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Home My WebLink About202-115 ) 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. J 0;1- - 1-5 Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 ~scan Needed 1111111111111111111 RE~AN ~J1or Items: ' p6eYSCale Items: 0 Poor Quality Originals: DIGITAL DATA OVERSIZED (Scannable) 0 Maps: D Diskettes, No. D Other, No/Type: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: NOTES: Scanning Preparation 0 Other::" , Date II. cWJ..' ólf 151 VtiP , 1111111111111111111 Date ¡ I f).r 'Dtt 151 Y/.1 (J ='TOT;LPAGES 60 (Count doe$ not ¡ndude cover s~~,;p ¡() Date: J I a-.?- Dlf Isl YV~'r Production Scanning , 1111111111111111111 Stage 1 Page Count from Scanned File: {¡; J (Count does ¡nclUd7er sheet) Page Count Matches Number in Scanning Preparation: V y~S HelenC Maria) BY: Project Proofing BY: Helen ~ ~ x 30 = ho + BY: Helen CMarii) NO Stage 1 If NO in stage 1, page(s) discrepancies were found: Date: II, d- J-. DLf YES NO Is/ vuf BY: HelenCMaria) BY: Helen Maria BY: Helen Maria Date: Isf r II' III 1111111111111111111 Date: Is/ Quality Checked IIIIII1II1111111111 Scanning is complete at this point unless rescanning is required. ReScanned Comments about this file: 8/24/2004 Well History File Cover Page.doc e e .... ... MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _Inserts\Microfilm _ Marlœr.doc ) ~) Memorandum State of Alaska Oil and Gas Conservation Commission To: Well File: Redoubt Unit 6 Cancelled Permit Action : Redoubt Unit 6XX Permit # 202-115 October 21,2002 API # 733-20514-00 This memo will remain at the front of the subject well file. Our adopted conventions for assigning API numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to drill. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The API number and in some instances the well name reflect the number of preexisting red rills and or multilaterals in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to drill. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the API numbering methods described in AOGCC staff memorandum "Multi-lateral (well bore segment) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. CANCELED PERMITS ARE RELEASABLE 2 years from the date on the letter or email received from the operator requesting the permit canceled. (Memorandum January 23, 1997 by Dave Johnston, subject: Canceled and Expired Permits) ~4?-v. 'Aç) ( ~ Steve McMains Statistical Technician Redoubt Unit #6 well name ) Subject: Redoubt Unit #6 well name Date: Mon, 21 Oct 2002 11 :11 :40 -0600 From: Rob Stinson <RDStinson@forestoil.com> To: "Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> CC: Paul White <PDWhite@forestoil.com> Tom, This e-mail is a follow-up to our phone conversation this morning. We requested the cancellation of the RU #6 Permit to Drill because the location of the RU #5A Hemlock penetration is in the proximity of the RU #6, as it was planned and permitted. Our intentions are to apply for a new Permit to Drill in the main Redoubt Shoal fault block. May we re-apply, using the well name of Redoubt Unit #6? This would avoid a confusing interruption in our well naming convention. Thanks, Rob Robert Stinson Drilling Engineer - Alaska Division Forest Oil Corporation (907)-868-2133 1 of 1 ') ~ 0 ;( - I /5 --i~ ~ ~({l¡t-a/ 10/21/2002 11 :22 AM ) ') ~1&\r~ [ill TONY KNOWLES, GOVERNOR AIfASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279.1433 FAX (907) 276.7542 Robert Stinson Drilling Engineer Forest Oil Corporation 310 K Street Ste 700 Anchorage AK 99501 Re: Redoubt Unit #6 Forest Oil Corporation Pennit No: 202-115 Surface Location: 1911' FSL, 321' FEL, Sec. 14, T07N, R14W, SM Bottomhole Location: 171' FSL, 2073' FWL, Sec. 19, T07N, R13W, SM Dear Mr. Stinson: Enclosed is the approved application for pennit to drill the above development well. The pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit 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 tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Annular disposal has not been requested as part of the Pennit to Drill application for Redoubt Unit #6. Your request for an exception to 20 AAC 25.035 (c) (1) (B) to drill 18-l/2" hole with a 16" diverter line is granted. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test perfonned before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, rllJJ..~Ak~. ~ Q;~; <ðechsli Taylor Chair BY ORDER OF THE COMMISSION DATED thi~ day of July, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ FOREST 0 I L ) CORPORATION .'110 ciYC9%<"-eøt. ~de 700 Q~k<"~J Q~-ca .9.9501 (SJ07) 258-86'00 . (907) 2.5'8-86'0:1 (CfJ0ä;) May 29,2002 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill (Form 10-401) Redoubt Unit #6 Enclosed is the Application for the Permit to Drill the Redoubt Unit #6 development well from Forest Oil's Osprey Platform. This well is planned to penetrate the Hemlock formation on structure in the Southern Fault Block. The well will be drilled using water based mud to the 13 3/8" surface casing point. We will change mud systems at this point to an oil based system. All mud and cuttings generated from drilling this well will be disposed of down the existing Class II disposal well, RU #Dl. We are requesting in a separate 10-403 Sundry Notice to use the 9 5/8" x 13 3/8" annulus for cuttings disposal. In addition, we are requesting a waiver to 20 AAC 25.035 (c). If there are any questions, please contact me at 258-8600. ~J¿¿ - / Robert Stinson Drilling Engineer Forest Oil Corporation - Alaska Division RECEIVED ~i'¡ .!J.\(' ') C 2002 ! "" L- ') Alaska Oil & Gas Cons. GommtSSiOn Anchorage ORIGINAL ~() } STATE OF ALASKA') ALASKA Oll'AND GAS CONSERVATION CvNlMISSION PERMIT TO DRILL 20 AAC 25.005 measured true vertical 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Drilling fluid program: X Time vs. depth plot: Refraction analysis: 21. I herby certify that the foregoing is true and correct to the best of my knowledge: 4Þ-#:). \<~ ) Signed:~( ~ ~ Robert Stinson 1 a. Type of work Drill: X 'Re-Entry: 2. Name of Operator Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 4. Location of well at surface 1911' FSL, 321' FEL, Section 14, T07N R14W, SM At top of productive interval 847' FSL, 1323' FWL, Section 19, T07N R13W, SM At total depth 171' FSL, 2073' FWL, Section 19, T07N R13W, SM 12. Distance to nearest 13. Distance to nearest well property line Red rill: Deepen: 1 b. Type of well Service: 3. Address 10,593 feet 16. To be completed for deviated wells Kickoff depth: 200 feet Maximum hole angle: 42 18. Casing program size Casing 30" 13 3/8" 95/8" 7 5/8" 2,069 Hole Driven 18 1/2" 121/4" 8 1/2" Weight nla 68# 47# 29.7# Specifications Grade Coupling nla Welded L-80 BTC L-80 BTC L-80 Hyd 521 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Exploratory: Developement Gas: 5. Datum Elevation (OF or KB) 90' MSL 6. Property Designation ADL 381203 (surf) 374002 (TO) 7. Unit or property Name Redoubt Unit 8. Well number Redoubt Unit #6 9. Approximate spud date 05-Jun-02 14. Number of acres in property Development Oil: X Multiple Zone: Stratigraphic Test: Single Zone: X !:b 10. Field and Pool Redoubt Shoal Oil Field 11. Type Bond (see 20 AAC 25.025) Type: Statewide Oil and Gas Bond RLBOO01940 Amount: $200,000 15. Proposed depth (MD and TVD) feet tf/ J~l .t71'J ~,-. 16,946' MD 113,010' TVD 17. Anticipated pressure (see 20 AAC 25,035 (e)(2» Maximum surface 1 ,518 psig At total depth (TVD) Setting Depth feet 5,855 psig Top Bottom Quantity of cement Length MD TVD MD TVD (include stage data) 200' Surf Surf 200' 200' nla 3,500' Surf Surf 3,500' 3,020' 6640 cu ft 15,439' Surf Surf 15,439' ,11,-QatY 1/ Çf)Ò/þ 1286 cu ft 1 ,707' 15,239' 11,742' 16,946' 13,010' 281 cu ft feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth RECEIVED M ,\Y .') 0 ?OO2 !It"'\1 L'!"" .. Alaska Oíl & Gas Cons. l;ÛIlIiOl~Sll} Anchor<\W Diverter Sketch: Drilling program: X Seabed report: 20 AAC 25.050 requirements: X Date: ~J;/ð 'l... Title: Drilling Engineer Commission Use Only Permit Numbe! /- API nu~ber """. . /- Approval d3f I I See cover lett,er 2-D2 - 1/::::> 50- 73::J- .2051"1' eX) I a (') :L for other reqUirements Conditions of approval Samples required: [] Yes b'] No Mud log required: [] Yes [X] No Hydrogen sulfide measures [] Yes [~No Directional survey required Del Yes [] No Required working pressure for BOPE [] 2M; r ,] 3M; [] 5M; [] 10M; [] 15M ~c:í)OC:;' \5~ ~ ~ ~ \- , rtJ ~ /1 Other: ,/(I):--' f v ( On Inal Signed By by order of ,! 1M (') Approved by Com~y Oochsli TeY'Of Commissioner the Commission Date: ,{;),.. J.."L-. Form 10-401 Rev. 12-1-85 ,,4 t- Submit in triplicate ') Attachments 1. Waiver Requests 2. Outline Procedure 3 . Well schematic 4. Unit Boundary Plat wi Proposed Well Path 5. Drilling Fluids Program 6. Pressure Information 7. Casing Design 8. Cement Calculations 9. Directional Information 10. Well Head Schematic 11. Nabors BOP schematic 12. Nabors BOP equipment list 13. Nabors Drilling Fluid System Description ) ) Request for Diverter Waiver Forest Oil requests that the diverter requirements in 20 AAC 25.035 be waived for Redoubt Unit #6 because Redoubt Unit #1, #2, #3, #5 and #Dl were all drilled from the same general surface location without encountering any shallow gas. Mud logging / gas detection on these wells also shows no presence of gas. RU #4 did encounter gas sands in the 12 'i4" hole section. Subsequent drill stem testing indicated that the shallower sands with. "shows" were wet. RU #6 will drill these sands significantly off structure, as was the case with RU #1, RU #2, RU #3, RU #5 and RU #Dl. Mud weights planned for the surface interval are 8.5 ppg at spud, building to 9.4 ppg at the 13 3/8" casing depth, due to drilled solids. These mud densities are consistent with the six prior wells. ) Redoubt Unit #6 OUTLINE PROCEDURE 1. Rig-up Nabors Rig 429 on Osprey Leg #3, Slot #4. 2. Install weld-on starting head on 30" Pile. 3. Nipple up 24" low pressure riser to bell nipple. 