67 E Target-LCU/Top A 12897.31 6888.80 9970.89 N 2392.67 E OliktokPtSt#2 Rvsd 15-May-03 13148.45 7003.80 10188.48 N 2442.73 E Base Kuparuk 13334.08 7088.80 10349.30 N 2479.72 E TD - Casing Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- Comment Rectangular Coords. TVD MD -------------------- -------------------- Comments in wellpath PROPOSAL LISTING Page 3 Your ref : Oliktok pt St 2 Vers#l Last revised : 16-May-2003 ConocoPhillips Alaska, Inc. Pad 3R,8 Kuparuk River Unit,North Slope, Alaska ) wa.. BfIIL., INTEQ SVY# Tie-In 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 Meåsured Depth 0.00 ~99·.0Q 3qq~9° '400.00 POO.Oo 600;00 709.·90 74.~:~9 apo.oo 900:00' 1~~Q:09 ,1199,90 1299;00 W90,QO 1400:00 1S00.00 1600;00 1199.00 1899.00 1;990..00 1~92.~8 ~QPO,Q9 ~100;00 220,0:0.0 ?~Qo.QO g4qp:oo 290Q;00 2548:44 ~OQQ.Qq ';3~~,ø:;db 4009,90 4500..00 5QOO,00 ~191,.:40 , ··5SÖò'iÖO: 6()OO;00 6$00.00 6979;51 7°99..00 7079.51 7500.00 8000.00 ~599;°.o 9000.00 9500.00 10000.0.0 10500.00 11000.00 11500.00 12000.00 12500.00 12591.57 12897.29 12897.31 13000.00 13148.45 13334.08 Angle deg 0.00 0.00 1.00 3.00 5.00 7.00 9.00 10.00 11.32 14.08 16.91 19.80 22.71 25.64 28.58 31.54 34.50' 37.47 40.44 43.41 43.48. 46.39 49.37 52.35 55.33' 58.32 61.30 62.75 62.75 62.75·,·' 62.75 62.75 62.75 62.75 62.75·;;"'1' 62.75 62.75 62.75, 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 62.75 OliktokPt St#2 Version#1 AZimuth .TVD"RKB deg., ft 0.00 0.00 0.0.0 250.00 39.~9 300.00 40~OO 399.93 40.00 499.68 40.00 599.13 ~ROQ 698.15 ~Q.OQ 747.46 36',t8 796.60 30:72 894.15 ?7CÖ41 990.51 ?~.~,~ 1085.41 ,??49 1178.60 20.8.4, 1269.83 19;59 1358.83 .1i8:54 1445.37 17:67 1529.21 16~91 1610.12 16.25 1687.88 15;67 1762.27 19.6,~ 1764.00' 15:14 1833.09 14;67 1900.16 1~.2~ 1963.27 13.84 2022.27 13.46 2076.98 1~.1;2: 2127.26i,' 12;95 2149.99' , 12;~P 2356.76 ···:1:~:95 2585.71 1?~§ 2814.66 19.9!5 3043.62 12..95 3272.57 1?:95 3319.00 '1,'2:96 3501.52 12.95 3730.48 12;95 3959.43 12.95 4179.00 12,.95 4188.38 12.95 4224.79 12.95 4417.34 12;95 4646.29 12:95 4875.24 12.95 5104.20 12.95 5333.15 12.95 5562.10 12.95 5791.06 12.95 6020.01 12.95 6248.96 12.95 6477.92 12.95 6706.87 12.95 6748.80 12.95 6888.79 12.95 6888.80 12.95 6935.82 12.95 7003.80 12.95 7088.80 ) Alåska~t~teP.IEiriê/zQn~4 ,...' NAP 27 .. ¢~ordíl'\~teS TVDX .......'., ...J¥:'" Sub~~Ei< '..·...'ft < '.'.. . ...,.'......,'~,/, ~3ß';~p 520639.12603,.1:,~~~.f4 ?1,1'fR 520639.12 .ßo.~,1,~~~.~4 ';.g~'1,.?Q: 520639.40 603:1694,158 '361 :.13 520641.64 603169i.25 4ê9.8,8 520646.11'6031'702.61 !5~q;.~3, 520652.80 6031710.63 §ê~,~~ 520661.72 60~17~t.31 ~9§:;§(:I 520667.01 6031727.65 ~§7"~~\' 520672.68. 6031734.95 ~9.~:35: 520684.64 6031753.36 'iÙg51.711 520697.416Ø31776.81 1046.\31 520710.95' S03tß,05..?2 '1139:80 520725.22.· 6031.a38:5~ 1231.03 520740.186031876.63 1320;03 520755.79S031919.43 1406.57 520772.02 '6031966.81 >J4~q.~.,: 520788.806032018.64 1p?;1..ª~' 520806.11 6032074,77 1~4@;~qê, 520823.88 6032135:06 17~êi~7.. 520842.08 6032199.34 H?§.?P: 520842.52 603220Q~92 t7~~:?9i 520860.66 603226.7.42 1ê~W:~E3' 520879.55 6032339.13 '~@f~:~?; 520898.71 6032414.27 1~~~.~7: 520918.09.6032492.63 ·?9.~~,.'1ê 520937.64 6032574.ob :g~~å.i~E3' 520957.29603265à.15 211(1;;'19 520966.84 6932699.85 2317:96 521 055.8660~3091.25 2546.91 521154.43' aO'å35'24:'64 2775.8S·. 521253.00)E3~ª.~~9ªÎQ~ 3004.82 521351.57. 603439-1..4'1 3233:77 521450.13.60~824.80 3280.20 521470.12 6034-912.69 3~62:72 521548. 70 :';60S~2'5lft9' 3691.68 521647.276035691.58 3920.63· 521745.84 6036124.S7 4140.20. 521840.376Ø.~E3~~9.p~ ~~~~;58 521844.41 ·6036558::35 4~Ø~(~9 521860.09 . 60~(:I627.27 43?~;54 521942.9860369!31:74 4607:49 522041.55 6037425.13 4,~~E3..¥ 522140.12 6037858.52 ~O~5,.4.o, 522238.69. 603829,1..91 5294.315 522337.26 6038725.29 5523:30. 522435.83. 6039158.68 5792.26 522534.40 6039592,07 5981.21 522632.976Q4Qo25.46 6210.16 522731.54 6040458;84 6439.12 522830.116040892~23 6668.07 522928,67 6041325.62 6710.00 522946.73 6041404.99 6849.99 523007.00 6041669.98 6850.00 523007.00 6041~70.00 6897.02 523027.24 6041759.01 6965.00 523056.51 6041867.68 7050.00 523093.10 6042048.58 .'..'.:'...""'..............,...........:.".....',:.......::...':'.................'. ,',,":, ,:",,;:,/,,' ,,''':'>'':''','') , .'...........,...:'..:......::........................................;:'.....'...............................................:............:.............;.:......................................':......................'\....................'............'......:,:............'......................................................,.................;".'. ,," \" """ ,,, , ~ ',',',,", "",1', I" ' \::·,...¡i',:....:',,·"':..:,: \' ""''',,':: '., ,"":,-:".":,:,"";.";,,.,,,,,,':,,.:., \ISect..···Plan~::=.t3.49° ..... !.'::,":':"',:>i "'1'(1'< II NI.:S, El~W> DLi.S, ft ,..... .,~.:)..·,Ø.~g{1QqJt 0.00 ·'p.qÓ 0.00 0.00 "i .. .;,.g.qp: 0.00 . 0.33:.;~;o..2!3¡ 2.00 3.01': ·,2.~2 2.00 8.35>i7':.9~ 2.00 16.36 ;!;'~i~~! 2.00:i 27.02;;,'f,~1§7 2.00 I 33.34 · . ':;:ii~Þ;~~i 2.00 40.63 ·······.i~~;6~. 3.00 59.01 '. .......!4'§(~? 3.00 82.43 ." "'/5~3:'50 3.00, 110.81. . "i.