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Home My WebLink About196-060Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned ianna Vincent Nathan Lowell Date:3,/~, ~ Is, ~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl oN OR BEFO W Memorandum State of Alaska Re: Oil ~nd Gas Conservation Commission Cancelled or Expired Permit Action EXAMPLE' Point McIntyre P2-36AXX API# 029-22801-95 This memo will remain at the front of the subject well f'de. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies i the treatment of these kinds of applications for permit to ddil. 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 remair unchangeci. The APl number and in some instances the well name reflect the number of preexistin! reddlls and or muitilaterais in a weti. 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 ddll. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 9~. The well name for a cancelled or expired permit is modified with an appended >o(. These procedures are an addendum to the AP! numbenng methods descnbed in AOGCC staff memorandum "Multi-lateral (weiibore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. e McMains ' ( Statistical Technician STATE OF ALASF~A ALASKA OIL AND GAS CONSERVATION COM/RISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE APPLICATION OF STEWART PETROLEUM COMPANY for an order granting an exception to spacing requirements of Title20 AAC 25.055 to provide for the drilling of the West McArthur River Unit No. I-1 enhanced oil recovery water injection well. Conservation Order No. 393 Stewart Petroleum Company West McArthur River Unit No. I-1 April 10, 1997 IT APPEARING THAT: 1. Stewart Petroleum Company submitted an application dated March 10, 1997 requesting exception to 20 AAC 25.055(a) (3) to allow drilling the West McArthur River Unit I-1 enhanced oil recovery service well to a location that is closer than 500 feet to a drilling unit boundary. 2. Notice of opportunity for public hearing was published in the Anchorage Daily News on March 21, 1997 pursuant to 20 AAC 25.540. 3. A petition was recieved from an interested party with concerns related to the proposed enhanced oil recovery operations at West McArthur River Unit. No substantive protests were recieved from an affected owner who may be harmed if the requested spacing exception is issued. FINDINGS: 1. The Stewart Petroleum Company West McArthur River Unit I-1 well as proposed will be a deviated hole drilled from a surface location 1953' from the west line (FWL) and 3233' from the north line (FNL) of Section 16, T8N, R14W, Seward Meridian (SM), the proposed top of the injection interval is 2400' FWL and 600' FNL of Section 15, T8N, R14W, SM and the proposed bottom hole location is 2765' FWL and 328' FNL of Section 15, T8N, R14W, SM. Conservation Order No. April 10, 1997 Page 2 2 Offset owner Union Oil Company of California has been duly notified. 3. An exception to 20 AAC 25.055(a) (3) is necessary to allow drilling of this well. CONCLUSION: Granting a spacing exception to allow drilling of the Stewart Petroleum Company West McArthur River Unit I-1 well as proposed will not result in waste nor jeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED: Stewart Petroleum Company's application for exception to 20 AAC 25.055 for the purpose of drilling the West McArthur River Unit I-1 well is approved as proposed. DONE at Anchorage, Alaska and David W. JohnstOn Ai~ Oil and Gas ~onservati( ission Mary Mars~n~ Commissioner Alaska Oil an~Gas Conservation Commission A.S 31.05.080 provides that within 20 days after receipt of written notice of the entQ' of an order, a person affected by it mav file with the Commission an application Ibr rehearing. A request for rehearing must be received bv 4:30 PM on the 23rd day Ibllowing the date of the order, or next working da), if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application bv not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or othenvise distributes) an order upon rehearing, both being the final order of the Commission. to appeal the decision to Superior Court. Where a request tbr rehearing is denied by nonaction of the Commission. the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e.. 10th day after the application/~br rehearing was filed). TONY KNOWLE$, GOVEI~NOR ~KA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 22. 1997 Paul D. White Operations 'Manager Stewart Petroleum Company 4700 Business Park Blvd., Suite 13 Anchorage, AK 99503 Re: West McArthur River Unit No. I- 1 Rev. Stewart Petroleum Company Permit No. 96-60 Sur Loc 1953'FWL and 2047'FSL. Sec. 16, T8N, R14W, SM Btmhole Loc 2765'FWL and 328'FNL, Sec. 15, T8N, R14W, SM Dear Mr. White: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated April 19, 1996 are in effect for this revision. · ~hyairomaRl~ER OF~ 'fiSSION dlf/Enclosures CC; Department of Fish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Ddll ] Redrill X Reoentr7 _- Deepen -_ 2. Name of Operator Stewart Petroleum Company 3. Address 4700 Business Park Blvd., Suite 13 Anchorage. Ak 99503 4. Location of well at surface 1953' FWL and 2047' FSL Sec. 16, TSN, R14W, SM At top of productive interval 2400' FWL and 600' FNL Sec. 15, T8N, R14W, SM At total depth 2765' FWL and 328' FNL Sec. 15, T8N, R14W, SM I lb. Type of well Exploratory ] Stratigraphic Test _- Development Oil Z Multiple Zone ] 10. Field and Pool Service X Development Gas ] Single Zone X 5. Datum Elevation (DF or KB) 130' RKB 6. Property Designation ADL-359111 (BHL) 7. Unit or Property Name West McArthur River Unit 8. Well Number No. i-1 9. Approximate spud date 5/1/97 14. Number of acres in property Lease 4175 acres Unit 6330 acres 12. Distance to nearest 13. Distance to nearest well property line 888' (~ surf 2515' @ BHL t938' @ top (WMRU#2A) 16. To be completed for deviated wells Kickoff depth 7000 feet Maximum hole angle 60° W. McArthur River Field W. McArthur River Pool 11. Type Bond (see 20AAC25.025) Blanket Number 1278657 Amount $200,000 15 Proposed depth (MD and TVD) 12,843' MD 9,910' TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2) Maximum Surface 1594 psig. At total depth (TVD) 4329 psig 18. Casing program size Hole I Casing " 5-1/2" Weight 29.7 17 Specifications I G,rade} Coupling i L-8O I STL IL-80 I FL-4S Length MD Setting Depth Top Bottom MD TVD 6346' 9277' TVD Quantity of cement 5085' 6795' 11880' 9378' 115 cuff Class G blend 1163' 11680' 12843' 9830' 130 cuff Class G blend 19. To be completed for Reddll, Re-entry and Deepen Operations Present well condition summary Total depth: measured 11,948 feet true vedcal 11,019 feet Effective Depth measured 362 feet true vertical 362 feet Casing Length Structural Conductor 655' Surface 2001' Intermediate 9083' Production Liner 3098' Perforation Depth: measured true vertical Plugs (measured) Size Cemented Junk (measured) 20" 1432 cuff G blend 13-3/8" 1967 cuff G blend 9-5/8" 2450 cuff G blend 410' DC Retainer 1910' DC Retainer 10,555' HDC Retainer 11,200' Bridgeplug 9083' 8438' ~' ~'.~-,:.~.;"." :;~,~, 11019' '"*~/bo 5-1/2" 805 cuff BG blend 11948' 10,600' - 10,670' and 11,340' - 11,385' 9,809' - 9,871' and 10,469' - 10,509' 20. Attachments Drillir~ fluid program X Time vs depth plot X Refraction analysis - Seabed report - 21. I h~re"l~y certify th, at the,foregoing is true and correct to the best of my knowledge Signe , _ _ Title: Operations Manager, Stewart Petroleum Commission Use Only Filing fee ~ Property Plat X BOP Sketch X Diverter Sketch Z Drilling Program X 20 AAC 25.050 requirements X Permit Number | APl Number I Approval date ! - o /I Conditions of approval Sample required - Yes X No Mud log required - Yes ~No Hydrogen Sulfide measures ' Yes ~'No Directional Survey required ",~'Yes - No Required working pressure for BOPE _- 2M _- 3M ~.5M _-- 10M ~_ 15M Other: by order of Approved.by 0ri~lRat Signe0 By Commissioner the commission Form 10-401 Rev. 12-1-85 David W. Johnston See cover letter for other requirements Submit in triplicate ORIGINAL WMRU #I-1 Proposed Sidetrack 20" 79.6# @ 655' MD ~ [~ 13-3t8" 54.5# @ 2001' MD ~.. .~ Cmted w/1710 sx Top of 7-5/8" liner @ 6795' MD/6346' TVD i [ of Sidetrack Window 6995' MD/6531' TVD / Top Cement Plug: 8600'-8900' [ ........................ [ 9-5/8" 40 & 43.5# @ 9083' MD ~ Cmtd w/2130 sx HDC Ret @ 10,555' MD w/50 sx DST Perfs. 10,600-10,670' BP @ 11,200' MD w/50 sx DST Perfs. 11,340'-11,385' 7" @ 11948' MD 11019' TVD 5-1/2" liner top @ 11880' MD/9378' TVD 7-5/8" liner @ 11880' MD/9378' TVD Cmtd wi115 cuft cmt 5-1/2" liner @ 12843' MD/9910' TVD Cmtd w/130 cuft cmt -~ ' BONr" ,, ~- ~ - ..... ~ PGHAL~M S~,20~.000 DUPLICATE ORIGINAL .~ ALASKA . ..................... ANCHORAGE :-~- ....... ...__,.,. , $~t~ ,.,-..-.- .... "-- ' . The City ~f,..-------"--'------ =~, ~.,,~s~ .s_~_j%~~~--~~-- ........ ' ....... ~--- ................ ~._---c3~.,i~-~,9, · · Su~fw W~J~ ~ T~.. Fin2. m~d Met. ~ A~gra,'ec~: West McArthur River Unit Property Plat TSN, R14W, Seward Meridian ICook Inlet Bluff Sec. 8 Surface ~ Locations ~ WMRU #lA, 2A, 3 1 Sec. 17 ADL 359111 Stewart Pet. Co. Sec. 9 1953' Sec, 16 Sec. 21 i WMRU #3 ! , WMRU#1A ~ ~ . ~ WMRU#2A Sec. 10 b 2400' ~~ Sec. 15 / WMRU #I-1 / Proposed WFU #2 Surface Location WMRU #I-1 i Sec. 22 ADL 359112 Stewart Pet. Co. Scale 1" = 1/2 mile West McArthur River Unit Unit Boundary Plat T8N, R14W, Seward Meridian W. McArthur River Unit ADL 17602 Stewart Pet. Co. Unocal ADL 3591 1 1 I I I 4 3 2 1 8 k 9 10 11 2 , WMRU #I- 1 Proposed BHL 17 15 14 3 I , :, W. McArthur River Unit ~~ Stewart Pet. Co. k ADL 359112 20 21~ 23 24 29 28 26 25 32 33 35 36 _ . , , . . . . . . 10. 11. 12. 13. McArthur River Unit #1-1 Sidetrack Drilling Program Move and rig up Nabors Rig #160. ND tree, NU 3000 psi BOPE. Drill out cement plugs and retainers at 410' and 1910'. Clean out 9-5/8" casing to 7200'. Pressure test integrity of existing casing. Set whipstock and mill out window in 9-5/8" casing at 6995' MD. Directionally ddll 8-1/2" hole to 7-5/8" liner casing point @ 11,880' MD. Run and cement 7-5/8~ liner. (no logs at this point, cased hole GR will be run later) Drill out 7-5/8"liner and 10' of new formation. Run formation integrity test. Drill 6-3/4" hole to TD @ 12,843' MD/9910' 'I'VD. Run and cement 5-1/2' liner. Run cased hole logs: GR/CET/CBT in 5-1/2" liner. Continue running GR log up to top of 7-5/8" liner. Perforate and run tubing completion for injection. Perform MIT on casing x tubing annulus with AOGCC representative prior to injection. 1 2/23/97 West McArthur River Unit #I-1 Pressure Information The following presents data used for calculation of anticipated surface presures (ASP) during drilling of the West McArthur River Unit #1-1. The pore pressure gradient was estimated using a salt water gradient. This gradient is conservative when considering the most recent bottom hole pressure surveys at West McArthur River Unit*. The fracture gradient information was obtained from formation integrity tests below casing points on the West McArthur River Unit # 1, #2A and #3. WMRU #lA, P=3781 psi @ 9563' TVD (7.6 ppg EMW) from initial static BHP survey on 12/30/95. WMRU #1, P= 3442 psi @ 9563' TVD (6.9 ppg EMW) from static BHP survey pdor to reddll on 10/17/95. WMRU #3, P = 3680 psi @ 9563' TVD (7.4 ppg EMW) from initial static BHP survey on 7/2/95. Casing Pore Casing Setting Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressure Drilling (in.) (TVD fi) ('lbsLqal) (Ibs/.qal) (psi) (psi) 9-5/8 6531 15.0 8.4 2583 1508 7-5/8 9378 14.5 8.4 4096 1594 5-1/2 9910 8.4 4329 Procedure for Calculating Anticipated Surface Pressure ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with one-half evacuation (one-half gas gradient of 0.115 psi/ft and one-half mud gradient of 8.4 ppg), or 2) formation pore pressure at the next casing point less one-half gas gradient and one-half mud gradinet to the surface as follows: 1) ASP = (FGx.052xD) - (0.115x. SxD) - (.437x.5xD) 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 0.115 = gas gradient in psi/ft 0.437 = mud gradient (8.4 ppg) D = true vertical Depth of casing seat in ft RKB OR 2) ASP = FPP - (0.115xDx. 5) - (0.437x. SxD) where: FPP = Formation Pore Pressure at the next casing point which is tied back to surface or at TD (total depth) West McArthur River Unit Well/ti-1 Pressure Information ASP Calculations Ddlling below whipstock in the intermediate casing (9-5/8") ASP = (FGx. 052xD) - (0.115x. SxD) - (.437x0.5xD) =(15.0x.052x6531) - (0.115x. Sx6531) - (.437x. Sx6531) = 3292 psi OR ASP = FPP - (0.115x. SxD) - (.437x. SxD) = 4096 - (0.115x. Sx9378) - (.437x.5x9378) = 1508 psi Drilling below liner (7-5/8") ASP = (FGx.052xD) - (0.115x. SxD) - (.437x. SxD) - (14.5x.052x9378) - (0.115x.5x9378) - (.437x. Sx9378) = 4483 psi OR ASP = FPP - (0.115x.5xD) - (.437x. SxD) - 4329 - (0.115x.5x9910) - (.437x. Sx9910) = 1594 psi , Blowout Prevention Equipment Nabors Rig No. 160 13-5t8" BOP Equipment 2 ea iea Iea 13-518" x 5000 psi wp ram type preventers (Hydrii) 13-5i8" x 5000 psi wp annular preventer (Hydril) 13-5i8" x 5000 psi wp ddlling spool with 2 ea 4" side outlets (choke and kill), HCR and manual-valves on both choke and kill lines. 1 ea 1 ea 1 ea BOP accumulator, Vaivcon, 300 psi w/t2 bottles, 180 gallons, and (1) 80 gallon Vatvcon accumulator. Accumulator pump, Gardner-Denver Triplex, Model PQ 172, air pump Model G7E. 8 bottles nitrogen backup. Valvcon, 6 station, remote control panel Thomhill Craver, automatic choke 3" - 10,000 psi with control choke panel 1 lot Hydraulic pipe and fittings from manifold to BOP stack. Nabors Rig #160 13-5/8" 3000 psi BOP Stack Annular Preventer i I 5000 psi Blind Rams I ! 