4. Mix Spud Mud. 5. Directionally drill 18 ~" hole to 3,500' MD, 3,020' TVD. Note: Annular velocity and mud viscosity will be important for proper hole cleaning in the 30" pile. 6. Condition hole to run casing. Space out hole to allow 7' tol0' of rat hole below 13 3/8" shoe. 7. Run the 13 3/8" casing to 3,500' MD. Land the 13 3/8" on the 24" landing ring. Slowly reciprocate pipe, while circulating the hole clean. Configure the 13 3/8" string for an 80' shoe track. 8. Perform first stage cement job while reciprocating pipe. Set pipe down on hanger as soon as the hole gets sticky. 9. Open the Halliburton ES Cementer at 1,500' MD. Circulate the hole clean from the ES Cementer to surface. Record cement volumes that return to surface. Discharge cement returns overboard. 10. Perform second stage cement job through the ES Cementer. Discharge cement returns overboard. 11. Close ES Cementer with the closing plug. Note: If there are no returns at surface, perform top-job with AOGCC witness. 12. Nipple down 24" riser. 13. Nipple up Vetco-Gray 13 5/8" 5M Multi-bowl wellhead assembly on the 13 3/8". 14. Nipple up 13 5/8" 5M high pressure riser assembly and Nabors 135/8" 5M BOPE. 15. Test wellhead and BOPE to 3,000 psi Notify AOGCC 24 hours prior to test. 16. RIH. Test casing to 3,000 psi. 17. Change over hole to Oil Base using detailed procedure from MI. 18. Drill out cement and float equipment. 19. After drilling 20', but no more than 50' of new formation, perform Leak off Test. Note: Leak off Test will be performed with the MI/Swaco injection pump. Shut the well in and pressure up the well at 0.5 bpm. Once pressure breaks over and stops increasing, continue pumping at 0.5 bpm for 10 minutes. Record all volumes and pressures during this test and send to the Forest Oil office. 20. Directionally drill 12 'i4" hole to 15,439' MD, 11,890' TVD or until the top of the Hemlock formation is encountered. 21. Condition hole for casing. 22. Run and cement 9 5/8" intermediate casing from 15,439' MD to Surface. Planned top of cement will be 13,439' MD. Hang casing with 9 5/8" mandrel hanger in wellhead. Configure casing for an 80' shoe track. 23. Back off 9 5/8" landing joint and run 9 5/8" packoff. 24. Test 9 5/8" packoff. 25. RIH. Test casing to 3,000 psi. 26. Drill out cement and float equipment. 27. After drilling 20', but no more than 50' of new formation, perform Formation Integrity Test to 10.5 ppg EMW. 28. Directionally drill 8 'i2" hole to 16,946'MD / 13,010' TVD. . 29. Condition hole for logs. 30. Run wire line logs: Quad Combo and UBI. Pull Neutron And Gamma Ray to the base of the 30" pile. 31. Condition hole, Run and cement 7 5/8" liner from 15,239' MD to 16,946' MD. Note: Liner hanger will be set by means of dropping a ball before the cement job. The liner hanger will have a bearing section, which will allow rotation during the cement job. The liner packer will be mechanically set once cement is in place. The entire length of 7 5/8" liner will be cemented, with an 80' shoe track. 32. Pick up 3 'i2" drill pipe / BHA and run in hole. 33. Clean out liner and test lap to 3,000 psi. 34. Change over to 5% KCl. 35. Run USIT and RST logs across the 7 5/8" liner. ~ Ç>~~~~ 36. Run Baker model-FA w/ 4.4" ID bore on wireline. Set at approximately 15,500' MD. 37. Run Sclumberger LLC-3 valve on drillpipe, set in packer. 38. Run 3 'i2" ESP completion. 39. Nipple up 3 1/8" production tree. ) Redoubt Unit #6 Casing Design 30" Pile 13 3/8" 68#, L-80 BTC 18 1/2" Hole 95/8" 47#, L-80 BTC 12 1/4" Hole 7-5/8" 29.7#, L-80 Hydril 521 8 1/2" Hole ') 200' MD, 200' TVD ES Cementer - 1500' MD 3,500' MD, 3,020' TVD Planned TOC - 13,439' 15,439' MD, 11,890' TVD 16,946' MD, 13,010' TVD ') ) 198200 I 2458088 - I T 1 N R 14 W FOREST OIL CORP. ALASKA BUSINESS UNIT 2434818 . REDOUBT UN I T REDOUBT UNIT NO.6 LOCATION - t- ... ......., I , ,-... "I _u- I I -151 b39' -151 b37' -60041' -61°39' -1s1b3S' ) Redoubt Unit #6 DRILLING FLUID PROGRAM ) ) Interval Summary - WBM Forest Oil Corporation Redoubt Shoal Unit #6 ~\ .. , f. ,¡ ;r 0 - 3500' MD 13-3/8" Casing 18-1/2" Hole Recommended Drilling Fluid Properties ~i ~.:¡ '~L':1f~ - ~ -~ í':~ ~it¡~~~. ~I -1. {~.'.:.~~ 11. -~ J'H:~:~- J! I ,,,,,.., ~ ~l.li ~ ~ !I I~ ~': l.~! IfÍI. i:i ¡ ,ïf~' ~:,:; ~~ æ1fBn ,. 150 - 250 3 to 5 ~: ,! 100 - 125 < 7% II ,III =' 1Iil ~.~ ;"J:~ . ..:;.t'~' ~ ~'J~ .,.. ' .' jq~ ï.~r' p,. I II. !7 ..~ ~!I'-=-~' ...1 i'- - - ~ ~~~~~~"f~ 1"'''' , .~; ¡:~;~ ,¡ ~lji, ,0:11.1, '[ I. 1'~1.' .'-,' ,.Ii Î, .,,,fJ. jI"1 .~:: -~~~~ 0 - 600 600 - 3500 8.6 - 9.0 9.0 - 9.4 8 -12 12 - 18 35 - 45 30 - 35 N/C 12 - 14 1""" .. m' -~ ~I Recommended Fluid Formulas Spud Mud I! I ;ji~~~1'~i: tÞ;'T~n-~ :;.~t~ __I _! ---- -' ' !!' ~_f --_: -l---ï ,i ~~--- :--- 0.1 l' "'~ , 500 bbls '_;J~} ~~~ ~ r.~~~ ã . ,~ ~_:. '-_:- _'too'- ~j ~ :e;~ f~~~ lo.1 "[ ::::: ..n',",,,..........,,..,,... PPB 0.96 bbl 0.05 0.25 25 ~ Mixing Procedure . Fill rig pits with drill water (Insure all oil residue is removed from pits before beginning mixing) . Add 0.25 ppb Soda Ash to reduce hardness . Add 22 - 25 ppb M-I Gel and let shear and hydrate through gun lines. . Adjust pH to 9.0 with Caustic Soda as needed. At time of spud, adjust rheology with Gelex. ~.. .. :".,.., . ---~~~ .{'Ï'i,,':.--._' ~..,~-,_~,~¡:b Is 5 10 to 15 50 bbls Mixing Procedure . Add 45 barrels of spud mud to slugging pit. Mix blend of LCM products & spot across the thief zone. M-I L.L.c. 721 W. 1st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 . Fax: (907) 279-6729 ~' Œ".1fIIIP uYM :~~IFE ¡Jr..; U"~=,; -- ! ~~ ) Interval Summary, Cont. Forest Oil Corporation Redoubt Shoal Unit #6 0 to 3,500' M.D. - 18 1/2" Hole - Set 13 3/8" Casing . ROP, GPM . Estimated ROP for this interval is 40 ft/hr. . Estimated flowrate of this interval is 600 GPM. . Use Virtual Hydraulics models as a guideline for flowrates and hole cleaning. . Bit balling . Drilling Detergent may be used to reduce the possibility of bit and/or BHA balling. . Hole cleaning . High viscosity Gel/Gelex sweeps may be needed to ensure cleaning of gravel zones just below the 36" drive pipe. . NOTE: Due to the large diameter bole and the deeper casing depth, a higher viscosity fluid will need to be maintained longer to insure sufficient hole cleaning. Lost Circulation . . Seepage losses may be controlled with moderate additions of M - I Seal Fine & Medium . Severe lost circulation should be handled with LCM pills such as the one listed for this inter- val. . Casing running fluid properties . The mud should be conditioned prior to POOH to run casing. Moderate or reduce yield point and progressive gel strengths in order to reduce surge pressure while running casing. A small addition ofPolypac UL should help lower the fluid loss (10 - 12 cc's) and tighten the wall cake prior to running casing. . The IFE Mud Engineer will communicate daily with the In Office IFE Coordinator. . VOLUME USAGE . Estimated fluid volume required for this interval is 5150 barrels. M-I L.L.c. 721 W. 1st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 . Fax: (907) 279-6729 r:zjj == ~IFE œ~.r.~ ':1.--- , ~,~ -=- ~ ') ) Recommended Displacement Procedure Forest Oil Corporation Redoubt Shoal Unit #6 M-I L.L.c. 721 W. 1st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 . Fax: (907) 279-6729 I :: i I \ ' .. !II I" Issues and Concerns . All COMMUNICATION efforts will be on2oin2. . During rig and pit preparation for the OBM displacement, the potential to generate unneces- sary fluid waste is great. The IFE Mud engineer should communicate with the Company Man, the Toolpusher and with rig personnel the preferred practices to minimize waste gen- eration. . It is very important to review the OBM displacement procedure with all rig personnel to en- sure a proper and mishap free displacement. . The displacement procedure will be reviewed with the Company Man by the IFE Mud Engi- neer and the SW ACO/DSR Supervisor. . Solids control equipment (other than shale shakers) should not be operated during initial cir- culations. . The IFE Mud Engineer will collaborate with the Companyman and arrange for all transfers of OBM unless otherwise instructed by the Company Man. All plans will be communicated to the SW ACO/DSR Supervisor by the IFE Mud Engineer. . All transfer ofOBM will be supervised by the IFE Mud Engineer. ~=~IÆœ;~'~ ) Recommended Displacement Procedure Forest Oil Corporation Redoubt Shoal Unit #6 Recommended displacement to oil base mud =::} Roll storage tanks to heat up oil mud beginning one day prior to displacement. =::} Change out any rubber goods to diesel resistant products. =::} Rig up catch pans, and any other necessary clean up equipment prior to displacement. Cuttings tanks etc.. should be in place to capture cuttings, etc. once displacement has begun. =::} With 13-5/8" casing on bottom, condition mud and reduce surface volume through injection. =::} Pump cement, drop plug, and displace cement with spud mud. =::} Drill out float collar, cement, etc., with water base mud. Treat as needed with Bicarb and/or Desco CF to reduce rheological properties for displacement purposes. After drill out, dump (or inject) surface volume of all water base mud. Clean surface pits. =::} Once pits and lines are clean and inspected, build 75 - 100 barrel water base spacer (with seawater or drill water) in appropriate pit. =::} Transfer oil mud from tanks to appropriate active pits. =::} Monitor both ends of transfer to ensure no mishaps. =::} Change shaker screens to 80 & 50 mesh for initial circulation of oil mud. =::} Displace spud mud to oil base mud starting with water spacer. Rotate and reciprocate continuously during displacement. Pump at the fastest possible flow rate. Discharge or inject spud mud and spacer based on per- mitting. =::} CAUTION: If discharging water base mud, take returns into a surface pit first to inspect fluid prior to dis- charge for any oil contamination (or oil sheen). =::} After drilling ahead and oil mud is wann and conditioned, change shaker screens to 200 & 180 mesh if possible. =::} Plan to put coarse screens (50 to 80 mesh) on the last shaker panels after trips to allow oil mud to wann up. M-I L.L.c. 721 W. 1 st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 . Fax: (907) 279-6729 ~..