~.11 3.00 144.0986:46 3.00 182.16' 101';52 3.00 224.93 117.24 3.00 272.27133.p8 3.00 324.06 "'1150:50 3.00 380.16 1~7.94 3.00 440.41, 185.87 3.00 504.65 '204.23 3.00 506.22 204.67 3.00 572.69 222.97 3.00 644.36 242.04 3.00 719.46 261.39 3.00 797.78 280:97 3.00 879.11' . ;~OO':71 3.00 963.22,320.58 3.00 1004.90 330..23 3.00 1396.12~~9;22 0.00 1829.31 ":'5'1'9:86 0.00 2262.49 ,,6.1~:.51! 0.00 2695.68 , ,719,'16 0.00' 3128.87 ',8,18.80 0.00 3216.71. 839.01 0.00 3562.051,,~,.:~,:g1;&;ït :5' 0.00 ~ 3995.24 101:8.09 0.00 4428.43 1117.74 0.00 4843.861·~1;å.3ô 0.00 4861.62 :j'~gi;~~ 0.00 4930.5012ª~Y23 0.00 5294.80 ·t~j.'f.q3 0.00 5727.99't41#:~8 0.00 6161.18 "151'6:33' 0.00 6594.36 ' "'6:t9~97 0.00 7027.55 ,1Jt6:~2 0.00 7460.74 '~8~P.~6 0.00 7893.93 t~1:4~91 0,00 8327.11 2q14.§G 0.00 8760.30' 2~,14.20 0.00 9193.49 2213.85 0.00 9626.67 23,13.49 0.00 9706.01 2331.74 0.00 9970.88 2392:67 0.00 9970.89 2392.67 0.00 10059.86 2413;14 0.00 10188.48 2442.73 0.00 10349.30 2479.72 0.00 :e.1~~;~9 ';';';,':':q:,qo ,?:/:i;'.~:i:i~~~~:: '···"'.';3:51" ~)7~ ,;it9:¡11,: , 31'156; 38.95 47'.36 68.04 93:;'8'1 1:24.5~ . 160.28 200;82 246.07 295,92 350..23 408.85 471.62 538,:37 540.01 , 606.9'1 683.05' 760.59 841.32 925.01 !.10.1t.44 1054;22 1455.63 " 19Öb'd1 23\!14;.59 ': " 2:7t89¡Ö7 32$~.55 '33~3;69 ",:"I:'~¡¡5"67ð:'Øi! .¡ 41'·22.fi2 4667.00 4993:26, q01 ~ .48 '50$2.16 5455.96 5900:44 ::å '.92; "·'LII:,,:,::,j::,:~f "0 I ,,'7:?M:~Ø ''{678JS6' /"~:~"~~.~:4 86~7';;32 '9011.80 9456.28 9900.76 9982.16 10253.94 10253.96 10345.24 10477.21 10642.23 ) ) Baker Hughes Incorporated Anticollision Report Company: Field: Reference Site: Reference Well: Reference Wellpath: ConocoPhillips Alaska, Inc. Kuparuk River Unit Pad 3R 8 Oliktok Pt St #2 Vers#1 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD + Stations Interval: 25.00 ft Depth Range: 0.00 to 13334.09 ft Maximum Radius: 10000.00 ft Survey Program for Definitive Wellpath Date: 5/16/2003 Validated: No Planned From To Survey ft ft 0.00 13334.09 Planned: Oliktok PtSt#2 Vers#1 Casing Points MD ft 7079.51 13334.09 TVD ft 4224.79 7088.80 9.625 7.000 Diameter in Hole Size in Name 12.250 8.500 95/8" 7" Summary <------------------ Offset Well path --------------------> Site Well Wellpath Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R 10 10 11 12 14 15 17 18 19 20 21 22 25 26 26 9 Olik Pt#2A Olik Pt#2A 3R-10 V4 3R-10A VO 3R-11 VO 3R-12 VO 3R-14 VO 3R-15 VO 3R-17 VO 3R-18 VO 3R-19 VO 3R-20 VO 3R-21 VO 3R-22 VO 3R-25 VO 3R-26 VO 3R-26A VO Oliktok Pt St 1 Vers#3 Olik pt 2A VO Olik St Pt#2 VO Date: 5/16/2003 Time: 15:12:02 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: 8, True North Wellhead(38.8') 38.8 Reference: Error Model: Scan Method: Error Surface: Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Version: 0 Toolcode Tool Name MWD+SAG MWD + Sag correction Reference Offset Ctr-Ctr No-Go Allowable MD MD Distance Area Deviation Warning ft ft ft ft ft 410.39 425.00 51.60 8.4t 43.19 Pass: Major Risk 410.39 425.00 51.60 8.41 43.19 Pass: Major Risk 360.26 375.00 75.07 7.19 67.88 Pass: Major Risk 359.81 375.00 99.25 6.75 92.50 Pass: Major Risk 333.56 350.00 216.15 6.28 209.88 Pass: Major Risk 333.22 350.00 240.59 6.27 234.32 Pass: Major Risk 332.42 350.00 291.51 6.26 285.25 Pass: Major Risk 308.44 325.00 316.50 5.82 310.69 Pass: Major Risk 331.74 350.00 341.35 6.24 335.11 Pass: Major Risk 307.98 325.00 366.35 5.81 360.54 Pass: Major Risk 284.38 300.00 391.01 5.38 385.63 Pass: Major Risk 330.74 350.00 415.22 6.23 408.99 Pass: Major Risk 308.97 325.00 266.07 5.83 260.24 Pass: Major Risk 357.22 375.00 189.43 7.29 182.16 Pass: Major Risk 357.22 375.00 189.43 7.29 182.16 Pass: Major Risk 870.21 875.00 32.72 19.91 13.13 Pass: Major Risk 2100.00 4825.00 2734.26 100.81 2663.09 Pass: Major Risk 1900.00 4325.00 2700.95 85.54 2642.11 Pass: Major Risk ) ) ConocoPhillips Alaska, Inc. Croatod by bmlchaol For: B Penrose Dato plattod : 19-May-20D3 Plat Roforonco io Ollktok pt St 2 Voreq,. Coordinates ere in feet reference slot NB. Truo Vortical Dopth. are ,.,fo,.,nco RKB(DoyanH141). .1- -=- INTEQ 340 - 320 - 300- 280 - 260- 240 - 220 - 200 - ^ 180 - I ....--... +- 160 - Q) Q) '+- ..........- ..c 140 - +- L 0 Z 120 - 100 - 80 - 60 - 40 - 20 - o - 20 - 40 Well: B ....../ ConocoPhillips Structure : Pad 3R Field : Kuparuk River Unit Location North Slope, Alaska .. 600 /11 '500 ,iii 800 ~300 '" 700 .. 600 E) AOO ~() ~~600 \()~ ~ .¡>. I I I I I 40 60 80 I 20 I o 20 "'~œØlM 8 I I I I ¡ 1500 I I I I I I I I I I I I I ,<9 iIo'1500 I f 1400 I I I I I I I I I I I ,'11 '1 400 ¡. 1 300 I I I I I I I I I ,<11300 ./1200 I I I I I I I : 1100 ,iii' '1200 ,iII'1100 ",'1000 .. 1700 I I I 100 120 140 160 180 East (feet) -> I 280 I 300 I 200 I 220 I 240 I 260 Creatod by bmlchaol For: B Penrose Dato plattod : 19-May-2DD3 Plot Roforenco 10 Ollklak PI SI 2 Vorel'. Coordinotos are in feet reference slot *B. True Vertical Depths are referencs RKB(Dayonl'41). ø£ INTEQ 3800 - 3600 - 3400 - 3200 - 3000 - 2800 - 2600 - 2400 - ^ I 2200 - ...---- - Q) Q) 2000 - - '-'" .r: - !.... 