5000 psi Pipe Rams 3-1/8' Kill Line~ 1 = HCR Valve 2 = Gate Valve Drilling Spool 13-5/8"x 11" / 11" 5M Wellhead 9-5/8" Casing 4-1/16' Choke Line Drilling Fluid System Description Nabors Rig No. 160 Mud Pumps 2 ea Continental Emsco F-1300 tdplex mud pumps 7" x 12", 1300 HP with (2) C-E pulsation dampeners, Model M822, each pump equipped with (2) 752 GE traction motors, cooled with ambient air. Each pump charged by a 5 x 6 Mission Magnum I with 50 HP AC motor. Mud Tank System (1035 Total Volume) Tank #1 (shaker tank) appx. 270 bbls. Three compartments which include desander, desiiter suction compartment and cuffing trap compartment equipped with shale shakers, degasser, poor boy degasser, and mud guns in top skidded section. Tank #2 (volume tank) appx. 460 bbls. One compartment equipped with desander, desilter, mud cleaner, mud guns and mud agitators in top skidded section. Tank #3 (suction tank) appx. 305 bbls. Three compartments, two of which are pill pits, 1 thru 65 bbls; one 55 bbl equipped with mud guns, mud agitators, mud mixing hopper, and chemical barrel in top skidded section. Mud System Equipment 1 ea Iea 1 ea 1 ea 4 ea 4 ea 1 ea 6 ea Derdck dual tandem shale shaker Ddlco degasser Picenco 16 cone desiiter Pioneer sidewinder mud mixer Brandt 7-1/2 HP mud agitators Mission Magnum pumps, 5' x 6' centrifugal with 50 HP GE Electdc Motors Pioneer desander, 2 cone, Model S-2-12 Dahiory 3" mud guns McArthur River Unit #1-1 Redrill Drilling Fluid Program Ddlling Liner Hole Section 6995'-11880' MD or 6531'-9378' TVD Hole size = 8-1/2" Casing Size = 7-5/8" Mud type = PHPA polymer Mud Parameters: Weight: 9.1-9.6 ppg Viscosity: 42-50 sec/qt pH: 8.0-9.0 PV: 10-20 YP: 12-25 Fluid Loss: <6 cc/30 min After setting the whipstock, mill out the 9-5/8" casing with a high yield point, non- dispersed bentonite mud sustem. After cleaning out the metal cuttings and drilling beyond any cement behind the 9-5/8' casing and into new formation, build a PHPA polymer system. Avoid drilling cement with the new PHPA system. Clean the remaining pits and fill with fresh water. Treat the fresh water with Soda Ash as required for hardness. Add 10-12 ppb bentonite and allow to properly hydrate. Add 0.75 ppb PHPA and do not add barite at this time. Continue PHPA additions until the complete system is treated with 0.75 ppb PHPA. Add sufficient polymer (0.5 ppb) until the Clapper Polymer test on the whole mud yields 0.4-0.6 ppb of available polymer. Because of potential cuttings bed problems, 10 minute gel stegths should be at 1'5-22 and 30 minute gels should be 25-30 which will indicate non-progressive gel structure. There may be siginificant viscosity increases as the polymer reacts initially with the native solids but additions should continue until you are over the "hump". Slight additions of Desco or Ligco will reduce the viscosity somewhat. Inspect the drill cuttings to help determine the proper polymer concentration. Sticky or visibly hydrated cuttings indicate Iow polymer concentration. The Clapper Polymer Test is the most accurate method to determine proper polymer concentration and should be run at least every 2 days. West McArthur River Unit ,~ ell #I-1 Sidetrack Drilling Fluid Program If more viscosity is desired to clean the hole, Biozan can supplement the system. Utilize Iow viscosity-high viscosity sweeps to reduce cuttings bed formation. To reduce fluid loss, add starch at 3-4 ppb while adding PAC polymer at 1-1.5 ppb. This will assist the bentonite and native clays in suspending solids when not circulating. Monitor the HTHP filtration for an indication of cake formation and compressibility. Adding an acrylamide and alkali salt will help stabilize the APl filtrate and improve the HTHP values to less than 12 cc/30 min. Supplementing the PHPA polymer with a 4 ppb blend of Bore-Plate will provide maximum shale stabilization especially as the Cook Inlet coal intervals are encountered. To smooth out rheological properties, add a Iow moecular weight polyacrylate thinner works which will not disperse the solids. Mud weights should be kept low by running all solids control equipment to their maximum efficiency. Run a minimum of 200 mesh screens on the mud cleaners to give maximum cut. A iow gravity solids of less than 7% is required for optimum performance of this system. Dilution or complete displacement should be considered if higher LGS contents persist. West McArthur River Unit ,, ell #I- 1 Sidetrack Drilling Fluid Program Production Liner Hole Section 11,880'-12,843' MD or 9378'-9910' TVD Hole size = 6-3/4" Casing Size = 5-1/2" Mud type - PHPA polymer Mud Parameters: Weight: 9.4-9.6 ppg Viscosity: 42-50 sec/qt pH: 8.0-9.0 PV: 10-20 YP: 12-25 Fluid Loss: <6 cc/30 min Bump the plug on the 7-5/8' liner with the PHPA mud treated with Bicarb to offset cement contamination. The fluid system will already be established from the previous hole section. Eliminate the PAC polymer for filtration control and use starch and acrylamide/alkali salt. This will also enhance the lubricity of the fluid along with a glycol lubricant. After drilling out the cement, have the PHPA concentration at .6-.75 ppb and Bore-plate at 4.0 ppg. The APl filtrate should be less than 6.0 cc. The glycol lubricant should be kept at 3% to provide lubricity for the high angle wellbore. Maintain rheoiogicai properties on the high side to prevent particle settlement and pump regular high viscosity/Iow viscosity sweeps. Keep the mud weight as Iow as possible because unnecessary solids have detrimental effects on the polymers. Anadri]l Schlumberger Alaska District llll East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for STEWART PETROLEUM COMPANY Well ......... ~ ~MRU {l-1 (P6) Field ........ z Wes~ McArthur River Unit Computation..~ Minimum Curvature Units ........ , FEET Surface Lat..: 60.78249688 N Surface Long. z 151.74669450 W Legal Description Surface ...... : 2047 FSL 3327 FEL S16 T08N R14W SM Tie-in surveyz 2291 FSL 1065 FEL S16 TOSN R14W SM Target ....... : 4680 FSL 2880 FEL S15 T08N R14W SM BHL .......... ~ 4951 FSL 2514 FEL S15 T08N R14W SM LOCATIONS - ALASKA Zone~ 4 X-Coord Y-Coord 187857.34 2482093.96 190124.56 2482268.18 193648.16 2484575.21 194020.34 2484836.06 PROPOSED WELL PROFILE Prepared ..... : 08 Feb 1997 Vert sect az.: 53.45 KB elevation.: 130.00 ft Magnetic Dcln: 40.000 (E) Scale Factor.: 1. 00001087 Convergence..: -1.524.__/8]{~ADRILL APPROVED FOR PERMITIING ONLY PLAN#,,, - II ' ' ~' 7 AKA-DPC mmmmmmmmmmmmmmmmmmmm mmmmmmmm mmmmm! STATION MEASURED INCLN IDENTIFICATION DEPT~ ANGLE Tie-in 6960.00 22.55 TOP OF WINDOW 6995.00 22.73 KOP / CURVE 2.5/100 7000.00 22.75 7100.00 24.89 7200.00 27.08 DIRECTION 77.00 77.00 77.00 7~.78 71.04 mmmmmmmmmmmmmmmmm mmmmmmm! VERTICAL-DEPTHS SECTION TVD SUB-SEA DEPART 6498.38 6368.38 1956.57 6530.69 6400.69 1968.92 6535.30 6405.30 1970.69 6626.78 6496.78 2008.15 6716.67 6586.6? 2049.58 mmmmmmmmmmmmmmmmmmmmm COORDINATES-FROM WELLHEAD 234.47 N .2261.76 E 237.50 N 2274.88 E 237.94 N 2276.77 E 248.17 N 2315.82 E 261.44 N 2357.55 E mmmmmmmmmmemmm#mmmmm mmmm mmme ALASKA Zone 4 TOOL DL/ X Y FACE 100 190124.56 2482268,18 ~S <TIE 190137.76 2482270.86 HS 0.50 190139.66 2482271.24 33L 0.50 190178.96 2482280.43 30L 2.50 190221.04 2482292.59 27L 2.50 7300.00 29.32 7400.00 31.59 7500.00 33.90 7600.00 36.23 7700.00 38.57 68.69 6804.80 6674.80 2094.91 277.74 N 2401.89 E 66.64 6891.00 6761.00 2144.04 297.03 N 2448.76 E 64.85 6975.10 6845.10 2196.89 319.27 N 2498.06 E 63.26 7056.95 6926.95 2253.35 344.42 N 2549.70 E 61.84 7136.39 7006.39 2313.32 372.44 N 2603.58 E 190265.80 2482307.70 25L 2.50 190313.16 2482325.73 24L 2.50 190363.03 2482346.65 22L 2.50 190415.32 2482~70.42 2IL 2.50 190469.93 2482397.00 20L 2.50 7800.00 40.93 60.55 9213.26 7083.26 2376.68 403.26 N 2659.60 E 190526.75 2482426.32 lgL 2.50 (Anadrlll {c)97 WI~I1P6 3.0C 11:21 AM P) Wi'4PU # ! I , P~. ~ 08 Feb 199'1 1' age Z mmmmmmmmmmmmmmmmmmmm STAT I ON IDENTIFICATION END CURVE 2.5/100 TARGET mmmmmmmm mmmmmm MEASURED INCLN DEPTH ANGLE mmmmmmmm mmmmmm 7900.00 43.31 8000.00 45.69 BlO0.O0 48.09 8200.00 50.49 8300.00 52.90 8400.00 55.31 8500.00 57.73 8578.78 59.64 12280.87 59.64 12300.00 59.26 12400.00 57.26 12500.00 55.26 12600.00 53.26 12700.00 51.26 12800.00 49.26 TD 12843.44 48.39 PROPOSED WELL PROFILE mmmmmmmmm mmmmmmmmmmmmmmmmm DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA mmmlmmmmm mmmmmmmm mmmmlmmm 59.39 7287.43 7157.43 58.32 7358.75 7228.75 57.33 7427.09 7297.09 56.42 7492.31 7362.31 55.57 7554.29 7424.29 54.77 7612.91 7482.91 54.01 7668.07 7538.07 53.45 7709.01 7579.01 53.45 9580.00 9450.00 53.45 9589.72 9459.72 53.45 9642.33 9512.33 53.45 9697.86 '9567.86 53.45 9756.27 9626.27 53.45 9817.48 9687.48 53.45 9881.40 9751.40 mmmmmmmm SECTION DEPART m~mm~mm~ 2443.31 2513.09 2585.87 2661.53 2739.92 2820.89 2904.28 2971.58 6166.09 6182.56 6267.60 6350.75 6431.92 6510.99 6587.89 mmmmmmmmmmmmmmmmmmmmm COORDINATES-FROM WELLHEAD 436.84 N 2717.65 E 473.10 N 2777.62 E 511.98 N 2839.40 E 553.41 N 2902.88 E 597.30 N 2967.92 E 643.57 N 3034.40 E 692.14 N 3102.21 E 731.96 N 3156.47 E 2634.42 N 5722.70 E 2644.23 N 5735.93 E 2694.87 N 5804.24 E 2744.39 N 5871.04 E 2792.73 N 5936.24 E 2839.82 N 5999.77 E 2885.61 N 6061.54 E 53.45 9910.00 978.0.00 6620.58 2905.09' N 6087.80 E mmmmmmmmmmmmmmmmmmmm mmmm mmmm ALASKA Zone 4 TOOL DL/ X Y FACE 100 mmmmmmmmm mm 190585.68 2482458.34 18L 2.50 190646.59 248249].00 lTL 2.50 190709.39 2482530.22 16L 2.50 190773.94 2482569.94 16L 2.50 190840.13 2482612.09 15L 2.50 190907.82 2482656.58 15L 2.50 190976.89 2482703.33 14L 2.50 191032.19 2482741.68 HS 2.50 193648.15 2484575.20 LS 0.00 193661.64 2484584.66 LS 2.00 193731.28 2484633.47 LS 2.00 193799.38 2484681.19 LS 2.00 193865.84 2484727.78 LS 2.00 193930.60 2484773.17 LS 2.00 193993.56 2484817.30 LS 2.00 194020.34 2484836.06 2.00 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN # (An&drill (c}97 ~RIXP6 3.0C 11:21 AN P) m aon'ljf~claO uOt. :l~aS ~oo8 0§28 OOc. L OcjL9 0009 O§ag OOC~l' OGLE 00~ 0~'~ 00§I OC~L 0 O§L- 00~ - .-OC~t[ ! ,kNYdHO3 HI]3qOk:l.L3d ik:lYMZlj. S '! STEWART PETROLEUM COMPANY Narker ldentlt:[aL:on MD BKB SECTN INCLN Al lie-~n 6960 6498 1957 22.55 BI lOP OF NINDO~ 6995 653! lg6g 22.73 C} KOP / cUnVE 2.5/100 7000 6535 1971 22.75 D) ENO CURVE 2.5/100 8579 7709 2972 59.64 El TAgGEI 12281 9580 6166 59.64 FI TD t2843 9910 662l 48.39 WMRU #I-1 (P6) VERTICAL SECTION VIEW Section at: 53.45 TVD Scale.' I inch = 800 feet Dep Scale.' 1 inch = 800 feet Drawn · OB Feb 1997 BO0 1200 1600 2000 2~100 2800 3200 3600 4000 4~I00 ~IBO0 5200 5600 6000 6,100 6800 7200 7600 8000 Sect ion Departure Anndr'% ! 1 .S:I~ lumb~.'rqo, r STEWART PETROLEUM COMPANY WMRU PLAN VIEW CLOSURE · 6745 feet at Azimuth 64.49 DECLINATION.' +0.000 lEi SCALE · I inch = BOO feet ]RAWN ' 08 Feb 1997 i I I Ill I I I I I I I I I I I Marker Identification MD N/S E/W A) Tie-in 6960 234 N 2262 E B) fOP OF WINDOW 6995 238 N 2275 E £) KOP / CURVE 2.5/100 7000 236 N 2277 E D} END CURVE 2.5/100 8579 732 N 3156 E E) TARGET 12281 2634 N 5723 E F) TD 12643 2905 N 6066 E ............... Al SADRIL ..................... Al(', k=DI=~ ............................................ ~.~ (P6'T61~! ........... APP IOVI:D I VI~ i ~l~lfll I I II~J ONLY , , , . ,, ,, , , .. ,. , , . , . ~ ' , ....... , ,, ....... ,, ~ ......... I_ ,,, ~..... - - , , , - ~ , ,, , , ,, [~ ., ....... ,,, 400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 <- WEST' EAS! -> ii i i ii i iii i i ! ii i i i i i i i i i ii i iii i i WFU #2 P &A 9114~66 2(:7' 79.6# ¢__. 655' MD ~ 13-3/8' 54.5~ ~ 2001' MD ~1 Cmted w/1710 sx 9-5/8' 40 & 43.5~ @ 9083' MD Cmtd w/2130 sx Calc TOC at 362' DC Retainer @ 410' w/100 sx Calc TOC @ 1886' DC Retainer (i~ 1910' wi50 sx Cement Plug: 8600'~' 7" liner top @ 8850' - ~ Hole in liner at 10,298'sqzed w/200 sx HDC Ret @ 10,555' MD wi50 sx DST Perfs. 10,600-10,670' BP @ 11,200' MD wi50 sx DST Perfs. 11,340'-11,385' 7' @ 11,948' MD 11,019' ']'VD RKB = 130' above sea level RKB = 17' above Ground Level Ave Hole Angle = 25 degrees STATE OF ALASKA tSe, oc~er revere IIdE)' OIL AND GAS CQNSERVA~ON COM~AISSIQN ~ ~E OF CO~PL~O~: 2~ ~e~c~ Petrolem Co~oration 3. ~DUS3 O~ .... B~ 779 Ancho~ge, Alaska 99501 ADL- 01804 WELL COMPLETION OR RECOMPLSTi©N REPORT AND LOG* .... ~. U.~IT 4Oa~E~.~T T;est Fo~l=d At 2~7' ~L, 1953' FI~, Sec. lS, TSN, ~41'[, S.i-[. AC ~p pr~ lnte~ ~tt~ ~low · c to~ d.o~2209~ ~, 835~ ~'IL, Sec. 15, TgN, R14U, S.H. u I2. BOROUGH . J 13. STARS Ken~i J Alaska IES, D£pmeter, Sonic, Dens£%7, ~-~, · · (:ASINO SLZIS WRIOHT. LL/FT. 20" 79.6 13-3/8" 9-5/8" 40 & 43.5 ~00~ ~083 29. . LINER RECORD 711 8850 :u. 38 25" 17-? ?00 ~~385, 1060~10670, re~ 1080~ 10670, re~ 1061~10660, ~ with A~i-jet T" cnsing at 10~650 with ~ s~d. ~710 sx w/ CaC1 . . ' 30. TU~n~G Rffd~ ur ~N~ & ~ I I 32. ACID. SHOT FRACTUR~ CEMENT SQUEEZE. ETC. DEFT]~ 'I.NTERY&L (MD) 10248 - 10298 .... 10610 - 10660 AIJO~NT AMD KIND OF MATZIIAr- USED '200 s.r,. cement squeeze L 5o 15¢ aci'd s:c~n ~ . ~..~ ::T:Z /~ea Su~e~ntender. t= o~r~ lO/lO/S6 *(See Instructions and Spaces for Additional Data on R~,,'se Side) West McArthur River Unit #1-1 Redrill Cementing Program 7-5/8~ Ddllin.q Liner 8-1/2~ hole @ 11,880' MD, top of liner at 6795' MD Cement volume for liner based on 1000' of fill-up above shoe: 1000' x 0.077 cuft/ft (8-1/2" x 7-5/8") x 1.50 excess = 115 cuff Cement = 15.8 ppg Class G 5-1/2" Ddllin,q Liner 6-3/4" hole @ 12,843' MD, top of liner at 11,680' MD Cement volume for liner based on caliper hole volume plus 25%, liner lap, and shoe joints. Estimated volume is: 963' (12,843' - 11,880') x 0.0835 cuft/ft (6-3/4' x 5-1/2") x 1.25 = 100 cuff 200' liner lap @ 0.0928 cuft/ft x 200' = 20 cuff 80' shoe jts x 0.1305 cuft/ff (5-1/2" liner capacity) = 10 cuff 100 + 20 +10 = 130 cuff Class G cement @ 15.8 ppg West McArthur River Unit #1-1 Redrill Casing Design 9-5~8" Intermediate Casing, L-80, BT&C (Already in place in WFU #2) Burst = (9910x.437) - (. 115x.5x9910) - (.437x.5x9910) = 1594 psi f/drlg to TD w/1/2 column of gas, 1/2 column 8.4 ppg mud 40~ & 43.5# from surface to 6995' MD/6531' TVD whipstock point 1/2 evacuation to gas, 1/2 remaining 8.4 ppg mud weight 40# rated @ 5750 psi for burst Safety Factor = 3.6 OK Collapse= (6531x.437) - (. 115x.5x6531 ) -(.437x. 5x6531 ) = 1052 psi for 1/2 evacuation 40# rated @ 3090 psi for clpse Safety Factor = 2.9 OK 7-.5/8.' 29.0#, L-80, STL liner ¢,, 11,880' MD, 9378' TVD (Top of liner ~ 6795') Tension = (11880'-6795') x 29.0# = 147K Rated = 444K for joint Safety Factor = 3.0 OK 1/2 evacuation to gas, 1/2 remaining 8.4 ppg mud weight Burst = (9910x.437) - (. 115x.5x 9910) - (.437x.5x9910) = 1594 psi f/drlg to TD with 1/2 evacuation Rated 6890 psi for burst Safety Factor = 4.3 OK N/A for liner Collapse = (9378x .437) - (9378x. 115x. 5) - (9378x.437x. 5) = 1510 psi for 1/2 evacuation Rated 4790 psi for collapse Safety Factor: 3.2 OK 5-1/2" 17#, L-80, STL liner ¢, 12,843' MD, 9910' TVD (Top of liner ¢,, 11,680' MD) Tension = (12843'-11680') x 17#= 20K Rated = 248K for joint Safety Factor = 13 OK 1/2 evacuation to gas, 1/2 remaining 8.4 ppg mud weight Burst = (9910x.437) - (. 115x.5x9910) - (.437x.5x9910) = 1594 psi Rated = 7740 psi for burst Safety Factor = 4.9 OK N/A for liner Collapse = (9910x.437) - (9910x.5x. 115) - (9910x.5x.437) = 1594 psi Rated = 6280 psi for collapse Safety Factor = 3.9 OK West McArthur River Unit #.I-1 Redrill Casing Specifications " . joint ...... B .°dy.'' .................................................................................................................... . .Stren,gth .... stren_gt.h ............. B_..ur_s! ............ _.c__0..!!.a..P..~.e .......................... !.~ .................. DriftlD. Min !orq Opt Torq Max Torq K_ !.~ .................... .K.._ !.bs.. ............ _.p_s! ............ _p..s_i ....................................... ftTrlbs ft-lbs, fi-lbs ...... Casin-a in place I-n'~e~m-~'~li-~a'[~" ';I--3:~)8" 54.5#, K-8o, BTa C 9'0'9 .......................... ~'5':~ ............... -2-~'~6 ........... ;I-l"~iJ .................. ~'2-:'~'~ .......... '.1"~. 4 ~9 · Intermediate 9-5/8" 43.5#, L-80, BT&C ...... ;i"5~':4 ................ :i'-05~' ............ ~-3-~[:)- ........ ~3-8-{~ .................... -~-~'~,~ ............... 8-.'599 9-5~8" 40//, L-80, BT&(: 979 916 5750 3090 8.835 8.679 _ P__r.-°-_pg.s.~..d.Lm_.e.r~s. . Liner 7-5/8" 29.04#, L-80, STL ......... -4~,-,~ ....................... -~' .......... -~-I~- ........... -,~-~-c~)- ........... ~.-8~- ......... ~1'7'~0 4600 5300 6000 Liner 5-1/2" 17#, L-80, FL4S ........ ~'8 .................. -~3b~ 7740 ..... -6-,',5§-0' ........ 4.892 .......... ~4::)i37 3'000"' 3300 3600 CSGSPECI.XLS WMRU No. I-1 Sidetrack -6500 ~ ............................................................ q ........................... r .......................... F ..................................... i ............ -7ooo ¢"'~'~*~'~"~_ ' i i -7500 , · i ~'~ ..... i t i i ............ -aooo ! ....... '~-i i .................................................... i .............................................. i .................................................. -85oo ,,., ._~....% i .............................................. i i -9000 i i. ~i ....... % ..... i ............................................. i i., i / -9500 , , ~ ............. ~ ............................ i ................................ i i t / -~oooo ~ ........ % .................... i -10500 i '~""'~ i i ' ' / -~ '~ ooo ~...... ~ .~ ........................ ~ ~ i / -~ ~ 5o0, ~i ..... N it Set 7-5/~" -12000 ........ · .......................... -~ 2500 -13000 ~ ~ ................. t ..................... ~ ..... i-- t 5 10 15 20 25 30 35 40 Days STATE 004525 8439 8439 WMRINJ AFE2 Total O 9.00 WEST McARTHUR RIVER OPERATING ACCOUNT · ANCHORAGE, AK 99503 _ STEWART PETROLEUM COMPANY WEST McARTHUR RIVER OPERATING ACCOUNT 2550 DENALI STREET, SUITE 1300 ANCHORAGE, AK 99503 NORTHRIM BANK ANCHORAGE. ALASKA 89-93J1252 004525 CHECK NO. Dollars and OO Cents PAY TOT HE CRCER CF STATE OF ALASKA DEPARTMENT OF REVENUE ,'OD L, 5 a 5"" :: L a 5 aOOCl a,t..,t:O i,O ?O a ar-., 5ct,' WMRU #I- 1 Proposed Sidetrack 20" 79.6# @ 655' MD ~' 13-3/8" 54.5# @ 2001' MD ~. Cmted w/1710 sx Top of 7o5/8" liner @ 6795' MD/6346' TVD Top of Sidetrack Window @ 6995' MD/6531' -I-VD Cement Plug: 8600'-8900' 9-5/8" 40 & 43.5# @ 9083' MD Cmtd w/2130 sx HDC Ret @ 10,555' MD w/50 sx DST Perfs. 10,600-10,670' BP @ 11,200' MD w/50 sx DST Perfs. 11,340'ol 1,385' 7" @ 11948' MD 11019' 'i-VD 5-1/2" liner top @ 11880' MD/9378' TVD 7-518" liner @ 11880' MD/9378' -I-VD Cmtd w/115 cuff cmt 5-1/2" liner @ 12843' MD/9910' TVD Cmtd w/130 cuft cmt Surf~ Wmi% ~ Tw~.. Rr~, mtd O!anne Hansen, A:=orne} West McArthur River Unit Property Plat TSN, R14W, Seward Meridian Inlet Bluff Sec. 8 ~':" Surface i Locations i WMRU #lA, 2A, 3 Sec. 17 ADL 359111 Stewart Pet. Co. Sec. 9 1953' Sec. 16 Sec. 21 Bottomhole Location, i WMRU #3 i WMRU#1A -" WMRU#2A Sec. 10 2400' ~~o Sec. 15 / WMRU #I-I / Proposed WFU #2 Surface Location WMRU #I-1 Sec. 22 ADL 359112 Stewad Pet. Co. RECE VL;D k/asV, a 0ti & Gas Cons. ¢.,0mmiSsi0n Anoh0rago Scale 1"= 1/2 mile West McArthur River Unit Unit Boundary Plat T8N, R14W, Seward Meridian I II II I mil " ' I It II II II I ' I W. McArthur River Unit ADL 17602 Stewart Pet. Co. Unocal ADL 3591 11 III II II 4 3 2 1 ,,, 8 L 9 10 11 [ WMRU #I-1 Proposed BHL 17 .... II II i W. McArthur River Unit . Stewart, Pet. Co. ~1~ADL 359112 20 21 I~ 22 I 23 24 29 28 7 26 25 ,, 32 33 35 36 . . . . . . . . . 10. 11. 12. 13. McArthur River Unit #1-1 Sidetrack Drilling Program Move and rig up Nabors Rig #160. ND tree, NU 3000 psi BOPE. Ddil out cement plugs and retainers at 410' and 1910'. Clean out 9-5/8" casing to 7200'. Pressure test integrity of existing casing. Set whipstock and mill out window in 9-5/8" casing at 6995' MD. Directionally ddll 8-1/2" hole to 7-5/8" liner casing point @ 11,880' MD. Run and cement 7-5/8~ liner. (no logs at this point, cased hole GR will be run later) Drill out 7-5/8"liner and 10' of new formation. Run formation integrity test. Ddll 6-3/4" hole to TD @ 12,843' MD/9910' TVD. Run and cement 5-1/2" liner. Run cased hole logs: GR/CET/CBT in 5-1/2" liner. Continue running GR log up to top of 7-5/8" liner. Perforate and run tubing completion for injection. Perform MIT on casing x tubing annulus with AOGCC representative prior to injection. 1 2/23/97 West McArthur River Unit #I-1 ' Pressure Information The following presents data used for calculation of anticipated surface presures (ASP) during drilling .of the West McArthur River Unit #1-1. The pore pressure gradient was estimated using a salt water gradient. This gradient is conservative when considering the most recent bottom hole pressure surveys at West McArthur River Unit*. The fracture gradient information was obtained from formation integrity tests below casing points on the West McArthur River Unit # 1, #2A and #3. WMRU #lA, P:3781 psi @ 9563' TVD (7.6 ppg EMW) from initial static BHP survey on 12/30/95. WMRU #1, P= 3442 psi @ 9563' TVD (6.9 ppg EMW) from static BHP survey prior to reddll on 10/17/95. WMRU #3, P = 3680 psi @ 9563' TVD (7.4 ppg EMW) from initial static BHP survey on 7/2/95. Casing Pore Casing Setting Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressure Drilling (in.) (TVD.ft) (lbs/gal) (lbs/gal) (psi) fpsi) 9-5/8 6531 15.0 8.4 2583 1508 7-5/8 9378 14.5 8.4 4096 1594 5-1/2 9910 8.4 4329 Procedure for Calculatinq Anticipated Surface Pressure ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with one-half evacuation (one-half gas gradient of 0.115 psi/ft and one-half mud gradient of 8.4 ppg), or 2) formation pore pressure at the next casing point less one-half gas gradient and one-half mud gradinet to the surface as follows: 1) ASP = (FGx. 052xD) - (0.115x.5xD) - (.437x. SxD) 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 0.115 = gas gradient in psi/ft 0.437 = mud gradient (8.4 ppg) D = true vertical Depth of casing seat in ft RKB OR 2) ASP = FPP - (0.115xDx. 5) - (0.437x.5xD) where: FPP = Formation Pore Pressure at the next casing point which is tied back to surface or at TD (total depth) West McArthur River Unit Well/ti-1 Pressure Information ASP Calculations , , Ddlling below whipstock in the intermediate casing (9-5/8") ASP = (FGx. 052xD) - (0.115x. SxD) - (.437x0.SxD) -(15.0x.052x6531) - (0.115x. Sx6531) - (.437x. Sx6531) = 3292 psi OR ASP = FPP - (0.115x. SxD) - (.437x.5xD) - 4096 - (0.115x.5x9378) - (.437x. Sx9378) = 1508 psi Drilling below liner (7-5/8") ASP = (FGx. 052xD) - (0.115x.5xD) - (.437x. SxD) = (14.5x. 052x9378) - (0.115x.5x9378) - (.437x. Sx9378) = 4483 psi OR ASP = FPP - (0.115x. SxD) - (.437x. SxD) = 4329 - (0.115x.5x9910) - (.437x. Sx9910) = 1594 psi Blowout Prevention Equipment Nabors Rig No. i60 13-5t8" BOP Equipment 2 ea 13-518" x 5000 psi wp ram type preventers (Hydril) 1 ea 13-5/8" x 5000 psi wp annular preventer (Hydril) 1 ea i3-518" x 5000 psi wp ddiiing spool with 2 ea 4" side outlets (choke and kill), HCR and manual valves on both choke and kill lines. 1 ea tea 1 ea BOP accumulator, Valvcon, 300 psi w/12 bottles, 180 gallons, and (1) 80 gallon Vatvcon accumulator. Accumulator pump, Gardner-Denver Triplex, Model PQ 172, air pump Model G7E. 8 bottles nitrogen backup. Valvcon, 6 station, remote control panel Thomhill Craver, automatic choke 3' - 10,000 psi with control choke panel I lot Hydraulic pipe and fittings from manifold to BOP stack. Nabors Rig #160 13-5/8" 3000 psi BOP Stack Annular Preventer 5000 psi Blind Rams 3-1/8" Kill Line 1 = HCR Valve 2 = Gate Valve 5000 psi Pipe Rams Drilling Spool 13-5/8"x 11" 11" 5M Wellhead 9-5/8" Casing 4-1/16" Choke Line Drilling Fluid System Description Nabors Rig No. 160 Mud Pumps 2 ea Continental Emsco F-1300 tdplex mud pumps 7' x 12", 1300 HP with (2) C-E pulsation dampeners, Model M822, each pump equipped with (2) 752 GE traction motors, cooled with ambient air. Each pump charged by a 5 x 6 Mission Magnum ! with 50 HP AC motor. Mud Tank System (1035 Total Volume) Tank #1 (shaker tank) appx. 270 bbls. Three compartments which include desander, desilter suction compartment and cutting trap compartment equipped with shale shakers, degasser, poor boy degasser, and mud guns in top skidded section. Tank #2 (volume tank) appx. 460 bbls. One compartment equipped with desander, desilter, mud cleaner, mud guns and mud agitators in top skidded section. Tank #3 (suction tank) appx. 305 bbls. Three compartments, two of which are pill pits, 1 thru 65 bbis; one 55 bbl equipped with mud guns, mud agitators, mud mixing hopper, and chemical barrel in top skidded section. Mud System Equipment 1 ea Iea Iea Iea 4 ea 4 ea Iea 6 ea Derrick dual tandem shale shaker Drilco degasser Picenco 16 cone desiiter Pioneer sidewinder mud mixer Brandt 7-1/2 HP mud agitators Mission Magnum pumps, 5' x 6' centrifugal with 50 HP GE Electric Motors Pioneer desander, 2 cone, Model S-2-12 Dahiory 3" mud guns McArthur River Unit #1-1 Redrill Drilling Fluid Program Ddilin.q Liner Hole Section 6995'-11880' MD or 6531'-9378' TVD Hole size = 8-1/2" Casing Size = 7-5/8" Mud type = PHPA polymer Mud Parameters: Weight: 9.1-9.6 ppg Viscosity: 42-50 sec/qt pH: 8.0-9.0 PV: 10-20 YP: 12-25 Fluid Loss: <6 cc/30 min After setting the whipstock, mill out the 9-518" casing with a high yield point, non- dispersed bentonite mud sustem. After cleaning out the metal cuttings and drilling beyond any cement behind the 9-5/8" casing and into new formation, build a PHPA polymer system. Avoid drilling cement with the new PHPA system. Clean the remaining pits and fill with fresh water. Treat the fresh water with Soda Ash as required for hardness. Add 10-12 ppb bentonite and allow to properly hydrate. Add 0.75 ppb PHPA and do not add barite at this time. Continue PHPA additions until the complete system is treated with 0.75 ppb PHPA. Add sufficient polymer (0.5 ppb) until the Clapper Polymer test on the whole mud yields 0.4-0.6 ppb of available polymer. Because of potential cuttings bed problems, 10 minute gel stegths should be at 15-22 and 30 minute gels should be 25-30 which will indicate non-progressive gel structure. There may be siginificant viscosity increases as the polymer reacts initially with the native solids but additions should continue until you are over the "hump". Slight additions of Desco or Ligco will reduce the viscosity somewhat. Inspect the drill cuttings to help determine the proper polymer concentration. Sticky or visibly hydrated cuttings indicate low polymer concentration. The Clapper Polymer Test is the most accurate method to determine proper polymer concentration and should be run at least every 2 days. West McArthur River Unit vv ell/ti-1 Sidetrack Drilling Fluid Program If more viscosity is desired to clean the hole, Biozan can supplement the system. Utilize Iow viscosity-high viscosity sweeps to reduce cuttings bed formation. To reduce fluid loss, add starch at 3-4 ppb while adding PAC polymer at 1-1.5 ppb. This will assist the bentonite and native clays in suspending solids when not circulating. Monitor the HTHP filtration for an indication of cake formation and compressibility. Adding an acrylamide and alkali salt will help stabilize the APl filtrate and improve the HTHP values to less than 12 cc/30 min. Supplementing the PHPA polymer with a 4 ppb blend of Bore-Plate will provide maximum shale stabilization especially as the Cook Inlet coal intervals are encountered. To smooth out rheoiogical properties, add a iow moecular weight polyacrylate thinner works which will not disperse the solids. Mud weights should be kept iow by running all solids control equipment to their maximum efficiency. Run a minimum of 200 mesh screens on the mud cleaners to give maximum cut. A iow gravity solids of less than 7% is required for optimum performance of this system. Dilution or complete displacement should be considered if higher LGS contents persist. West McArthur River Unit ,, ell #I-1 Sidetrack Drilling Fluid Program Production Liner Hole Section 11,880'-12,843' MD or 9378'-9910' TVD Hole size = 6-3/4" Casing Size = 5-112" Mud type = PHPA polymer Mud Parameters: Weight: 9.4-9.6 ppg Viscosity: 42-50 sec/qt pH: 8.0-9.0 PV: 10-20 YP: 12-25 Fluid Loss: <6 cc/30 min Bump the plug on the 7-5/8' liner with the PHPA mud treated with Bicarb to offset cement contamination. The fluid system will already be established from the previous hole section. Eliminate the PAC polymer for filtration control and use starch and acrylamide/alkali salt. This will also enhance the lubricity of the fluid along with a glycol lubricant. After drilling out the cement, have the PHPA concentration at .6-.75 ppb and Bore-plate at 4.0 ppg. The APl filtrate should be less than 6.0 cc. The glycol lubricant should be kept at 3% to provide lubricity for the high angle wellbore. Maintain rheoiogicai properties on the high side to prevent particle settlement and pump regular high viscosity/Iow viscosity sweeps. Keep the mud weight as Iow as possible because unnecessary solids have detrimental effects on the polymers. Anadri]l Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for STEWART PETROLEUM COMPANY Well ......... z ~RU {I-! (P6) Field ........ { WeoC McArthur River Unit Computation..: Minimum Curvature Units ........ : FEET Surface Lat..: 60.78249688 N Surface Long.