~\IFEœ~ . ' == --~ J , "'" . . .I." . ¡II' . fIllY ~.;r;i,' ~ ' ~~ ) ') Interval Summary - OBM Forest Oil Corporation Redoubt Shoal Unit #6 3500 - 15439' MD 9-5/8" Casing 12-1/4" Hole Recommended Drilling Fluid Properties 8000 - 15,439 k ~¡ I, 9.0 - 9.4 19 - 23 5-7 82:18 5 to 8 IWJ1 - Recommended Formulas Base Oil Mud .1 '¡!, ,,} I~I 2 ppb .J Amount .18 bbl .76 bbl 6 - 8 ppb 5 ppb 2 ppb 0 - 1 ppb .. .....,......"'.."..,..,."'- Mixing Procedure (For new volume) . Premix and store 10.3 PPG CaCl2 Brine (0.914 bbl H2O, 113.4lbs. CaC12) . Place Mapco 200 in a clean mixing tank . Add IMG 400 and lime slowly through hopper. Let shear for 30 minutes. . Add primary emulsifier, Versacoat. . Blend and shear for a minimum of 30 minutes. . Add CaCl2 Brine. . Blend and shear for a minimum of 30 minutes. . Add Versawet, check rheology, add Versamod or VersaHRP as needed. . Estimated volume usage 5200 barrels new volume in addition to 1100 barrels existing volume. . NOTE: If sloughing coal becomes a problem, first bring SoUex concentration of the mud to 6 PPB, then, if needed, consider increasing mud weight for added stability. M-I L.L.c. 721 W. 1st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 . Fax: (907) 279-6729 ~ """~IÆ~~ r J,L;t~ff' ~ ~ ~~!_¡~ ) ) Interval Summary - OBM Forest Oil Corporation Redoubt Shoal Unit #6 3500 - 15439' MD 9-5/8" Casing 12-1/4" Hole JI Recommended Formulas jilllU ""'O"'V'~'I.'."\"-"""""""""""""""-"'-v-'W'-~ 'I'.~""" ... ~'II\'\"'tïW'_-~ '~~"WII!< ~A'.'l".llfl.w.o:!'A~1 li;;.<H~ '\,\¡'MW^~~ U Ii! LCM Pill - ~[~- J[ ~ Mixing Procedure . Place 35 bbls oil mud in slugging pit. Add blend of lost circulation material. Spot across theft zone. !r Coal Sloughing Pill Spot Soltex pill across suspected coal bed PPB 35 bbls 15 - 20 ppb prior to pulling out of hole for trip. Mixing Procedure . Place 35 bbls oil mud in slugging pit. Add 15 - 20 ppb Soltex. Spot across theft zone and ap- ply squeeze pressure not greater than annular pressure loss. PPB Weighted Sweep I If hole cleaning is suspect, pump a weighted sweep. Monitor returns for 2 gal 120 sx indications of increased cuttings. . 30 bbls ~-~~_~mu~:~~M7'f~~,.....,...::.¡ç;;:m _IXL_i.""__w,"--w,It.m-.- -.0." oom 0: 'f.1''''7~ !fA..l~ml~r~1..~~r~F;ï~~~~-.-_-' Mixing Procedure . Place 30 bbls oil mud in slugging pit. Add 5 bbls base oil, 5 gallons Versacoat and 2 gallons Versawet. Add barite for a mud weight of 3 PPG above current weight. Reciprocate and rotate while pumping pill. Do not stop circulating until pill has surfaced. M-I L.L.c. 721 W. 1st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 . Fax: (907) 279-6729 .,,--( - 41Æ ""/~~C~ ,~~. -=- ~~~ ) ) Interval Summary, Cant. Forest Oil Corporation Redoubt Shoal Unit #6 3,500 - 15,439' M.D. .. 12 1/4" Hole.. Set 9 5/8" Casing . ROP, GPM . Estimated ROP for this interval is 30 - 60 fi/hr. . Estimated flowrate for this interval is 650 GPM. ~ . Use Virtual Hydraulics models as a guideline for flowrates and hole cleaning. . Lost Circulation . Seepage losses may be controlled with moderate additions of G-Seal. . Severe lost circulation should be handled with LCM pills such as the one listed for this interval. . Coal Beds . Sloughing/running coal should be treated by adding 4 - 6 ppb Soltex to the mud system de- pending on the severity of the problem. NOTE: Soltex additions can reduce the rheology of the mud. Be prepared to add rheology modifiers (IMG 400, VersaMod, VersaHRP), as needed to maintain proper rheology. . For severe coal sloughing, a concentrated pill consisting of 15 - 20 ppb Soltex may be spotted across the coal bed prior to POOH for a trip. A slight amount of pressure (equal to the annular pressure loss) may be applied to the pill to squeeze it into the coal bed. . Casing running fluid properties . The mud should be conditioned prior to POOH to run casing. Moderate or reduce yield point and progressive gel strengths in order to reduce surge pressure while running casing. The IFE Mud Engineer will communicate daily with the In Office IFE Coordinator. . VOLUME USAGE . Estimated fluid volume required for this interval is 6050 barrels. M-I L.L.c. 721 W. 1st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 . Fax: (907) 279-6729 r::J. ....J....Þ:" ~IÆ œ, ';-,,'..~.~;;1 ~,.J''''''!, - i ~ -=- ~-"mï~.:~,i ~~~ ~ ) ) Interval Summary - OBM Forest Oil Corporation Redoubt Shoal Unit #6 15439 - 16946' MD 7 -5/8" Casing 8-1/2" Hole I ¡ J J ' Depth Interval Recommended Drilling Fluid Properties Mud Plastic Yield HTHP Oil:Water Total Drilled- Solids (%) 5 to 7 (ft) 15439 - 16946 Weight Viscosity Point Fluid Loss Ratio (PPG) (cp.) (lb./100ft2) (ml/30min) (:) 9.4 - 9.6 23 -27 19 - 23 4-6 82:18 . æ Recommended Formulas " " LCM Pin Product PPB Oil Mud 20 bbls Safecarb M 10 ppb OM Seal 10 bbl G-Seal 10 ppb :~~~ ..-II ')..r-~I jiJL t' C. I I '-~f'.. í!1I.A.'r-.- [""III\!!"", ~'''o Mixing Procedure . Place 20 bbls oil mud in slugging pit. Add blend of lost circulation material. Spot across theft zone. Product Coal Sloughing Pill Soltex Spot Soltex pill across suspected coal bed I Oil Mud PPB 20 bbls 15 - 20 ppb prior to pulling out of hole for trip. --- -B 1 .",,,,,,,- II ~~<_m . Mixing Procedure Place 35 bbls oil mud in slugging pit. Add 15 - 20 ppb Soltex. Spot across theft zone and ap- ply squeeze pressure not greater than annular pressure loss. Weighted high Viscosity Pin Product Oil Mud Base Oil Versa- Ver- Barite If hole cleaning is suspect, pump a coat sawet weighted sweep. Monitor returns for 30 bbls 5 bbls 5 gal 2 gal 120 sx indications of increased cuttings. PPB ~~---- ::r~:.---'W_"-'''--1A ê~"'.':"-fl':M""'''''''''''---I!~ ~_._- 1 M-I L.L.C. 721 W. 1st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 . Fax: (907) 279-6729 ~".-~IFEœ~ ..r!.. - if n.., :' -~ I~m-I"'" II.. .. .. ' &.1__" .',,-, n', --=- ~,.,',. ;",/~ ) Interval Summary, Cant. Forest Oil Corporation Redoubt Shoal Unit #6 15,439 - 16,946' M.D. .. 8 1/2" Hole . ROP, GPM . Estimated ROP for this interval is 50 to 150 ft/hr. . Estimated flowrate for this interval is 450 - 470 GPM. . Use Virtual Hydraulics models as a guideline for flowrates and hole cleaning. . Lost Circulation . Seepage losses may be controlled with moderate additions of Safecarb and/or G-Seal. Severe lost circulation should be handled with LCM pills such as the one listed for this interval Coal Beds . . Sloughing/running coal should be treated by adding 4 - ppb Soltex to the mud system de- pending on the severity of the problem. NOTE: Soltex additions can reduce the rheology of the mud. Be prepared to add rheology modifiers (IMG 400, VersaMod, VersaHRP), as needed to maintain proper rheology. . F or severe coal sloughing, a concentrated pill consisting of 15 - 20 ppb Soltex 1 may be spot- ted across the coal bed prior to POOH for a trip. A slight amount of pressure (equal to the an- nular pressure loss) may be applied to the pill to squeeze it into the coal bed. . Swab/Surge Pressures . Care should be taken while running in the hole and breaking circulation after an extended pe- riod of time out of the hole. Bringing up the pump rates too rapidly while the drilling fluid is cold may cause excessive annular pressure loss on the fonnation. While running in the hole after trips, circulation should be broken at least once at the casing shoe. At T.D. the pumps should be brought up slowly in order to allow the fluid to heat up prior to reaching nonnal flowrates. . Casing running fluid properties . The mud should be conditioned prior to POOH to run liner. Moderate or reduce yield point and progressive gel strengths with additions of base oil in order to reduce surge pressure while running casing. NOTE: See recommended liner running speed for this interval in Virtual Hy- draulics. . The IFE Mud Engineer will communicate daily with the In Office IFE Coordinator. . VOLUME USAGE . Estimated fluid volume required for this interval is 1050 barrels. ~. ..~IÆ""Jr¡;- r ~ - ~ ìaJ¿;",.-;,,,, M-I L.L.c. 721 W. 1st Avenue Anchorage, Alaska 99501 Tel: (907) 274-5564 . Fax: (907) 279-6729 ) ) REDOUBT UNIT #6 PRESSURE INFORMATION The following presents data used for calculation of anticipated surface pressures (ASP) during drilling of the Redoubt Unit #1 and Redoubt Unit #2. Redoubt Shoal State 29690-1, P=5309 psi @ 12,070' TVD from DST #2 (as per 407 Comp Report, 1/9/68) EMW = 8.46 ppg Gradient = 0.440 psi/ft Redoubt Shoal State 29690-2, P=5249 psi @ 12,202' TVD from DST #l(as per 407 Comp Report, 10/15/68) EMW = 8.27 ppg Gradient = 0.430 psi/ft Redoubt Bay Unit #1, P=4800 psi @ 10,953' TVD from DST (as per monthly drilling report, 12/13/76) EMW = 8.43 ppg Gradient = 0.438 psi/ft The most conservative (highest) formation pressure gradient of 8.65 ppg or .45 psi/ft was used in these calculations. Procedure for Calculatinl! Anticipated Surface Pressure ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point and a 1/3 gas gradient plus a 2/3 saltwater gradient to the surface. We have chosen this method based on no sign of gas in the Redoubt Unit #1 and Redoubt Unit #2. 1) ASP = ((FG x .052) - 0.10) x D where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.10 = gas gradient in psi/ft D = true vertical Depth of casing seat in ft RKB OR 2) ASP= FPP-( 1/3 x 0.10 x D) - (2/3 x .45 x D) where: FPP = Formation Pore Pressure at the next casing point which is tied back to surface or at TD (total depth) -) ) ASP Calculations Drilling below Surface Casing (13 3/8") ASP = ((FG x .052)- 0.10) x D = ((13.5 x .052) - 0.10) x 3020' = 1818 psi OR ASP = (11890' x .45) - ( 1/3 x .10 x 11890') - (2/3 x .45 x 11890') = 1387 psi Drilling below Intermediate Casing (9 5/8") ASP = ((FG x .052)- 0.10) x D = ((10.5 x .052) - 0.10) x 11890' = 5303 psi OR ASP = (13010' x .45) - (1/3 x .10 x 13010') - (2/3 x .45 x 13010') = 1518 psi Size Hole Casing Driven 30" 18 1/2" 133/8" 12 1/4" 95/8" 8 W' 7 5/8" ) REDOUBT UNIT #6 CASING DESIGN Weight nla 68# 47# 29.7# Specifications Grade Coupling nla Welded L-80 BTC L-80 BTC L-80 Hydril 521 Setting Depth Bottom TVD MD TVD Surf. 200' 200' Surf. 3,500' 3,020' Surf. 15,439' 11,890' 11,742' 16,946' 13,010' Top Length 200' 3,500' 15,439' 1 ,707' MD Surf. Surf. Surf. 15,239' Casing Joint Strength Body Strength Burst Collapse Klbs Klbs Psi Psi 13 3/8" 68# L-80 BTC 1545 1556 5050 2260 9 5/8" 47# L-80 BTC 1122 1086 6870 4760 75/8" 29.7# L-80 Hydril521 566 683 6890 4790 Desi2n Criteria Tension Burst Collapse Straight Hook Load - Ignoring Deviation and Buoyancy Full Column of Gas against deepest formation pressure Except for liners where a 3000 psi test pressure on top of9.6 ppg fluid is backed on the outside by a fresh water gradient of 0.43 psi/ft. Full evacuation on the inside backed by expected formation gradient of .45 psi/ft. on the outside. 