1800 - 0 Z 1600 - 1400 - 1200 - 1000 - 800 - 600 - 400 - 200 - 800 ') ConocoPhillips Alaska, Inc. ........... ConocoPhillips ~~~ Structure : Pad 3R Well : 8 Field : Kuparuk River Unit Location North Slope, Alaska 600 200 o 400 , , I I I I 2900. , I , , I I I I 2700t I I , , I , , 2500 f I , , , I I , 2300 ~ I , I I , I I , 2100f f 1900 , I I f 1700 <9 200 400 East (feet) -> 1000 1200 1600 2200 390~ I , , 370c4 ,/ , I I : t 3300 ',' 357 3100~1 , I " t 3300 I + 2900 .¡. 2700 .;. 2500 ~ 2300 .2100 600 + 3100 8 8 800 I , I , ~ 3500 n 1800 2000 1400 Created by bmlchael For: B Penrose Dole plotted : , 9-May-2003 Plol Reference i. Oliklok PI 51 2 VersH'. Coordinates are In feet reference: ::Ilot *B. True Vertical Deplhe are reference RKB(Doyon#141). .£ INTEQ 1 0400 - 10000 - 9600 - 9200 - 8800 - 8400 - 8000 - 7600 - ^ I 7200 - ,,--... +- Q) Q) 6800 - - "-...-/ ...t: +- L 6400 - 0 Z 6000 - 5600 - 5200 - 4800 - 4400 - 4000 - 3600 - 3200 - 1200 ~.\> 5500 5300 .;. I I 800 J Structure : Pad 3R ConocoPhillips Alaska, Inc. Well: 8 Field: Kuparuk River Unit Location North Slope, Alaska 4900 ~ 4 700 ~ 4500 ~ 4300~ 4100~ 3900~ ' + 3500 3700~ I 88 400 400 o 5500 ~ 5300 ~ 5100 ~ IIJ 6900 . 6700 ~ 6500 ~ 6300 ~ 6100 ~ 5900.¡. 5700 ~ ~ 3700 800 IJ I I , f 6900 , , ; 6700 , I I ~ 6500 , I , t 6300 , I I f 6100 , , f 5900 , I ~ 5700 I , , ~ 5500 , , , + 5300 , , I f 5100 I , ; 4900 I , I ~ 4700 , I , t 4500 I I I f 4300 I I f 4100 I I ~ 3900 1200 1600 2800 2000 2400 East (feet) -> ) .../ ConocoPhillips .,¿.""~.!". .r{~AJj.......',.t;ll!rlWlll#l 1,1": ~"'\ ... "T\ 3200 4800 5200 3600 4000 4400 ) ) ConocoPhillips Alaska, Inc. Created by bmlchael For: B Penrose Date platted : 19-May-2DDJ Plot Reference is Dliktak pt 5t 2 Versll1. Coordinates are In feet reference slot *B. True Vertical Depthe are reference RKB(DayanIl141). 1ft- .... Structure: Pad 3R Well: 8 ...../ ConocoPhillips y¿.~ <.,.' ..... ..: ...... .......,'~..".."".". .Ii" I Field : Kuparuk River Unit Location: North Slope, Alaska INTEQ 330 TRUE NORTH ~ c::::J 350 0 10 210 20 340 30 240 310 50 320 40 300 60 290 70 280 80 270 90 260 250 110 230 220 140 210 150 200 @" Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ) ) Baker Hughes Incorporated Error Ellipse Survey Report Company: CçmocoPhHlips Ala~ka, Inc. Field: Kuparuk River Unit Site: Pad 3R Well: 9 Wellpath: Oliktok pt St 1 Vers#3 Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Dat~:4/17/2P03 Time: 10:50:18 Page: Co-ordinate(1'1JØ Ileference: Well: 9., Trut;} North Verµcal(XV))) Refere.nce: Wellhead($8.8'). 38~8 Section (VS) Reference: Well (0.OON,O.OOE,8:58Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: Pad 3R Site Position: From: Map Position Uncertainty: Ground Level: Northing: 6033356.18 ft Easting: 518296.98 ft Latitude: 70 30 Longitude: 149 51 North Reference: Grid Convergence: 8.305 N 1.222 W True 0.14 deg 0.00 ft 0.00 ft Well: 9 Slot Name: Well Position: +N/-S -1691.45 ft Northing: 6031670.68 ft Latitude: 70 29 51.666 N +E/-W 2346.27 ft Easting : 520647.18 ft Longitude: 149 49 52.156 W Position Uncertainty: 0.00 ft Wellpath: Oliktok pt St 1 Vers#3 Drilled From: Surface Tie-on Depth: 0.00 ft Current Datum: Wellhead(38.8') Height 38.80 ft Above System Datum: Mean Sea Level Magnetic Data: 4/17/2003 Declination: 25.37 deg Field Strength: 57498 nT Mag Dip Angle: 80.83 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 8.58 Survey Program for Definitive Wellpath Date: 4/17/2003 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 0.00 11144.30 Planned: Oliktok pt St 1 Vers# MWD+SAG MWD + Sag correction Position uncertainty and bias at surver statiol1 Late.rål-------> V ertical;.~---> M!gn, Semi-major SClßi.;.minor All uncertainties at 2.6·. standard d~viation Highside----> . MD IDcI Azim TVD1Jn~, Bias Unc. Bias Une,· Bias of Bias· Unc, Unc. Azimuth Tool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE LINE 100,00 0.00 0.00 100.00 0.09 0.00 0.09 0.00 2.96 0.00 0.00 0.09 0.09 0.00 MWD+SAG 200.00 0.00 0.00 200.00 0.38 0.00 0.38 0.00 2.96 0.00 0.00 0.38 0.38 0.00 MWD+SAG 300.00 0.00 0.00 300.00 0.67 0.00 0.67 0.00 2.97 0.01 0.01 0.67 0.67 0.00 MWD+SAG 400.00 2.00 45.00 399.98 0.92 0.00 0.92 0.00 2.97 0.02 0.02 0.92 0.92 135.00 MWD+SAG 500,00 4.00 45.00 499.84 1.17 0.00 1.18 0.00 2.97 0.03 0.03 1.19 1.17 82.86 MWD+SAG 600.00 6.50 45.00 599.41 1.43 0.00 1.52 0.00 2.97 0.04 0.04 1.52 1.45 55.36 MWD+SAG 700.00 9.00 45.00 698.49 1.70 0.00 1.98 0.01 2.96 0.06 0.06 1.98 1.75 49.80 MWD+SAG 800.00 12.50 45.00 796.72 1.97 -0.01 2.61 0.01 2.95 0.08 0.08 2.61 2.06 47.86 MWD+SAG 900.00 16.00 45.00 893.63 2.24 -0.01 3.46 0.02 2.93 0.10 0.10 3.46 2.38 46.92 MWD+SAG 1000.00 19.50 45.00 988.85 2.51 -0.02 4.54 0.04 2.90 0.12 0.13 4.54 2.70 46.40 MWD+SAG 1100.00 23.00 45.00 1082.04 2.78 -0.03 5.85 0.07 2.87 0.14 0.16 5.85 3.03 46.08 MWD+SAG 1200.00 26.50 45.00 1172.83 3.05 -0.04 7.39 0.10 2.84 0.17 0.20 7.39 3.36 45.87 MWD+SAG 1300.00 30.00 45.00 1260.91 3.32 -0.05 9.15 0.15 2.82 0.20 0.25 9.15 3.68 45.73 MWD+SAG 1400.00 33.50 45.00 1345.93 3.58 -0.06 11.12 0.20 2.80 0.22 0.31 11.12 4.00 45.62 MWD+SAG 1500.00 37.00 45.00 1427.57 3.84 -0.08 13.29 0.26 2.81 0.25 0.38 13.29 4.31 45.54 MWD+SAG 1600.00 40.50 45.00 1505.55 4.10 -0.09 15.67 