~ 151.74669450 W Legal Description Surface ...... : 2047 FSL 3327 FEL S16 T08N R14W SM Tie-in survey~ 2281 FSL 1065 FEL S16 T08N R14W SM Target ....... : 4680 FSL 2880 FEL S15 T08N R14W SM BHL .......... z 4951 FSL 2514 FEL S15 T08N R14W SM bOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord 187857.34 2482093.96 190124.56 2482268.18 193648.16 2484575.21 194020.34 2484836.06 PROPOSED WELL PROFILE Prepared ..... : 08 Feb 1997 Vert sect az.: 53.45 KB elevation.: 130.00 ft Magnetic Dcln: +0.000 (E) Scale Factor.: 1.0000 087 Convergence..: -1.524 8~IADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN # -- _ II I I _ ~ _ _ I _ STATION MEASURED INCLN DIRECTION IDENTIFICATION DEPTH ANGLE AZIMUTH mmmmmmmmmmmmmmmmmmmm mmmmmmmm mmmmmm mmmmmmmmm Tie-in 6960.00 22.55 77.00 TOP OF WINDOW 6995.00 22.73 '77.00 KOP / CURVE 2.5/100 7000.00 22.75 77.00 7100.00 24.89 73.78 7200.00 27.08 71.04 mmmmmmmmmmmmmmmmm mmmQmmmm mmmmmmmmmmmmmmmmmmmmm VERTICAL-DEPTHS SECTION COORDINATES-FROM TVD SUB-SEA DEPART WELLHEAD 6498.38 6368.38 1956.57 234.47 N .2261.76 E 6530.69 6400.69 1968.92 237.50 N 2274.88 E 6535.30 6405.30 1970.69 237.94 N 2276.77 E 6626.78 6496.78 2008.15 248.17 N 2315.82 E 6716.67 6586.67 2049.58 261.44 N 2357.55 E 7300.00 29.32 68.69 6804.80 6674.80 2094.91 277.74 N 2401.89 E 7400.00 31.59 66.64 6891.00 6761.00 2144.04 297.03 N 2448.76 E 7500.00 33.90 64.85 6975.10 6845.10 2196.89 319.27 N 2498.06 E 7600.00 36.23 63.26 7056.95 6926.95 2253.35 344.42 N 2549.70 E 7700.00 38.57 61.84 7136.39 7006.39 2313.32 372.44 N 2603.58 E mmmmm.mmmmmmmmmmmmmm mmmm mmmm ALASKA Zone 4 TOOL OL/ X Y FACE 100 mmmmmmmmm mmmmmmmmmm mmmm mmmm 190124.56 2482268.18 HS <TIE 190137.76 2482270.86 HS 0.50 190139.66 2482271.24 33L 0.50 190178.96 2482280.43 30L 2.50 190221.04 2482292.59 27L 2.50 190265.80 2482307.70 25L 2.50 190313.16 2482325.73 24L 2.50 190363.03 2482346.65 22L 2.50 190415.32 2482370.42 21L 2.50 190469.93 2482397.00 20L 2.50 7800.00 40.93 60.55 7213.26 7083.26 2376.68 403.26 N 2659.60 E 190526.75 2482426.32 19L 2.50 (Anadrlll {c)97 WNRIlP6 3.0C 11:21 AN P) WHPU #I i ,P6~ 08 Feb 199'I mmmmmmmmmmmmmmNmNmIN STATION IDENTIFICATION END CURVE 2.5/100 TARGET mmmmmmmm mmmmmm MEASURED INCLN DEPTH ANGLE mmmmmmmm mmmmmm 7900.00 43.31 8000.00 45.69 8100.00 48.09 8200.00 50.49 8300.00 52.90 8400.00 55.31 8500.00 57.73 8578.78 59.64 12280.87 59.64 12300.00 59.26 12400.00 57.26 12500.00 55.26 12600.00 53.26 12700.00 51.26 12800.00 49.26 TD 12843.44 48.39 PROPOSED WELL PROFILE mmmmmmmmm mmmmmmmmmmmmmmmmm DIRECTION VERTICAb-DEPTHS AZIMUTH TVD SUB-SEA 59.39 7287.43 7157.43 58.32 7358.75 7228.75 57.33 7427.09 7297.09 56.42 7492.31 7362.31 S~.57 7554.29 7424.29 immmmmmm SECTION DEPART 2443.31 2513.09 2585.67 2661.53 2739.92 54.77 7612.91 7482.91 2820.89 54.01 7668.07 7538.07 2904.28 53.45 7709.01 7579.01 2971.58 53.45 9580.00 9450.00 6166.09 53.45 9589.72 9459.72 6182.56 53.45 9642.33 9512.33 53.45 9697.86 '9567.86 53.45 9756.27 9626.27 53.45 9817.48 9687.48 53.45 9881.40 9751.40 6267.60 6350.75 6431.92 6510.99 6587.89 mmmmmmmmmmmmmmmmmmmmm COORDINATES-FROM WELLHEAD 436 84 N 2717.65 E 473 10 N 2777.62 E 511 98 N 2839.40 E 553 41 N 2902.88 E 597 30 N 2967.92 E 643.57 N 3034.40 E 692.14 N 3102.21E 731.96 N 3156.47 E 2634.42 N 5722.70 E 2644.23 N 5715.93 E mmmmmmmmmmmmmmmmmmmm mmmm mmmm ALASKA Zone 4 TOOL DL/ X Y FACE 100 190585.68 2482458.34 18L 2.50 190646.59 2482493.00 lTL 2.50 190709.39 2482530.22 16L 2.50 190773.94 2482569.94 16L 2.50 190840.13 2482612.09 15L 2.50 190907.82 2482656.58 15L 2.50 190976.89 2482703.33 14L 2.50 191032.19 2482741.68 HS 2.50 193648.15 2484575.20 LS 0.00 193661.64 2484584.66 LS 2.00 2694.87 N 5804.24 E 193731.28 2484633.47 LS 2.00 2744.39 N 5871.04 E 193799.38 2484681.19 LS 2.00 2792.73 N 5936.24 E 193865.84 2484727.78 LS 2.00 2839.82 N 5999.77 E 193930.60 2484773.17 LS 2.00 2885.61 N 6061.54 E 193993.56 2484817.30 LS 2.00 53.45 9910.00 978.0.00 6620.58 2905.09' N 6087.80 E 194020.34 2484836.06 2.00 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN (~adrlll (¢)97 WMRIlP6 3.0C 11:21 AM P) I..~ . STEWART PETROLEUM COMPANY . WMRU #I-1 (P6) VERTICAL SECTION VIEW i i i Sect ion at' 53.45 J , TVO Scale.' 1 inch = 1500 feet ! ! Dep Scale.' ~ inch = ~500 feet i I Drawn .....· 08 Feb ~gg7 I i · ~% I . ,, ,, , , , ~4naUri ]] SchZu~berger i ~ ' i ~ ; ~ . , ~ :, Narker Identification ~ BKB SECTN INCLN , ,~ j B960 6498 1957 22.55 , % I A)Tie-1n ) % I B) TOP ¢ WINDOW 6995 B53~ ~969 2~.73 m C) KOP / CURVE 2.5/100 7000 6535 ~97i 22.75 ~ J D) END CCVE 2.5/~00 8579 7709 2972 59.64 J ~m J E) TARGET ~228~ 9580 B~66 59.B4 ~ I F) TD 12~3 99~0 6B2l 48.39 , ~ . ~ ... x ~ -. ~ .[, .. ~ I AN~DRILL A~'-DPC I J , I ~ ~ ~PPROVE~ .... '~ FOR~ pE~MiT'[iNC ,~ j ~ 0~4 LY ~ : ,, - ~SO0 -750 0 750 ~500 2~0 ~00 3750 4500 5250 6000 6750 7500 8~50 Section Depantune m m T STENART PETROLEUM Xar'k~r Identification MD 8KB SECTN INCLN Al lle-~n 6960 6498 t957 22.55 8) lOP OF WINDOW 6995 6531 1969 22.73 C) KOP / CURVE 2.5/100 7000 6535 197! 22.75 D) END CURVE 2.5/I00 8579 7709 2972 59.64 E) TARGEI 1228! 9580 6166 59.64 F) TD 12843 9910 662t 48.39 COMPANY ..... xlnadr ] J] S~'l~]umberger ,, i VERTICAL SECTION VIEN Sect ion at' 53.45 TVD Scale.' I inch : 800 feet Dep Scale.' 1 inch : 800 feet I i i i ~ ~ AN&DRILl'/ AKA.DPC ' " ~.PPI~OVED ~,~ " FOR?Ei~M][ m iN~: , 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 dB00 5200 5600 6000 6400 6800 7200 7600 8000 Sect ion Departure ql w. IIIIP6 ) 0£ 11. AM PI i i ..... , i , i , i im m , ii , ,11 STEWART PETROLEUM COMPANY WMRU (PC) PLAN VIEW CLOSURE · 6745 feet at Azimuth 64.49 DECLINATION.' +0.000 {E) SCALE · I inch = 800 feet DRAWN · OB Feb ~gg7 Marker Identification A) Tie-in B) TOP OF WINDOW C) KOP / CURVE 2.5/100 D) END CURVE 2.5/100 E) TARGET F) ID MD N/S E/W 6960 234 N 2262 E 6995 238 N 2275 E 7000 238 N 2277 E 6579 732 N 3156 E ~228! 2634 N 5723 E ~2643 2905 N 6086 E -,.,.. , I -Al,tADRILt - · 'Al(,k~D~-" ........................... 'T6~ [PbTfiI] .......... APP IOVI~D, FOI) pc~'~I~T~Ii~ [ ~ I ~ITI i I ....... ONLY , ,,, , ,, , , ,, ........................... ~ ........................................ ....... . ~~ ....... .... i ..... , , t, _ _ ,,,, , , 400 0 400 800 ! 200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 <- WEST ' EAS! -> --,, ~ ~.1,~ ~ oc, ,. ~ ,, .................................... ,,~ , , , i. WFU #2 P&A 9/14/66 20' 79.¢:~ ~_. 655' MD ~ 13-3/8" 54.5~ (f~ 2001' MD ~ Cmted w11710 sx Calc TOC at 362' DC Retainer @ 410' wi100 sx Calc TOC @ 1886' DC Retainer @ 1910' w/50 sx 9-5/8' 40 & 43.5~ @ 9083' MD Cmtd w/2130 sx Cement Plug: 8600'.8900' 7' liner top @ 8850' - ~' Hole in liner at 10,298'sqzed w/200 sx HDC Ret @ 10,555' MD w/50 sx DST Perfs. 10,600-10,670' BP @ 11,200' MD wi50 sx DST Perfs. 11,340'-11,385' 7' @ 11,948' MD 11,019' TVD RKB = 130' above sea level RKB = 17' above Ground Level Ave Hole Angle = 25 degrees STATE OF ALASKA OIL AND GAg CONSERVA~ON CCM:AIS$ION ,,,,~ ,,d,~, WELL COMPLETION OR RECOMPLETION REPORT AND LOG* TYP.~ OF ',VELJ..; ol~, · ~ ~ O~ CO~O~ Other America~ Petroleum Co~orntion 779 AnchorageS' Alask= 99501 ' ' At to,-, ~'"~2209' FNL, 835' ~{L, Sec. 15, TSN, R14;;, S.}[. Effective: j,dy I. 13G4 ADL- 01804 ~. IF [."~OlaH, A&LO"L'"Te~ ~'. (,'.~IT 4O2CC.~.'V'~ West ~o~d lfest ForeI~nd $. ~ NO. 2 10. FI~ AND ~0~ O~ Alask~ I2. BOROUGH Kenai ~' "'' '""'"'"5/25/66 ! ze' ~"' "~' 7'¢a=~i ~" ""~ c°"'~' (~e~ ""o~')8/28 66 I8' '~'m°~' ("""~ '"~""~')' I ~" '~" ~'"~pd~ 130' above SL ..... 1{. ~OD~CXN~ ~IIIT~(i), O~ ~818 COM~IION,--~, BQ~OM,.N~gl (ID ~D ~D)e 2~. WA3 DIBI~IO~ ; . ,. xeg ~6. T~n x~IC ~D ~HE~ ~ xON 2T. WAI WELL co~ lES, DiF:eter, ~o~ic, Density, ~.,"1',. CASINO 8L~ut , , 13-3/8, , 5/81' , WBI(3HT, 79.6 40 & 43.5 ~c~a scT 646 2001 9083 26" 29. . LINER RECORD 30. SCZEEN (~D) 8LZB '='7" ~' 8850 ("")[Jl ,o~o. 11938 (x.) 31. I'B,XrO~TION aSCOXD (Zn~erva4 .~e m1%d ~Um~T) 11340-~1.385~ '10~00-.10~?0, reperf 10~00- 10S?0, reperf' 10Sl0-10SS0, ~ with 4 ~s.~ :V~si-~et ?" ca.s£ng ~1:10,550 with 50 32. ACID, SHOT. FRACT~RF_.. CEMENT SQUEEZE, ETC. 10248 - 10298 106lO - lOSSO '200 s.x cement squeeze . '12~50 gal.' 15% acid 33." PRODUCTION . YES, Hud Log, Dire~ional data, 17el! H;.s +~o~, " 36. ~ 3e~y ~7 ~ac ~e foregotn; and at~c~e~ t~ormaclo~ ti complete and ~rrect aa dete~lae~ from ~l avttlaole :~or~a T:~z ;~rea Su:er{ntendent- DA:'. 10/10/SS *(See Instructions and Spc:c,s for Additional Data on Re',ene Side) West McArthur River Unit #1-1 Redrili Cementing Program 7-5/8" Ddilin,q Liner 8-1/2' hole @ 11,880' MD, top of liner at 6795' MD Cement volume for liner based on 1000' of fill-up above shoe: 1000' x 0.077 cuft/ft (8-1/2" x 7-5/8") x 1.50 excess = 115 cuft Cement = 15.8 ppg Class G 5-1/2" Ddllinq Liner 6-3/4" hole @ 12,843' MD, top of liner at 11,680' MD Cement volume for liner based on caliper hole volume plus 25%, liner lap, and shoe joints. Estimated volume is: 963' (12,843' - 11,880') x 0.0835 cuft/ft (6-3/4' x 5-1/2") x 1.25 = 100 cult 200' liner lap @ 0.0928 cuftJft x 200' = 20 cult 80' shoe its x 0.1305 cuft/ft (5-1/2" liner capacity) = 10 cuff 100 + 20 +10 = 130 cuff Class G cement @ 15.8 ppg West McArthur River Unit #1-1 Redrill Casing Design 9-5~8" Intermediate Casing, L-80, BT&C (Already in place in WFU #2) 40# & 43.5# from 1/2 evacuation to Burst (9910x.437) - (. 115x.5x9910) - (.437x.5x9910) 1594 psi f/drlg to TD w/1/2 column of gas, 112 column 8.4 ppg mud surface to 6995' MD/6531' TVD whipstock point gas, 1/2 remaining 8.4 ppg mud weight 40# rated @ 5750 psi for burst Safety Factor = 3.6 OK Collapse= (6531x.437) - (. 115x. 5x6531 ) -(.437x.5x6531 ) = 1052 psi for 1/2 evacuation 40# rated @ 3090 psi for clpse Safety Factor = 2.9 OK 7-5/8" 29.0~, L-80, STL liner ~ 11,880' MD, 9378' TVD (Top of liner ~ 6795') Tension = (11880'-6795') x 29.0# = 147K Rated = 444K for joint Safety Factor = 3.0 OK Burst 1/2 evacuation to gas, 1/2 remaining 8.4 ppg mud = (9910x.437) - (. 115x.5x 9910) - (.437x. Sx9910) = 1594 psi fl drlg to TD with 1/2 evacuation Collapse: (9378x .437) - (9378x. 115x. 5) - (9378x.437x. 5) = 1510 psi for 1/2 evacuation weight Rated 6890 psi for burst Safety Factor = 4.3 OK N/A for liner Rated 4790 psi for collapse Safety Factor = 3.2 OK 5-1/2' 17#, L-80, STL liner ¢_. 12,843' MD, 9910' TVD (Top of liner ¢.. 11,680' MD) Tension = (12843'-11680') x 17#= 20K Burst Rated = 248K for joint Safety Factor = 13 OK 1/2 evacuation to gas, 1/2 remaining 8.4 ppg mud weight = (9910x.437) - (. 115x.5x9910) - (.437x.5x9910) = 1594 psi Collapse: (9910x.437) - (9910x.5x. 115) - (9910x.5x.437) = 1594 psi Rated: 7740 psi for burst Safety Factor = 4.9 OK N/A for liner Rated: 6280 psi for collapse Safety Factor = 3.9 OK West McArthur River 'Unit #I-1 Redrill Casing Specifications · JOint .strength Strength ............. B....U.~..s! .............. _.C._o...!!~.e .................... !_D.. .................. D. dftlU .. Min Torq. Opt Torq Max Torq .............. K !.b..S. .................... K.!..b.s ................ __p..s_i .............. _pS.i_ ..................................... ftTIbs ft-lbs ft-lbs .... casin.q in place Int---e~m-~i~'i~' ':1-~i8" 54.5#, K-80,' BT&C ......... ~09- ....................... 8'5'3 ............... 2-'~'0- ............ :1-1'~[3 ................ ~'2-~'~"~ .......... i'~. 459 intermediate 9-5/8" 43.~, L-80, BT&c .......... i--8~.~i. ................ ;i.50~5- ........... ~-33--0- .......... -3-8~..~ ...................... -~.-~5-~ ........... §-..~99 ................. 9-5~8" 40#, L-80, BT&C 979 916 5750 3090 8.835 8.679 __-P_r-°-Eo..s_e. _d L!n_.e.r.s Liner 7-5/8" 29.'04#, L-80, STL ..... 44-4 .............. '555 ............. -6-~;9-0' ................ ~:~'9'5 .................. ~-.'~':/;~ ........ 6.'7'~0' 4600 5300 6000 Liner 5-1/2" 17#, L-80, FL4S ...... ~'~i8 .............. -3'9~;: .............. :~740- ........ 8-2§5 .................... 4.--~-~ ............. 4;f87 "3'000' 33oo 36oo CSGSPECI.XLS WMRU No. I-I Sidetrack -6500 -7000 -7500 -8000 -8500 -9000 -9500 -1OOOO -10500 -11000 -11500 -12000 -12500 -13000 10 15 20 ................ omp. I 25 30 35 40 Days -- Plannea. I I STRTE 00452 8439 03/13/96 8439 WMRINJ AFE2 Total. ~ 0.00 e .oo lOO.o9 lOO WEST McARTHUR RIVER OPERATING ACCOUNT · ANCHORAGE, AK 99503 . - STEWART PETROLEUM COMPANY WEST McARTHUR RIVER OPERATING ACCOUNT 2550 DENAL! STREET, SUITE 1300 ANCHORAGE, AK 99503 NORTHRIM BANK ANCHORAGE. ALASKA 89-93/1252 00452E CHECK NO. PAY TO THE CRCER CF STATE OF ALASKA DEPARTMENT OF REVENUE ,'OOt~Si~5,' ~:l, 85;~OOCi:~L,t:O;i,O?08i~¢'5~i"' 03/~.3/96 Stewart Petroleum Company 4700 Business Park Blvd., Suite 13 Anchorage, Ak 99503 February 28, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Attn: Re: Commissioner David Johnston Application for Permit to Drill (Form 10-401) West McArthur River Unit #I-! (Injector #1) Commissioner Johnston: Enclosed is the revised Application for Permit to Drill the West McArthur River Unit #I-1 including two copies. The bottomhole location has been revised from the previously approved (Appr. #96-60) Permit to Drill. The proposed sidetrack ddlling operation will be conducted with a BOP stack consisting of one annular BOP and two-5000 psi ram BOPs. This BOP configuration was previously approved by Sundry Application Approval #96-148 on 7/24/96. Since this application is a BHL revision of a previously approved APD, a second $100 payment is not enclosed. If there are any questions, please contact me at 563-5775. Paul D. White Operations Manager Stewart Petroleum Company ~laska 0il & 6as Cons. ¢0mmissi0rl A,~ch0rag~, Stewart Petroleum Company 4700 Business Park Blvd., Suite 13 Anchorage, Ak 99503 February 28, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Attn: Re: Commissioner David Johnston Application for Permit to Drill (Form 10-401) West McArthur River Unit Cfi;- ! (Injector #1) Commissioner Johnston: Enclosed is the revised Application for Permit to Drill the West McArthur River Unit #I-1 including two copies. The bottomhole location has been revised from the previously approved (Appr. #96-60) Permit to Ddil. The proposed sidetrack ddlling operation will be conducted with a BOP stack consisting of one annular BOP and two-5000 psi ram BOPs. This BOP configuration was previously approved by Sundry Application Approval #96-148 on 7/24/96. Since this application is a BHL revision of a previously approved APD, a second $100 payment is not enclosed. If there are any questions, please contact me at 563-5775. Paul D. White Operations Manager Stewart Petroleum Company Stewart Petroleum Company Denali Towers North, Suite 1300 2550 Denali Street, Anchorage, Alaska 99503 (907) 277-4004 · FAX (907) 274-0424 Alaska Oil and Gas Conservation Commission 3001 Pomupine Drive Anchorage, Alaska 99501 July 23, 1996 Re: Application for Sundry Approval (Form 10-403) West McArthur River Unit #1-1 (APD Permit #96-60) Revision Request for BOP Stack Dear Sirs: Enclosed is the Application for Sundry Approval to revise the BOP stack configuration for the drilling of the VVest McAdhur River Unit # f-]. The proposed well will be a sidetrack of the Pan American West Foreland Unit ¢2 (AP! ¢50-133-10027, Permit ¢66- 12) which was drilled and abandoned in 1966. The original Application for Permit to Drill the sidetrack well (¢96-60) specified a four- preventer 5000 psi system with one annular preventer and three ram preventers. The reason for specifying the 5000 psi system was that this equipment is already on location as part of Nabors Rig ¢160. However, the maximum anticipated surface pressure as described in the approved Permit to Ddll will only be 1581 psi. It has recently been observed that the four-preventer BOP stack on top of the existing wellhead is too tall to fit under the Nabors Rig ¢160 rig floor. Therefore, this sundry application is requesting a change to a three-preventer BOP stack for the entire drilling of the sidetrack well in order to fit the BOP stack under the rig floor. The three preventers from top to bottom will be: an annular preventer, a 5,000 psi ram preventer with blind rams and a 5,000 psi ram preventer with pipe rams. This will meet the requirements for a 3,000 psi BOP stack configuration as described in 20 AAC 25.035(d)(1)(A). Attached is the diagram for the proposed BOP stack. if there are any questions, please contact me at 277-4004. Petroleum Engineer, Stew, art Petroleum Company cc: Paul D. White, Operations Manager- Stewart Petroleum Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,ype of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program _.% Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance ~ Perforate __ Other 2. Name of Operator Stewart Petroleum Company 3. Address 2550 Denali St., Suite 1300 Anchorage, AK 99503 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service -.x- 4. Location of well at surface 1953' FWL, 2047' FSL, At top of productive interval Sec. 16, TSN, R14W, SM 6. Datum elevation (DF or KB) -I 30 feet 7. Unit or Property name West McArthur River Unit 8. Well number No. I-1 9. Permit number 96-60 10. APl number 50-- 133-10027-01 1780' FWL, 1500' FNL, At effective depth At total depth 2118' FWL, 1303' FNL, 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Sec. 15, T8N, Sec. 15, TSN, R14W, SM R14W, SM 11. Field/Pool W. McArthur River/Same 11,948 11,019 362 362 feet feet feet feet Plugs (measured) Junk (measured) 410 DC Retainer 1,910' DC Retainer 10,555' HDC Retainer 11,200' Bridge Plug Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: ~ngth Size 655' 20" 2001' 13-3/8" 9083' 9-5/8" 3098' 7-5/8" measured 10,600' true vertical 9,809' Tubing (size, grade, and measured depth) 1432 1967 2450 8O5 - 10,670' - 9,871' None Packers and SSSV (type and measured depth) None Cemented Measured depth True vertical depth cuft G blend 655' 655' cuft G blend 2,001' 1,953' cuft G blend 9,083' 8,438' cuft G blend 11,948' 11,019' and 11,340' - 11,385' and 10,469' - 10,509' ORiGiNAL 13. Attachments Description summary of proposal Detailed operations program BOP s ke"tc~h 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: u ~ ;.. Suspend2~askn~u 0il & Gns Ce~ls. Oil Gas ~1,'...: Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,'/~ Title Petroleum Engr., FOR COMMISSION USE ONLY Stewart Pet. Date'¢//~/c~g Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test I Subsequent form required 10- Approved by order of the Commission David W. Johnston ,-/~ "~"~Commissioner Form 10-403 Rev 06/15/88 I Approval No. ?~ _/~r~ Date/~'-, ~< -(~1 ,~ SUBMIT IN TRIPLICATE [On Nabors Rig #160 13-5/8" 5000 psi BOP Stack Annular Preventer I ! 5000 psi Blind Rams 3-118" Kill Line HCR Valve Gate Valve 5000 psi Pipe Rams Drilling Spool 13-518"x 11" 11" 5M Wellhead 9-5/8" Casing I 4-1/16" Choke Line '~l~sk.s. Oi~ 8,. 6as 60~'~s. 6 An¢~or~%s CONSERVATION CO~$SION / TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April19,1996 Tim Billingsley, Petroleum Engineer Stewart Petroleum Company 2550 Denali St., Ste 1300 Anchorage, AK 99503 West McArthur River Unit No. I-1 Stewart Petroleum Company Permit No 96-60 Surf Loc 1953'FWL, 2047'FSL, Sec. 16, T8N, K14W, SM Btmhole Loc 2118'FWL, 1303'FNL, Sec. 15, T8N, R14W, SM Dear Mr. Billingsley: Enclosed is the approved application for permit to redrill the above referenced well; however, the subject well cannot begin operation as an injector until an area injection order is written for the West McArthur River Unit. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of injection wells must be demonstrated under 20 AAC 25.412 and 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission at 279-1433. BY ORDER OF THE COMMISSION c: Dept offish & Game, Habitat Sect- w/o encl Dept of Environmental Conservation- w/o end STATE OF ALASKA ALASK/-, ,.)IL AND GAS CONSERVATION ~.,OMMISSION la. Typeofwork Drill- Redrill~l Re-Entry - Deepen PERMIT TO DRILL 20 AAC 25.005 lb. Type of well. Exploratory ,'-' Stratigraphic Test ~ Service X Developement Gas ~ Single Zone 2. Name of Operator Stewart Petroleum Company 3. Address 2550 Denali St., Suite 1300 Anchorage, AK. 99503 4. Location of well at surface - 1953' FWL, 2047' FSL, Sec 16, TSN, R14W, SM At top of productive interval 1780' FWL, 1500' FNL, Sec 15, TSN, R14W, SM At total depth 2118' FWL, 1303' FNL, 'Sec 15, TSN, R14W, SM 12. Distance to nearest property line 3162 ' @ BHL feet 13. Distanceto nearest well 888' @ Surf 2840'@top (WMR#2A) fee~. 16. To be completed for deviated wells Kickoff depth 7488 feet Maximum hole angle 55 0 Specifications CouplingI ~ngth STL 13776 FL-4S I 1113 18. Casing program size Hole Casing 8.5" 7-5/8" 6.75" 5-1/2" Weight [ Grade MD 7283 10859 5. Datum Elevation (DF or KB) 130' ~,~ feet 6. Property Designation ALD 359111 (BRL) Development Oil [] Multiple Zone [] 7. Unit or property Name West McArthur River UnJ 8. Well number No. I-1 9. Approximate spud date 7/1/96 14. Number of acres in property Lease 4175 acres Unit 6330 acres 10. Field and Pool West McArthur River Field and Pool 11. ~pe Bond(see20AAC25.025) t Blanket Number 1278657 Amwest Security Ins. Amount $2OO,00O 15. Proposed depth (MO and TVD) 11,972' ND 9,830' TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (eX2)) Maximum surface 1581 psigAt total depth C'VD) 4294 Setting Depth Top Bottom TVD] MDI TVD 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 11,948 true verticalll 019 psig Effective depth: measured 362 true vertical 362 Casing Length Structural Conductor Surface 655 ' Intermediate 2001' Production 9083 ' 3098' Liner Perforation depth: measured true vertical Quantity of cement (include stage data) 115 cuft Class G blen~ 125 cuft Class G blenE 410' DC Retainer feet Plugs (measured) 1910' DC Retainer feet 10,555' HDC Retainer ....... ~ :i .... .~ ::~ :.....,.. :.. ;:. ...... 11,200' BridgePlug ~,feet.>::, ..... i! Jt~nk";(me'asured) feet Size t..'i>~','~ ~;~'rn~ Measured depth True Vertical depth :;._i i:!:":i:/;.~. 20" 1432 cuft G blend 13-3/8" 1967 cuft G blend 9-5/8" 2450'cuft G blend 7-5/8" 805 cuft G blend 10,600' - 10,670' and 11,340' 9,809' - 9,871' and 10,469' 655' 2001' 9083' 11,948' - 11,385' - 10,509' 655' 1953' 8438' 11,019' 20. Attachments Filing fee ~ Property plat [] BOP Sketch I~ Diverter Sketch '~ Drilling program Drilling fluid program ~ Time vs depth plot ~ Refraction analysis [] Seabed report ,% 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ TitlePetroleum Engr., Stewart Pet. Co. Signed ' ~ Commission Use Only ! Conditions of approval Samples req.uired F-] Yes ~ No Mud 10g required L-'] Yes No Hydrogen sulfide.measures [] Yes ~"No Directional survey required ~;' Yes r'-I No Required working pressure for BOPE [-12M; [] 3M; j~ SM; [] 10M; [] 15M Other: d~-~g~nai Signed By by order of Approved by 0avid W. Johnston Commissioner the commission See cover letter for other requirements Date'~ - Form 10-401 Rev. 12-1-85 Submit in triplicate '~ '" STATE OF ALASKA ALASK,-. OIL AND GAS CONSERVATION ~,OMMISSION PERMIT TO DRILL 20 AAC 25.005 Re-Entry -- Deepen lb. Type of well. Exploratory ~_ Stratigraphic Test ,~ Service X Developement Gas ;-- Single Zone Development Oil Multiple Zone 2. Name of Operator Stewart Petroleum Company 3. Address 2550 Denali St., Suite 1300 Anchoraqe, AK. 99503 4. Location of wellatsurface 1953' FWL, 2047' FSL, Sec 16, TdN, R14W, SM Attop of productiveinterval 1780' FWL, 1500' FNL, Sec 15, TdN, R14W, SM Attotaldepth 2118' FWL, 1303' FNL, Sec 15, TdN, R14W, SM 12. Distance to nearest property line 3162' @ BHL feet 13. Distance to nearest well 888' @ Surf 2840' @top .(WMR#2A) feet. 16. To be completed for deviated wells Kickoff depth 7488 feet Maximum hole angle 55 0 18. Casing program size Hole Casing 8.5" 7-5/8" 6.75" 5-1/2" Specifications Weight ! Grade i Coupling 5. Datum Elevation (DF or KB) 130 ' KB feet 6. Property Designation ALD 359111 (BHL) 7. Unit or property Name West McArthur River Un~ 8. Well number No. I-1 9. Approximate spud date 7/1/96 14. Number of acres in property Lease 4175 acres Unit 6330 acres 10. Field and Pool West McArthur River Field and Pool 11. ~pe Bondlsee2OAAC25.025) t Blanket Number 1278657 Amwest Security Ins. Amount $200,000 15. Proposed depth(MOandTVD) 11,972' ND 9,830' TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum sudace 1581 psig At total depth (TVD) 4294 psig Setting Depth Top 7283 !6793 I 110591 19. To be completed for Redrill, Re-entry, and Deepen Operations. Bottom TVD Quantity of cement (include stage data) 9271 115 cuft Class G blend 9830 125 cuft Class G blend 410' DC Retainer Present well condition summary Total depth: measured 11,948 true verticalll, 019 Effective depth: measured 362 true vertical 362 Casing Length Size Structural Conductor Surface 655 ' 20" Intermediate 2001' 13-3/8" Production 9083 ' 9-5/8" 3098' 7-5/8" Liner Perforation depth: measured 10,600' true vertical 9,809 ' feet Plugs (measured) feet feet :.~ementeo "- Measured depth 1432 cuft G blend 1967 cuft G blend 2450'cuft G blend 805 cuft G blend 1910' DC Retainer 10,555' HDC Retainer 11,200' BridgePlug ~ue Verticaldepth 655' 655' 2001' 1953' 9083' 8438' 11,948' 11,019' - 10,670' and 11,340' - 11,385' - 9,871' and 10,469' - 10,509' 20. Attachments Filing fee ~ Property plat [] BOP Sketch EX Diverter Sketch '--_' Drilling program ..~ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis [] Seabed report ,~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge '~~ TitlePetroleum Engr. , ~..~._... Stewart Pet. Co. Dat Signed Commission Use Only APl number 50-/$_~ -/~ o ~ 7 - o / Approval date Permit Number Conditions of approval Samples req~.ire, d El Yes ~ No Mud Icg required [] Yes .~ No Hydrogen sulfide measures ~ Yes ~f' No Direcbonal survey required ~Yes F'I No Required working' pressure for BOPE- E]2M; [] 3M; ,~ 5M; [] 10M; -lq 15M Other: di-~glnd.~ Signed By by order of Approved by 0~tv[d W. Johnston Commissioner the commission See cover letter for other requirements Form 10-401 Rev. 12-1-85 Submit in triplicate -~'~.A~., .A QII.. AND ~A~ CON6~ctVATIQ/~, ,OMMI6610N. · 1 ! ; ..... ~,~. .A OIL, AND GAS CDON~'~'c:iVATIOI~ .OMMICd~ION ' BON,-, 'T KNOW ALI. MEN BY' THE~E-PRESEHT~, T" _ ~ w. ........ ~~..~~~~~~ .... ~ .............................................. ' f ~IFO~IA -- - ~'3m~ ac' ~~. Ind u~gns ~intly ~ ~e'eeellly, firmly by theee ,orm, e~ts. -- _ · _ ii i · Unit, or I. sem ~ Well { A~i;r2recJ: I · 4carrot ~a ~.t4-,me ~efm .sis · · West McArthur River Unit Property Plat T8N, R14W, Seward Meridian ICook Inlet Bluff Sec. 8 Surface Locations Sec. 17 ADL 359111 Stewart Pet. Co. Sec. 9 1953' o Sec. 16 Sec. 21 Bottomhole t.. ...... ~¢¢" {~ Location,I WMRU #3 ] I WMRU#1A ~ t1~ WMRU#2A Sec. 10 1780' Sec. 15 WMRU #I-1 Proposed WFU #2 Sl.lrface Location WMRU #I-1 Sec. 22 Scale 1" = 1/2 mile West McArthur River Unit Property Plat T8N, R14W, Seward Meridian Sec. 8 Surface Locations WMRU #lA, 2A, Sec. 17 Sec. 9 1953' Sec. 16 Sec. 21 Bottomhole [ ...... .~¢~,~ Location, WMRU #3 [ WMRU#1A ~ WMRU#2A Sec. 10 1780' Sec. 15 O WMRU #I- 1 Proposed WFU #2 Sudace Location WMRU #I-1 Sec. 22 ADL 359112 Stewa~ Pet. Co. Scale 1" = 1/2 mile West McArthur River Unit Unit Boundary Plat T8N, R14W, Seward Meridian I I ,I W. McArthur River Unit ADL 17602 Stewart Pet. Co. Unocal ADL 359111 I 4 3 2 1 8 9 10 11 2 WMRU #I- 1 Proposed BIlL 17 15 14 II W. McArthur River Unit Stewart Pet. Co. ADL 359112 i 20 21 ~ 22 23 24 29 28 7 26 25 [ Cook Inlet Bluff ~ 32 33 35 36 , . , . West McArthur River Unit Unit Boundary Plat T8N, R14W, Seward Meridian W. McArthur River Unit ADL 17602 Stewart Pet. Co. Unocal ADL 359111 II 4 $ 2 1 8 L 9 10 11 2 ?reposed 17 15 14 , , W. McArthur River Unit I Stewart Pet. Co. ADL 359112 I 20 21 22 23 24 29 28 7 26 25 Cook Inlet Bluff ',:~'-: .... · , , , , ', i% '. ~ ~'.'? i¢" ,?'. "~! 'i i':'~ ' ~ ~ 32 33 35 '.36~' . , .~ ... ! ..; ~.~ : , . · . . , . . . . . . . . . 10. 11. 12. 13. McArthur River Unit ~-I Sidetrack Drilling Program Move and rig up Nabors Rig #160. ND tree, NU 5000 psi BOPE. Drill out cement plugs and retainers at 410' and 1910'. Clean out 9-5/8" casing to 7500'. Pressure test integrity of existing casing. Set whipstock and mill out window in 9-5/8" casing at 7483' MD. Directionally ddll 8-1/2" hole to 7-5/8" liner casing point @ 11,059' MD. Run and cement 7-5/8" liner. (no logs at this point, cased hole GR will be run later) Ddll out 7-5/8'liner and 10' of new formation. Run formation integrity test. Ddll 6-3/4' hole to TD @ 11,972' MD/9830' TVD. Run and cement 5-1/2" liner. Run cased hole logs: GR/CET/CBT in 5-1/2" liner. Continue running GR log up to top of 7-5/8" liner. Perforate and run tubing completion for injection. Perform MIT on casing x tubing annulus with AOGCC representative prior to injection. 1 3/9/96 , . . . . , . . , 10. 11. 12. 13. McArthur River Unit ~-1 Sidetrack Drilling Program Move and rig up Nabors Rig #160. ND tree, NU 5000 psi BOPE. Drill out cement plugs and retainers at 410' and 1910'. Clean out 9-5/8" casing to 7500'. Pressure test integrity of existing casing. Set whipstock and mill out window in 9-518~ casing at 7483' MD. Directionally ddll 8-1/2" hole to 7-5/8" liner casing point @ 11,059' MD. Run and cement 7-5/8= liner. (no logs at this point, cased hole GR will be run later) Ddll out 7-518"liner and 10' of new formation. Run formation integrity test. Ddll 6-3/44 hole to TD @ 11,972' MD/9830' 'I'VD. Run and cement 5-1/2" liner. Run cased hole logs: GR/CET/CBT in 5-1/2" liner. Continue running GR log up to top of 7-5/8" liner. Perforate and run tubing completion for injection. Perform MIT on casing x tubing annulus with AOGCC representative prior to injection. 