13 3/8" Surface Casin2 Tension Burst Collapse = 3500' x 68# = 238.0 K = (11890 x .45) - (.10 x 11890') = 4162 psi = (3020' x .45) - (.10 x 3020') = 1057 psi Rated = 1545 K Safety Factor = 6.5 Rated = 5050 psi Safety Factor = 1.2 Rated = 2260 psi Safety Factor = 2.1 ) 9 5/8" Intermediate Casine Tension = 15439' x 47# = 725.6 K = (13010' x .45) - (.10 x 13010') = 4554 psi = (11890' x .45) - (.10 x 11890') = 4162 psi Burst Collapse 7 5/8" Production Liner Tension = 1707' x 29.7# = 50.7 K = «13010 x .4992)+3000)-(13010 x .43) = 3900 psi = (13010' x .45) - (.10 x 13010') = 4554 psi Burst Collapse ) Rated = 1086 K Safety Factor = 1.5 Rated = 6870 psi Safety Factor = 1.5 Rated = 4760 psi Safety Factor = 1.1 Rated = 566 K Safety Factor = 11.2 Rated = 6890 psi Safety Factor = 1.8 Rated = 4790 psi Safety Factor = 1.1 ) ) REDOUBT UNIT #6 CEMENTING PROGRAM Operator Name: Forest Oil Corporat; ) Well Name: REDOUBT UNIT 6 Job Description: 13-3/8" Surface Casing, 2-Stage Date: May 24, 2002 JOB AT A GLANCE Depth (TVD) Depth (MD) 3,020 ft 3,500 ft Hole Size 18.5 in Casing SizelWeight : 13 3/8 in, 68 Ibs/ft Pump Via Casing 133/8" 0.0. (12.415" .1.0) 68 Total Mix Water Required 35,747 gals Stage No: 1 Float 3,420 ft Pre-flush Water Density 40 bbls 8.4 ppg Lead Slurry Class G Cement Density Yield 1,280 sacks 12.5 ppg 2.09 cf/sack Tail Slurry Class G, Cement Density Yield 835 sacks 15.8 ppg 1 .15 cf/sack Displacement Drilling Mud Density 512 bbls 9.0 ppg Report PIinted on: May 24.20024:11 PM Page 1 ) f£j Proposal No: 100171932A Gr41 09 Operator Name: Forest Oil Corporati ) Well Name: REDOUBT UNIT 6 Job Description: 13-3/8" Surface Casing, 2-Stage Date: May 24, 2002 JOB AT A GLANCE (Continued) Stage No: 2 Pre-flush Water Density Lead Slurry Class G Cement Density Yield Tail Slurry Class G Cement Density Yield Displacement Drilling Mud Density Report Printed on: May 24,20024:11 PM Page 2 1,500 ft 40 bbls 8.4 ppg 1,179 sacks 12.5 ppg 2.10 cflsack 465 sacks 15.8 ppg 1 .15 cflsack 225 bbls 9.0 ppg ) Wj Proposal No: 100171932A Gr41 09 Operator Name: Forest Oil CorporaV ..').. Well Name: REDOUBT UNIT 6 Job Description: 13-3/8" Surface Casing, 2-Stage Date: May 24, 2002 WELL DATA ANNULAR GEOMETRY ANNULAR I.D. (in) 28.500 CASING 18.500 HOLE ') (£j Proposal No: 100171932A DEPTH(ft) MEASURED I TRUE VERTICAL 200 I 200 3,500 I 3,020 SUSPENDED PIPES DIAMETER (in) O.D. I 13.375 I I.D. 12.415 WEIGHT (Ibs/ft) 68 DEPTH(ft) MEASURED I TRUE VERTICAL 3,500 I 3,020 STAGE: 2 Stage Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. 1,500 ft 9.00 ppg Water Based 800 F 850 F VOLUME CALCULATIONS 200 ft x 3.4544 cf/ft 1,000ft x 0.8910cf/ft 300 ft x 0.8910 cflft with 0 % excess = with 100 % excess = with 100 % excess = TOTAL SLURRY VOLUME = STAGE: 1 Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. VOLUME CALCULATIONS 1,500 ft x 0.8910 cf/ft 500 ft x 0.8910 cf/ft 80 ft x 0.8407 cf/ft with 100 % excess = with 100 % excess = with 0 % excess = TOTAL SLURRY VOLUME = Report Printed on: May 24. 20024:12 PM Page 3 = 690.9 cf 1782.0 cf 535.2 cf 3008.1 cf 536 bbls 3,420 ft 9.00 ppg Water Based 1 05 0 F 900 F = 2672.9 cf 891.6 cf 67.3 cf (inside pipe) 3631.7 cf 647 bbls Gr4115 Operator Name: Forest Oil CorporatioQ Well Name: REDOUBT UNIT 6 ) Job Description: 13-3/8" Surface Casing, 2-Stage Date: May 24, 2002 ') f£j Proposal No: 100171932A FLUID SPECIFICATIONS STAGE NO.: 1 Pre-flush 40.0 bbls Water @ 8.4 ppg FLUID VOLUME VOLUME CU-FT FACTOR AMOUNT ANn TYPF OF CFMFNT I = 1280 sacks Class G Cement + 0.4% bwoc CD- 32 + 0.3% bwoc FL-52 + 1 gals/100 sack FP-6L + 1.5% bwoc Sodium Metasilicate + 105.4% Fresh Water = 835 sacks Class G Cement + 0.3% bwoc CD-32 + 1 gals/100 sack FP-6L + 44.1 % Fresh Water Lead Slurry 2673 I 2.09 Tail Slurry 959 1.15 Displacement CEMENT PROPERTIES 512.1 bbls Drilling Mud @ 9 ppg SLURRY SLURRY NO.1 NO.2 Slurry Weight (ppg) 12.50 15.80 Slurry Yield (cflsack) 2.09 1.15 Amount of Mix Water (gps) 11.88 4.97 Amount of Mix Fluid (gps) 11.89 4.98 Estimated Pumping Time - 70 BC (HH:MM) 4:30 3:50 Free Water (mls) @ 95 0 F @ 90 0 angle 0.0 Free Water (mls) @ 95 0 F @ 45 0 angle 0.0 COMPRESSIVE STRENGTH 24 hrs @ 80 0 F (psi) 200 2700 RHEOLOGIES FLUID TEMP 600 300 200 100 6 3 Lead Slurry @ 950 F 90 89 76 74 57 39 Report Printed on: May 24.20024:12 PM Page 4 Gr4129 Operator Name: Forest Oil Corporation Well Name: REDOUBT UNIT 6 ) Job Description: 13-3/8" Surface Casing, 2-Stage Date: May 24, 2002 FLUID SPECIFICATIONS (Continued) STAGE NO.: 2 Pre-flush FLU ID VOLUME VOLUME CU-FT FACTOR Lead Slurry 2473 I Tail Slurry 535 Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cflsack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) Estimated Pumping Time - 70 BC (HH:MM) Free Water (mls) @ 80 0 F @ 90 0 angle Free Water (mls) @ 80 0 F @ 45 0 angle COMPRESSIVE STRENGTH 24 hrs @ 1000 F (psi) Report Printed on: May 24.20024:12 PM ') f£j Proposal No: 100171932A 40.0 bbls Water @ 8.4 ppg AMOUNT ANn TYPF OF CFMFNT = 1179 sacks Class G Cement + 0.3% bwoc Calcium Chloride + 0.4% bwoc CD-32 + 1 gals/100 sack FP-6L + 2% bwoc Sodium Metasilicate + 105.9% Fresh Water = 465 sacks Class G Cement + 0.3% bwoc CD-32 + 1 gals/100 sack FP-6L + 44.1 % Fresh Water 2.1 1.15 SLURRY NO.1 12.50 2.10 11.94 11.95 4:00 0.0 0.0 Page 5 224.6 bbls Drilling Mud @ 9 ppg SLURRY NO.2 15.80 1.15 4.97 4.98 3:50 0.0 0.0 2700 Gr4129 Operator Name: Forest Oil corporatir--,") Well Name: REDOUBT UNIT 6 Job Description: 9-5/8" Intermediate Casing Date: May 24, 2002 JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Casing SizelWeight : Pump Via Total Mix Water Required Pre-Flush Fluid Base Oil Density Pre-flush Water + 1 gpb MCS-A Density Weighted Spacer MCS-4D Spacer Density Lead Slurry Class G Cement Density Yield Tail Slurry Class G Cement Density Yield Displacement Drilling Mud Density Report Printed on: May 24. 2002 4:12 PM 11 ,890 ft 15,439 ft 12.25 in 9 5/8 in, 47 Ibs/ft Casing 9 5/8" 0.0. (8.681" .1.0) 47 Page 8 6,818 gals 30 bbls 7.8 ppg 20 bbls 8.4 ppg 30 bbls 10.5 ppg 451 sacks 12.5 ppg 2.09 cf/sack 301 sacks 15.8 ppg 1 .15 cf/sack 1,124 bbls 9.2 ppg ) !£j Proposal No: 100171932A Gr4109 Operator Name: Forest Oil corporatir"'). Well Name: REDOUBT UNIT 6, Job Description: 9-5/8" Intermediate Casing Date: May 24, 2002 ') !£j Proposal No: 100171932A WELL DATA ANNULAR GEOMETRY ANNULAR I.D. (in) 12.415 CASING 12.250 HOLE DEPTH(ft) MEASURED I TRUE VERTICAL 3,500 I 3,020 15,439 I 11,890 SUSPENDED PIPES DIAMETER(n1) etD. 9.625 8.681 WEIGHT . (Ib$lft) 47 Dr:pma(ft) MEASURED I TRUEVERTICAL 15,439 I 11,890 Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. 15,359 ft 9.20 ppg Oil Based 180 0 F 143 0 F VOLUME CALCULATIONS 1,500 ft x 0.3132 cf/ft 500 ft x 0.3132 cf/ft 80 ft x 0.4110 cf/ft with 100 % excess = with 100 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 939.6 cf 313.2 cf 32.9 cf (inside pipe) 1285.6 cf 229 bbls = Report Printed on: May 24. 2002 4:12 PM Page 9 Gr4115 Operator Name: Forest Oil Corporatioq Well Name: REDOUBT UNIT 6 ) Job Description: 9-5/8" Intermediate Câsing Date: May 24, 2002 f£j ) Proposal No: 100171932A FLUID SPECIFICATIONS Pre-Flush Fluid Pre-flush 30.0 bbls Base Oil @ 7.8 ppg Weighted Spacer 30.0 bbls MCS-4D Spacer + 6 Ibs/bbl MCS-D + 22.61 Ibs/bbl Bentonite + 90 Ibs/bbl Barite, Bulk @ 10.5 ppg VOLUME VOLUME CU-FT FACTOR FLUID AMOUNT AND TYPE OF CFMFNT Lead Slurry = 451 sacks Class G Cement + 0.35% bwoc R-3 + 0.4% bwoc CD-32 + 0.6% bwoc FL-52 + 1 gals/100 sack FP-6L + 1 % bwoc Sodium Metasilicate + 105% Fresh Water 940 I 2.09 Tail Slurry = 301 sacks Class G Cement + 0.15% bwoc R-3 + 0.3% bwoc CD-32 + 0.7% bwoc FL-33 + 1 gals/100 sack FP-6L + 43.6% Fresh Water 1,124.4 bbls Drilling Mud @ 9.2 ppg 346 1.15 I Displacement CEMENT PROPERTIES SLURRY NO.1 12.50 2.09 11.84 11.85 5:15 SLURRY NO.2 15.80 1.15 4.92 4.93 4:00 Slurry Weight (ppg) Slurry Yield (cflsack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) Estimated Pumping Time - 70 BC (HH:MM) Pilot tests will be preformed prior to loading. Slight additvie adjustments should be expected to achieve the desired slurry properties based on pilot test results. Gr4129 Report Printed on: May 24.20024:12 PM Page 10 Operator Name: Forest Oil corporatjr-,), Well Name: REDOUBT UNIT 6 Job Description: 7-5/8" Production Liner Date: May 24,2002 JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Liner SizelWeight : Pump Via Total Mix Water Required Pre-Flush Fluid Base Oil Density Pre-flush Water + 1 gpb MCS-AG Weighted Spacer MCS-4D Density Cement Slurry Class G Cement Density Yield Displacement Drilling Mud Density Report Pnnted on: May 24,20024:12 PM ) f£j Proposal No: 100171932A 13,010 ft 16,946 ft 8.5 in 7 5/8 in, 29.7 Ibs/ft Drill Pipe 5" 0.0. (4.276" .1.0) 19.5 Drill Pipe 7 5/8" 0.0. (6.875" .1.0) 29.7 1,185 gals 30 bbls 7.8 ppg 20 bbls 30 bbls 10.5 ppg 241 sacks 15.8 ppg 1.17 cf/sack 348 bbls 9.6 ppg Page 13 Gr4109 Operator Name: Forest Oil corporatj,,~).. Well Name: REDOUBT UNIT 6 . Job Description: 7-5/8" Production Liner Date: May 24, 2002 WELL DATA ANNULAR GEOMETRY 8.681 CASING 8.500 HOLE MEASURED 15,439 16,946 SUSPENDED PIPES DIAMETER«iri) QlD~ 7.625 WEIGHT (I~~tft) 29.7 0 EPTH(ft) MEASURED ..L. . TRUE VERTICAL 16,946 I 13,010 6.875 Drill Pipe 5.0 (in) 00, 4.276 (in) ID, 19.5 (Ibs/ft) set @ Drill Pipe 7.625 (in) 00, 6.875 (in) 10, 29.7 (Ibs/ft) set @ Depth to Top of Liner Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. VOLUME CALCULATIONS 300 ft x 0.0939 cf/ft with 0 % excess = 1,507 ft x 0.0770 cf/ft with 100 % excess = 80 ft x 0.2578 cf/ft with 0 % excess = TOTAL SLURRY VOLUME = Report Printed on: May 24. 