0.34 2.83 0.28 0.45 15.67 4.62 45.48 MWD+SAG 1700.00 44.00 45.00 1579.55 4.36 -0.11 18.23 0.43 2.89 0.30 0.54 18.23 4.92 45.43 MWD+SAG 1722.15 44.78 45.00 1595.38 4.41 -0.12 18.82 0.45 2.87 0.31 0.56 18.82 5.01 45.42 MWD+SAG 1800.00 44.78 45.00 1650.64 4.70 -0.12 20.92 0.52 3.00 0.33 0.64 20.92 5.19 45.39 MWD+SAG 1863.02 44.78 45.00 1695.37 4.93 -0.12 22.62 0.58 3.13 0.35 0.70 22.62 5.34 45.36 MWD+SAG 1900.00 45.01 42.93 1721.57 5.08 -0.13 23.47 0.62 3.18 0.36 0.74 23.49 5.41 45.32 MWD+SAG ') ) Baker Hughes Incorporated Error Ellipse Survey Report Company: ConocoPhiJllps Alaska, Inc. D3te: 4/1.7/2P03 Time: 10:50:18 Page: 2 Field: Kuparuk River Unit CO·(jtdinate(NE)···R~ferente: Wen: 9, True North Site: Pad 3R V erti~31 (TVD) Referençe: Wellhead(38.8') 38.8 Well: 9. SettiQu (VS)R.d~rente: Well (0.00N,O.00E;a.58Azi) Wellpath: Oliktok pt .St 1· Vers#3 S1irvey. Ca~eul8:~i~n·· MethQd: MinimumCurvat.ure Db: Oracle Position unèertåintya~dbiåslltsurvey station Lateral··~~··-:> V ertic~l.....";> Magn. .. Semi·maJorSemi·minor All uncertainties at 2.6 standard deviat~on Highside......> MD Inti Azim TV» Une. Bias Unto Bias Unto Bias of Bias Unto Une. Azimuth Tool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 2000.00 45.81 37.42 1791.80 5.68 -0.18 25.36 0.71 3.29 0.39 0.82 25.56 5.55 44.87 MWD+SAG 2100.00 46.86 32.09 1860.87 6.63 -0.24 27.16 0.77 3.43 0.42 0.88 27.73 5.70 44.02 MWD+SAG 2200.00 48.16 26.96 1928.44 7.76 -0.30 28.88 0.80 3.58 0.45 0.92 29.97 5.90 42.82 MWD+SAG 2300.00 49.67 22.04 1994.18 8.94 -0.35 30.53 0.80 3.77 0.48 0.93 32.28 6.14 41.34 MWD+SAG 2400.00 51.38 17.36 2057.78 10.09 -0.40 32.14 0.77 3.97 0.51 0.92 34.64 6.45 39.65 MWD+SAG 2500.00 53.27 12.90 2118.91 11.13 -0.45 33.75 0.70 4.20 0.54 0.88 37.06 6.82 37.76 MWD+SAG 2600.00 55.32 8.67 2177.28 12.03 -0.48 35.36 0.60 4.46 0.56 0.83 39.54 7.26 35.74 MWD+SAG 2700.00 57.51 4.65 2232.62 12.76 -0.52 37.02 0.47 4.73 0.59 0.76 42.09 7.78 33.59 MWD+SAG 2739.25 58.40 3.12 2253.44 12.99 -0.53 37.69 0.41 4.84 0.60 0.73 43.11 8.01 32.73 MWD+SAG 2800.00 58.40 3.12 2285.28 13.11 -0.53 39.55 0.31 5.03 0.62 0.69 44.72 8.26 31.46 MWD+SAG 2900.00 58.40 3.12 2337.68 13.33 -0.53 42.62 0.16 5.34 0.64 0.66 47.44 8.52 29.62 MWD+SAG 3000.00 58.40 3.12 2390.08 13.56 -0.53 45.73 0.00 5.67 0.67 0.67 50.23 8.80 27.96 MWD+SAG 3100.00 58.40 3.12 2442.48 13.80 -0.53 48.87 -0.16 6.00 0.70 0.73 53.08 9.09 26.46 MWD+SAG 3200.00 58.40 3.12 2494.88 14.05 -0.53 52.03 -0.32 6.33 0.73 0.81 55.98 9.38 25.11 MWD+SAG 3300.00 58.40 3.12 2547.29 14.30 -0.53 55.21 -0.48 6.67 0.75 0.92 58.93 9.67 23.88 MWD+SAG 3400.00 58.40 3.12 2599.69 14.57 -0.53 58.41 -0.63 7.01 0.78 1.04 61.91 9.96 22.76 MWD+SAG 3500.00 58.40 3.12 2652.09 14.84 -0.53 61.62 -0.79 7.35 0.82 1.18 64.93 10.24 21.75 MWD+SAG 3600.00 58.40 3.12 2704.49 15.12 -0.53 64.84 -0.95 7.69 0.85 1.33 67.98 10.52 20.83 MWD+SAG 3700.00 58.40 3.12 2756.89 15.41 -0.53 68.08 -1.11 8.04 0.88 1.48 71.06 10.79 19.98 MWD+SAG 3800.00 58.40 3.12 2809.29 15.70 -0.53 71.32 -1.27 8.39 0.91 1.63 74.16 11.06 19.21 MWD+SAG 3900.00 58.40 3.12 2861.70 16.00 -0.53 74.57 -1.43 8.74 0.95 1.79 77.27 11.32 18.50 MWD+SAG 4000.00 58.40 3.12 2914.10 16.31 -0.53 77.83 -1.58 9.09 0.98 1.95 80.41 11.57 17.84 MWD+SAG 4100.00 58.40 3.12 2966.50 16.62 -0.53 81.09 -1.74 9.44 1.02 2.12 83.56 11.83 17.24 MWD+SAG 4200.00 58.40 3.12 3018.90 16.94 -0.53 84.36 -1.90 9.80 1.05 2.28 86.73 12.07 16.68 MWD+SAG 4300.00 58.40 3.12 3071.30 17.26 -0.53 87.63 -2.06 10.15 1.09 2.45 89.90 12.31 16.16 MWD+SAG 4400.00 58.40 3.12 3123.70 17.58 -0.53 90.91 -2.22 10.51 1.13 2.62 93.09 12.55 15.67 MWD+SAG 4500,00 58.40 3.12 3176.10 17.91 -0.53 94.19 -2.37 10.86 1.16 2.79 96.29 12.79 15.22 MWD+SAG 4600.00 58.40 3.12 3228.51 18.25 -0.53 97.47 -2.53 11.22 1.20 2.96 99.50 13.02 14.80 MWD+SAG 4700.00 58.40 3.12 3280.91 18.59 -0.53 100.76 -2.69 11.58 1.24 3.13 102.71 13.25 14.40 MWD+SAG 4800.00 58.40 3.12 3333.31 18.93 -0.53 104.05 -2.85 11.94 1.28 3.30 105.94 13.48 14.04 MWD+SAG 4900.00 58.40 3.12 3385.71 19.27 -0.53 107.34 -3.01 12.30 1.32 3.48 109.16 13.71 13.69 MWD+SAG 5000.00 58.40 3.12 3438.11 19.62 -0.53 110.64 -3.17 12.66 1.37 3.65 112.40 13.93 13.36 MWD+SAG 5100.00 58.40 3.12 3490.51 19.98 -0.53 113.94 -3.32 13.02 1.41 3.83 115.64 14.16 13.05 MWD+SAG 5200.00 58.40 3.12 3542.92 20.33 -0.53 117.23 -3.48 13.38 1.45 4.01 118.89 14.38 12.76 MWD+SAG 5300.00 58.40 3.12 3595.32 20.69 -0.53 120.53 -3.64 13.74 1.50 4.18 122.14 14.60 12.49 MWD+SAG 5400.00 58.40 3.12 3647.72 21.05 -0.53 123.84 -3.80 14.10 1.54 4.36 125.39 14.82 12.23 MWD+SAG 5500.00 58.40 3.12 3700.12 21.41 -0.53 127.14 -3.96 14.46 1.59 4.54 128.65 15.04 11.98 MWD+SAG 5600.00 58.40 3.12 3752.52 21.78 -0.53 130.45 -4.11 14.82 1.63 4.72 131.92 15.26 11.75 MWD+SAG 5700.00 58.40 3.12 3804.92 22.15 -0.53 133.75 -4.27 15.18 1.68 4.90 135.18 15.47 11.53 MWD+SAG 5800.00 58.40 3.12 3857.33 22.52 -0.53 137.06 -4.43 15.54 1.73 5.08 138.45 15.69 11.32 MWD+SAG 5900.00 58.40 3.12 3909.73 22.89 -0.53 140.37 -4.59 15.91 1.77 5.27 141.73 15.91 11.12 MWD+SAG 6000.00 58.40 3.12 3962.13 23.26 -0.53 143.68 -4.75 16.27 1.82 5.45 145.00 16.12 10.92 MWD+SAG 6100.00 58.40 3.12 4014.53 