1 3/9/96 West McArthur River Unit #I-1 Pressure Information The following presents data used for calculation of anticipated surface presures (ASP) dudng ddlling of the West Mc, Arthur River Unit #1-1. The pore pressure gradient was estimated using a salt water gradient. This gradient is conservative when considering the most recent bottom hole pressure surveys at West McArthur River Unit*. The fracture gradient information was obtained from formation integrity tests below casing points on the West McArthur River Unit # 1, #2A and #3. WMRU #lA, P=3781 psi @ 9563' TVD (7.6 ppg EMW) from initial static BHP survey on 12/30/95. WMRU #1, P= 3442 psi @ 9563' TVD (6.9 ppg EMW) from static BHP survey pdor to reddll on 10/17/95. WMRU #3, P = 3680 psi @ 9563' TVD (7.4 ppg EMW) from initial static BHP survey on 7/2/95. Casing Pore Casing Setting Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressure Drilling (in.) (TVD ft) (Ibs/¢lal) (lbs/¢ial) (psi) (psi) 9-5/8 6974 15.0 8.4 3046 1491 7-5/8 9271 14.5 8.4 4050 1581 5-1/2 9830 8.4 4294 Procedure for Calculating Anticipated Surface Pressure ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with one-half evacuation (one-half gas gradient of 0.115 psi/ft and one-half mud gradient of 8.4 ppg), or 2) formation pore pressure at the next casing point less one-half gas gradient and one-half mud gradinet to the surface as follows: 1) ASP = (FGx.052xD) - (0.I 15x.5xD) - (.437x.5xD) 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 0.115 = gas gradient in psi/ft 0.437 = mud gradient (8.4 ppg) D = true vertical Depth of casing seat in ft RKB OR 2) ASP = FPP - (0.115xDx.5) - (0.437x.5xD) where: FPP = Formation Pore Pressure at the next casing point which is tied back to surface or at TD (total depth) West McArthur River Unit #I-1 Pressure Information The following presents data used for calculation of anticipated surface presures (ASP) during drilling of the West Mc, Arthur River Unit #1-1. The pore pressure gradient was estimated using a salt water gradient. This gradient is conservative when considering the most recent bottom hole pressure surveys at West McArthur River Unit*. The fracture gradient information was obtained from formation integrity tests below casing points on the West McArthur River Unit # 1, #2A and #3. WMRU #lA, P=3781 psi @ 9563' TVD (7.6 ppg EMVV) from initial static BHP survey on 12/30/95. WMRU #1, P= 3442 psi @ 9563' 'I'VD (6.9 ppg EMW) from static BHP survey pdor to reddll on 10/17/95. WMRU #3, P = 3680 psi @ 9563' TVD (7.4 ppg EMW) from initial static BHP survey on 7/2/95. Casing Pore Casing Setting Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressure Drilling (in.) (3'VD ft) (Ibs/.clai) (Ibs/.clal) (psi) /P_AJl 9-5/8 6974 15.0 8.4 3046 1491 7-5/8 9271 14.5 8.4 4050 1581 5-1/2 9830 8.4 4294 Procedure for Calculating Anticipated Surface Pressure ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with one-half evacuation (one-half gas gradient of 0.115 psi/ft and one-half mud gradient of 8.4 ppg), or 2) formation pore pressure at the next casing point less one-half gas gradient and one-half mud gradinet to the surface as follows: 1) ASP = (FGx.052xD) - (0.115x.5xD)- (.437x.5xD) 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 0.115 = gas gradient in psi/ft 0.437 = mud gradient (8.4 ppg) D = true vertical Depth of casing seat in ft RKB OR 2) ASP = FPP - (0.115xDx.5) - (0.437x.5xD) where: FPP = Formation Pore Pressure at the next casing point which is tied back to surface or at TD (total depth) West McArthur River Unit Well #I-1 Pressure Information ASP Calculations 1. Drilling below whipstock in the intermediate casing (9-5/8') ASP = (FGx.052xD) - (0.115x.5xD) - (.437x0.5xD) =(15.0x.052x6974) - (0.115x.5x6974) - (.437x.5x6974) = 3515 psi OR ASP = FPP - (0.115x.5xD) - (.437x.5xD) = 4050 - (0.115x.5x9271) - (.437x.5x9271) = 1491 psi 2. Drilling below liner (7-5/8") ASP = (FGx.052xD) - (0.115x.5xD) - (.437x.5xD) = (14.5x. 052x9271) - (0.115x.5x9271) - (.437x.5x9271) = 4432 psi OR ASP = FPP - (0.115x.5xD) - (.437x.5xD) = 4294 - (0.115x. 5x9830) - (.437x.5x9830) = 1581 psi West McArthur River Unit Well #I-1 Pressure Information ASP Calculations 1. Drilling below whipstock in the intermediate casing (9-5/8") ASP = (FGx.052xD) - (0.115x.5xD) - (.437x0.5xD) =(15.0x.052x6974) - (0.115x.5x6974) - (.437x.5x6974) = 3515 psi OR ASP = FPP - (0.115x.5xD) - (.437x.5xD) = 4050 - (0.115x.5x9271) - (.437x.5x9271 ) = 1491 psi 2. Drilling below liner (7-5/8') ASP = (FGx.052xD) - (0.115x.5xD) - (.437x.5xD) = (14.5x. 052x9271) - (0.115x.5x9271) - (.437x. 5x9271) = 4432 psi OR ASP = FPP - (0.115x.5xD) - (.437x.5xD) = 4294 - (0.115x.5x9830) - (.437x.5x9830) = 1581 psi Blowout Prevention Equipment Nabors Rig No. 160 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 (Hyddl) Iea 13-5/8' x 5000 psi wp ddlling spool with 2 ea 4' side outlets (choke and kill), HCR and manual valves on both choke and kill lines. 1 ea Iea 1 ea 1 lot BOP accumulator, Valvcon, 300 psi w/12 bottles, 180 gallons, and (1) 80 gallon Valvcon accumulator. Accumulator pump, Gardner-Denver Tdplex, Model PQ 172, air pump Model G7E. 8 bottles nitrogen backup. Valvcon, 6 station, remote control panel Thornhill Craver, automatic choke 3"- 10,000 psi with control choke panel Hydraulic pipe and fittings from manifold to BOP stack. Blowout Prevention Equipment Nabors Rig No. 160 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 (Hyddl) 1 ea 13-518' x 5000 psi wp ddlling spool with 2 ea 4" side outlets (choke and kill), HCR and manual valves on both choke and kill lines. 1 ea 1 ea 1 ea I lot BOP accumulator, Valvcon, 300 psi w/12 bottles, 180 gallons, and (1) 80 gallon Valvcon accumulator. Accumulator pump, Gardner-Denver Tdplex, Model PQ 172, air pump Model GTE. 8 bottles nitrogen backup. Valvcon, 6 station, remote control panel Thornhill Craver, automatic choke 3" - 10,000 psi with control choke panel Hydraulic pipe and fittings from manifold to BOP stack. Nabors Rig #160 13-5/8" 5000 psi BOP Stack 5000 psi Annular Preventer ! I 5000 psi Pipe Rams I I ~ Drilling ~ 3-118" Kill Line I 2 J Spool 2 1 I - HCRVaIve I 5000 psi Pipe Rams ! 2 = Gate Valve 13-5/8"x 11" 11" 5M Wellhead 9-5/8" I Casing 4-1/16" Choke Line Nabors Rig #160 13-5/8" 5000 psi BOP Stack 5000 psi Annular Preventer I I 5000 psi Pipe Rams I I 5000 psi Blind Rams 3-118" Kill Line I = HCR Valve 2 = Gate Valve Drilling Spool 5000 psi Pipe Rams 13-5/8"x 11 ' 11" 5M Wellhead 9-5/8" ! Casing 4-1/16" Choke Line Drilling Fluid System Description Nabors Rig No. 160 Mud Pumps 2 ea Continental Emsco F-1300 tdplex mud pumps 7" x 12", 1300 HP with (2) C-E pulsation dampeners, Model M822, each pump equipped with (2) 752 GE traction motors, cooled with ambient air. Each pump charged by a 5 x 6 Mission Magnum ! with 50 HP AC motor. Mud Tank System (1035 Total Volume) Tank #1 (shaker tank) appx. 270 bbls. Three compartments which include desander, desilter suction compartment and cuffing trap compartment equipped with shale shakers, degasser, poor boy degasser, and mud guns in top skidded section. Tank #2 (volume tank) appx. 460 bbls. One compartment equipped with desander, desilter, mud cleaner, mud guns and mud agitators in top skidded section. Tank #3 (suction tank) appx. 305 bbls. Three compartments, two of which are pill pits, 1 thru 65 bbls; one 55 bbi equipped with mud guns, mud agitators, mud mixing hopper, and chemical barrel in top skidded section. Mud System Equipment Iea 1 ea Iea 1 ea 4 ea 4 ea 1 ea 6 ea Derrick dual tandem shale shaker Ddlco degasser Picenco 16 cone desiiter Pioneer sidewinder mud mixer Brandt 7-1/2 HP mud agitators Mission Magnum pumps, 5' x 6' centrifugal with 50 HP GE Electdc Motors Pioneer desander, 2 cone, Model S-2-12 Dahlory 3" mud guns Drilling Fluid System Description Nabors Rig No. 160 Mud Pumps 2 ea Continental Emsco F-1300 triplex mud pumps 7" x 12", 1300 HP with (2) C-E pulsation dampeners, Model M822, each pump equipped with (2) 752 GE traction motors, cooled with ambient air. Each pump charged by a 5 x 6 Mission Magnum ! with 50 HP AC motor. Mud Tank System (1035 Total Volume) Tank #1 (shaker tank) appx. 270 bbls. Three compartments which include desander, desilter suction compartment and cutting trap compartment equipped with shale shakers, degasser, poor boy degasser, and mud guns in top skidded section. Tank #2 (volume tank) appx. 460 bbls. One compartment equipped with desander, desilter, mud cleaner, mud guns and mud agitators in top skidded section. Tank #3 (suction tank) appx. 305 bbls. Three compartments, two of which are pill pits, 1 thru 65 bbis; one 55 bbi equipped with mud guns, mud agitators, mud mixing hopper, and chemical barrel in top skidded section. Mud System Equipment 1 ea 1 ea Iea 1 ea 4 ea 4 ea Iea 6 ea Derrick dual tandem shale shaker Drilco degasser Picenco 16 cone desilter Pioneer sidewinder mud mixer Brandt 7-1/2 HP mud agitators Mission Magnum pumps, 5' x 6' centrifugal with 50 HP GE Electric Motors Pioneer desander, 2 cone, Model S-2-12 Dahlory 3" mud guns McArthur River Unit #lA Redrill Drilling Fluid Program Drillinq Liner Hole Section 7483'-11059 MD or 6974'-9271' TVD Hole size = 8-1/2" Casing Size = 7-5/8" Mud type = PHPA polymer Mud Parameters: Weight: 9.1-9.6 ppg Viscosity: 42-50 sec/qt pH: 8.0-9.0 PV: 10-20 YP: 12-25 Fluid Loss: <6 cc/30 min After setting the whipstock, mill out the 9-5/8' casing with a high yield point, non- dispersed bentonite mud sustem. After cleaning out the metal cuttings and drilling beyond any cement behind the 9-5/8" casing and into new formation, build a PHPA polymer system. Avoid drilling cement with the new PHPA system. Clean the remaining pits and fill with fresh water. Treat the fresh water with Soda Ash as required for hardness. Add 10-12 ppb bentonite and allow to properly hydrate. Add 0.75 ppb PHPA and do not add barite at this time. Continue PHPA additions until the complete system is treated with 0.75 ppb PHPA. Add sufficient polymer (0.5 ppb) until the Clapper Polymer test on the whole mud yields 0.4-0.6 ppb of available polymer. Because of potential cuttings bed problems, 10 minute gel stegths should be at 15-22 and 30 minute gels should be 25-30 which will indicate non-progressive gel structure. There may be siginificant viscosity increases as the polymer reacts initially with the native solids but additions should continue until you are over the "hump". Slight additions of Desco or Ligco will reduce the viscosity somewhat. Inspect the drill cuttings to help determine the proper polymer concentration. Sticky or visibly hydrated cuttings indicate iow polymer concentration. The Clapper Polymer Test is the most accurate method to determine proper polymer concentration and should be run at least every 2 days. McArthur River Unit #lA Redrill Drilling Fluid Program Ddllin,q Liner Hole Section 7483'-11059 MD or 6974'-9271' 'I-VD Hole size = 8-1/2" Casing Size = 7-5/8" Mud type = PHPA polymer Mud Parameters: Weight: 9.1-9.6 ppg Viscosity: 42-50 sec/qt pH: 8.0-9.0 PV: 10-20 YP: 12-25 Fluid Loss: <6 cc/30 min After setting the whipstock, mill out the 9-5/8" casing with a high yield point, non- dispersed bentonite mud sustem. After cleaning out the metal cuttings and drilling beyond any cement behind the 9-5/8" casing and into new formation, build a PHPA polymer system. Avoid ddlling cement with the new PHPA system. Clean the remaining pits and fill with fresh water. Treat the fresh water with Soda Ash as required for hardness. Add 10-12 ppb bentonite and allow to properly hydrate. Add 0.75 ppb PHPA and do not add barite at this time. Continue PHPA additions until the complete system is treated with 0.75 ppb PHPA. Add sufficient polymer (0.5 ppb) until the Clapper Polymer test on the whole mud yields 0.4-0.6 ppb of available polymer. Because of potential cuffings bed problems, 10 minute gel stegths should be at 15-22 and 30 minute gels should be 25-30 which will indicate non-progressive gel structure. There may be siginificant viscosity increases as the polymer reacts initially with the native solids but additions should continue until you are over the "hump". Slight additions of Desco or Ligco will reduce the viscosity somewhat. Inspect the drill cuttings to help determine the proper polymer concentration. Sticky or visibly hydrated cuttings indicate Iow polymer concentration. The Clapper Polymer Test is the most accurate method to determine proper polymer concentration and should be run at least every 2 days. West McArthur River Unit Well #I-1 Sidetrack Drilling Fluid Program If more viscosity is desired to clean the hole, Biozan can supplement the system. Utilize low viscosity-high viscosity sweeps to reduce cuttings bed formation. To reduce fluid loss, add starch at 3-4 ppb while adding PAC polymer at 1-1.5 ppb. This will assist the bentonite and native clays in suspending solids when not circulating. Monitor the HTHP filtration for an indication of cake formation and compressibility. Adding an acrylamide and alkali salt will help stabilize the APl filtrate and improve the HTHP values to less than 12 cc/30 min. Supplementing the PHPA polymer with a 4 ppb blend of Bore-Plate will provide maximum shale stabilization especially as the Cook Inlet coal intervals are encountered. To smooth out rheological properties, add a Iow moecular weight polyacrylate thinner works which will not disperse the solids. Mud weights should be kept Iow by running all solids control equipment to their maximum efficiency. Run a minimum of 200 mesh screens on the mud cleaners to give maximum cut. A Iow gravity solids of less than 7% is required for optimum performance of this system. Dilution or complete displacement should be considered if higher LGS contents persist. West McArthur River Unit Well #I-1 Sidetrack Drilling Fluid Program If more viscosity is desired to dean the hole, Biozan can supplement the system. Utilize low viscosity-high viscosity sweeps to reduce cuttings bed formation. To reduce fluid loss, add starch at 3-4 ppb while adding PAC polymer at 1-1.5 ppb. This will assist the bentonite and native clays in suspending solids when not circulating. Monitor the HTHP filtration for an indication of cake formation and compressibility. Adding an acrylamide and alkali salt will help stabilize the APl filtrate and improve the HTHP values to less than 12 cc/30 min. Supplementing the PHPA polymer with a 4 ppb blend of Bore-Plate will provide maximum shale stabilization especially as the Cook Inlet coal intervals are encountered. To smooth out rheological properties, add a Iow moecular weight polyacrylate thinner works which will not disperse the solids. Mud weights should be kept Iow by running all solids control equipment to their maximum efficiency. Run a minimum of 200 mesh screens on the mud cleaners to give maximum cut. A Iow gravity solids of less than 7% is required for optimum performance of this system. Dilution or complete displacement should be considered if higher LGS contents persist. West McArthur River Unit Well #I-1 Sidetrack Drilling Fluid Program Production Liner Hole Section 11,059'-11,972' MD or 9271'-9630' TVD Hole size = 6-3/4' Casing Size = 5-1/2" Mud type = PHP^ polymer Mud Parameters: Weight: 9.4-9.6 ppg Viscosity: 42-50 sec/qt pH: 8.0-9.0 PV: 10-20 YP: 12-25 Fluid Loss: <6 cc/30 min Bump the plug on the 7-5/8' liner with the PHPA mud treated with Bicarb to offset cement contamination. The fluid system will already be established from the previous hole section. Eliminate the PAC polymer for filtration control and use starch and acrylamide/aikali salt. This will also enhance the lubricity of the fluid along with a glycol lubricant. After drilling out the cement, have the PHPA concentration at .6-.75 ppb and Bore-plate at 4.0 ppg. The APl filtrate should be less than 6.0 cc. The glycol lubricant should be kept at 3% to provide iubricity for the high angle wellbore. Maintain rheological properties on the high side to prevent particle settlement and pump regular high viscosity/low viscosity sweeps. Keep the mud weight as Iow as possible because unnecessary solids have detrimental effects on the polymers. West McArthur River Unit Well #I-1 Sidetrack Drilling Fluid Program Production Liner Hole Section 11,059'-11,972' MD or 9271'-9630' TVD Hole size = 6-3/4" Casing Size = 5-1/2" Mud type = PHPA polymer Mud Parameters: Weight: 9.4-9.6 ppg Viscosity: 42-50 sec/qt pH: 8.0-9.0 PV: 10-20 YP: 12-25 Fluid Loss: <6 cc/30 min Bump the plug on the 7-5/8' liner with the PHPA mud treated with Bicarb to offset cement contamination. The fluid system will already be established from the previous hole section. Eliminate the PAC polymer for filtration control and use starch and acrylamide/alkali salt. This will also enhance the lubricity of the fluid along with a glycol lubricant. After drilling out the cement, have the PHPA concentration at .6-.75 ppb and Bore-plate at 4.0 ppg. The APl filtrate should be less than 6.0 cc. The glycol lubricant should be kept at 3% to provide lubricity for the high angle wellbore. Maintain rheological properties on the high side to prevent particle settlement and pump regular high viscosity/low viscosity sweeps. Keep the mud weight as Iow as possible because unnecessary solids have detrimental effects on the polymers. AnadrilI Schlu,~erger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for STEWART PETROI,~[~ COMPANY well ......... : WMR U#I-1 (Pl) Field ........ : West McArthur River Computation..: Minimum Curvature Units ........ FEET Surface Lat..: 60.78249688 N Surface Long.: 151.74669450 W LOCATIONS - ALASKA Zone: 4 Legal Description X-Coord Y-Coord Surface ...... : 20.t7 FSL 3327 FEL 816 T08N R14W SM 187857.34 2482093.96 Tie-in Survey: 2325 FSL 888 FEL S16 T08N R14W SM 190302.43 2482306.92 TARGET ....... : 3780 FSL 3500 FEL S15 T08N R14W SM 193005.80 2483691.66 BM! ........... : 3977 FSL 3162 FEL S15 T08N R14W SM 193349.09 2483879.98 Prepared ..... : 03/07/96 Vert sect az.: 59.72 KB elevation.: 130.00 ft Magnetic Dcln: +0.000 (E) Scale Factor.: 1.00001087 Convergence..: -1.52458087 PROPOSED WELL PROFILE STATION IDENT I FI CAT ION TIE-IN SURVEY TOP OF W£NDOW KOP / CUR_VE 2.5/100 MEAS INCLN DIRECTION VERT-DEPTHS SECT DEPTII ANGLE AZIMUTH TVD SUB-S DIST ................ ~ ~ ~ ~ 7400 24.75 ~6.00 6899 6769 2246 7483 24.33 76.00 6974 6844 2279 7488 24.31 76.00 6979 6849 2281 7580 24.58 75.69 6990 6860 2286 ';600 26.86 73.33 7080 6950 2328 7700 29.18 7800 31.52 7900 33.88 8000 ~6.25 8100 38.65 COORDINATES ~ FROM STATE- PT~dqE TOO[, DL/ WELLHEAD X Y FACE 100 277.93 N 2438.54 E 190302.43 2482306.92 LS <TIE 286.27 N 2471.99 E 190336.10 2482314.36 LS 0.50 286.77 N 2473.99 E 190338.11 2482314.81 26L 0.50 287.98 N 2478.80 E 190342.95 2482315.89 25L 2.5~ 299.61 N 2520.60 E 190385.05 2482326.40 23L 2.50 71.31 7168 7038 2374 313.90 N 2565.34 R 190430.15 2482339.50 21L 2.50 69.57 7255 7125 2423 330.84 N 2612.93 E 190478.1.8 2482355.16 20L 2.50 68.05 7339 7209 2477 350.38 N 2663.29 E 190529.03 2482373.36 19L 2.50 66.70 7421 7291 2534- 372.50 N 2716.30 g 190582.62 2482394.06 lTL 2.50 65.50 7500 7370 2594 397.14 N 2771.88 E 190638.84 2482417.22 lTL 2.50 8200 41.05 I/madrill (c)96 WMRIIPI 3.01',.02 4:09 PM P) 64.42 7577 7447 2658 424.27 N 2829.92 E 19069'1.58 2482442.79 16L 2.50 Anadrill Schluu~erger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for STEWART PETRO[,RI~ COMPANY Well ......... : WMR U#I-1 (Pl) Field ........ : West McArthur River Computation..: Minimum Curvature Units ........ : FEET Surface Lat..: 60.78249688 N Surface Long.: 151.74669450 W LOCATIONS - ALASKA Zone: Legal Description X-Coord Surface ...... : 2047 FSL 3327 FEL Tie-in Survey: 2325 FSL 888 FEb TARGET ....... : 3780 FSL 3500 FEL BM[ ........... : 3977 FSL 3162 FEL 4 Y-Coord El6 T08N R14W SM 187857.34 2482093.96 S16 T08N R14W SM 190302.43 2482306.92 S15 T08N R14W SM 193005.88 2483691.66 S15 T08N R14W SM 193349.09 2483879.98 PROPOSED WELL PROFILE STATION MEAS IDENTIFICATION DEPTII T'IE-IN SURVEY 7400 TOP OF WINDOW 7483 KOP / CUI~.VE 2 5/100 748~ ' 7500 '~600 INCLN DIRECTION VERT-DEPTHS SECT ANGLE ;LZIMUTH ~ SUB-S DIST 24.75 ~6.00 6899 6769 2246 24.33 76.00 6974 6844 2279 24,31 76.00 6979 6849 2281 24.58 75.69 6990 6860 2286 26,86 73.33 7080 6950 2328 7700 29.18 7800 31,52 7900 33.88 8000 36.25 8100 38.65 8200 41 .05 71.31 7168 7038 2374 69.57 7255 7125 2423 68.05 7339 7209 2477 66.70 7421 7291 2534' 65.50 7500 7370 2594 64.42 7577 7447 2658 {Anadrill (c)96 WM. RI1PI 3.0D.02 4:09 PM P) CooRDINATES-FROM WELLHEAD 277.93 N 2438.54 286.27 N 2471.99 286.77 N 2473.99 287.98 N 2478.80 299.61 N 2520.60 313.90 N 2565.34 E 330.84 N 2612.93 E 350.38 N 2663.29 E 372.50 N 2716.30 E 397.14 N 2771.88 E 424,27 N 2829.92 · . 0"! ....... :.- ~ ,,.~ .: ~ '-''·" .... ,' .~: I '"~ 0 R ........ ,--U.T,:-~N PLAN ~-~ ~ Prepared ..... : 03/07/96 Vert sect az.: 59.72 KB elevation.: 130.00 ft Magnetic Dcln: +0.000 (E) Scale Factor.: 1.00001087 Convergence..: -1.52458087 STATE-PlJ~NE TOOl, DL/ X Y FACE 100 190302.43 2482306.92 LS <TIE 190336.10 2482314.36 LS 0.50 190338.11 2482314.81 26L 0.50 190342.95 2482315.89 25L 2,50 190385.05 2482326.~0 25L 2.50 190430.15 2482339.50 21L 2.50 190478.1.8 2482355.16 20L 2.50 190529.03 2482373.36 19L 2.50 190582.62 2482394.06 lTL 2.50 190638.8~ 2482417.22 17L 2.50 190697.58 2482442.79 16L 2.50 STATION IDENTIFICATION END CURVE 2.5/100 DROP 2/100 TARGET MEAS DE PTtl 8300 8400 8500 8600 8700 8775 11459 ].1459 11500 11600 11700 11800 11900 11972 INCLN ANGLE 43.46 45.88 48.30 50.73 53.17 55.00 55,00 55.OO 54.18 52.18 50.18 48 18 46.18 44.74 DIRECTION AZIMUTH ....... ~ 63.44 62.54 61.71 60.94 60.23 PROPOSED WELL PROFILE VERT-DEPTHS SECT TVD SUB-S D/ST 7651 7521 2725 7722 7592 2795 7790 7660 2868 7855 7725 2944 7916 7786 3~23 Page 59,7~ 7960 7830 3084 59.72 9500 9370 5282 59.72 9500 9370 5282 59.72 9524 9394 5316 59.72 9584 9454 5396 59.72 9646 9516 5474 59.72 9712 9582 5549 59.72 9780 9650 5623 59.72 9830 9700 5674 COORDINATES-FROM WELLHEAD X 453.83 N 2890.31 E 190758.73 485.77 N 2952.93 E 190822.18 520.02 N 3017.67 E 190887.80 556.52 N 3084.39 E 190955.48 595.20 N 3152.98 E 191025.07 PLANE TOOL DL/ Y FACE 100 2482470 · 74 15L 2 . 50 2482500.99 14L 2.50 2482533.51 ].4L 2,50 2482568.22 13L 2.50 2482605.06 1RL 2.50 625.S5 N 3205.50 E 191078.38 1734.10 N 5104.16 E 193005.88 1734.10 N 5104.16 E 193005.88 1750.96 N 5133.03 E 193035.19 1791.31 N 5202.15 E 193105.36 2482634.01 2.50 2483691.66 LS 0.00 2483691.66 LS 0.00 2483707.74 LS 2.00 2483746.24 LS 2.00 1830.59 N 5269.43 E 193173.66 1868.75 N 5334.78 E 193240.00 1905.73 N 5398.11 E 19~304.3~ 1931.49 N 5442.23 E 193349.09 2483783.72 LS 2.00 2483820.12 LS 2.00 2483855.40 LS 2.00 2483879.98 2.00 tAnadr~ll (c)96 WMRI!P) ~.Ob. O2 %:t)9 PM /e) I ,~ I I , ANA,. ,.., t.~_ I.,,,A. DFC FE/'.cl ! L!TY PLAN NOT ".. r,r.,p, rh\/c; FOR E::<ECUTiON PLAN STATION IDENTIFICATION END CURVE 2.5/100 DROP 2/100 TARGET 03/07/96 Page PROPOSED WELL PROFILE MEAS INCLN DIRECTION 'VERT-DEPTHS SECT DEPTH ANGLE 8300 43.46 8400 45.88 BS00 48.30 8600 50.73 8700 53.17 COORDINATES-FROM STNPE-PLANE TOOL DL/ AZIMUTH TVD SUB-S DIET WELLHEAD X Y FACE 100 63.44 7651 7521 2725 453.83 N 2890.31 E 190758.73 2482470.74 15L 2.50 62.54 7722 7592 2795 485.77 N 2952.93 E 190822.18 2482500.99 14L 2.50 61.71 7790 7660 2868 520.02 N 3017.67 E 190887.80 2482533.51 1.4L 2.50 60,94 7855 7725 2944 556.52 N 3084.39 E 190955.48 2482568.22 13L 2.50 60.23 7916 7786 3D23 595.20 N 3152.98 E 191025.07 2482605.06 1~1, 2.50 8775 55.00 11459 55.00 11459 55.00 11500 54.18 11600 52.18 59.72 7960 7830 3084 625.55 N 3205.50 E 191078.38 2482634.01 2.50 59.72 9500 9370 5282 1734.10 N 5104.16 E 193005.88 ~483691.66 LS 0.00 59.72 9500 9370 5282 1734.10 N 5104.16 E 193005.88 2483691.66 I,S 0.00 59.72 9524 9394 5316 1750.96 N 5133.03 E 193035,19 2483707.74 LS 2.00 59.72 9584 9454 5396 1791.31 N 5202.15 E 193105.36 2483746.24 LS 2.00 13700 50~18 11800 48 18 11900 46.18 11972 44.74 59.72 9646 9516 5474 1830.59 N 5269.43 E 193173.66 2483783.72 LS 2.00 59.7~ 9712 9582 5549 1868.75 N 5334.78 E 193240.00 2483820.12 LS 2.00 59.72 9780 9650 562~ 1905.73 N 5398.11 E 193304.30 2483855.40 I,S 2.00 59,72 9830 9700 5674 1931.49 N 5442.23 E 193349.09 2483879.98 2.00 [&nadril] t,c)96 WMRI!Pl 3.Ob 02 ~:L~9 PM P) AN/t.,. ,.,, [.,. ~,,,.: .-DFC PLAN NOT FOR It ~V ~ ~..~.1 E,.', :CUTiON PLAN AnaOr~ 11 $ch ~umberger WNR U#I- (P1) PLAN VIEW CLOSURE ..... · 5775 feet at Azimuth 70.46 DECLINATION.' ~0.000 (E) SCALE ....... · ~ ~nch = BO0 feet ...... · 03/07/96 STEWARTPETROLEUM ~arker ]'dent i t icat ion ~D N/S [/~ A) TIE-IN SURVEY 7400 278 N 2439 E B) TOP ¢ WINDOW 7463 286 N 2472 E C) KDP / CURVE 2.5/100 7480 287 N 24/4 E D) END CURVE 2.5/100 8775 626 N 3205 E E) DRI3P 2/100 11459 1734 N 5104 E F) TARGET t14§9 1734 N 5104 E G) TO 11972 1931 N 544~ E COMPANY ANADR~! t AKA-DPC FEASIr"ILITY'...,. PLAN NOT APPROVED FOR E><ECUTION PLAN 400 ;) 400 <- WESI ' EAST > [¢l~16 W~IIPl 3.00.02 4: I! {~ P) BOO 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 li(X)O 6400 bBP. I) ~- · .... _, il_ i Ana~f' J 11 .clc'h lumberger ,__ i i i i iiii ...... - ~= - .... WNR U#I.-1 lPg) PLAN VIEW ............ , ~1 i_ , ~m - _ CLOSUAE · 5775 feet aL Azimuth 70.46 DECL IN, lION.' ,0.000 SCALE ' ~ inch = ilO0 feet DgAWN '03/07/06 STEWART , , ,, , ,, PETROLEUM I~arker ]dent i t icat ion ND N/S r/i~ Aj fIE-IN SURVEY 7400 270 N 2439 B) TOP OF WINDOW 74B3 2B6 N 2472 CJ KOP / CURVE 2.5/100 7488 287 N 24/4 O) END CURVE 2.5/~00 8775 626 N 3205 E) ~ ~/I00 J1459 J734 N 5104 F) TARGET ~459 ~734 N 5~04 6} ID lJ972 ~931 N 5442 ANAD"n'~! t AKA-DPC FEAS i P ~ LI T¥_:. PLAN NOT/~,PPROVfD FOR EXECUTION PLAN-~1 ........................................... ~ ................. i .........i ............. 4 ...... f ..................................... I ......... ~ . i . i "?':J ~,:' I I I ''f' t;. , ! ",;- :" .... ': i : ' " .... , . ?' '::' ! ~ I i" ':' '?'- ' j .,,, , ' :'_,': . /i:.. ': .... i -' ' :i.', "'- ': I '. · : · '..:..' i .~¢~ ; , '..' ............. ~ ~ 'h ..... ~ "' -~ .......... I · · _, .. _ _ _., _ ~ _.L ; : ~ ! ,- .... ~ . .~ · 400 ;) 400 §00 12{)0 1600 ~OOO 2400 2800 3200 3600 4000 4,400 ~d800 5200 5riO0 60{10 6400 bHP, O <- WESI · EA$I > ,, . i i i ~ .! . m _ - , -, .._. ~! ~ ! ~= . , . · , Mar'-O7-g6 17:36 A*--'-~dt-ill DPC 7 344 2160 P.O5 ' ' STEWART PETROLEUM COMPANY i ii i i i iii · mi mmm III Im I i ~ I[ VERTICAL SECTION VIEW iI Section at: 59.72 ~,, il i ,i ! fro Scale · i ~ncn : 600 feet --* ' ' I .I Del;) $ca)e.' ! inch : 600 feet · , i I i ' ' ') Drawn · 03/07/96 ' I ' i .... I '- ~~ ' ~ "~ ................ ' ~ , Anadrd]] Schlumberger ~ - Marker Identification MD BK8 SECfN i '~ ' , j ~] TIE-ZN S~VEY 7~00 6Bgg 2246 2~.75 ~ [ ) B) TOP ~ WINDOM 74B3 6974 2879 ~ ~ I ~ ) ' C] KOP / CURVE 2.5/10D 7~ 6g7g 22Bt 24 3t ........ { ..... ",~ '-( - - ~ --~ P (O) END ~RVE e.5/tOC 87~ 7960 3084 55 ' , % ' I ~ E) mOP 2/t00 &t4sg 9500 5~8~ 55.00 · ~.~ ~ ~ F) TARGET ' ~1459 gSO0 52B2 55.00 -- i '~, ~ I ! G)TO ltg72 9830 5674 4~.74 ! - ~ ~ ,-r ..... i ~ ,~ ............. +. . ~ ...... ~ .... I ................. r i ~. , ~ i . I ' ~ , . I ~ I ' A . I & , ii ,~ ~ ~ F'-....... , ..................... ~ ,. i' ,~ ~ , '~ ..... ~ ............ ~ _ ' 'i i , ' ~.--,,'-.~.~" .... : i dFC , . ~ , i' "", . I ~' i r:.. ,. i ~- ~-C~ ~"~' ...... J ............. I ~. ., ~ -~ ~-.- 105OO- 10800 - 1!400 , 2000 2300 2500 2ciO0 3200 3520 3BO( 410(3 44C0 4700 5000 5300 5600 5903 6200 Section De )arture i i . Ma~-07-g6 17:36 A~nad~ill DPC D7 344 2160 P.05 ! STEWART PETROLEUM COMPANY' I ' ii iii i i m I · i m ii i i , U#I- ~oo i i ! 'i I VERTICAL SECTION VIEW ~ ~ i ) Section at: 59.7~ ' · , fVD Scale · ! inch = 600 feet , I I ,Dep Sca)e' ! inch = 600 feet ', i i , i I Drawn ..... · 03/07/96 ...... ~ "i ............... ~ · imm ~oo-- ~+~(~ ' ' ~ ~na~rd ] ] Sc~ ]umberger ! I i , I i - Marker Identification MD BK8 SECTN ]IICLN 7~o I ,. i '~ , , i ~ TIE-IN S~VEY 7aO0 6899 2246 2~.75 I %~ i BI TOP ~ WINOOM 7463 6974 2279 7500 ........ )-----'~% "~" ~ 'i O)END~RVE 2.5/100 87~ 7960 3084 550C I ~ E) ~OP 2/mO ~taSg 9500 50B2 5b.O0 ~ ) Fl TARGET lia59 9500 5262 55.00 ; ' .{ {, G)TD ,t972 9830 5674 4~.74 , . , ' ) m ,. % , I ~ { TARGET 9900- - { ................. :, - ) G , . .. , { ' ~ { ' ' ' ~ """-' i'- ~'::~ { K..q.~c ~ { ,~-- { ................... '~ ............. = 5~.A' ~' { tTY--P - . - , ==- ._AN { ~o8~ ~ ~ :' ', i r:, .~7C, '~' · %' I ~:co~ ............... ~ ...... ~ _ i~ - .. ~ ~,~-- _. , i i I ~ { i ! 2000 230C 2500 2900 3200 3500 3800 4100 4400 4700 5000 5300 5600 5903 6~00 Sectzon Departure m m WFU #2 P&A 9/14/66 20" 79.6:~ @ 655' MD '~ 13-3/8" 54.5# @ 2001' MD ,~ Cmted w/1710 sx | . ! Calc TOC at 362' DC Retainer @ 410' wi100 sx Calc TOC @ 1886' DC Retainer @ 1910' wi50 sx 9-5/8' 40 & 43.5~ @ 9083' MD Cmtd w/2130 sx 7" liner top @ 8850' Hole in liner at 10,298'sqzed wi200 sx HDC Ret @ 10,555' MD wi50 sx DST Perfs. 10,600-10,670' BP @ 11,200' MD wi50 sx DST Perfs. 11,340'-11,385' 7'" @ 11,948' MD 11,019' TVD RKB = 130' above sea level RKB = 17' above Ground Level Ave Hole Angle = 25 degrees WFU #2 P&A 9/14/66 20" 79.6:~ @ 655' MD ,~¢ 13--3/8" 54.5~ @ 2001' MD ,~ Cmted w/1710 sx Calc TOC at 362' DC Retainer @ 410' wi100 sx Calc TOC @ 1886' DC Retainer @ 1910' wi50 sx 9-5/8' 40 & 43.5~ @ 9083' MD Cmtd w/2130 sx Hole in liner at 10,298'sqzed wi200 sx HDC Ret @ 10,555' MD wi50 sx DST Peris. 10,600-t0,670' BP @ 11,200' MD wi50 sx DST Perfs. 11,340'-11,385' 7" @ 11,948' MD 11,019' TVD RKB: 130' above sea level RKB: 17' above Ground Level Ave Hole Angle = 25 degrees Form P-~? SUBMIT LN DL~PLICATE' STATE OF A~ASKA tSe, otherlu- itr~ct ;one on revell~ iJde)' OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETiON REPORT AND LOG* Effecttve: Ju/y 1. 1964, ADL- 01804 6. IF INDIAN, ALLOTTEE Oa TRiflE NAME TYPE OF WELL= . OIL w,L~ WELL [~ D.r ~ aa, er ~ACK NAME OF OI~EHATO]~ Pan American Petrolenm Corporation Box 779 Anchorage;' Alaska 99501 '" 7. UNIT AOHEEM&NT NAME West Foreland Urd. t '6. FARM O0, LgAB~ NAMB West Foreland Unit ~. wE,~- NO. 2 10. FIELD AND POOl,,, OB WILDCAT Wildcat At la.ace 2~7' FSL, 1953' FI~, Sec. 16, TSN, ~41f~ S.I-L At ~P pr~ inte~ re~rt~ ~low 11. s£c.. T., a., M., Oa sLaCK AND sunveT Sec. 15, T8N, R141f, $.I.L 12. BOROUGH . I 13. STATS KenaiI Alaska TYPE E~CTRIC AMD OTHE~ IA)G8 RUN IES, Dip~eter, ,Sonic, Density, ~-[L. 27. WA8 WELL COB~D . · · 2S. CASING RECORD (Report ~ll at~nga act in ~ell) CASINO ~1~ WEIGHT, LB./FT. DEPTH 5ET (MD) 79.6 646 13-3/8" 54.5 2001 9-5/8" 40 & 43.5 9083 29. LINER RECORD s=n TO. (am) BOTTOM (~.) 8850 3_1938 71, }IOLB SIZE / CEMZNTINO RI;CORD ~ ~I~N~ ~;~F~ ~ 17 ' I171o sx /c cz / SACKS Cg~[g~T* SCREEN (HO) S~= OZ~TH atT (MD) D) 700 31. PEa~'Oa. ATION B[¢OaD (Interval, ~e and number) 11~40-Ll~85, 10600-10S?0~ re~rf 10600- 10S?0~ re~erf 10610-10~60, ~l w£th 4 Abrasi-~et ?" cumin§ at 10~650 with 50 32. ACID, SItOT. FRACTURE. CE~HENT SQUEEZE. ETC. DEPTH '~NTERVAh (MD) 1024~ - 10298 10610- 10660 AMOUNT AND KIND or MATERIA~ 200 sx cement squeeze 12.50 gal. 15% a~id 33.' PRODUCTION ..............I ~ ~hut.in) 9/11/68 13 ~n. ~' ,,,, ,,~,o~ --.~.. :::~.;.~ ?:/:~-::::..: ..-. ':,,' ;~ · I -' 34. DISm)aITIOI~OrO~ (~old,~edlof,$ael, vc'~ted, ego.) ....... ,~i:';~i~. ] TInT WlIN/aagD mX .... '.': · IES, Hud Log, Dire~ional data, Yell ttisto~, .'::.::~::-.':: " 36. I here~y certify that the foregoing and attached information is complete and correct as determined from all available records SIGNED TITLE o~TE111016_0._____6 *(See Instructions an~ ~paces lot Additional Data on Reveme Side) ¥orm P--7 SUBMIT LN DI/PLICATE' STATE OF ALASKA tS,,oth,rp~- str~¢t~ofl8 on OIL AND GAS CONSERVATION COMMISSION r.'..,'~ ,id,el' WELL COMPLETION OR RECOMPLETION REPORT AND LOG* TYPE OF WELL: . OIL ' ~m:t ~er~.can Petrol. em Corporation ADDRESS OF OPE~KATOR_ Box 779 Anchorage;' Alaska 99501 '" sub&ce 2~7' FSL~ 1953' FI~, Sec. la, TaN, ~41'I, S.H. top pr~ inte~ re~rt~ ~low ~c tot~ dep,~2209, FNL, 835' ~{L, Sec. 15, TaN, R14U, S.}[. J1~. PERMIT NO. DATE ISSUED Effective: Ju2y 1. 1964 ~. L~ASg DrBIONATION AHD aERIAL NO. ADL- 01804 ~. IF INDIAN, ALLOTTEE O~ TRIBE NAME UNIT AOREEMENT NAME West Foreland Unit FARM O~Z LgA~a NAM~ West Foreland Unit WE,J- NO. 2 lO. FISLD AND POOI~ OK WILDCAT Wildcat 11. a£C.. T,, R., M., Ol& BLOCK AND SURVEY BHLO:~ ,R,, Sec. 15, TaN, R141~, S.}I. 12. BOROUGH 13. STATn Kenai Alaska 5/25/66 8/28 66 PJ(B 130' above SL ..... · 4. PRODUCING INTIHYAL(S)~ OF THIS COMPLETION--TOP, BOITOM, NAIIE (.MD A.'4D T~D)* 2[. WAS DIRECTIONA~ ' ' ." 8U~VET 2fi. T~PE EI~CTRIC AND OTHER LOGS R0N IES, Dipmeter, Sonic, Density, J27. WAS WELL CORED rio 23. CASING RECORD (Report all ~tring~ ec~ ~ well) CASINO sl~ WI~IOHT, LB./~T. DEPTH SET (MD) 2(~' 13-3/8" 9-5/8" 79.6 40 & 43.5 646 2001 9083 29. LINER RECORD 711 8850 11938 SACKS 700 SCREEN 30. al. PERFORATION RECORD (Interval, ~e and number) 11340-11385, 10600-10670, reperf 10~00- 10670, reperf 10610-10660, all ~ith 4 Abrasi-jet 7" c~sing at 10,650 with 50 ax sand. 32. ACID. SIIOT. FRACTURE. CEMENT SQUEEZE. ETC. D£PTH '~NTERVAL (MD) 10248 - 10298 10610- 10660 AMOUNT AND KIND OF MATERIAL USED 200 ax cement squeeze ~250 gal. 15% acid · 33.' PRODUCTION DATa FIRaT PaoDucTz0N .............. [ PaovucTloN McTHOD (Flosoing, gaa lilt, pumping---~i~e and typs o] p~mp) J WZL~. STATUS (Producing Or ~hut.ln) 34. DISI~381TXON or o~s (8old, t~ed ~oe Suel, verged, eta.) ....... ] TEaT WITNESBZD IX -: ' 35. LI~T OF A~AC~M~NT~ 1ES, Hud Log, Dire~ional data, l;ell }{[sto~~ " 3& I herel)y e~rr. ffy that the foregoln~ and at~ached information is complete and correct aa determined from all available records SIGED - TITLE DATE1/10/ *(See Instructions and Spaces Jar Additional Data on Reyerse Side) WMRU #I-1 Proposed Sidetrack 20" 79.6# @ 655' MD ~' 13-3/8" 54.5# @ 2001' MD ~. Cmted wi1710 sx Cement Plug: 8600'-8900' 9-5/8" 40 & 43.5# @ 9083' MD Cmtd w/2130 sx HDC Ret @ 10,555' MD wi50 sx DST Perfs. 10,600-10,670' BP @ 11,200' MD wi50 sx DST Perfs. 11,340'-11,385' 7" @ 11948' MD 11O19' TVD Top of 7-5/8" liner @ 7283' MD @ 7483' MD *~'7-5/8" liner @ 11059' MD 9271' TVD ~l~ 5-1/2~ liner @ 11972' MD 9830' TVD WMRU #I-1 Proposed Sidetrack 20" 79.6# @ 655' MD "~ 13-3/8" 54.5g @ 2001' MD ~. Cmted w/1710 sx Top of 7-5/8" liner @ 7283' MD Top of Sidetrack Window @ 7483' MD Cement Plug: 8600'-8900' 9-5/8" 40 & 43.5# @ 9083' MD ,~. Cmtd w/2130 sx HDC Ret @ 10,555' MD wi50 sx DST Perfs. 10,600-10,670' BP @ 11,200' MD wi50 sx DST Perfs. 11,340'-11,385' .,, :::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::: 7"@ 11948' MD ~¢J 11019' TVD ~a'.7-5/8' liner @ 11059' MD 9271' TVD ~. 5-1/2' liner @ 11972' MD 9830' TVD West McArthur River Unit #lA Redriil Cementing Program 7-5/8" Ddllinq Liner 8-1/2" hole @ 11,059' MD, top of liner at 7283' MD Cement volume for liner based on 1000' of fill-up above shoe: 1000' x 0.077 cuft/ft (8-1/2" x 7-5/8") x 1.50 excess = 115 cuff Cement = 15.8 ppg Class G 5-1/2" Ddllinc~ Liner 6-3/4" hole @ 11,972' MD, top of liner at 10,859' MD Cement volume for liner based on caliper hole volume plus 25%, liner lap, and shoe joints. Estimated volume is: 913' (11,972' - 11,059') x 0.0835 cuff/ff (6-3/4" x 5-1/2") x 1.25 = 95 cuff 200' liner lap @ 0.0928 cuft/ff x 200' = 20 cuff 80' shoe jts x 0.1305 cuft/ft (5-1/2" liner capacity) = 10 cuff 95 + 20 +10 = 125 cuff Class G cement @ 15.8 ppg West McArthur River Unit #lA Redrill Cementing Program 7-5/8" Ddllinq Liner 8-1/2" hole @ 11,059' MD, top of liner at 7283' MD Cement volume for liner based on 1000' of fill-up above shoe: 1000' x 0.077 cuft/ft (8-1/2" x 7-5/8") x 1.50 excess = 115 cuff Cement = 15.8 ppg Class G 5-1/2" Ddllinq Liner 6-3/4" hole @ 11,972' MD, top of liner at 10,859' MD Cement volume for liner based on caliper hole volume plus 25%, liner lap, and shoe joints. Estimated volume is: 913' (11,972'- 11,059') x 0.0835 cuft/ff (6-314" x 5-1/2") x 1.25 = 95 cuff 200' liner lap @ 0.0928 cuft/ft x 200' = 20 cuff 80' shoe jts x 0.1305 cuft/ft (5-1/2" liner capacity) = 10 cuff 95 + 20 +10 = 125 cuff Class G cement @ 15.8 ppg West McArthur River Unit #lA R-edrili Casing Design 9-5/8" Intermediate Casing, L-80, BT&C (Already in place in WFU #2) Burst = (9830x.437) - (. 115x.5x9830) - (.437x.5x9830) = 1581 psi f/drlg to TD w/1/2 column of gas, 1/2 column 8.4 ppg mud 40~ & 43.5# from surface to 7483' MD/6974' TVD whipstock point 1/2 evacuation to gas, 1/2 remaining 8.4 ppg mud weight 40# rated @ 5750 psi for burst Safety Factor = 3.6 OK Collapse= (6974x.437) - (. 115x. 5x6974) -(.437x. 5x6974) = 1123 psi for 1/2 evacuation 40~ rated @ 3090 psi for clpse Safety Factor = 2.8 OK 7-5/8" 29.0#1 L-80, STL liner ~ 11,059' MD, 9271' TVD (Top of liner ¢. 7283'} Tension = (11059'-7283') x 29.0~ = 110K Rated = 444K for joint Safety Factor = 4.0 OK 1/2 evacuation to gas, 1/2 remaining 8.4 ppg mud weight Burst = (9830x.437) - (.115x. 5x 9830) - (.437x.5x9830) = 1581 psi fl drlg to TD with 1/2 evacuation Rated 6890 psi for burst Safety Factor = 4.4 OK N/A for liner Collapse= (9271x .437) - (9271x. 115x.5) - (9271x.437x.5) = 1493 psi for 1/2 evacuation Rated 4790 psi for collapse Safety Factor = 3.2 OK 5-1/2" 17#, L-80, STL liner ~ 11,972 MD, 9830' TVD (Top of liner ¢. 10,859' MD) Tension = (11972'-10859') x 17#= 19K Rated = 248K for joint Safety Factor = 13 OK 1/2 evacuation to gas, 1/2 remaining 8.4 ppg mud weight Burst = (9830x.437) - (. 115x.5x9830) - (.437x. 5x9830) = 1581 psi Rated = 7740 psi for burst Safety Factor = 4.9 OK N/A for liner Collapse = (9830x.437) - (9830x.5x. 115) - (9830x.5x.437) = 1581 psi Rated = 6280 psi for collapse Safety Factor = 4.0 OK West McArthur River Unit #lA drili Casing Design 9-5/8' Intermediate Casinq, L-80, BT&C (Already in place in WFU #-2) Burst = (9830x.437) - (. 115x.5x9830) - (.437x.5x9830) = 1581 psi f/drlg to TD w/1/2 column of gas, 1/2 column 8.4 ppg mud 40~ & 43.5# from surface to 7483' MD/6974' TVD whipstock point 1/2 evacuation to gas, 1/2 remaining 8.4 ppg mud weight 40¢ rated @ 5750 psi for burst Safety Factor = 3.6 OK Collapse= (6974x.437) - (. 115x. 5x6974) -(.437x. 5x6974) = 1123 psi for 1/2 evacuation 40~ rated @ 3090 psi for clpse Safety Factor = 2.8 OK 7-5/8" 29.0#, L-80, STL liner ~ 11,059' MD, 9271' TVD (Top of liner ¢, 7283') Tension = (11059'-7283') x 29.0~ = 110K Rated = 444K for joint Safety Factor = 4.0 OK 1/2 evacuation to gas, 1/2 remaining 8.4 ppg mud weight Burst = (9830x.437) - (. 115x. 5x 9830) - (.437x.5x9830) = 1581 psi f/drlg to TD with 1/2 evacuation Rated 6890 psi for burst Safety Factor = 4.4 OK N/A for liner Collapse= (9271x .437) - (9271x. 115x.5) - (9271x.437x.5) = 1493 psi for 1/2 evacuation Rated 4790 psi for collapse Safety Factor = 3.2 OK 5-1/2" 17#, L-80, STL liner ~ 11,972 MD, 9830' TVD (Top of liner ~ 10,859' MD) Tension = (11972'-10859') x 17#= 19K Rated = 248K for joint Safety Factor = 13 OK 1/2 evacuation to gas, 1/2 remaining 8.4 ppg mud weight Burst = (9830x.437) - (. 115x.5x9830) - (.437x.5x9830) = 1581 psi Rated = 7740 psi for burst Safety Factor = 4.9 OK N/A for liner Collapse = (9830x.437) - (9830x. 5x. 115) - (9830x.5x.437) = 1581 psi Rated = 6280 psi for collapse Safety Factor = 4.0 OK West McArthur River Unit #lA Redrill Casing Specifications Joint Body ~_-i_~ii~.-__~_-i.ii~'~.'.i~iiiii' 'i.iiii~i.iii ii-~.'._-_-~i'~_~.i'~_~_iii'~i._-_~_i_i i.i~i.~_~-_~__.S-_t~_-_e_n_--~t~_ Strength Burst 'Collapse' i__D--- Drift ..................... ID Min T0_.r__q.._._0._P_t__T_or_q_ K lbs K lbs psi psi fi-lbs ft-lbs ft-lbs Casing in place Intermediate 13-3/8" 54.5#, Ko80, BT&C 909 853 2730 1130 12.615. 12.459 i~.~m~-~Ji-a-t-e.- ~:~,./-~,-r.;4-:~15~¢I- E:8-01- B~r-8~-C .................. 1-6~7-~ .......... ~-b05 6330 3810 -- 8.75,~- 8.599 .............................................................................. Proposed Liners Liner 7-5~8" 29.04#, L-80, STL 444 555 6890 4790 6.875 6.750 4600 5300 6000 'i~¥r~'~ ................. 5-"~i'~;;'77-~i'-E':~'~"'~i-~§' ................. --~48 397 ' .-~-- 77401 .... 6280 -- . 4.892 4.767 3000: ' ...... -~3~ ................ CSGSPECI.XLS West McArthur River Unit #lA Redrill Casing Specifications Joint Body ..-'--_-_-_~ii--i._~'i.ii_-.'-~iii'i'/~'.~_~_-~.i~. '_._-_'i,.i.iii~i'i.~.iii i'i~.i..i_-__i _S_??n_g_gth____S_t_r__e,.ng__t_h__ Burst __Collapse ID Drift ID _.MJ_-.n,__T_o_rD___O__P_t~?r_9_ ._Max__T._or__q. .............................................................................................. ~J_b_s__ .... __.K._~lb_S_ p_si psi fi-lbs .,__f!_-_!b_s_ .......... _f!.-..!b_s_ ..... -C-~'S-i~-~q ' ' i ~ - P-I-~ ~'~ ...................................................................................................... Intermediate 13-3/8" 54.5#, K-80, BT&C 909 853 2730 1130 12.615 12.459 .............................................................................................................................................. Intermediate 9-518" 43.,5~, L-80, BT&C 1074 1005 6330 3810 8.755 8.599; 9-518" 40#, L-80, BT&C 979 916 5750 3090 8.835 8.679 ................. : ____ _P ?_p_ _o__s?_d_ L_i?_e_.r~ Liner 7-5/8" 29.04#, L-80, STL 444 555 6890! 4790 6.875 6.750 4600 5300 6000 .......................................................................................................................................................................................................................................... '[i'~'~'~: ...................... ¢:~)2;;"':i"~-~:--!~:~80: 'i~ i~,§ ........................... -2-~§ 397 7740 6280 .4.892 , , CSGSPECI.XLS WMRU No. I-1 Sidetrack -7oo0 -7500 -8000 -8500 -9000 -9500 -10000 -10500 -11000 -11500 -12000 -12500 Set 7-5/8" ~ I 5 10 15 20 25 30 Set 5-1/2", Comp. 35 Days WMRU No. I-1 Sidetrack -7000 -7500 -8000 -8500 -9000 -9500 -10000 -10500 -11000 -11500 -12000 -12500 Set 7-5/8,,I Set 5-1/2", Comp. I--e--Planned 5 10 15 2O 25 30 Days 35 Denali Tow~. rs North, Sui~ 1300 2550 Denali ~tre~t, Anchorage, ~Alaska 99503 (907) 27~4004 · FAX (907) 2.74-0424 March 12, 1996 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Ddll (Form 10-401) West McArthur River Unit #I- 1 (Injector #1) Greetings: Enclosed is the Application for Permit to Ddll the West McArthur River Unit # I-1 including two copies. The proposed well will be a reentry of the Pan Amedcan West Foreland Unit #2 (AP! #50-133-10027) which was ddlled and abandoned in 1966. This proposal will drill out the cement plugs in the abandoned weilbore and sidetrack to a new bottom hole location. This proposed well will be the first water injector for the West McArthur River Field. We understand that an application for an area injection order will also need to be submitted and approved by the AOGCC pdor to commencement of injection. If there are any questions, please contact me at 277-4004. Tim Billingsl~y ~ Petroleum Engineer Stewart Petroleum Company CC: William R. Stewart, President- Stewart Petroleum Company ?~-::~,,"-;'~: ~" .... '~-.~:- ~ Paul D. White, Operations Manager- Stewart Petroleum Company GEOL AREA PROGRAM: expo dev [] redrl~ serv~wellbore segO ann disp para reqO F~ ~-__~ UNIT# /._~ O/~- ON/OFF SHORE O~J 1. 2. 3. 4. 5. 6. 7. ADMINISTRATION Permit fee attached ................... Lease number appropriate ................ Unique well name and number .............. Well located in a defined pool ............. ..... Well located proper distance fro, drlg u,it boundary.. Well located proper distance from other wells Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force. ........ Permit can be issued without conservation order .... Permit can be issued witho.t administrative approval.. 8. 9. 10. 11. 12. ~ ,~?~.~. 13. Can permit be approved before 15-day wait ....... Surface casing protects all known USDWs ......... Y CMT vol adequate to circulate on conductor & surf cng.. Y 14. 15. 16. ENGINEERING APPR DATE 17. CMT vol adequate to tie-in long string to surf cng . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost..... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved.'~ 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate ....... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... ~ 26. BOPE press rating adequate; test to ~~ psig.~ Choke manifold complies w/API RP-53 (May 84) ...... ~ 27. N 28. Work will occur without operation shutdown ....... G N 29. Is presence of H2S gas probable ............. Y ~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ....... ./Y N 34. Contact name/phone for weekly progress reports . . /.. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: BEW~ DWJ JDH~ mcm ~ Comments/Instructions: PERMIT CHECKLIST .//~ ~-'~, WET.L NAN~.~ ~,/~, ~/.~,~¢._~. PROGI~AN: exp [] dev [] redrll/~ser~//wellbore seg [] ADMINISTRATION D~TE y ENGINEERING !. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ....... REMARKS N .<,,., Z / ' VT/ //?, .,.' ' ,' APPR 14. Conductor string provided ................ Y N~ 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg.. Y N 17. CMT vol adequate to tie-in long string to surf csg . . · Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate ~ N 25. BOPEs adequate ..................... %~' N 26. BOPE press rating adequate; test to ~d~ psig. Y~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. Y GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y N 32. Seismic analysis of shallow gas zones .......... Y 33. Seabed condition survey (if off-shore) ......... Y/N 34. Contact name/phone for weekly progress reports . . . . .~ [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: DWJ~. JDN ~ HOW/Ijb - A:~FORMS\cheklist rev 11195