2002 4:12 PM Page 14 15,139 ft 16,866 ft ) E£j Proposal No: 100171932A DEPTH(ft) I. TRUEVERTICAL I 11 ,890 I 13,010 15,139 ft 16,866 ft 9.60 ppg Oil Based 192 0 F 154 0 F = 28 cf 232 cf 21 cf (inside pipe) 281 cf 50 bbls Gr4117 Operator Name: Forest Oil Corporatioq Well Name: REDOUBT UNIT 6 ) Job Description: 7-5/8" Production Liner Date: May 24, 2002 FLUID SPECIFICATIONS Pre-Flush Fluid Pre-flush Weighted Spacer FLUID VOLUME VOLUME CU-FT FACTOR Cement Slurry 281 I Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) Estimated Pumping Time - 70 BC (HH:MM) Free Water (mls) @ 155 0 F @ 90 0 angle Fluid Loss (cc/30min) at 1000 psi and 1550 F COMPRESSIVE STRENGTH 24 hrs @ 1900 F (psi) ) E£j Proposal No: 100171932A 30.0 bbls Base Oil @ 7.8 ppg 30.0 bbls MCS-4D + 6 Ibs/bbl MCS-D + 22.61 Ibs/bbl Bentonite + 90 Ibs/bbl Barite, Bulk @ 10.5 ppg AMOUNT AND TYPF OF CFMENT 1.17 = 241 sacks Class G Cement + 0.15% bwoc R-3 + 2% bwow Potassium Chloride + 0.6% bwoc CD- 32 + 0.2% bwoc FL-33 + 1 gals/100 sack FP-6L + 0.15% bwoc Sodium Metasilicate + 0.9% bwoc BA-10A + 43.6% Fresh Water 348.2 bbls Drilling Mud @ 9.6 ppg SLURRY NO.1 15.80 1.17 4.92 4.93 4:15 0.0 20.0 3200 Pilot tests will be preformed prior to loading. Slight additvie adjustments should be expected to achieve the desired slurry properties based on pilot test results. . Report Printed on: May 24.20024:12 PM Page 15 Gr4129 Operator Name: Forest Oil Corporat' ) Well Name: REDOUBT UNIT 6 Date: May 24, 2002 ) f£j Proposal No: 100171932A PRODUCT DESCRIPTIONS BA-10A Improves cement bonding and acts as a matrix flow control agent. BA-10A is effective in a wide variety of slurries. Barite, Bulk A naturally occuring mineral (Barium Sulfate). It is widely used as a weighting material in cement spacers and occasionally in cement slurries. It can yield a slurry density in excess of 19 Ibs/gal. Bentonite Commonly called gel, it is a clay material used as a cement extender and to control excessive free water. CD-32 A patented, free-flowing, water soluble polymer that is an efficient and effective dispersant for primary and remedial cementing. Calcium Chloride A powdered, flaked or pelletized material used to decrease thickening time and increase the rate of strength development. Class G Cement Intended for use as a basic cement from surface to 8000 ft as manufactured, or can be used with accelerators and retarders to cover a wide range of well depths and temperatures. FL-33 A patented cement fluid loss additive that provides exceptional fluid loss control across a wide range of temperatures, salinity conditions, and remedial cementing applications at low to high temperature ranges. FL-52 A water soluble, high molecular weight fluid loss additive used in medium to low density slurries. It is functional from low to high temperature ranges. FP-6L A clear liquid that decreases foaming in slurries during mixing. MCS-4 A turbulent flow spacer system that prevents water and oil-base mud and cement contamination and water-wets the casing to increase bonding. MCS-A A water-base spacer surfactant designed to effectively remove drilling mud and wall cake during cementing operations and prevent contamination of the cement slurry during placement. MCS-A is compatible with some oil-base muds, water-base muds and all common cementing systems. MCS-A is easily mixed on location, with all dry materials pre-blended at the district. Therefore, a separate batch mixer is not a necessity. MCS-AG A surfactant used in cement spacer systems to prevent mud incompatability and improve bonding. Report Printed on: May 24, 20024:12 PM Page 18 Gr4163 Operator Name: Forest Oil Corpora+" ') Well Name: REDOUBT UNIT 6 Date: May 24, 2002 ) E£j Proposal No: 100171932A PRODUCT DESCRIPTIONS (Continued) Potassium Chloride A granular salt used to reduce clay swelling caused by water-base stimulation fluids. R-3 A low temperature retarder used in a wide range of slurry formulations to extend the slurry thickening Sodium Metasilicate An extender used to produce an economical, low density cement slurry. Sodium Metasilicate An extender used to produce an economical, low density cement slurry. Report Printed on: May 24, 20024:12 PM Page 19 Gr4163 REDOUBT UNIT #6 DIRECTIONAL PROGRAM ) ) .P~V"'SUI1 Alaska CRtLL~£L.~..)lJJ;sì;i Cook Inlet __~_':I"_I'.~,~~.,t?~~~!._, 1600 - 3200 - 4800 - ..- ã) ~ .c 15. 6400- () 0 m u :e () > 8000 - 9600 - : 11200 - ~ iI:= 0 0 CD ..- II J:: .š 12800 - (¡) ro 0 (f) DrillQuest 2,00.09.006 0 ) Osprey RU#6 WP02 Leg 3 - Slot 4 Current Well Properties DrillQuest'" ,--__----Begin 18-1/2" Hole --,__-,-Begin Dir@ 1.000'/100ft: 200.00fl MD, 200.00ft lVD ~-___.--Dir Rate Increase@ 2.000'/1000 : 400.0OOMD,399.96ftTVD ~--_,----Dir Rate Increase @ 3.000°/1000 : 600.00ftMD,599.46ftTVD Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: RKB Elevation: ¡OQ,QO Grid North Convergence: North Reference: Units: <800'O:'_Ænd Dir, Start Sail @ 42.018' : 2122,27ftMD,1996.92ftTVD RU#6 WP02 Leg 3 - Slot 4 2449934.00 N, 200624.17 E 1677.00 S, 2250986.83 W 60° 41' 43.6725" N, 1510 40' 14.5672" W 90.00ft above Mean Sea Level 90.OOft above Structure -1.457° Grid North Feet (US) Proposal Data for RU#6 WP02 / Begin 12-114" Hole / '..'Err.!...::!! OrlfJ!rr ~,~~~,~";~~,~:~11~~;D~: IIt~ Nc.rn"1 Rf.'fF.:-r¿.n':t; . , Grid r J(¡nn C(n..,o;:"g~n(t:" '.'\10:11 'lJ ¿.I I fr G'".1 r.Jt',nt1 -1 ..1S Î Dogleg severity: Degrees per 100 feet (US) Vertical Section Azimuth: 133.880° Vertical Section Description:Well Vertical Section Origin: 0.00 N,O.OO E Coordinate System: Measured Incl. Depth 0.00 200.00 4IXU)O 600.00 2122.27 15438.57 16946.12 NAD27 Alaska State Planes, Zone 4, US Foot Azim Vertical Northings Eastings Vertical Dogleg Depth Section Rate 0,000 0.00 O.OON O,OOE 0.00 0.000 200.00 O.OON O,OOE 0.00 0,000 280.000 399.96 0-61N 3.44 W -2.90 1.0(X) 259,877 599.46 0,57 S 16.86W -11.76 2,000 133.457 1996,9'2 385.14 S 293.62 E 478.60 3.000 133.457 .1890.00 6516.00 S 6763,83 E 9391.89 0.000 133.457 13010.00 7210.08 S 7496.33 E 10400.97 0,000 0.000 0,000 2.000 5.818 42.018 42.018 42,018 I 0 1600 Scale: 1 inch = 1600ft 3200 i I 4800 6400 Vertical Section (Well) . ,- ,,", ,'. , ' .~. . .. -, . =. ~. . '-. ~'" ~ Begin 8-112" Hole -- Iþ~ ----z 9 5/8" Casing 15439.000 MD 11890.32ft TVD R(:#6 T2 H"mí(>c~ (J-e" p(>/¡".-" 1 15iH}.fNljr T17J . t1516.(jt} S. 67ri3~.J3 l:' -~..,. RF¡;" 1'.1 TO ¡test ¡--",.dam! . 7=; ~~~~1~~(.~~:~~~~~ F /7 518" Liner / 16946. 12ft MD / 13010.0Oft TVD Total Depth: 16946.12ftMO.13010.00ftlVD/ I I 8000 9600 Section Azimuth: 133.8800 (Grid North) -~--._--~--_.._------- spE!r'r'Y-&...Jr"1 Alaska ,"",a'I'LL. lìoi¡",f ....=¡ií HUC'""""" C k I I t "."",o.''''''~'''''''~'"'''';~';':;;~''~ 00 n e ~~~~e~P02 Leg 3 - Slot 4 i DrillQue;sl~ Single Well Target Data for RU#6 WP02 Leg 3. Slot 4 -'-----' Begin 18-112" Hole Measurement Units: ft 0 '''''~;''~;;~:::- Begin Oir @ 1,000'/100ft: 200.0Oft MD, 200.0Oft TVD Coordinate "<:::::.:;:Dir Rate Increase @ 2.000'/100ft : 400.0OftMD,399.96ftTVD Target Point TVD Northings Eastings SSTVD Northings Eastings Target '---."Dir Rate Increase @ 3.0000/100It : 600.0OftMD,599.46ftTVO Name Type ASPY ASP X Shape '''-"" End Dir, Start Sail @42.018° : 2122,27ftMD,1996.92ftTVD RU#6 T2 Hcmlock Gco P(1)' Entr.v Point 11890,00 6516,00 S 6763.83 E 11800.00 2443418.00 N 207388,00 E Ellipse RU#61'3 TO West Forc1and Enny Point 130W.OO 7210.08 S 7496.33 E 12920,00 2442723.92 N 208120.50 E Point 90(1.(10 133/8" Casing ~ -,,-,,-----"" Begin 12-1/4" Hole 3500.0Oft MD 3020,48ft TVO Proposal Data for RU#6 WP02 -1200 - Vertical Origin: Horizontal Origin: Measurement Units: North Reference: Grid North Convergence: Well Well ft Grid North -1.457" Dogleg severity: Degrees per 100 feet (US) Vertical Section Azimuth: 133.880° Vertical Section Description:Well Vertical Section Origin: 0,00 N,O.OO E -2400 - Coordinate System: NAD27 Alaska State Planes, Zone 4, US Foot Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate 0.00 0.000 0.000 0.00 O.OON O.OOE 0.00 200.00 0.000 0.000 200.00 O.OON O.OOE 0.00 0.000 400.00 2.000 280.000 399.96 0.61 N 3.44 W -2.90 1.000 600.00 5.818 259.877 599.46 0.57 S 16.86 W -11.76 2.000 2122.27 42.018 133.457 1996.92 385.14 S 293.62 E 478.60 3.000 15438.57 42.018 133.457 11890.00 6516.00 S 6763.83 E 9391.89 0.000 16946.12 42.018 133.457 13010.00 7210.08 S 7496.33 E 10400.97 0.000 -. ëi3 ~ ";;; -3600 - 0> C :ë t 0 Z -4800 - Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: RKB Elevation: Current Well Properties .m....,. ... --.... -.....----..----..---.......--m'--m"'.m."--_"''''''-'''',,---,.... RU#6 WP02 Leg 3 - Slot 4 2449934.00 N, 200624.17 E 1677.00 S, 2250986.83 W 60" 41' 43.6725" N, 151040' 14.5672" W Grid North Convergence: North Reference: Units: 90,00ft above Mean Sea Level 90.00ft above Structure -1.457" Grid North Feet (US) ~. -6000 - i1= 0 0 N II .!: .~ -7200 - à) ëi:i ü (j) llU#6 T3 TÐ ¡Yest P,wd,,!'<d 1.WlfJ.tiWt ,['VD."'''''--'''''''' 72l1!Ji8.S; N96.H E Liner 16946.12ft MD 1301 O.OOft TVD .....-....... ~. ":'. ','.', "".',' ,.,,:,'. 0 Scale: 1 inch = 1200ft I 1200 I 2400 I 3600 Eastings (Well) I 4800 :';~;;~~:l' / / Total Depth: 16946.12ftMD,13010.00ftTVÓ ¡ I 6000 7200 Reference is Grid North SperrÝ-Sun Drilling SerJices Proposal Data - Plan: RU#6 Leg 3 - Slot 4 - RU#6 WP02 Approved Plan ~~ - :;I~) '~~fl ~~lli- ~f ~~~ft) Nor:~~ngSE(~t)9'- - (~~~I}i1:~ -- ~i16~)T~)aGelvs¡~f;) 1 0.00, 0.00:' 0.00 0.00: ; 0.00 0.00 ' i' ¡ , " , 0:0 2, :20g...Q~:' 200.00 0.001 ,',' 0.00' 2oo.ooí, .?q2:~Ql, ",O:~o, . 0.00: ,,'0.60.: 0.00 .,9ß()l',~.:99,:'"",-,-,_._:,_9.Q --_1._-----~~o.oo' __--3_Q2:2~_~___?:Q~l' 280.~~- 399.9~- 199.961 <?:?~------_~:.~~m_m----~:g.9~-~--~:.o.Q...--~-_0.00im----?_~2:.q~- ", .2.9 4 .' '600.00, 200.00:' : 5:a.~: "2~~~~8,, ,599~~6:, , 199.50\' 0.57 S , 16.86 W, , '" 2.00: ' 1.-91 ,-10.061 330.00: ',-11..~ 5 ::2122~27 1522.27 42.02 133.46 1996.92 ,1397.46 385.'148 293.62E 3.00, '2.38' '-8.30 228:85 '478.6 6T i5438~57 13316~31 42.02 133.46 11890.00 9893.08 6516.00 S 6763.83 E 0.00 0.00' 0.00 0.00 9391.9, ~--- . f6~6:12'" "'''1507.55'1' ..~2.~?L.._].~i:!~~-- 1,3010,?0~..Ù.?2:'~~! "72'10.oíÙ;" 7496.33 ' ' 'ö,'6~.:~__~.oo: o.6ö: ' "ò.~Ö;"'" '{~2.