23.64 -0.53 146.99 -4.90 16.63 1.87 5.63 148.28 16.34 10.74 MWD+SAG 6200.00 58.40 3.12 4066.93 24.02 -0.53 150.30 -5.06 17.00 1.92 5.82 151.56 16.55 10.57 MWD+SAG 6300.00 58.40 3.12 4119.33 24.40 -0.53 153.61 -5.22 17.36 1.98 6.00 154.84 16.76 10.40 MWD+SAG 6400.00 58.40 3.12 4171.74 24.78 -0.53 156.92 -5.38 17.72 2.03 6.19 158.13 16.98 10.24 MWD+SAG 6500.00 58.40 3.12 4224.14 25.16 -0.53 160.24 -5.54 18.09 2.08 6.37 161.41 17.19 10.09 MWD+SAG 6600.00 58.40 3.12 4276.54 25.54 -0.53 163.55 -5.70 18.45 2.13 6.56 164.70 17.41 9.94 MWD+SAG 6700.00 58.40 3.12 4328.94 25.93 -0.53 166.87 -5.85 18.81 2.19 6.75 167.99 17.62 9.80 MWD+SAG 6800.00 58.40 3.12 4381.34 26.32 -0.53 170.18 -6.01 19.18 2.24 6.94 171.28 17.83 9.66 MWD+SAG 6900.00 58.40 3.12 4433.74 26.71 -0.53 173.50 -6.17 19.54 2.30 7.13 174.58 18.05 9.53 MWD+SAG 7000.00 58.40 3.12 4486.14 27.10 -0.53 176.81 -6.33 19.91 2.36 7.32 177.87 18.26 9.41 MWD+SAG 7100.00 58.40 3.12 4538.55 27.49 -0.53 180.13 -6.49 20.27 2.41 7.51 181.17 18.47 9.29 MWD+SAG ) ) Baker Hughes Incorporated Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Date: .4/17/2003 Time: 10:50:18 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Refe..en~e: Well: 9. True North Site: Pad 3R VertiCal (TVD) Reference: Wellhead(38.8') 38.8 Well: 9 Se.ction (VS).Reference: Well (0.OON,0.OQE,8;58Azi) WeUpath: Oliktö.kPt St 1 Vers#3 S"rvey.Cah:ulation MethO(I: Minimum Curvature Db: Oracle Position uncertainty and bias at survey station All uncertainties at 2.6 standard deviation Highside-----> Lateral-------> Vertical------> Magn. Semi-major Semi-minor MD Incl Azim TVD Unc. Bias Unc. Bias Unc. Bias of Bias Unc. Unc. Azimuth Tool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 7200.00 58.40 3.12 4590.95 27.88 -0.53 183.45 -6.64 20.64 2.47 7.70 184.46 18.69 9.17 MWD+SAG 7300.00 58.40 3.12 4643.35 28.27 -0.53 186.77 -6.80 21.00 2.53 7.89 187.76 18.90 9.06 MWD+SAG 7400.00 58.40 3.12 4695.75 28.67 -0.53 190.09 -6.96 21.37 2.59 8.09 191.06 19.12 8.95 MWD+SAG 7500.00 58.40 3.12 4748.15 29.06 -0.53 193.40 -7.12 21.73 2.65 8.28 194.36 19.33 8.84 MWD+SAG 7600.00 58.40 3.12 4800.55 29.46 -0.53 196.72 -7.28 22.10 2.71 8.48 197.66 19.54 8.74 MWD+SAG 7700.00 58.40 3.12 4852.96 29.85 -0.53 200.04 -7.44 22.46 2.77 8.67 200.97 19.76 8.65 MWD+SAG 7800.00 58.40 3.12 4905.36 30.25 -0.53 203.36 -7.59 22.83 2.83 8.87 204.27 19.97 8.55 MWD+SAG 7900.00 58.40 3.12 4957.76 30.65 -0.53 206.68 -7.75 23.19 2.90 9.07 207.57 20.18 8.46 MWD+SAG 8000,00 58.40 3.12 5010.16 31.05 -0.53 210.00 -7.91 23.56 2.96 9.26 210.88 20.40 8.37 MWD+SAG 8100.00 58.40 3.12 5062.56 31 .45 -0.53 213.32 -8.07 23.92 3.03 9.46 214.19 20.61 8.29 MWD+SAG 8200.00 58.40 3.12 5114.96 31.85 -0.53 216.65 -8.23 24.29 3.09 9.66 217.49 20.83 8.21 MWD+SAG 8300.00 58.40 3.12 5167.37 32.25 -0.53 219.97 -8.38 24.65 3.16 9.86 220.80 21.04 8.13 MWD+SAG 8400.00 58.40 3.12 5219.77 32.66 -0.53 223.29 -8.54 25.02 3.22 10.07 224.11 21.26 8.05 MWD+SAG 8500.00 58.40 3.12 5272.17 33.06 -0.53 226.61 -8.70 25.38 3.29 10.27 227.42 21.47 7.97 MWD+SAG 8600.00 58.40 3.12 5324.57 33.46 -0.53 229.93 -8.86 25.75 3.36 10.47 230.73 21.69 7.90 MWD+SAG 8700.00 58.40 3.12 5376.97 33.87 -0.53 233.26 -9.02 26.12 3.43 10.67 234.04 21.90 7.83 MWD+SAG 8800.00 58.40 3.12 5429.37 34.27 -0.53 236.58 -9.18 26.48 3.50 10.88 237.35 22.12 7.76 MWD+SAG 8900.00 58.40 3.12 5481.77 34.68 -0.53 239.90 -9.33 26.85 3.57 11.08 240.66 22.33 7.69 MWD+SAG 9000.00 58.40 3.12 5534.18 35.09 -0.53 243.22 -9.49 27.21 3.64 11.29 243.97 22.55 7.63 MWD+SAG 9100.00 58.40 3.12 5586.58 35.49 -0.53 246.55 -9.65 27.58 3.71 11.50 247.28 22.76 7.56 MWD+SAG 9200.00 58.40 3.12 5638.98 35.90 -0.53 249.87 -9.81 27.95 3.79 11.71 250.60 22.98 7.50 MWD+SAG 9300.00 58.40 3.12 5691.38 36.31 -0.53 253.20 -9.97 28.31 3.86 11.91 253.91 23.20 7.44 MWD+SAG 9342.25 58.40 3.12 5713.52 36.48 -0.53 254.60 -10.03 28.47 3.89 12.00 255.31 23.29 7.42 MWD+SAG 9400.00 56.74 3.70 5744.49 36.50 -0.39 256.22 -10.18 28.59 3.93 12.12 256.75 23.36 7.39 MWD+SAG 9500.00 53.86 4.75 5801.42 36.25 -0.17 258.15 -10.41 28.67 4.02 12.32 258.42 23.39 7.37 MWD+SAG 9600.00 51.00 5.88 5862.38 35.97 0.03 259.95 -10.64 28.74 4.11 12.51 260.04 23.42 7.36 MWD+SAG 9700.00 48.15 7.11 5927.22 35.80 0.21 261.59 -10.86 28.80 4.22 12.68 261.60 23.45 7.35 MWD+SAG 9800.00 45.31 8.45 5995.76 35.94 0.36 263.04 -11.06 28.86 4.33 12.85 263.09 23.47 7.35 MWD+SAG 9900.00 42.49 9.93 6067.81 36.71 0.47 264.25 -11 .27 28.91 4.46 13.01 264.52 23.50 7.36 MWD+SAG 10000.00 39.70 11.58 6143.17 38.48 0.54 265.15 -11.46 28.96 4.60 13.15 265.86 23.52 7.38 MWD+SAG 10068.76 37.79 12.83 6196.80 40.51 0.56 265.55 -11.59 28.99 4.70 13.24 266.74 23.54 7.40 MWD+SAG 10100.00 37.79 12.83 6221.49 40.56 0.56 266.11 -11.61 29.03 4.74 13.28 267.29 23.59 7.41 MWD+SAG 10200.00 37.79 12.83 6300.52 40.88 0.56 268.41 -11.66 29.26 4.90 13.42 269.58 23.87 7.46 MWD+SAG 10300.00 37.79 12.83 6379.55 41.19 0.56 270.71 -11.70 29.49 5.05 13.55 271.87 24.15 7.50 MWD+SAG 10400.00 37.79 12.83 6458.58 41.51 0.56 273.01 -11.75 29.71 5.20 13.69 274.17 24.43 7.55 MWD+SAG 10500.00 37.79 12.83 6537.61 41.83 0.56 275.31 -11.80 29.94 5.36 13.84 276.46 24.71 7.59 MWD+SAG 10600.00 37.79 12.83 6616.64 42.15 0.56 277.62 -11.84 30.16 5.51 13.98 278.75 24.99 7.63 MWD+SAG 10700.00 37.79 12.83 6695.67 42.47 0.56 279.92 -11.89 30.39 5.67 14.13 281.05 25.27 7.68 MWD+SAG 10800.00 37.79 12.83 6774.70 42.79 0.56 282.22 -11.94 30.62 5.83 14.28 283.34 25.56 7.72 MWD+SAG 10900.00 37.79 12.83 6853.73 43.11 0.56 284.53 -11.98 30.84 6.00 14.43 285.64 25.84 7.76 MWD+SAG 11000.00 37.79 12.83 6932.76 43.43 0.56 286.83 -12.03 31.07 6.16 14.59 287.93 26.12 7.80 MWD+SAG 11100.00 37.79 12.83 7011.79 43.76 0.56 289.14 -12.08 31.30 6.33 14.74 290.23 26.41 7.84 MWD+SAG 11144.30 37.79 12.83 7046.80 43.90 0.56 290.16 -12.10 31.40 6.40 14.81 291.25 26.53 7.86 MWD+SAG ) ) ConocriP'hillips ,ECErVt:[) JUN 2 6 2003 June 24, 2003 Ms. Sarah Palin, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 A~a\stŒ m~ & t\m:,h([)mg(¡~ RE: Application for Permit to Drill: Winstar Oliktok Point State #2 Dear Ms. Palin, ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development production well, the Oliktok Point State #2, from KRU 3R Pad. The anticipated spud date of Oliktok Point State #2 is approximately July 1£; 2003. / However, this well will only be drilled if the previous well, Oliktok Point State #1, proves up the oil-bearing potential of the target fault block. ConocoPhillips Alaska, Inc. has been designated the operator of record from Winstar Petroleum for Winstar's Lease ADL 388584. As such, ConocoPhillips will be drilling this well into this lease, which is within the Kuparuk River Unit. The well will be drilled from the existing KRU 3R-8 conductor. A 12-1/4" hole will be directionally drilled to the base of the West Sak Formation where 9-5/8" surface casing will be set and cemented. An 8-1/2" hole will then be directionally drilled to penetrate the Kuparuk sands and 7" production casing will be set and cemented after which a 3- 1/2" gas lift completion will be installed. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 MC 25.005 (a). 2) Fee of $100.00 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the well's proposed surface and bottom hole locations per 20 AAC 25.050 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. ORIGINAL 5) Diagrams anr }escriptions of the diverter and BOP equipment to be used as required by Lv'AAC 25.035 (a)(l) and (b) were p )¡ously submitted to the AOGCC and are on file. A complete proposed casing program is attached as per 20 AAC 25.030. The drilling fluid program, in addition to the requirements of 20 AAC 25.033 are attached. A copy of the proposed drilling program is attached. ConocoPhillips does not anticipate the presence of H2S in the formation to be encountered in this well. However, H2S monitoring equipment will be functioning on the rig at all times during drilling and completion operations. Since this well is a development well, no mud logging will be performed. A Summary of Drilling Hazards is attached. The following are the designated contacts for reporting responsibilities to the Commission: 6) 7) 8) 9) 10) 11) 12) 1) Completion Report (20 AAC 25.070) Bill Penrose, Senior Drilling Engineer 258- 3446 2) Geologic Data and Logs (20 AAC 25.071) Doug Hastings, Senior Geologist 272-1232 If you have any questions or require additional information, please contact me at 265 6830 or Bill Penrose at 258-3446. Sincerely, CONOCOPHILLIPS ALASKA, INC. -\ ~~~- Randy Thomas GKA Drilling Team Leader enclosu res cc: Mr. Jim Weeks - Winstar Petroleum, LLC W"'" ~::.: c ~~i=~ ~:7~~' ',! JUN 2. G c:nr:l ~'~ ~ , . ...... . J _ " l._ 4",' ':' ORIG\NAL . , ---- f . .' ... . ..' "129 5 ~ ~ WINSTAR PETROLEUM,LLC . .. ... II . P.O. BOX 1364 ~~ PETERSBURG, AK 99833 ~ I' PH. (907) 772-4414 89"5-1252 J.' t· DATE I - PAY ~~L~ a~J¿ ~ .. ~ TO THE .' ~; it ORDER OF ~. A.- 'Á (j 1/, r' ß.... "---,. . '. ...... '. .' I oj he)u</YYC ..Eðl., g; /M/) þ/Jð r ¿ National ..... ..... . ! ~ BSIJ1{,tffAlas1(¡:l .'~'.'."'.'»" ; ,¡ . ............ '., ~ [ FOR ß/ì~/ I'> .. '. .... ..... ,'.. ..... ............ ..,&./)I::~ ..¡ ~ 11100 ~ 2 q Sill ~tI: ~ 25 20005 ?I:J. ~022 ? ba..'1 C¡lï'<> ............. .... H> ' .~ .~-,.,\"""""'<Y".Ø/"'- _....\.....'1"'~"",.,'-_".'.\~n_""',.""'-....,F.\"._.,.,....",.,,'--,,.,~""~~-,··,~"'iI"'....,'..('~'*hiif(iJ.'7'......-_."~);.."--",~"'~/;.,..--""......,'"..,<<<",)J/'·'~_"'~'''''_'''''''ffl¡'''I,_-:""~,....,,..'''h9ì'''~''''',",_''''~/''''_._'!&',--,...,_.~ - ') ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARA GRAPH S TO BE INCLUDED IN TRANSMtTT AL LETTER WELL NAME ð!tkkL ß"nl S~~ Z- PTD# 2.03 -(Ie¡ 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(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). paOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE 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. 5Uf;:r-c;/-e-cl Jc!:h~~ *;(/-11 y- ~v~ /~ ~ þCÇ(-Ád ~ \t~js // b# ~ 4J~/( am, I- d~hl-, /:0-.. r o.-:! ()r,¿ , Rev: 07110/02 -- Ö ajody\templates ~~~~~~~.~~I!.~C;:tt~ÇKLI.!3T Company CONOCQPHILLIPS ALASKA INC Well Name: Oliktok Point State 2 Program DEV Well bore seg D PTD#: 2031190 Field & Pool KUPARUK RIVFR, KUPARUK RV OIL - 490100 Initial ClasslType DFV /1-011 GeoArea 890 Unit 11160 On/Off Shore ~ Annular Disposal D Administration 1 P~(rnil fee attacl)e.