~:~ 24 May~ 2002 - 9:40 -1 - DrillQuest ~' Alaska oak Inlet Osprey, lot Leg 3 - Slot 4 Plan: RU#6 Leg 3 - Slot 4 - RU#6 WP02 Revised: 22 May, 2002 PROPOSAL REPORT 24 May, 2002 Surface Coordinates: 2449934.00 N, 200624.17 E (60041' 43.6725" N, 151040' 14.5672" W) Surlace Coordinates relative to Project H Reference: 2550066.00 S, 299375.83 W (Grid) Surface Coordinates relative to Structure: 1677.00 S, 2250986.83 W (Grid) Kelly Bushing: 90.00ft above Mean Sea Level ~pl!i"-" 1:/-!5LJ11 itfFifmLJ.:c.,1I N1 ~_,,~"E5AV,~r;:,-~l!ê! ...,*.111:...118, ç;a,. t:~1 ~ Proposal Ref: pr079 Sperry-Sun Drilling Services Proposal Report for Plan: RU#6 Leg 3 - Slot 4 - RU#6 WP02 Revised: 22 Mays 2002 Cook Inlet Alaska Osprey Measured Sub-Sea Vertical Local Coordinates Global Coordinates Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin Section Comment (ft) (ft) (ft) (ft) (ft) (ft) "eft)' 0.00 0.000 0.000 -90.00 0.00 0.00 N C;. ()() ï: 2/: (.9!n': ,00 N 200624.17 E 0.00 Begin 18-112" Hole 100.00 0.000 0.000 10.00 100.00 O.OON 000 E 244~934.00 N 0694.17 E 0.000 0.00 200.00 0.000 0.000 110.00 200.00 O.OON 0,00 E 2449934.00 N 624.17 E 0.000 0.00 Begin Dir@ 1.0000/100ft: 200.00ft MD, 200.00ft TVD 300.00 1.000 280.000 209.99 299.99 0.15 N 244993.).15 N 200623.31 E 1.000 -0.72 400.00 2.000 280.000 309.96 399.96 0.61 N 244993~,61 N 200620.73 E 1.000 -2.90 Dir Rate Increase @ 2.000°/1 OOft-:-"" 400.00ftMD ,399. 96ftTVD 500.00 3,864 264.991 409.83 499.83 2449934.61 N 200615.66 E 2.000 -6.56 600.00 5.818 259.877 509.46 599.46 2449933.43 N 200607.31 E 2.000 -11.76 Dir Rate Increase @ 3.000°/1 OOft : 600.00ftM D ,599.46ftTVD 700.00 4.457 229.404 609.08 699.08 24.80 W 2449930.01 N 200599.37 E 3.000 -15.11 800.00 4.883 192.248 708.77 79a.ZZ" 28.66 W 2449923.32 N 200595.51 E 3.000 -13.25 900.00 6.766 168.771 808,26 898.26 28.41 W 2449913.38 N 200595.76 E 3.000 -6.19 1000.00 9.257 156.601 907 28 99728 24.07 W 2449900.22 N 200600.10 E 3.000 6.07 1100.00 11 .982 149.730 1005 57 1095.57 15.64 W 2449883.87 N 200608.53 E 3.000 23.48 1200.00 14.812 145.413 11 02 84 1192.84 3.15W 2449864.38 N 200621.02 E 3.000 45.99 1300.00 17.697 142.466 1198.83 1288.83 13.37 E 2449841.79 N 200637.54 E 3.000 73.55 1400.00 20.614 140.326 93:29 ';@k'1383.29 33.87 E 2449816.19 N 200658.04 E 3.000 106.08 1500.00 23.552 138.699 1385.94 1475.94 146.38 S 58.30 E 2449787.62 N 200682.47 E 3.000 143.49 1600.00 26.502 137.415 1476.54 1566.54 177.82 S 86.59 E 2449756.18 N 200710.76 E 3.000 185.67 1700.00 29.462 136.372 1564.84 1654.84 212.06 S 118.67 E 2449721.94 N 200742.84 E 3.000 232.52 1800.00 32.429 135.504 1650.60 1740.60 248.99 S 154.44 E 2449685.01 N 200778.61 E 3.000 283.91 1900.00 35.401 134.767 1733.58 1823.58 288.53 S 193.80 E 2449645.47 N 200817.97 E 3.000 339.68 ~ 2000.00 38.376 134.131 1813.55 1903.55 330.55 S 236.65 E 2449603.45 N 200860.82 E 3.000 399.70 2100.00 41 .355 133.573 1890.30 1980.30 374.94 S 282.88 E 2449559.06 N 200907.05 E 3.000 463.79 2122.27 42.018 133.457 1906.92 1996.92 385.14 S 293.62 E 2449548.86 N 200917.79 E 3.000 478.60 End Dir, Start Sail @ 42.018° : 2122.27ftMD,1996.92ftTVD 2200.00 42.018 133.457 1964.67 2054.67 420.93 S 331.39 E 2449513.07 N 200955.56 E 0.000 530.63 2300.00 42.018 133.457 2038.97 2128.97 466.97 S 379.98 E 2449467.03 N 201004.15 E 0.000 597.56 24 May, 2002 - 9:41 Page 20f9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: RU#6 Leg 3 w Slot 4 w RU#6 WP02 Revised: 22 May, 2002 Cook Inlet Alaska Osprey Measured Sub-Sea Vertical Local Coordinates Global Coordinates Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin Section Comment (ft) (ft) (ft) (ft) (ft) (ft) ~»(ft) 2400.00 42.018 133.457 2113.26 2203.26 513.01 S 428,57 E 244942(1,99 N 201052,74 E 0.000 664.50 2500.00 42.018 133.457 2187.55 2277.55 559.05 S 477,15 E 2449374.95 N 1'1itJl1~32 E 0.000 731.43 2600.00 42.018 133.457 2261.85 2351.85 605.09 S 52574 E 2449328.91 N 149.91 E 0.000 798.37 2700.00 42.018 133.457 2336.14 2426.14 651 .13 S 574,33 E 2449282,87 N 201198.50 E 0.000 865.30 2800.00 42.018 133.457 2410.43 2500.43 697.17 S 622 92 E 244923683 N 201247.09 E 0.000 932.24 2900.00 42.018 133.457 2484.72 2574.72 2449190.79 N 201295.68 E 0.000 999.17 3000.00 42.018 133.457 2559.02 2649.02 2449144.75 N 201344.27 E 0.000 1066.11 3100.00 42.018 133.457 2633.31 2723.31 2449098.71 N 201392.86 E 0,000 1133.04 3200.00 42.018 133.457 2707.60 2797.60 2449052.67 N 201441.44 E 0.000 1199.98 3300.00 42.018 133.457 2781.90 2871.90 2449006.63 N 201490.03 E 0.000 1266.92 3400.00 42.018 133.457 2856.19 2946.1,9. 914.45 E 2448960.59 N 201538.62 E 0.000 1333.85 3500.00 42.018 133.457 2930.48 3020.48 963.04 E 2448914.55 N 201587.21 E 0.000 1400.79 Begin 12-1/4" Hole 13 3/8" Casing 3600.00 42.018 133.457 3004.78 3094,78 1065.49 S 1011.63E 2448868.51 N 201635.80 E 0.000 1467.72 3700.00 42.018 133.457 3079.07 316907 1111 .53 S 1060.22 E 2448822.47 N 201684.39 E 0.000 1534.66 3800.00 42.018 133.457 3153 36 3243 36 1157.57 S 1108.81E 2448776.43 N 201732.98 E 0.000 1601.59 3900.00 42.018 133.457 ~¡;g¡3227.65 331ï.65 1203.61 S 1157.39 E 2448730.39 N 201781.56 E 0.000 1668.53 4000.00 42.018 133.457 1i¡iJ¡i3301.95 3391.95 1249.65 S 1205.98 E 2448684.35 N 201830.15 E 0.000 1735.46 4100.00 42.018 133.457 3376.24 3466.24 1295.69 S 1254.57 E 2448638.31 N 201878.74 E 0.000 1802.40 4200.00 42.018 133.457 3450.53 3540.53 1341.73 S 1303.16 E 2448592.27 N 201927.33 E 0,000 1869.33 4300.00 42.018 133.457 3524.83 3614.83 1387.77 S 1351.75 E 2448546.23 N 201975.92 E 0.000 1936.27 4400.00 42.018 133.457 3599.12 3689.12 1433.81 S 1400.34 E 2448500.19 N 202024.51 E 0.000 2003.20 4500,00 42.018 133.457 3673.41 3763.41 1479.85 S 1448.93 E 2448454.15 N 202073.10 E 0.000 2070.14 4600.00 42.018 133.457 3747.70 3837.70 1525.89 S 1497.51 E 2448408.11 N 202121.68 E 0.000 2137.07 4700.00 42,018 133.457 3822.00 3912.00 1571.93 S 1546.10 E 2448362.07 N 202170.27 E 0,000 2204.01 4800,00 42.018 133.457 3896.29 3986.29 1617.97 S 1594.69 E 2448316.03 N 202218,86 E 0,000 2270.94 4900.00 42.018 133.457 3970.58 4060.58 1664.01 S 1643.28 E 2448269.99 N 202267.45 E 0.000 2337.88 5000.00 42.018 133.457 4044.88 4134.88 1710.05 S 1691.87 E 2448223.95 N 202316.04 E 0.000 2404.81 5100,00 42.018 133.457 4119.17 4209.17 1756.09 S 1740.46 E 2448177.91 N 202364.63 E 0,000 2471.75 5200.00 42,018 133.457 4193.46 4283.46 1802.14 S 1789.05 E 2448131.86 N 202413.22 E 0,000 2538.68 5300.00 42.018 133.457 4267.76 4357.76 1848.18 S 1837.64 E 2448085,82 N 202461.81 E 0.000 2605.62 24 May, 2002 w 9:41 Page 3 of9 DriJ/Quest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: RU#6 Leg 3 . Slot 4 * RU#6 WP02 Revised: 22 May, 2002 Cook Inlet Alaska Osprey Measured Sub-Sea Vertical Local Coordinates Global Coordinates ogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin ate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) "f¥t) . OOft) 5400.00 42.018 133.457 4342.05 4432.05 1894.22 S 2448039,78 N 202510,39 E 0.000 2672.55 5500.00 42.018 133.457 4416.34 4506.34 1940.26 S 2..\47993.74 N - 2558.98 E 0.000 2739.49 5600.00 42.018 133.457 4490.63 4580.63 1986.30 S 2447947.70 N 607.57 E 0.000 2806.42 5700.00 42.018 133.457 4564.93 4654.93 2032.34 S 24..\ 7901.66 N 202656.16 E 0.000 2873.36 5800.00 42.018 133.457 4639.22 4729.22 2078.38 S m2447855 62 N 202704.75 E 0.000 2940.29 ~ 5900.00 42.018 133.457 4713.51 4803.51 2124.42 S 7809.58 N 202753.34 E 0.000 3007.23 6000.00 42.018 133.457 4787.81 4877.81 2170.46 S 2447763.54 N 202801.93 E 0.000 3074.16 6100.00 42.018 133.457 4862.10 4952.10 2216505 2447717.50 N 202850.51 E 0.000 3141.10 6200.00 42.018 133.457 4936.39 5026.39 2262,54 5 2447671.46 N 202899.10 E 0.000 3208.03 6300.00 42.018 133.457 5010.68 5100.68 2447625.42 N 202947.69 E 0.000 3274.97 6400.00 42.018 133.457 5084.98 5174.98^ 2372.11 E 2447579.38 N 202996.28 E 0.000 3341.91 6500.00 42.018 133.457 5159.27 5249.27 2420.70 E 2447533.34 N 203044.87 E 0.000 3408.84 6600.00 42.018 133.457 5233.56 5323.56 2469.29 E 2447487.30 N 203093.46 E 0.000 3475.78 6700.00 42.018 133.457 5307,86 5397.86 2517.88 E 2447441.26 N 203142.05 E 0.000 3542.71 6800.00 42.018 133.457 82.15 5472.15 2566.46 E 2447395.22 N 203190.63 E 0.000 3609.65 6900.00 42.018 133.457 5546.44 2584.82 S 2615.05 E 2447349.18 N 203239.22 E 0.000 3676.58 7000.00 42.018 133.457 5620.74 2630.865 2663.64 E 2447303.14 N 203287.81 E 0.000 3743.52 7100.00 42.018 133.457 5695.03 2676.90 S 2712.23 E 2447257.10 N 203336.40 E 0.000 3810.45 7200.00 42.018 133.457 5769.32 2722.94 S 2760.82 E 2447211.06 N 203384.99 E 0.000 3877.39 7300.00 42.018 133.457 5843.61 2768.98 S 2809.41 E 2447165.02 N 203433.58 E 0.000 3944.32 7400.00 42.018 133.457 5827.91 5917.91 2815.02 S 2858.00 E 2447118.98 N 203482.17 E 0.000 4011.26 7500.00 42.018 133.457 5902.20 5992.20 2861.065 2906.59 E 2447072.94 N 203530.76 E 0.000 4078.19 7600.00 42.018 133.457 5976.49 6066.49 2907.10 S 2955.17 E 2447026.90 N 203579.34 E 0.000 4145.13 - 7700.00 42.018 133.457 6050.79 6140.79 2953.14 S 3003.76 E 2446980.86 N 203627.93 E 0.000 4212.06 7800.00 42.018 133.457 6125.08 6215.08 2999.18 S 3052.35 E 2446934.82 N 203676.52 E 0.000 4279.00 7900.00 42.018 133.457 6199.37 6289.37 3045.22 S 3100.94 E 2446888.78 N 203725.11 E 0.000 4345.93 8000.00 42.018 133.457 6273.66 6363.66 3091.26 S 3149.53 E 2446842.74 N 203773.70 E 0.000 4412.87 8100.00 42.018 133.457 6347.96 6437.96 3137.30 S 3198.12 E 2446796.70 N 203822.29 E 0.000 4479.80 8200.00 42.018 133.457 6422.25 6512.25 3183.34 S 3246.71 E 2446750.66 N 203870.88 E 0.000 4546.74 8300.00 42.018 133.457 6496.54 6586.54 3229.38 S 3295.29 E 2446704.62 N 203919.46 E 0.000 4613.67 24 May, 2002. 9:41 Page 4 of 9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: RU#6 Leg 3 - Slot 4 - RU#6 WP02 Revised: 22 May, 2002 Cook Inlet Alaska Osprey Measured Sub-Sea Vertical Local Coordinates Vertical Depth Incl. Azim. Depth Depth Northings Eastings Section Comment (ft) (ft) (ft) (ft) (ft) 8400.00 42.018 133.457 6570.84 6660.84 3275.42 S 3343.88 E 2446658 58 N 203968.05 E 0.000 4680.61 8500.00 42.018 133.457 6645.13 6735.13 3321.46 S 3392.4 7 E 2446612,54 N 4'fJ;li@":64 E 0.000 4747.54 8600.00 42.018 133.457 6719.42 6809.42 3367.50 S 3441.06 E 2446566.50 N 065.23 E 0.000 4814.48 8700.00 42.018 133.457 6793.72 6883.72 3413.54 S 3489.65 E 2446520.46 N 204113.82 E 0.000 4881.41 8800.00 42.018 133.457 6868.01 6958.01 3459.58 S 3538.24 E 2..