ø _ _ _ . _ _ . . . . . _ _ _ . . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ . _ . _ _ _ . . . Y~s _ _ _ . _ _ . _ _ _ _ _ . _ _ . _ . _ _ . . . . . . . _ . _ . _ _ _ _ _ _ _ _ . . _ _ _ . . _ . . _ _ . . . . . . _ _ . . _ _ . . _ _ . _ . _ . _ . _ 2 _Leas~ _number .apprQRriSite_ . . . . . _ _ _ _ _ _ . . _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ . .. . _ . . . . _ _ . Y~s _ _ _ _ _ _ . Surface Ipca.tion in APt.. _35Q0.23;Jop. RrQd.uctive jntervaJ and.TD_ ilJ API,.. 3138_564. _ . . . _ . . . . . . _ . . . . . _ _ _ _ 3 _U.nique weILn.am~.aod ou.mb.er . . _ _ . . . . . _ . _ _ _ . . . . . . . _ . . . _ . . . . _ _ _ . _ . _ _ .Y~$ . . . __ . . __ _ . . . . . . . . . _ _ _ _ . _ . _ _ . . _ _ . . _ . _ _ _ _ . . _ _ . _ _ . _ . _ __ _ . _ . _ . _ _ _ _ . _ . _ _ . . . . _ _ _ _ . _ 4 _Well JQcaled in_a. d.efine_d _ppol_ . . _ _ .. . . . _ _ _ _ _ _ _ . . . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ . . _ _ _ . WßIJ i~ Jo.cated with.i11 tile l<up-aru_k .RJv~( Oil I? Q oJ, _aoc! i~ go~ern_ed þy CO .432a. _ _ _ . _ _ _ . _ _ _ _ _ _ _ _ . _ _ . _ 5 _We.IIJQcaled prppe.r .distance_ from c!riJIing unitb_ound.a(y. _ . . _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ . Y~s _ _ . _ . . . The.p.ool.rnay _nolb_e.opened _ctoser th.an 500 fßeUo anY.prQper:ty.line._ ~lb_ase ofKuparuk, thjs_ _ _ _ _ _ _ _ _ . _ . 6 ..WellJQcaled prpper .distance_ from otber Wßl!s_ _ _ _ .. . . . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _Y~s . _ . . . _ _ well.will be_5.03 fe_et frQrn ~Ol." 35.5018... a ßP Jea~e. _ Caution_ary.text in_Com.ments, beJow_ _ _ _ . _ _ _ _ _ . _ _ _ . . 7 .S_utficientacrßag.e.aYaiISiblein_drilJiogunjt_ _ _. _.. _ _ _ _ _ _ _ _ _ _ _ _._ _' _ _.. _.... Y~s.. _ _. _ . mu&tbe include.øJnpermitaRPrO_vaUette(._ ... _.... _ _ _ _ _ _ _..... _ _ _ _. _ _ _ _ _ _ _. _. _.. _ _ __ 8 Jf.dßviated, js. weJlbQre plaUlJcJu.dec! _ _ . _ _ _ . _ . _ _ . . _ _ _ _ _ _ _ _ _ . _ . . . . . . . . _ . . Y~s . . _ _ _ _ _ 00 plat, welLis tabeled_ "3R-_8," _ _ _ . . . . . _ . . . _ _ _ _ _ _ _ . . _ _ . . _ _ . _ . _ . _ . _ _ _ _ _ _ _ _ _ _ . . . _ . _ 9 _Oper:ator only: affected party. . . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . . . _ . _ _ _ _ . .. _ _ _ _ _ _ _ _ _ _ _ Y~s . . _ _ _ . . _ . . _ . _ _ . . . . _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . . 10 _Oper.ator bas_appropriateJ).ol1d inJorce . . . . . _ _ _ _ _ _ . . . _ _ . . . _ _ . . _ _ _ _ _ _ _ . _ _ _Y~s _ . . . . _ . . . . _ . . . . _ . _ _ _ _ _ _ _ _ _ . . . . . _ _ _ . . . . . . . . . . _ . _ _ . . _ _ _ _ _ _ . _ _ . . . . . _ . . _ _ . _ _ . __ _ 11 .P~(rnil c_ao Þe issu.ed wjtbQut co.nservation order. _ . . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ . . Y~s . _ . . . . _ UlJles.$ _50Q' otf&etto _BP.lease to.tbe ea.st is yioISited._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Appr Date 12 P~(rnilc_ao Þe iS$u.ed wjtbQut admilJistr:athle_appr.ovaJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ . . . . . _ _ _ _ _ _ _ . _ __ . _ __ _ _ _ . _ _ . __ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ . _ _ __ _ _ __ __ __ _ _ _ _ _ __ _ _ _ _ _ ~"''i 6/26/2003 13 Can permit be approved before 15-day wait Yes } 14 .WelUQcaled within area and_strata .author~ed by.l(ljectipo Ord~( # (pulIO# in_c.o01m~ots).(For_ NA _ . . . . . _ . . _ . . . _ . . . . . . _ _ . . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ 15 _AJI wßlJs. witÞi.n .1 l4.llJile .are.a.of (eyiew jd~otified (For: &ervjc~ .w.ell only). _ _ . _ _ _ _ . . . . . . . _NA. _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . __ . _ __ __ __ . . . . . _ . _ _ . __ _ _ _ . . . __ . . . . __ _ _ _ . . . . _ . . . . _ . . . . 16 Pre-produ.cediojector; _durSitiQn.ofprß-productiolJl~ss__tÞan_3months_(For_ser:vi.cewell QnJy) _ _ _NA _..... _ _ _... _. _ _. _ _ _ _ _ _. _. _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _... _ _ _ _ _.. _. 17 ACMP_F.indjng.ofCon_si.stency_h.asÞee_nJ&sued_for.tbispr.oiect. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s..... _ _Oev~topmen.twellc!riJledfromexistilJg.KRUpa.d_3R _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _. _. _ _ _ _ _ _ _ _ _ _... _.. Engineering 18 _C_oodu_ctor st(ing.prQvidßd _ _ . . _ . . . _ _ __ _ _ _ _ _ . _ _ . _ . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ . _ . . . . . . . . . . . . . _ . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ . . . . . 19 _S_ur:facß .ca&ing_ PJotec.t& all.known USDWs _ _ _ _ . _ . _ . _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y~s . . . . _ . _ . . . _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ . _ . . _ . _ _ _ _ _ . _ . _ _ _ __ . . . . _ _ _ . 20 _CMTv_otadßQu_ate.to circ_utate.o.n_cOlJd_uctor_& $U.rf_~g . . . . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ Yes. _ _ . . _ . ~c!e.quate exce$.S, _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ . _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ . . . . . _ . 21 _CMT v.ot adßQu.ate.to tie-inJQng _striog to.sur:f C&g_ _ . _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ . _ _ __ . _ _ _ . _ . . _ _ _ . _ . _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . . . . _ 22 _CMTwill coyer_aU klJow_n_pro_ductiYe bQri~on_s_ _ _ __ _ _ _ _ . . _ _ _ . . _ _ _ _ . _ _ _ _ _ _ . _ _ _ Y.ßs. _ _ _ . . . . _ . . _ _ _ _ _ _ . _ _ . . . _ _ _ _ . _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ . _ . . _ _ _ _ . . 23 _C_asi(lg de.signs adeQua.te f.o( C,.T, B.&.RerllJafr_ost _ _ _ _ _ _ . . . . _ . _ _ __ . _ _ _ _ . . _ _ _ _ Y~s _ _ _ . _ _ _ . _ . _ . . _ _ _ . _ . _ . . . . _ . __ . _ _ . _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ . . . . _ 24 AdequSite.tan.kage_oJ re_serye pit. . . . . . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . . . __ . _ _ _ _ _ _ _ _ Y.ßs _ _ _ _ _ . _ Doy.olJ :141.. _ _ . _ . . _ . . _ . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . . _ _ _ . _ . _ _ _ _ _ _ _ . _ . . . . 25 .If.a_ re-d(ill... has. a. to:-403 fQr Sibandonrnent be~1J apPJQvßd _ _ _ _ _ _ _ _ _ _ . _ . . . _ _ _ _ _ . _ .NA _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ . _ _ _ _ _ _ . . _ . . . . _ . . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ 26 .A.øequ.ate.w.ellbore. &epars:¡tjo.n .propo~ed _ _ _ _ _ _ . . . . . . . . . _ _ . _ _ _ _ _ _ _ . _ _ . . . . . .Y.ßs . _ . _ _ _ _ . _ _ _ _ _ . _ _ . . _ _ _ _ _ . _ _ _ _ . _ _ . _ . . . . . _ . . . . . . . _ . . . . _ . . . . . . _ _ . . . . _ . _ . . _ . _ _ _ . 27 Jf.divßr:ter Jeq.uired, dQe~ jt .meßt reguJatioos. . . __ _ _ _ _ _ _ _ _ . _ _ . _ . . _ _ _ _ . _ _ . . _ _ _ Y~s _ _ _ _ . _ _ . . . . . . . _ _ _ _ _ _ _ . . _ . . . _ . . _ _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ . . _ _ _ _ . _ _ . Appr Date 28 _DriUiog flujd_Rrogram schematic_& eq.uipJistadequate. _ . . _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ Y.ßs _ _ _ _ _ _ _ Max MW.1.0,5.ppg.. _ _ _ _ . . _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ . . . _ . _ __ _ . . _ \AlGA 6/26/2003 29 .B.OPE$,_d_o_they.meßtreguJa_tioo.... _ _ _ _ _ _ _ _ _ _ . . _ . . . . __ _ __ . _ __ . _ . _ _ _ . _ _ Y.ßs. . . _ _ . _ . . _ . . . _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ . _ . __ _ _ . _ . _ . _ . _ _ _ _ . __ _ . . _ _ _ . _ _ _ _ _ _ . _ _ _ _ ) 30 .BPPE_press ratilJg approp(iate;.testto_(pu.t psig in_commelJts}. _ . . . . . . . . __ . . . _ _ . . . . Y~s _ _ _ _ _ _ . Testto.50QO_psi. .I\lIS~ 22.60 psi.. . . _ _ _ _ _ _ . . _ _ . . _ . _ _ . _ . . _ _ . . . _ . . _ _ . . _ _ __ _ _ __ . . 31 _C_hoke_llJanjfold cQrnpJies_ w/API. R~-53 (May 84). . _ . _ _ _ . . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ . y~s _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ . _ _ _ _ _ _ __ _ _ _ _ _ . _ _ . _ _ . . . _ _ _ _ _ _ _ _ . _ _ _ _ __ _ . _ _ . . . _ _ . . _ . _ . _ _ . _ . . 32 _WQrk will PCC_U( withput.operation _sbutdo.w.n_ _ _ . . _ . _ . . . . . _ _ . _ _ . . _ . . _ _ _ . . . . _ y~s _ . . . . _ _ . . _ . . . . _ _ . . _ _ _ _ _ _ _ _ . . . . . . _ . _ . . _ _ _ . _ _ _ _ _ _ _ _ _ _ . . . _ . _ . . . . . _ _ . _ _ _ _ . _ . _ . _ 33 .Is presence. Qf H2S gas_ Rrob.able. . . . . . _ _ . . . . _ . . . _ __ . . _ . . . _ _ . . . . . . . _ _ . . No. _ . . _ . . _ . . . _ _ . __ . _ _ . . _ . . _ . _ _ . _ . _ . _ _ _ . _ . . . _ . _ . _ . _ . _ . _ _ _ . . . . . _ . _ _ _ _ _ _ _ _ . _ _ . . _ _ 34 Meçha.nicaI. CO IJd.itjo 0 .of wells within ~OR yerified (for_ s_ervice wßIJ only). . _ _ _ _ _ _ _ __ _ . . _ _NA _ . . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . __ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ Geology 35 PßlJ1'Jit can Þe issu.ed w!o_ hydr.ogen. s.ulfide meas.u(e$ _ . . . . . _ _ . __ . _ _ _ . _ . _ . . . . . . . y~s _ _ _ _ _ __ . WelJ ta(gßst.aJauJt.b!oçk thath.a$ not .been. Rrod_uced.. _H.2S _n1onitQring equIp.. wi.IIÞe functi.ooal at all.tim~$. _ _ _ . . 36 .D_ata.preseotec! on. Rote.ntial pve.rpres.surß _zone~ _ . . . . . . . . . . . . . . _ _ . _ . _ . _ . . . . . Y.ßS _ . _ _ . _ . OveJ-pr:es&ure oot expected. . l<up_a(Uk reser:voi( pre&s!Jr.e_expe_cted to. be. tOJ.Ppg EMW; reseIYoi( _ _ . _ _ _ . _ _ Appr Date 37 _Sei~01ic.analys.is_ Qf sha.llow gas.z.ooe.s_ . . . _ _ . _ . . _ . . . . . _ . . _ _ _ . . . . . . . _ . . . _ .NA _ . . _ _ _ . will be drilled with. to.5.ppg mud._ _ . _ _ _ . . . _ _ . . . _ . . . . __ . . . _ _ _ _ . . . . . . . . _ . . . _ . . . SFD 6/26/2003 38 .S~abed .condjti.oo $urvey.(if off-$hp(e) . . _ _ . __ _ _ . _ . . . . _ . _ . . _ _ _ . . _ . _ _ . _ . . . . NA. . . . _ . _ . _ . _ . . _ _ . . . . . . _ _ _ _ _ . . . . . . . . . . . . _ . _ . _ _ . _ . _ . . . . . _ _ . _ . . _ . . _ _ 39 . CQnta.ct nam.e(pÞone_ for.wee~ly prpgress.reRorts [exploratpry _onlYl _ . _ . .NA . . _ . . . . . . _ . . _ . . . _ . . . . . . . _ . _ _ . _ _ . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ Geologic Commissioner: Date: O~ O~/1-7Þ) Engineering Commissioner: Date Public Commissioner Date ~ ConocoPhillips, as designated operator for Lease ADL 388584, is cautioned that the Kuparuk River Oil Pool penetrated by this well may not be opened closer than 500 feet to any property line (Ref Conservation Order 432B, Rule 3).