\46474.42 N 204162.41 E 0.000 4948.35 -' 8900.00 42.018 133.457 6942.30 7032.30 3505.62 S 3E 2446~28 38 r, 204211.00 E 0.000 5015.28 9000.00 42.018 133.457 7016.59 7106.59 3551.66 S '%t'fijF2446382.34 N 204259.58 E 0.000 5082.22 9100.00 42.018 133.457 7090.89 7180.89 2,597 70 S E 2446336.30 N 204308.17 E 0.000 5149.15 9200.00 42.018 133.457 7165.18 7255.18 3643,75 S 37 :59 E 2446290.25 N 204356.76 E 0.000 5216.09 9300.00 42.018 133.457 7239.47 7329.47 3781.18 E 2446244.21 N 204405.35 E 0.000 5283.02 9400.00 42.018 133.457 7313.77 7 403.;I~Z»> 3829.77 E 2446198.17 N 204453.94 E 0.000 5349.96 9500.00 42.018 133.457 7388.06 7478.06 3878.36 E 2446152.13 N 204502.53 E 0.000 5416.89 9600.00 42.018 133.457 7462.35 7552.35 3926.95 E 2446106.09 N 204551.12 E 0.000 5483.83 9700.00 42.018 133.457 7536.64 7626.64 3975.54 E 2446060.05 N 204599.71 E 0.000 5550.77 9800.00 42.018 133.457 7610.94 '7700.94 4024.12 E 2446014.01 N 204648.29 E 0.000 5617.70 9900.00 42.018 133.457 7775.23 3966.03 S 4072.71 E 2445967.97 N 204696.88 E 0.000 5684.64 10000.00 42.018 133.457 '7849.52 4012.07 S 4121.30 E 2445921.93 N 204745.47 E 0.000 5751.57 10100.00 42.018 133.457 7923.82 4058.11 S 4169.89 E 2445875.89 N 204794.06 E 0.000 5818.51 10200.00 42.018 133.457 7998.11 4104.15 S 4218.48 E 2445829.85 N 204842.65 E 0.000 5885.44 10300.00 42.018 133.457 8072.40 4150.19 S 4267.07 E 2445783.81 N 204891.24 E 0.000 5952.38 10400.00 42.018 133.457 8056.70 8146.70 4196.23 S 4315.66 E 2445737.77 N 204939.83 E 0.000 6019.31 10500.00 42.018 133.457 8130.99 8220.99 4242.27 S 4364.24 E 2445691.73 N 204988.41 E 0.000 6086.25 10600.00 42.018 133.457 8205.28 8295.28 4288.31 S 4412.83 E 2445645.69 N 205037.00 E 0.000 6153.18 10700.00 42.018 133.457 8279.57 8369.57 4334.35 S 4461.42 E 2445599.65 N 205085.59 E 0.000 6220.12 10800.00 42.018 133.457 8353.87 8443.87 4380.39 S 4510.01 E 2445553.61 N 205134.18 E 0.000 6287.05 10900.00 42.018 133.457 8428.16 8518.16 4426.43 S 4558.60 E 2445507.57 N 205182.77 E 0.000 6353.99 11000.00 42.018 133.457 8502.45 8592.45 4472.47 S 4607.19 E 2445461.53 N 205231.36 E 0.000 6420.92 11100.00 42.018 133.457 8576.75 8666.75 4518.51 S 4655.78 E 2445415.49 N 205279.95 E 0.000 6487.86 11200.00 42.018 133.457 8651.04 8741.04 4564.55 S 4704.36 E 2445369.45 N 205328.53 E 0.000 6554.79 11300.00 42.018 133.457 8725.33 8815.33 4610.59 S 4752.95 E 2445323.41 N 205377.12 E 0.000 6621.73 24 May, 2002 - 9:41 Page 50f9 DríllQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: RU#6 Leg 3 - Slot 4 - RU#6 WP02 Revised: 22 May, 2002 Cook Inlet Alaska Osprey Measured Sub-Sea Vertical local Coordinates Global Coordinates Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin Section Comment (ft) (ft) (ft) (ft) (ft) (ft) . (H) 11400.00 42.018 133.457 8799.62 8889.62 4656.63 S 4801.54 E 2445277,37 N 205425.71 E 0.000 6688.66 11500.00 42.018 133.457 8873.92 8963.92 4702.67 S 4850,13 E 2-1045231.33 N 54;74.30 E 0.000 6755.60 11600.00 42.018 133.457 8948.21 9038.21 4748.71 S 4898,72 E 2445185.29 N 522.89 E 0.000 6822.53 11700.00 42.018 133.457 9022.50 9112.50 4794.75 S 4947.31 E 2445139.25 \J 205571.48 E 0.000 6889.47 11800.00 42.018 133.457 9096.80 9186.80 4840.79 S 4995,90 E 2044509321 I'J 205620.07 E 0.000 6956.40 -- 11900.00 42.018 133.457 9171.09 9261.09 4886.83 S 5044.49 E 24~5047,17 N 205668.66 E 0.000 7023.34 12000.00 42.018 133.457 9245.38 9335.38 4932.87 S 509307 E 2445001 13 I'J 205717.24 E 0.000 7090.27 12100.00 42.018 133.457 9319.68 9409.68 497891 S 5141,66 E 2444955,09 N 205765.83 E 0.000 7157.21 12200.00 42.018 133.457 9393.97 9483.97 5024.95 S 5fgd:'~5 E 2444909.05 N 205814.42 E 0.000 7224.14 12300.00 42.018 133.457 9468.26 9558.26 5238.84 E 2444863.01 N 205863.01 E 0.000 7291.08 12400.00 42.018 133.457 9542.55 9632.5;fi. 5287.43 E 2444816.97 N 205911.60 E 0.000 7358.01 12500.00 42.018 133.457 9616.85 9706.85 5336.02 E 2444770.93 N 205960.19 E 0.000 7424.95 12600.00 42.018 133.457 9691 14 9781.14 5384.61 E 2444724.89 N 206008.78 E 0.000 7491.88 12700.00 42.018 133.457 9765.43 9855.43 5433.19 E 2444678.85 N 206057.36 E 0.000 7558.82 12800.00 42.018 133.457 9839.73 9929.73 5481.78 E 2444632.81 N 206105.95 E 0.000 7625.76 12900.00 42.018 133.457 9914.02 1000'¡.02 5347.23 S 5530.37 E 2444586.77 N 206154,54 E 0.000 7692.69 13000.00 42.018 133.457 88.3'1 \iW10078.31 5393.27 S 5578.96 E 2444540.73 N 206203.13 E 0.000 7759.63 13100.00 42.018 133.457 062.60 10152.60 5439.31 S 5627.55 E 2444494.69 N 206251.72 E 0.000 7826.56 13200.00 42.018 133.457 10136.90 10226.90 5485.35 S 5676.14 E 2444448.65 N 206300.31 E 0.000 7893.50 13300.00 42.018 133.457 10211.19 10301.19 5531.40 S 5724.73 E 2444402.60 N 206348.90 E 0.000 7960.43 13400.00 42.018 133.457 10285.48 10375.48 5577.44 S 5773.31 E 2444356.56 N 206397.48 E 0.000 8027.37 13500.00 42.018 133.457 10359.78 10449.78 5623.48 S 5821.90 E 2444310.52 N 206446.07 E 0.000 8094.30 13600.00 42.018 133.457 10434.07 10524.07 5669.52 S 5870.49 E 2444264.48 N 206494.66 E 0.000 8161.24 .--- 13700.00 42.018 133.457 10508.36 10598.36 5715.56 S 5919.08 E 2444218.44 N 206543.25 E 0.000 8228.17 13800.00 42.018 133.457 10582.66 10672.66 5761.60 S 5967.67 E 2444172.40 N 206591.84 E 0.000 8295.11 13900.00 42.018 133.457 10656.95 10746.95 5807.64 S 6016.26 E 2444126.36 N 206640.43 E 0.000 8362.04 14000.00 42.018 133.457 10731.24 10821.24 5853.68 S 6064.85 E 2444080.32 N 206689.02 E 0.000 8428.98 14100.00 42.018 133.457 10805.53 10895.53 5899.72 S 6113.44 E 2444034.28 N 206737.61 E 0.000 8495.91 14200.00 42.018 133.457 10879.83 10969.83 5945.76 S 6162.02 E 2443988.24 N 206786.19 E 0.000 8562.85 14300.00 42.018 133.457 10954.12 11044.12 5991.80 S 6210.61 E 2443942.20 N 206834.78 E 0.000 8629.78 24 May, 2002 - 9:41 Page 60f9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: RU#6 Leg 3 - Slot 4 . RU#6 WP02 Revised: 22 May, 2002 Cook Inlet Alaska Osprey Measured Sub-Sea Vertical Local Coordinates Global Coordinates Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin Section Comment (ft) (ft) (ft) (ft) (ft) (ft) ^"(ft) 14400.00 42,018 133.457 11028.41 11118.41 6037.84 8 6259,20 E 2443896,16 N 206883,37 E 0.000 8696.72 14500.00 42.018 133.457 11102.71 11192.71 6083.88 S 6307.79 E 2443850.12 hi 69611':96 E 0.000 8763.65 14600.00 42.018 133.457 11177.00 11267.00 6129.928 6356.38 E 244380408 N 980.55 E 0.000 8830.59 14700.00 42.018 133.457 11251.29 11341 .29 6175.96 8 6404 97 E 2443758,04 f.J 207029.14 E 0.000 8897.52 14800.00 42,018 133.457 11325.58 11415.58 6222.00 S 6453 56 E 244371200 N 207077.73 E 0.000 8964.46 - 14900.00 42.018 133.457 11399.88 11489.88 6268.04 8 502.14 E 244366596 N 207126.31 E 0.000 9031.39 15000.00 42.018 133.457 11474.17 11564.17 6314.08 S ""P¡Pv2443619.92 N 207174.90 E 0.000 9098.33 15100.00 42.018 133.457 11548.46 11638.46 6360.12 S E 2443573.88 N 207223.49 E 0.000 9165.26 15200.00 42.018 133.457 11622.76 11712.76 6406.168 66 . 1 E 2443527.84 N 207272.08 E 0.000 9232.20 15300.00 42.018 133.457 11697.05 11787.05 6696.50 E 2443481.80 N 207320.67 E 0.000 9299.13 15400.00 42,018 133.457 11771.34 1186 t,34. 6745.09 E 2443435.76 N 207369.26 E 0.000 9366.07 15438.57 42.018 133.457 11800.00 11890.00 6763.83 E 2443418.00 N 207388.00 E 0.000 9391.89 Target - RU#6 T2 Hemlock Geo Poly, Drillers Target 15439.00 42.018 133.457 .11800.32 11890,32 6516.20 S 6764.04 E 2443417.80 N 207388.21 E 0.000 9392.17 Begin 8-1/2" Hole 9 5/8" Casing Hemlock 15500.00 42,018 133.457 6544.28 8 6793.68 E 2443389.72 N 207417.85 E 0.000 9433.00 15600.00 42.018 133.457 6590.32 S 6842.26 E 2443343.68 N 207466.43 E 0.000 9499.94 15700.00 42.018 133.457 6636.36 S 6890.85 E 2443297.64 N 207515.02 E 0.000 9566.87 15800.00 42.018 133.457 6682.40 S 6939.44 E 2443251.60 N 207563.61 E 0.000 9633.81 15900.00 42.018 133.457 6728.44 S 6988.03 E 2443205.56 N 207612.20 E 0.000 9700.75 16000.00 42.018 133.457 6774.48 S 7036.62 E 2443159.52 N 207660.79 E 0.000 9767.68 16100.00 42.018 133.457 6820.52 S 7085.21 E 2443113.48 N 207709.38 E 0.000 9834.62 ~ 16200.00 42.018 133.457 12365.69 12455.69 6866.56 S 7133.80 E 2443067.44 N 207757.97 E 0.000 9901.55 16300.00 42.018 133.457 12439.98 12529.98 6912.60 8 7182.38 E 2443021.40 N 207806.55 E 0.000 9968.49 16400.00 42.018 133.457 12514.27 12604.27 6958.64 S 7230.97 E 2442975.36 N 207855.14 E 0.000 10035.42 16500.00 42.018 133.457 12588.56 12678.56 7004.68 8 7279.56 E 2442929.32 N 207903.73 E 0.000 10102.36 16600.00 42.018 133.457 12662.86 12752.86 7050.72 8 7328.15 E 2442883.28 N 207952.32 E 0.000 10169.29 16700.00 42.018 133.457 12737.15 12827.15 7096.76 8 7376.74 E 2442837.24 N 208000.91 E 0.000 10236.23 16800,00 42.018 133.457 12811.44 12901.44 7142.80 S 7425.33 E 2442791.20 N 208049.50 E 0.000 10303.16 16900.00 42.018 133.457 12885.74 12975.74 7188.848 7473.92 E 2442745.16 N 208098.09 E 0.000 10370.10 24 May, 2002 - 9:41 Page 70f9 Dri//Quest 2.00.09.006 Alaska Measured Depth (ft) 16946.12 42.018 Incl. Sub-Sea Depth (ft) 12920.00 Vertical Depth (ft) 13010.00 Sperry-Sun Drilling Services Proposal Report for Plan: RU#6 Leg 3 - Slot 4 - RU#6 WP02 Revised: 22 May, 2002 Local Coordinates Northings Eastings (ft) (ft) 7210.08 S 7496.33 E Global Coordinates Northings Eastings (ft) (ft) 2442723 Azim. 133.457 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to Grid N Vertical depths are relative to Well. Northings and Eastings are relative to Well. Coordinate System is NAD27 Alaska State Planes, Zone 4, US Foot. Grid Convergence at Surface is -1.45]0. Coordinate System is NAD27 Alaska State Planes, Zone 4, US Fool Magnetic Convergence al Surface is -21.992° (13-May-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azim 33,880' (Gnd). '-::::;:::::7~»;«$:::' , ~.'-".-"..' Based upon Minimum Curvature type calculations. at a Measured Depltl of 16946.12ft., The Bottom Hole Displacement is 10400.:J7ft. :1'1 Ibe lJi¡ù'::tb~ cf : 3:1.:385° (Grid). Comments Measured Depth (ft) 0.00 200.00 400.00 600.00 2122.27 3500.00 --15439.00 16946.12 24 May, 2002 - 9:41 Stati n Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 200.00 399.96 599.46 1996.92 0.00 N 0.00 N 0.61 N 0.57 S 385.14 S O.OOE 0.00 E 3.44W 16.86 W 293.62 E 3020.48 11890.32 13010.00 1019.45 S 6516.20 S 7210.08 S 963.04 E 6764.04 E 7496.33 E Comment Begin 18-112" Hole Begin Dìr @ 1.000°/1 OOft : 200.00ft MD, 200.00ft TVD Dir Rate Increase @ 2.000o/100ft: 400.00ftMD,399.96ftTVD Dir Rate Increase @ 3.0000/100ft: 600.00ftMD,599.46ftTVD End Dir, Start Sail @ 42.018° : 2122.27ftM D, 1996.92ftTVD Begin 12-1/4" Hole Begin 8-112" Hole Total Depth: 16946.12ftMD,13010.00ftTVD Page 80f9 Dogleg Rate (D/100ft) 0.000 10400.97 Vertical Section Cook Inlet Osprey Comment Total Depth: 16946.12ftMD, 1301 O.OOftTVD 7 5/8" Liner Target - RU#6 T3 TD West Foreland, Drillers Target '-.-" .~ DríllQuest 2.00.09.006 Alaska Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. 11800.32 0.000 Casing details Fr om Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> <Surface> <Surface> Targets associated with this we/lpath Target Name RU#6 T2 Hemlock Geo Poly RU#6 T3 TO West Foreland 24 May, 2002 - 9:41 Sperry-Sun Drilling Services Proposal Report for Plan: RU#6 Leg 3 - Slot 4 - RU#6 WP02 Revised: 22 May, 2002 Profile Penetration Point Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) 0.000 15439.00 11890.32 To Measured Vertical Depth Depth (ft) (ft) 3500.00 1 39.00 112 3020.48 ' 11890.32 13010.00 Northings (ft) Formation Name 11800.32 emlock Casing Detail 13 ' Casing 9 5/8" Casing 7 5/8" Liner Cook Inlet Osprey .~ Target Entry Coordinates TVD Northings Eastings Target Target (ft) (ft) (ft) Shape Type 11890.00 6516.00 S 6763.83 E Drillers Target Mean Sea Level/Global Coordinates: 11800.00 2443418.00 N 207388.00 E ,-" Geographical Coordinates: 60° 40' 41 .1996" N 151Q 37' 55.4941" W 13010.00 7210.08 S 7496.33 E Point Drillers Target Mean Sea Level/Global Coordinates: 12920.00 2442723.92 N 208120.50 E Geographical Coordinates: 60° 40' 34.5456" N 151° 37' 40.4477" W Page 9 of9 DrillQuest 2.00.09.006 All DIMENSIONS ARE APPROX. ) REDOUBT UNIT #6 WELLHEAD SCHEMATIC 80.68. i '1 3-1/8 5000 ~~- I~L Li ~3_1/8 5000 i i S ~t I .........., , ., I II i r~ T'r i ': t f: :b' I ! - ¡! ~. 2-1/16 5000 W/VR ~ ! i -;- ,~ :E::: ! 1 Lt=:E--~~ -~ ~I~-'~ ~ "t-U-~ ,( i ~! )(. 13-5/8 5000 68X - ~ I = t' 2-1/16 5000 W/VR -:- 1- t--;--, , :b -Œ-' -Ð--- , I.. ~I ~ ~~ ¡= I :~' i.! ' I I - I i I i i i I /i 3-1/2" OD ruBIN~ 18.63. ! 13-5/8 5000 6BX -- AUGNMENT PIN SHOWN 90' OUT OF POSIllON 28.00. 24.75" 19.50. ~ 36" 00 CASING ~ 13-3/8" OD CASING ~ 9-5/8" OD CASING ') Nabors Rig 429 13-5/8" 5000 psi BOP Stack Redoubt Unit #6 C 5000 psi Annular ) 5000 psi Blind Rams 5000 psi Pipe Rams 3" Kill Line Y<I><C Mud Cross=r><J><C 3" Choke Line 1 2 2 1 1 = HCR Valve 2 = Gate Valve 5000 psi Pipe Rams \ / 13 5/8" 5M r><c= Wellhead =r><J 13-3/8" Surface Casing 9-5/8" Intennediate ') ) BLOWOUT PREVENTION EQUIPMENT NABORS RIG No . 429 13-5/8" BOP Equipment 3 ea 13-5/8" x 5000 psi wp ram type preventers (Hydril) 1 ea 13-5/8" x 5000 psi wp annular preventer (Hydril) 1 ea 13-5/8" x 5000 psi wp drilling spool with 2 ea 4" side outlets (choke and kill), HCR and manual valves on both choke and kill lines. 1 ea BOP accumulator, Koomey Model T20000-3S blowout preventer control unit with 280 gallon volume tank, main energy provided by two 20 HP electric motor driven triplex plunger pump charging 16 each II-gallon bladder type separate accumulator bottles. Second energy charging system consists of two air pumps. Above two energy systems backed up by six each 220 cubic feet nitrogen bottles connected to the manifold system. All above system controlled by a Model SU2KB7S S series manifold with six manual control stations at the unit. .. . ') ) DRILLING FLUID SYSTEM DESCRIPTION Mud Pumps 2 ea IDECO T1600 (triplex, single acting pistons), 5000 psi fluid end discharge manifold system. Gear end equipped with electric driven lube oil pump, filtration. Pumps are driven by two each traction motors designed to stroke pumps at a maximum of 120 SPM under full load. Pumps are charged by two 40 HP, 1200 RPM Mission 5" x 6" centrifugal pumps. Mud Tank System (975 bbls Total Volume) " Tank #1 (de sander tank) appx. 170 bbls. Tank #2 (mud cleaner tank) appx. 145 bbls. Tank #3 (centrifuge tank) appx. 145 bbls. Tank #4 (suction tank) appx. 44 bbls. Tank #5 (pill tank) appx. 44 bbls. Tank #6 (volume tank) appx. 430 bbls. Trip Tank appx. 40 bbls. Located in the substructure. Mud System Equipment 3 ea 1 ea 1 ea 3 ea 2 ea 3 ea 1 ea 1 ea 1 ea Derrick dual tandem shale shakers Derrick 20 cone desilter Geosource sidewinder mud hopper Brandt 15 HP mud agitators. Brandt 5 HP mud agitators Mission Magnum pumps, 6" x 8" centrifugal with 100 HP motors Mission Magnum pump, 4" x 5" centrifugal with 25 HP motor DEMCO des ander, two 12" cones Brandt Model CF-2 centrifuge ) Redoubt Unit #6 Summary of Drilline Hazards POST THIS NOTICE IN THE DOGHOUSE -'-I All formations should be normally pressured, with the exception of the Jurassic. -'-I No shallow gas expected. -'-I Coals will be encountered throughout the Tyonek formation. Tripping speed and mud weight will help alleviate stuck pipe tendencies. -'-I Lost circulation is unlikely, however lost circulation potential increases when crossing faults. -'-I H2S has never been encountered in the Redoubt Unit Field. CONSULT THE WELL PLAN FOR ADDITIONAL INFORMATION .. CHECK 1 ST ANDARD LETTER DEVELOPMENT ( DEVELOPMENT REDRILL EXPLORA TION INJECTION WELL INJECTION WELL REDRILL Rev: 5/6/02 C\jody\templates ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ,~u.6./ t&¡:/ ¿; CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL "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. (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) 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 number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please nøte that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD L-J SPACING EXCEPTION Enclosed is the approved application for permit to drill the above. referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. ~~"0~\~\7!(Oso. \. '\") ~ê)-\ C>..0+~'\""¿~ \)\--:) <L'\~' (ê'!--c.(((ÇÀ-\~",- \Cè~~ ~~ ~ ~ Cé \ <è ~ -\-é)\ '<.~~ '-\ ð()\~\~ ~ ¡r -" 'fI"U¡Ù...,~..,~/¡'~n~""",-_- ~"ttm''!iz?;''''''\'''..""" ;..--""tifl11M';'"",,~\. ;,....';":':':!!'!!!,""'~"\""';~-,",it,,,,,,,;.;,,,,~,,'';'';';;~~iEiq'!E^\\.,,i.,~~~'i'"Y~\~:' . .""-"Zi1[Iill,..",-"-...;"'(J",,,>z.zz~';iii;=tJ!!-';mãll':~:--.-::.,,,~\,,,.,~..._--::.?tmUl!!~'""......i'7fi~yç:;"'-1f! I~ 1 2 8 9 I~ II FOREST Oil CORPORATION II ' PH. 907-258-8600 I,' 310 K 5T, 5TE, 700 I~ ANCHORAGE, AK 99501 89-6/ 1252 ¡~ 5/22/02 ~ I~,I 1 ~ ~I !~I I~i PAY .\,! TO THE ~.~I ORDER OF - ACf3CC ~i 1: 11 "'il -- One nl1T1(Jrro and , I~I DATE --_----.J $ 100.00 00/100-------------------- --------}:-:;/¡J~LLARS ~ 02.. l,.:¡~ ~ (!)OO First National Bank . of Anchorage , 'i Ii FOR Application for Permit to drill RO #6 Iii ,~; 11100 ¡. 2 a gill,: ¡. 2 5 2000 b 0 I: '., 1.~"!:.";.~l:O~~-_-~-,,:"~~,';I-':"~--_."';'1I"':-:7"..!JJ." -.-.._--rl~:."r..'!..'T'" .--." Y.E'::.-'~:'.C" .--.' :'o:.."t:':'-T. -. -.. --17""'.". " - - -..- . - - ''-.-:'" :""':'j' . - -, ".' "," - .. .' .".', - .. ~ .. I . , - . - .... .. . RECEIVED i') 'ì Ji('!\2. L :; ¿Uu Alasi<ft . ': ;ommission iLl ~,__;f þ':;: I:"~ Ir! I~I 'I j' -, M> I~ I ~1 ¡, -,I J - .;IJ dutl WELL PERMIT CHECKLIST COMPANY fl~ve..-S'¡- WELL NAME ¡;t¡.4 I:{ ~ FIELD & POOL 7"ZDI()O INITCLASS -~E'l/' 7ðll - ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ~. - N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. .. . . . . . . . . . . . . . . . N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N A. Àp . DATE.. 10. Operator has appropriate bond in force. . . . . . . . . . . . . N - 11. Permit can be issued without conservation order. . . . . . . . N :£: 30.D ~ 2. Permit can be issued without administrative approval.. . . . . N .-" 13. Can permit be approved before 15-day wait.. . . . . . . . . . N - " . / ,f L 14. ACMP Final Consistency Determination issued for this project Y N ~k-t ,Þ'K ¿ net ru::ru. "'TfIC 0201 - 0 I ~4 ~ 15. Conductor string provided. . . . . . . . . . . . . . . . . .. ~N 16. Surface casing protects all known USDWs. . . . . . . . . . . 17. CMT vol adequate to circulate on conductor & surf csg. . . . . . N 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ¡QD 19. CMT will cover all known productive horizons. . . . . . . . . . N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . Y N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . Y N Q'~\?\:\",-,'("'"\c.... ( t"."U ~~I;[' ~,~ 22. If a re-drill, has a 10-403 for abandonment been approved. . . Y N J ..:> ~~: ~~~:~~~~~I~~:~,~:c:~t~~~r~¿;~:1ï~~~:: ::: ::: :: y ~ ~\~~~~~~~,",~~"~--\\l:~ \~~~\Jit~"~~\Ck~CA,~~~\'~4~ 25. Drilling fluid program schematic & equip list adequate. . . . . N . "'~ ~~ ~~ ~ ~ C'\..s. 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N -.J 27. BOPE press rating appropriate; test to 3- c;on psig. Y N 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . Y N 29. Work will occur without operation shutdown. . . . . . . . . . . Y ~~- 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y \J::V /) 31. Permit can be issued w/o hydrogen sulfide measures. . . . . ~ ~ ~ ~ no;' /.ß ~ ~.' , . {~, ~ 't' ,,~u ~ . 32. Data presented on potential overpressure zones. . . . . . . /C ~~ ~v..L~ t<.X:..Æ ~">7 n1t"vt- ~ 51-n.>~,¡- 33. Seismic analysis of shallow gas zones. . . . . . . . : : : :.~ Æ Y N - '-,£]'; {' L.~ ~ ( u" ~)1-YJ. D~~: ~~~~:~ ~~~~~~o~~~~i ~:~~;~~~~~s~ ;ep~rt~ [e~~ry only] ~ ~ /ÆJ ~ -~. ß- ANNULAR DISPOSAL 36. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage formation or impair recovery from a pool; & Y N (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ENGINEERING APPR DATE !fi!trv\ 'Y;r"tJ) GEOLOGY APPR DATE Y N Y N GEOLOGY: ENGI~~I~G: UIC/Annular: TEM jdf!fY ,-, I? JBR ~ ~ WGA COMMISSION: ~~~~()ì/D4°~ RPC- SFD# G: \geology\perm its \checklist.doc PROGRAM: Exp - Dev ~ Redrll - Serv - Well bore seg - Ann. disposal para req - GEOL AREA [37 D UNIT# 01/81Z) ON/OFF SHORErW' ~tÁ-6/~~ ¡:"<M' / iA:J ~ ~ ) d\\\\\~~~\x ~ \<.~\> \ ~\<J-S<> ~ ~'~\\A2e \ \ Commentsllnstructions: