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Home My WebLink About204-056 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~O Y-- 0 -510 Well History File Identifier Organizing (done) D Two-sided 11111111111" 111111 D Rescan Needed ""1111111"" 1111 RES CAN DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Color Items: D Greyscale Items: D Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: BY: ~aria ") Date 7//:J. /0 J I I Date 7/'d-/O 7 D Other:: Isl mf Project Proofing BY: ~ Isl 1111111111111111111 ü1£ áq Scanning Preparation BY: C--Maria ~ Date: + = TOTAL PAGES (Count does not include cover sheet) Isl Production Scanning Stage 1 Page Count from Scanned File: 30 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES BY: C Mari~ Date:7!¡ ~/07 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 11111111111111 ,,1/1 NO Isl M~ NO BY: Maria Date: Isl III 111111111111111I Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111" III BY: Maria Date: Isl Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • • ~._ ~ - ,;.> - ~~ ~ ~; :~~:' ..~- MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfihn Marker.doc bp . . Terrie Hubble Technical Assistant GPB Drilling & Wells BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 April 5, 2005 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Permit # 204-056, PBU V-118 RECEIVED ÁPR ,- 5 ZOQ5 A'~~k' Oil $, Ciaa Gon.. Cømminiº" AnohOr_g, Reference: API # 50-029-23204-00 Direct: (907) 564-4628 hubbletl@bp.com To Whom It May Concern: Please cancel approved Permit to Orill for PBU V-118, Permit Number 204-056 (50-029-23204-00). The surface location was re-named later in 2004 to V-120. A new Permit to Orill was submitted and that well was drilled to TO in March 2005. Thank you very much for your assistance in this matter. Sincerely, ~~ Terrie Hubble xc: Well Files POC Performance Unit . . FRANK H. MURKOWSKI, GOVERNOR AI,ASKA OIL AND GAS CONSERVATION COMMISSION Lowell Crane BP Exploration (Alaska), Inc. Senior Drilling Engineer PO Box 196612 Anchorage AK 99519 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudheo Bay Unit V -118 BP Exploration (Alaska), Inc. Pennit No: 204-056 Surface Location: 4897' NSL, 1547' WEL, Sec. 11, TIIN, RIlE, UM Bottomhole Location: 2355' NSL, 1100' EWL, Sec. 07, TllN, RI2E, UM Dear Mr. Crane: Enclosed is the approved application for penn it to drill the above referenced service well. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspect a 659-3607 (pager). BY ORDER.Bj THE COMMISSION DA T~D thip- day of April, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. yU6A- q'~/lðo<f .. _ STATE OF ALASKA _ '. ALASKA C'PAND GAS CONSERVATION COMW'3SIRECEIVED PERMIT TO DRILL . 20 MC 25.005 APR - 2 2004 1 a. Type of work III Drill o Redrill rb. Current Well Class ~ ~~~?~:tOry ~~~"~~~tø~ ~_~ñ ORe-Entry o Stratigraphic Test 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well DENumber: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 PBU V-118~ 3. Address: 6. Proposed Depth: 12. Field 1 Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 11503 TVD 6882 Prudhoe Bay Field 1 Borealis Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Prudhoe Bay Field 1 Orion Surface: ADL 047450 4897' NSL, 1547' WEL, SEC. 11, T11N, R11E, UM 8. Land Use Permit: 13. Approximate Spud Date: /' Top of Productive Horizon: 3089' NSL, 4577' EWL, SEC. 12, T11N, R11E, UM May 10, 2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2355' NSL, 1100' EWL, SEC. 07, T11N, R12E, UM 2560 10,000' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 590753 y-5970146 Zone- ASP4 (Height above GL):Plan 82.1 feet V-117PB1,1935' 16. Deviated Wells: 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) 0 Kickoff Depth 300 ft Maximum Hole Angle 64 Downhole: 3474 psig Surface: 2792 psig 18.ißa.sing...Program Specifications ~ettiogQðpth ....(c.tèi~··· Size Top·· .. · .... .... ... ... .. ,..·Sóttdrn Hole CasinQ WeiQht Grade Couplina LenQth MD TVD MD TVD (includinQ staoe data) 42" 20" 91.5# H-40 Weld 80' Surface Surface 110' 110' 1260 sx Arctic Set (Approx.) 12-1/4" 9-518" 40# L-80 BTC 4175' Surface Surface 4175' 2727' ~18 sx PF II, 292 sx Class 'G' 8-3/4" 7 26# L-80 BTC-M 11503' Surface Surface 11503' 6882' 111 sx LiteCrete, 126 sx Class 'G' / ~ 468 sx Class 'G' 19. PRESENT W!;LLCONDITION SUMMARY(T() be completec;lfor~~I"ÎIIANPRe-entry O~rÿti()l'\s) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 1ÄeOgfh §iZØ < ..../l\.!Ip ii « ··..TVDi ii ~trur.tlJr;::¡1 Conductor SurfacA Intermediate Proour.tion Liner Perforation Depth MD (ft): IPerfOration Depth TVD (ft): 20. Attachments 181 Filing Fee, $100 o BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis 181 Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 181 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jim Smith, 564-5773 Printed Name Lo~1I Crane Title Senior Drilling Engineer / I~~ .0. Date 4-z -~O(¡ Prepared By Name/Number: SiQnature)\rl,.( ~ce-eA Phone 564-4089 Terrie Hubble, 564-4628 V < i ,i ·".."'i·¡ ,.i i ii ../ < Pi i".,· ii PermitTo Dril:.y. '?:' API Numb~9 2$..2.09 Permit Approval I See cover letter for Number: Z ø - Ó_~ 50- a z.. -- Date: other requirements Conditions of Approval: Samples Required DYes ;gNo Mud Log Required D Yes ~NO ) ~"f_en Sulfode Measu,"" llYes ~NO Directional Survey Required ~Yes D No 00", ~o P '/J~ </00';> p.¡. 'O¡.J N'd ÂI{ L. , ~¿t.[;;l to 1 I ~~ . Date if'" ff Annrove : U ~. BY ORDER OF THE COMMISSION Form 1 0-~evised12/2003 - UKllJII\JAL ~ubm~ In DuPlicate ~~ - - IWell Name: V-118 I Drill and Complete Plan Summary Target Location: To Ku aruk Bottom Hole Location: 82.1' Mud Program: 12 %" Surface Hole (0-4175'): Fresh Water Surface Hole Mud Densitv Viscosity Yield Point API FL PH (ppq) (seconds) (b/100ft¿) (mls/30min) Initial 8.5 -9.2 250-300 50 - 70 15 - 20 8.5 - 9.5 Base PF to top SV 9.0 - 9.5 200-250 30 - 45 <10 8.5 - 9.5 SV to TD 9.5 max 200 20 - 40 <10 8.5- 9.5 8 3.,4" Production Hole 4175' -11503'): LSND Interval Density Tau 0 YP PV pH API 10' Gel (ppg) Filtrate Upper 9.5-9.7 4-7 25-30 1 0-15 8.5-9.5 6-10 10 Interval ~ Top of HRZ W 3-7 20-25 1 0-15 8.5-9.5 4-6 10 to TD Hydraulics: Surface Hole: 12-1/4" Interval Pump Drill AV Pump PSI ECD Nozzles TFA GPM Pipe (fpm) ppç¡-emw (in2) 0-2,000 550 5" 19.5# 90 1600 9.6 18,18,18,16 .942 2,000'-4,164' 600 to 5" 19.5# 116 1800 9.8 18,18,18,16 .942 650 Production Hole: 8 3,4" Interval Pump Drill Pipe AV (fpm) Pump PSI ECD ppg- Nozzles TFA GPM emw (in2) 4175' -11503' 600 5" 19.5# 270 3100 at TD 11.3 6 x 15 1.04 Hydraulics based on full string of 5" DP and BHA. V-118 Drilling Program (draft) Page 1 It -- Directional: Ver. Intermediate/Production Hole Logging 64 de at 2139' MD All wells pass major risk criteria. V-03 is 13' center to center at 400' V-111 is 42' center to center at 400' IFR-MS corrected surveys will be used for survey validation. G roData will be needed for surface hole close a roaches. Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / RES / DEN / NEU / PWD Open Hole: None Cased Hole: USIT cement evaluation Ku and Schrader Surface logging Formation Markers: Formation Tops MDbkb TVDss Estimated pore pressure, PPG SV5 1838 1575 Start kick off at 300' SV4 2052 1695 8.5 PPQ Base Permafrost 2115 1725 8.5 ppg Fault 2719 1995 8.5 ppg SV3 2977 2110 8.5 ppg SV2 3290 2250 8.5 ppg SV1 3951 2545 8.5 ppg 9-5/8" surface csg 4175 2645 8.5 ppg UG4A 4746 2900 8.6 PPQ UG3 5564 3265 8.6 ppg UG1 6661 3755 8.6 ppg Ugnu Ma 7277 4030 8.5 PPQ (TOe to be 500' above the UQnu Ma) Schrader Na 7949 4330 8.0 PPQ Schrader Oa 8352 4510 8.2 PPQ Schrader target 8363 4515 Schrader OBa 8486 4570 8.2 PPQ Schrader OBb 8565 4605 8.3 PPQ Schrader OBc 8688 4660 8.1 ppg Schrader OBd 8811 4715 8.0 PPQ Schrader Obf Base 9169 4875 8.5 PPQ CM2 (Colville) 9692 5190 8.5 PPQ CM1 (Colville) 10402 5800 Fault Crossing 10787 6150 THRZ 10997 6340 BHRZ (Kalubik) 11217 6540 TKUP target 11283 6600 Kuparuk C4 11283 6600 8.8 PPQ LCU (Kuparuk B) 11354 6665 9.8 PPQ Kuparuk A5 11432 6735 9.8 PPQ TMLV (Miluveach) 11503 6800 TD Criteria 11503 6800 TD 150' below LeU Kuparuk B top C1(.1 10.1.. V-118 Drilling Program (draft) Page 2 e e C IT b" p aSln g¡ u Ing rogram: Hole Csgl WtlFt G~e Conn Length Top Btm Size Tbg O.D. / MDITVD MDITVD bkb 42" Insulated 20" 91.5# H-40 WLD 80' GL 110/110 12 W' 9 5/8" 40# L-80 BTC 4175' GL 4175'/2727' 8%" 7" 26# L-80 BTC-M 11503' GL 11503'/6882' Tubinq 4~" 12.6# L-80 TC-II 8363' GL 8363'/4597' Tubinq 3-1/2" 9.3# L-80 TC-II 2770' 8363' 11133'/6447' CasingITubing Design Ratings: / / Cs ITb WtlFt Grade Conn Burst Tension Insulated 20" 91.5# H-40 WLD si #M 9 5/8" 40# L-80 BTC 5750 916 7" 26# L-80 BTC-M 7240 604 4~" 12.6# L-80 TC-II 288 3-1/2" 9.3 L-80 TC-II 159 Inte rit Testin : Test Point Depth Surface Casing Shoe 20' min from surface shoe Test Type LOT EMW 12.0 ppg EMW Target Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as a contingency if cement is not circulated to surface. Casin Size 9-5/8" Surface Basis: Lead: Based on 100' of conductor, 2015' of annulus in the permafrost @ 225% excess and 1310' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 750' MD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -3414' MD Shoe at 4175'MD V-118 Drilling Program (draft) Page 3 e e The 7" production casing job assumes a two stage job due to the requirement for good cement to 500' above the Ugnu Ma sand which will also be part of an injection zone. Casin Size 7" Production Longstring Basis: Stage 1: Based on TOC at 9583'MD (1700' above top of Kuparuk) + 40% excess + 80' shoe. (Plan 1200' of lead and 720' of tail) Cement Placement: From shoe at 11503'MD to 9583' D Total Cement Volume: Lead 4 /253 ft / 111 sks LiteCRETE at 12.0 ppg and Sta e 1 dIsk. Tailbls / 152 ft / 1 sks of DS Premium "G" with latex at 15.8 an dIsk. Basis: Stage 2: Based on TOC 500' above top of Ug . a formation + 40% excess Placement: From sta e collar at 9250'MD to 6755' MD Total Cement Volume: Tail 96.6 bbls / 542 ft /468 sks of DS Premium "G" with Sta e 2 latex at 15.8 ppg and 1.16 dIsk. Well Control: Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the need to test the production casing to 4000 psi (MI service Well) the BOP equipment will be tested to 4000 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: 3474 psi @ 6735' TVDss - Kuparuk A Sands 2792 psi @ surface (based on BHP and a full column of gas from TO @ 0.10 psi/ft) · Planned BOP test pressure: required for MI service.) · Planned completion fluid: ppg diesel 4000 psi (The casing and tubing will be tested to 4000 psi as / Filtered seawater with 2% KCL with corrosion inhibitor / 6.8 Nearest well: 2300' to the currently drilling V-115 ( at top Kuparuk) Nearest boundary: 10000' to the PBU boundary / Closest penetration (at Top OA Schrader Bluff) - V-117PB1, 1935' to SW of V-118. Next closest: Exploration Well K071112, 2810' to SE of V-118. Disposal: · No annular disposal in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. V-118 Drilling Program (draft) Page 4 e e DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor is installed. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. V-03 will require a surface shut-in during move in, to put the V-03 back on production while the rig is over V-118 it will be necessary to install an ESD system by the driller's console. Rig Operations: / 1. MIRU Nabors 9ES. 2. Nipple up diverter spool and riser. PU 5" DP as required for surface hole and stand back in derrick. 3. MU 12 1,4" drilling assembly with MWD/GR and directionally drill surface hole to approximately 4175' MD / 2727' TVD which is below the SV1 sand. An intermediate wiper/bit trip to surface for a will be /' performed just after exiting the Permafrost. The actual surface hole TD will be +/-100' TVD below the top of the SV1 sand in a shale. /' 4. Run and cement the 9-5/8",40# surface casing back to surface with TAM p~ collar installed at 1000'. 5. ND diverter and NU casing / tubing head. NU BOPE and test to 4000 psi. 6. MU 8-3/4" drilling assembly with MWD/PWD/RES/DEN/NEU/GR and RIH to float collar. There will be a full string of 5" DP used in this interval. Test the 9-5/8" casing to 3500 psi for 30 minutes. /' 7. Drill out shoe joints and displace well to 9.5 ppg LSND drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 8. Drill ahead and increase mud weight to 10.2 ppg prior to the HRZ, ensure mud is in condition to 10.2 / ppg and perform short trip as needed. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. 9. Drill ahead to TD at -150' below top Kuparuk B (11503' MD, 6826' TVD). /" 10. Condition hole for running 7" 26# long-string casing. LD 5" DP on trip out. /" 11. Run and cement the 7" production casing as a two stage job. Displace the cement with mud. 12. Freeze protect the 7" x 9-5/8" annulus as required after WOC. Record formation breakdown pressure on the Morning Report. 13. PU Bit and stabilizer on a full string of 4" DP and RIH to drill the stage collar at 9250'MD, continue in hole to the float collar, displace wellbore to 9.2 ppg brine (brine weight to overbalance the Schrader by 130 psi minimum). / 14. RU Schlumberger and run USIT log on e-line from the 7" float collar to 500' above TOC (expected at 500' above the Ugnu Ma). 15. Test casing to 4000 psi for 30 minutes. / 16. DPC perforate the Schrader intervals in a single gun run(estimate 250' of 4-1/2" guns) but do not perf the Kuparuk. 17. Make a cleanout run with bit & scraper to PBTD. POOH, LD 4" DP for subsequent rig move. 18. Run the 3-1/2" 9.3#, L-80 TCII and 4-1/2", 12.6#, L-80 TC-II completion assembly for dual zone / injection. Kuparuk perforations will be post rig. Set packers and test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes. Shear DCK valve and install TWC. Test below to 1000 psi. 19. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 20. RU hot oil truck and freeze protect well by pumping diesel to lowermost GLM. Allow to equalize. 21. Rig down and move off. ./ V-118 Drilling Program (draft) Page 5 e e V-118 Hazards and Contingencies Job 1: MIRU Hazards and Contingencies ~ V-Pad is not designated as an H2S site. None of the current producers on V-Pad have indicated the presence of H2S. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. ~ There is one well directly adjacent to V-118. The V-03 is 15' to the west. The next nearby well is the V-111 at 45' to the west. Surface shut-in and bleed of of gas-lift gas will be required on the adjacent V-03 well during move-in and out. ~ Check the landing ring height on V-118. The BOP nipple up may need review for space out. ~ The AOGCC will not support a diverter dispensation on V pad. We will need to use a diverter for the surface hole drilling. ~ Critical concerns for drilling on V pad due to the abundance of hydrates and some free gas in the surface hole interval are: Monitoring the hole, checking connections, importance of maintaining mud properties (including pre-treating with DrillTreat for Hydrates), focus on avoiding swabbing situations, importance of not loading up the hole (hole cleaning), evacuation drills, muster areas, etc. should be topics for discussion and actions. Job 2: DrillinQ Surface Hole ~ A fault is expected at 1995' TVDss. This fault has been cut numerous times without losses. ~ There are two close approach issues in the surface hole. The closest existing wells,V-03 (15' center-center at surface to -400' MD) and V-111 (at 42' away down to 400'MD) will require a down hole shut in, gas lift bled off until new well is 500' below close approach. Afterwards a rig floor ESD system will be required to bring the V-03 well back on production whilst drilling the remainder of V-118. ~ A GyroData survey will be utilized while drilling the surface hole until clear of magnetic intereference. ~ Gas hydrates have been observed in wells drilled on V-pad. These were encountered near the base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to MI mud recommendation Job 3: Install surface Casinq Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 225% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. A 9-5/8" port collar will be positioned at ±1 OOO'MD to allow remedial cementing. ~ "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement 2. Cement - Top of tail >500' TVD above shoe using 30% excess. 3. Casing Shoe Set approximately 100'TVD below SV-1 sand. 9-58", 40#, L-80, STC Collapse Burst Tensile ID Make-up Torque 100% 3090 psi 5750 psi 916,000 Ib 8.835" To Position 80% 2472 psi 4600 psi 732,800 Ib 8.679" drift V-118 Drilling Program (draft) Page 6 e e · Centralizers: one bow-spring type per joint first 13 joints, plus one each side of the port collar. · With higher viscosity mud left in the hole for gravel suspension, be prepared to circulate for a longer period of time to condition the mud prior to pumping cement. Circulate to bring the mud viscosity <80 sec/qt (25-35 yield point) · Pump cement as per recommended practice at volumes specified in attached cement program. Reciprocate casing -10' while displacing cement, as hole allows, to meet criteria for annular disposal. (Report pipe reciprocation on Morning Report.) Note: Check surface cement level prior to leaving well to establish if cement has slumped. If TOC greater than 20' below conductor, perform top job at an opportune time. Note: In the event that cement is not circulated to surface during the initial surface casing /' cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Job 7: DrillinQ Production Hole Hazards and Contingencies ~ V-118 should cross one fault in the Lower Colville (approx 10787'MD, 6150TVDss). The fault has 40' of throw. This fault is not expected to cause difficulties. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures should a surprise occur. ~ KICK TOLERANCE: In the case scenario of 9.8 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 12.0 ppg at the surface casing shoe, 10.2 ppg mud in the hole the kick tolerance is 34 bbls. An accurate LOT will be required as well as heightened awareness for kick detection.Çorít~ct Drilling Manager if LOT is less than 11.9 ppg. /)" ~ V-pad development wee Is pic y have "kick tolerances" in the 30-50 bbl range. A heightened awareness k" detection, pre-job planning and trip tank calibration will be essential while drilling/t" ing the intermediate/production intervals þ.- There are no "close approach" issues with the production hole interval of V-118. Job 9: Case & Cement Production Hole Hazards and Contingencies ~ A first stage lead and tail slurry (lead LiteCRETE at 12.0 ppg and 15.8 ppg latex tail) will be used from TD to 1700' above the Kuparuk, the second stage cement will also be 15.8 ppg but designed for the cooler temperatures at the Schrader. The second stage cement is planned to cover to 500' above the Ugnu Ma sand from the stage collar at 9250'MD. ~ Ensure the Schrader cement has reached a compressive strength of 500 psi prior to freeze protecting. After freeze protecting the 7" x 9-5/8" casing outer annulus with 85 bbls of dead crude (2995' MD, 2200'TVD), the hydrostatic pressure will be 8.0 ppg vs 8.5 ppg EMW of the formation pressure immediately below the shoe. To prevent this underbalance problem, pump 10 bbl of 10.5 ppg mud ahead of the dead crude, that will produce a slight overbalance to the formation pressure. Record formation breakdown pressure when pumping into the annulus, report this in the morning report. >- A USIT log will be required from across the Kuparuk to 500' above the top of cement (expected at 500' above the Ugnu Ma. Since this is a two stage job there may be a blank section between the two zones. Send results of USIT log into Anchorage office as soon as practical for evaluation. V-118 Drilling Program (draft) Page 7 · e Notify Bruce Smith (H. 345-2948, W. 564-5093) immediately upon obtaining results of USIT log for review of possible remedial cement work. >- Ensure a minimum hydrostatic equivalent of 10.2 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. >- Considerable losses during running and cementing the 7" longstring has been experienced on some offset wells. A casing running program will be issued detailing circulating points and running speed. In addition a LCM pill composed of "G-Seal" will be placed across the Schrader and Ugnu to help arrest mud dehydration. 7", 26#, L-SO, BTC-mod Collapse Burst Tensile ID Make-up Torque 100% 5410 psi 7240 psi 604,000 Ib 6.276" To Position 80% 4328 psi 5792 psi 483,200 Ib 6.151" drift Job 10: Cleanout 7" production Casina Hazards and Contingencies >- Failure to get seal at ES cementer. Pressure test the ES cementer after drilling it out. Reference RPs .:. Stage Cementing Job 11: USIT Loaaina and Schrader Perforation Hazards and Contingencies >- Failure to allow adequate time to determine set cement. The cleanout run of the 7" and necessary time to pick up 4" DP should provide at least 15 hours time for cement set. The OS cement testing lab results can be used as a compressive strength guide. Reference RPs .:. OPC Perforating Job 12: Run Completion Hazards and Contingencies >- Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The well may take fluid into the Schrader if too much pressure is applied. Slow running speed if necessary. >- Shear valves have been failing at lower than the 2500 psi differential pressure. When test annulus maintain no more than a 1500 psi differential: 2500 psi tubing pressure, 4000 psi annulus pressure. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. V-118 Drilling Program (draft) Page 8 · e Job 13: ND/NUlRelease RiQ Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Post Rig work: 1. 2. 3. RU wireline and pull rod and ball from RHC profile install dummy GLM in place of DCK Pressure test through tubing into the open 7" casing to 4000 psi for 30 minutes to confirm set and seal of the bottom Premier packer. Perforate the Kuparuk interval. 4. V-118 Drilling Program (draft) Page 9 . e V-118 Well Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates may be encountered near the base of the Permafrost at 1800' MO and near the TO hole section through the SV sands. · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. · There is one expected fault in the surface hole interval. This fault (1995'TVDss) has been crossed by a number of wells without problems. Maintain LCM available for use if required. Production Hole Section: · A majority of the V-Pad development wells will have "kick tolerances" in the 25-45 bbl. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the production interval. · The intermediate hole section will be drilled with a recommended mud weight of 10.2 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 9.8 ppg pore pressure. · Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices and close monitoring of PWO data will contribute to favorable hole conditions. · Reservoir pressure in the Kuparuk is expected to be 9.8 ppg EMW. The planned mud weight of 10.2 ppg should provide sufficient overbalance for tripping activity. Maintain awareness of fluid volume for any gains or losses. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. V-118 Drilling Program (draft) Page 10 e e CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION ,// V-118 Drilling Program (draft) Page 11 TREE = 4-1/16" erN WELLI-1EAD = FMC A CTUA TOR = KB. ELEV = e V-118 / SAFETY NOTES: GLM'S @ STA #1 thru #6 ARE3-1/2" X 1-1/2" MMG-W'S, WHICH ARE WA TERFLOOD MANDRELS. BF. ELEV = ........1 H 9-5/8" TAM PORT COLLAR I KOP= 1000' Max Angle - GAS LIFT MANDRELS Datum MD - ST MD TVD DEV TYÆ VLV LA TCH PORT DATE DatumTVD- ,.... I I 8 4970 3000 KBG-2 DumrY1J BK-5 I 2200'M D H 4-1/2" HES X NIP, ID = 3.813" I........ 7 7350 4063 KBG-2 DCK BK-5 I 9-5/8" CSG, 40#, L-80, ID = 8.835" I µ ~ ST WA TERFLOOD MANDRELS 4175' MD TVD DEV TYÆ VLV LATCH PORT DATE L 6 MMG-W Dumnl) RKP 5 MMG-W DumrY1J RKP 4 MMG-W DumrY1J RKP 3 MMG-W Dum~ RKP Minimum ID = 2.75" @ 11153' 2 MMG-W Dum~ RKP 1 MMG-W Dumrm RKP 3-1/2" HES XN NIPPLE 4-1/2" TBG, 12.6#. L-80, .0152 bpf, ID = 3.958" H 7460' I H 4-1/2" HES X NIP, ID = 3.813" I . I 7400' 8 ~ I 7450MD I 7" X 4-1/2" BKR PREMIER PKR, ID = 3.875" I I.C> r=::¡ 7460MD H 4-1/2" X 3-1/2" XO, ID = 2.992" I :8:J t8: ~I r=::¡ H 7" X 3-1/2" BKR PREMIER PKR, :8: ~ TBD I 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" I / ¡:g ~ I . [] / h-BD H 3-1/2"HESXNIP,ID=2.813" I ] . Stage cementing collar at 9250'MD ~ 'I.-, I 11083MD 7" X 3-1/2" Premer PKR, ID - 3.875" I ~ . I I 11103MD H 3-1/2" HES X NIP, ID = 2.813" I 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 1 11153' 1-- .......... I I 11143MD H 3-1/2" HES XN NIP, ID = 2.75" I ÆRFORA TION SUMMARY 11153MD1-i 3-1/2" WLEG, ID = 2.875" I REF LOG: TCP ÆRF Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I PBTD I 11418'MD I 7" CSG, 26#, L-80, .0383 bpf, ID 6.276" I 11503'M D I ~ DA TE REV BY COMMENTS 03/31/04 JES PROPOSED COMPLETION DA TE REV BY COMMENTS GPB BOREA LIS WELL: V-118 ÆRMrr No: API No: BP Exploration (Alaska) e c--------------- II E 5.172 I I I I I I I I I I I I I I I I I I I Ig '" I~ Iz I I I I I I I I I I I I I I I I I -~------- GRID 15'00'00"(' PLANT I JZ- I V-118 t V-03 · V-115 · V-100 · V-117 · SLOT S-R · V-111 · V-103 · V-106 · V-105i · SLOT NM · V-102 · V-201 · V-107 · V-116 · SLOT S-J · V-104i · V- 202 · V-114 · V-109 · V-113 · V-101 · V-10B V-PAD 10 SPINE ROAD --- LEGEND + RENAMED EXISTING CONDUCTOR . EXISTING CONDUCTOR ~ N , N , N NOTES 1, DATE OF SURVEY: MARCH 4, 2003. 2. REFERENCE FIELD BOOK: W003-01 PGS. 52-53. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD-27. 4. BASIS OF HORIZONTAL CONTROL IS V-PAD OPERATOR MONUMENTATION. 5. BASIS OF ELEVATION IS KUPARUK PIPELINE CONTROL. ELEVATIONS ARE BP MSL DATUM. 6. THE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. · ~ ^ > ~ 9 m , > SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH 4, 2003. ~ · E · E · ~ WELL NO. V-118 LOCATED WITHIN PROTRACTED SEC. 11, T. 11 N., R. 11 E., UMIAT MERIDIAN, ALASKA A.s.P. PLANT GEODETIC GEODETIC CELLAR SECTION COORDINATES COORDINATES POSITION(DMS POSITION(D.DD) BOX ELEV. OFFSETS Y= 5,970,146.49 N=1O,180.39 70·19'41.410" 70.3281694" 536' 4,897' FSL X= 590,752.78 E= 5,014.99 149·15'50.329" 149.2639803" . 1,547' FEL o 2 18 04 ISSUED FOR INFORMATION NO. DATE RE\1S1ON I F. [(0 berl- D::¿AWN: COTTON ~ CHECKED: OHANLEY DATE: 2/18/04 DRAWING: FR804 WOV 01-00 i ¡Uij5ij5rnœo JOB NO: ENONEERS /\NO LIoNO SURVEYORS SCALE: JJC LOH 801'11[$1 fifl£W£ED l.AIoI[ '"=150' BY CHK ANCHORI,C£, AU.SK'" 99!oDJ GREATER PRUDHOE BAY V-PAD RENAMED CONDUCTOR AS-BUILT WELL V-118 SHEET: 1 OF 1 bp V-118 (P5) Proposal S U ger Report Oats: March 16, 2004 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Aiaska Vertical Section Azjmuth: 107.750" Field: Prudhoe Bay Unit - WOA 03/1 Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: V-Pad I Plan V-11 8 (N-X) d TVO Reference Datum: Rotary Table Well: PlanV-118(N-XA prove TVD Reference Elevation: 82.10 ft relative to MSL Borehole: Plan V-118 p Sea Bed / Ground Level Elevation: 53.60 ft relaüve to MSL UWIIAPI#: 50029 Magnetic Declination: 24.999" Survey Name I Date: V-118 (P5) I March 16,2004 Total Field Strength: 57564.053 nT T or! I AHD I 0011 ERD ratio: 107.349"/8372.01 ft/6.177/1.216 Magnetic Dip: 80.816" Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: Apnl 30, 2004 Location Lat/Long: N 70.32816943, W 149.26398020 Magnetic Declination Model: BGGM 2003 Location Grid NIE Y/x: N 5970146.490 ftUS. E 590752.780 ftUS North Reference: True North Grid Con....ergence Angle: ..0.69306719" Total Corr Mag North -> True North: +24.999" e Grid Scale Factor: 0.99990936 local Coordinates Referenced To: Well Head Com me nts RTE KOP Bid 1.5/100 Base Gubik Bid 2.5/100 Bid 4/100 600.00 6.50 65.00 599.44 517.34 11.20 15.26 6.45 13.83 2.50 2.50 0.00 O.OOG 5970153.10 590766.53 N 70.32818704 W 149.26386808 700.00 10.50 65.00 698.32 616.22 22.05 30.03 12.69 27.22 4.00 4.00 0.00 O.OOG 5970159.51 590779.84 N 70.32820410 W 149.26375947 800.00 14.50 65.00 795.93 713.83 37.94 51.67 21.84 46.83 4.00 4.00 0.00 O.OOG 5970168.89 590799.34 N 70.32822909 W 149.26360043 Crv 4/100 812.50 15.00 65.00 808.02 725.92 40.28 54.86 23.18 49.72 4.00 4.00 0.00 49.63G 5970170.27 590802.21 N 70.32823276 W 149.26357704 900.00 17.47 73.91 892.04 809.94 59.51 79.27 31.61 72.60 4.00 2.82 10.19 41.07G 5970178.97 590824.99 N 70.32825578 W 149.26339145 SV6 989.90 20.31 80.73 977.10 895.00 84.63 108.34 37.86 100.98 4.00 3.16 7.58 34.62G 5970185.57 590853.28 N 70.32827286 W 149.26316135 1000.00 20.65 81.38 986.56 904.46 87.78 111.87 38.41 104.47 4.00 3.30 6.44 34.01G 5970186.16 590856.76 N 70.32827436 W 149.26313306 1100.00 24.06 86.87 1079.04 996.94 122.64 149.87 42.17 142.27 4.00 3.42 5.49 28.93G 5970190.37 590894.51 N 70.32828462 W 149.26282653 1200.00 27.63 91.05 1169.03 1086.93 163.91 193.44 42.85 185.82 4.00 3.56 4.17 25.17G 5970191.58 590938.05 N 70.32828650 W 149.26247335 1300.00 31.29 94.32 1256.10 1174.00 211.39 242.60 40.47 234.91 4.00 3.66 3.27 22.32G 5970189.80 590987.17 N 70.32827999 W 149.26207523 1400.00 35.02 96.97 1339.81 1257.71 264.86 297.27 35.03 289.31 4.00 3.73 2.65 20.10G 5970185.02 591041.62 N 70.32826512 W 149.261634_ 1500.00 38.80 99.16 1419.76 1337.66 324.04 357.31 26.56 348.74 4.00 3.78 2.19 18.34G 5970177.27 591101.14 N 70.32824197 W 149.261152 1600.00 42.61 101.02 1495.56 1413.46 388.66 422.51 15.10 412.92 4.00 3.81 1.86 16.93G 5970166.58 591165.45 N 70.32821065 W 149.26063175 EOUC 1693.14 46.18 102.52 1562.10 1480.00 453.46 487.66 1.79 476.70 4.00 3.84 1.61 15.86G 5970154.04 591229.37 N 70.32817427 W 149.26011460 1700.00 46.45 102.62 1566.84 1484.74 458.40 492.62 0.71 481.54 4.00 3.85 1.51 15.79G 5970153.02 591234.23 N 70.32817132 W 149.26007536 1800.00 50.30 104.04 1633.25 1551.15 532.91 567.35 -16.55 554.25 4.00 3.86 1.41 14.85G 5970136.64 591307.14 N 70.32812415 W 149.25948572 SV5 1837.93 51.77 104.53 1657.10 1575.00 562.35 596.85 -23.83 582.83 4.00 3.87 1.30 14.54G 5970129.71 591335.80 N 70.32810426 W 149.25925396 1900.00 54.18 105.30 1694.47 1612.37 611.84 646.40 -36.59 630.71 4.00 3.88 1.24 14.08G 5970117.53 591383.83 N 70.32806939 W 149.25886571 2000.00 58.06 106.45 1750.21 1668.11 694.80 729.40 -59.31 710.54 4.00 3.89 1.15 13.44G 5970095.78 591463.92 N 70.32800730 W 149.25821835 SV4 2052.34 60.10 107.01 1777.10 1695.00 739.69 774.30 -72.24 753.54 4.00 3.89 1.07 13.15G 5970083.38 591507.07 N 70.32797197 W 149.25786966 2100.00 61.96 107.50 1800.18 1718.08 781.39 816.00 -84.61 793.36 4.00 3.90 1.03 12.91G 5970071.49 591547.03 N 70.32793817 W 149.25754680 Base Perm 2114.86 62.54 107.65 1807.10 1725.00 794.53 829. 14 -88.58 805.89 4.00 3.90 1.01 12.84G 5970067.68 591559.61 N 70.32792733 W 149.25744517 End Crv 2139.04 63.48 107.89 1818.07 1735.97 816.08 850.69 -95.15 826.41 4.00 3.90 0.99 O.OOG 5970061.35 591580.20 N 70.32790936 W 149.25727880 Faull Crossing 2719.17 63.48 107.89 2077. 10 1995.00 1335.17 1369.78 -254.61 1320.41 0.00 0.00 0.00 O.OOG 5969907.90 592076.05 N 70.32747355 W 149.25327316 WellDesiUil Ver 3.1RT-SP3.03-HF4.00 Bld( d031rt-546) Plan V-118 (N-X)\Plan V-118 (N-X)\Plan V-118\V-118 (P5) Generated 3/16/2004 2:31 PM Page 1 of 2 Comments SV3 SV2 3290.28 63.48 107.89 2332.10 2250.00 1846.20 1880.81 -411.58 1806. 73 0.00 0.00 0.00 O.OOG 5969756.83 592564.19 N 70.32704443 W 149.24932995 SV1 3950.99 63.48 107.89 2627.10 2545.00 2437.38 2472.00 -593.18 2369.33 0.00 0.00 0.00 O.OOG 5969582.07 593128.90 N 70.32654789 W 149.24476841 9-5/8" Csg PI 4174.95 63.4 8 107.89 2727.10 2645.00 2637.78 2672.40 -654.74 2560.05 0.00 0.00 0.00 O.OOG 5969522.82 593320.32 N 70.32637955 W 149.24322218 UG4 4622.89 63.48 107.89 2927.10 2845.00 3038.59 3073.21 - 777. 86 2941.47 0.00 0.00 0.00 O.OOG 5969404.34 593703.18 N 70.32604282 W 149.24012979 UG4A 4746.07 63.48 107.89 2982.10 2900.00 3148.81 3183.43 -811.71 3046.37 0.00 0.00 0.00 O.OOG 5969371.76 593808.46 N 70.32595021 W 149.23927939 UG3 5563.55 63.48 107.89 3347.10 3265.00 3880.28 3914.90 -1036.40 3742.47 0.00 0.00 0.00 O.OOG 5969155.52 594507.17 N 70.32533552 W 149.23363609 UG1 6660.99 63.48 107.89 3837.10 3755.00 4862.25 4896.87 -1338.04 4676.97 0.00 0.00 0.00 O.OOG 5968865.24 595445.16 N 70.32451004 W 149.22606068 Ma 7276.90 63.48 107.89 4112.10 4030.00 5413.35 5447.98 -1507.33 5201.43 0.00 0.00 0.00 O.OOG 5968702.32 595971.58 N 70.32404662 W 149.22180944 Na 7948.80 63.48 107.89 4412.10 4330.00 6014.56 6049. 18 -1692.00 5773.57 0.00 0.00 0.00 O.OOG 5968524.60 596545.86 N 70.32354096 W 149.21717195 OA 8351.94 63.48 107.89 4592.10 4510.00 6375.28 6409.91 -1802.81 6116.86 0.00 0.00 0.00 O.OOG 5968417.96 596890.43 N 70.32323750 W 149.21438956 V-118 58 Tg\ 8363.14 63.48 107.89 4597.10 4515.00 6385.30 6419.93 -1805.89 6126.39 0.00 0.00 0.00 O.OOG 5968415.00 596900.00 N 70.32322907 W 149.2143122. OBa 8486.32 63.48 107.89 4652.10 4570.00 6495.52 6530.15 -1839.74 6231.29 0.00 0.00 0.00 O.OOG 5968382.42 597005.28 N 70.32313634 W 149.2134621 OBb 8564.71 63.48 107.89 4687.10 4605.00 6565.66 6600.29 -1861.29 6298.04 0.00 0.00 0.00 O.OOG 5968361.68 597072.28 N 70.32307733 W 149.2129211 OBc 8687.89 63.48 107.89 4742.10 4660.00 6675.88 6710.51 -1895.15 6402.93 0.00 0.00 0.00 O.OOG 5968329. 10 597177.57 N 70.32298459 W 149.21207097 OBd 8811.07 63.48 107.89 4797.10 4715.00 6786. 11 6820.73 -1929.00 6507.82 0.00 0.00 0.00 O.OOG 5968296.52 597282.85 N 70.32289185 W 149.21122083 Crv 4/100 9158.22 63.48 107.89 4952.10 4870.00 7096.73 7131.36 -2024.42 6803.43 0.00 0.00 0.00 173.10G 5968204.69 597579.56 N 70.32263046 W 149.20882504 OBf Base / Top Colville 9169.33 63.04 107.95 4957.10 4875.00 7106.65 7141.28 -2027.47 6812.87 4.00 -3.97 0.54 173.08G 5968201.75 597589.04 N 70.32262210 W 149.20874851 9200.00 61.82 108.12 4971.29 4889.19 7133.84 7168.47 -2035.89 6838.72 4.00 -3.97 0.55 173.00G 5968193.65 597614.99 N 70.32259904 W 149.20853900 9300.00 57.85 108.69 5021.53 4939.43 7220.28 7254.91 -2063.17 6920.74 4.00 -3.97 0.58 172.71G 5968167.36 597697.33 N 70.32252430 W 149.20787424 9400.00 53.89 109.32 5077.63 4995.53 7303.02 7337.67 -2090.12 6999.00 4.00 -3.97 0.63 172.36G 5968141.37 597775.89 N 70.32245050 W 149.20724007 9500.00 49.92 110.01 5139.31 5057.21 7381.65 7416.35 -2116.58 7073.09 4.00 -3.96 0.69 171.93G 5968115.80 597850.30 N 70.32237800 W 149.20663957 9600.00 45.97 110.80 5206.28 5124.18 7455.81 7490.59 -2142.45 7142.68 4.00 -3.96 0.78 171.41G 5968090.78 597920.18 N 70.32230715 W 149.20607568 CM2 9691.75 42.34 111.61 5272.10 5190.00 7519.60 7554.49 -2165.55 7202.26 4.00 -3.95 0.89 170.82G 5968068.41 597980.03 N 70.32224390 W 149.20559284 9700.00 42.01 111.69 5278.21 5196.11 7525.12 7560.03 -2167.59 7207.40 4.00 -3.95 0.95 170.76G 5968066.43 597985.21 N 70.32223831 W 149.20555113 9800.00 38.07 112.73 5354.75 5272.65 7589.25 7624.35 -2191.88 7266.96 4.00 -3.94 1.04 169.97G 5968042.87 598045.05 N 70.32217179 W 149.20506849 9900.00 34.14 113.97 5435.53 5353.43 7647.89 7683.27 -2215.20 7321.06 4.00 -3.93 1.24 168.96G 5968020.20 598099.42 N 70.32210794 W 149.20463010 10000.00 30.22 115.49 5520.16 5438.06 7700.74 7736.51 -2237.44 7369.44 4.00 -3.92 1.52 167.68G 5967998.55 598148.06 N 70.32204706 W 149.20423809 10100.00 26.33 117.41 5608.21 5526.11 7747.55 7783.87 -2258.49 7411.86 4.00 -3.90 1.92 165.98G 5967978.02 598190.72 N 70.32198944 W 149.20389439 End Cry 10140.42 24.76 118.35 5644.68 5562.58 7764.71 7801.29 -2266.63 7427.26 4.00 -3.87 2.31 O.OOG 5967970.07 598206.23 N 70.32196715 W 149.20376957 CM1 10401.88 24.76 118.35 5882. 10 5800.00 7872.34 7910.80 -2318.63 7523.63 0.00 0.00 0.00 O.OOG 5967919.24 598303.21 N 70.32182484 W 149.20298874 Faull Crossing 10787.30 24.76 118.35 6232.09 6149.99 8031.01 8072.22 -2395.28 7665.70 0.00 0.00 0.00 O.OOG 5967844.33 598446. 18 N 70.32161505 W 149.20183772 TLBK 10787.31 24.76 118.35 6232.10 6150.00 8031.02 8072.22 -2395.28 7665.70 0.00 0.00 0.00 O.OOG 5967844.32 598446. 18 N 70.32161505 W 149.201837. Top HRZ 10996.54 24.76 118.35 6422.10 6340.00 8117.15 8159.85 -2436.89 7742.82 0.00 0.00 0.00 O.OOG 5967803.65 598523.79 N 70.32150115 W 149.201212 Base HRZ / KalulJik 11216.79 24.76 118.35 6622.10 6540.00 8207.82 8252.10 -2480.69 7824.00 0.00 0.00 0.00 O.OOG 5967760.84 598605.49 N 70.32138127 W 149.200555 V-118 Kup Tgt 11282.86 24.76 118.35 6682.10 6600.00 8235.02 8279.77 -2493.83 7848.36 0.00 0.00 0.00 O.OOG 5967748.00 598630.00 N 70.32134530 W 149.20035780 Top Kup 0/C4 11282.88 24.76 118.35 6682.11 6600.01 8235.03 8279.77 -2493.83 7848.36 0.00 0.00 0.00 O.OOG 5967748.00 598630.00 N 70.32134529 W 149.20035777 LCUIKupB 11354.44 24.76 118.35 6747.10 6665.00 8264.49 8309.75 -2508.06 7874.74 0.00 0.00 0.00 O.OOG 5967734.09 598656.55 N 70.32130634 W 149.20014404 Kup A5 11431.53 24.76 118.35 6817.10 6735.00 8296.23 8342.03 -2523.39 7903.16 0.00 0.00 0.00 O.OOG 5967719.10 598685.15 N 70.32126437 W 149.19991384 TMLV 11503.10 24.76 118.35 6882.09 6799.99 8325.69 8372.01 -2537.63 7929.54 0.00 0.00 0.00 O.OOG 5967705.19 598711.69 N 70.32122541 W 149.19970012 TO 17" Csg Pt 11503.11 24.76 118.35 6882.10 6800.00 8325.69 8372.01 -2537.63 7929.54 0.00 0.00 0.00 O.OOG 5967705.19 598711.70 N 70.32122541 W 149.19970008 Leqal Description: Northina IY) [ftUS] Eastinq IX) [ftUS] Suríace : 4896 F5L 1547 FEL 511 T11N R11E UM 5970146.49 590752.78 V-118 SB Tgt: 3088 F5L 703 FEL 512 T11N R11E UM 5968415.00 596900.00 V-118 Kup Tgt: 2399 F5L 3899 FEL 57 T11N R12E UM 5967748.00 598630.00 BHL: 2355 F5L 3818 FEL 57 Tl1N R12E UM 5967705.19 598711.70 WellOesi'Jll Ver 3.1RT-5P3.03-HF4.00 81d( d031rt-546) Plan V-118 (N-X)\Plan V-118 (N-X)\Plan V-118\V-118 (P5) Generated 3/16/2004 2:31 PM Page 2 of 2 ~ Õ 3000 0 L() C e:::.- " Q) (\Í ü (f) 0 > 4500 f- WELL FIELD Prudhoe Bay Unit - WOA STRUCTURE V _ Pad V-118 (P5) Magnetk:Pa~ Model: BOGM 2003 NAD27 Alaska State Planes. Zooa 04, US Feet Northing: 5970146.49 flUS GMCOnv: +0.69306719" Easting: 590152.78 flUS Scala Facl; 0.999909356 l\IDRef; Rotary Table (82.10fl aboveMSl) SlvyOate: March16,2004 Miscellémeous Slot· PlanV-118 (N-X) Plan: V-118 (P5) Surface Location Lat" N701941.410 Lon: W1491550.329 ~: 80.816' Mag Dec' +24,999' Date: Apri130,2004 FS: 57564.1 nT o 1500 3000 7500 9000 4500 6000 o RTF .,-..-..-"-,. __KOP Bid 1.5/100 ~ld2.5/100 ~~'d 4/100 Cry 4/100 '\ -,,,,,...p ... /End C rv '_.¡;:::_oo ~1 ~ ~ ~/ ". ~ ~ ~ ........... ~ ~ -",Vo'''':;'' Ig. ..-..-..-. JBd ........../ UOT oase I op "OIVllle "- CM2 VEndCrv \ TLBK \ Topf- ,Z \ '0 , .ue '.' _. rMLV TD/7"CS9J 7500 o e 1500 1500 3000 4500 e 6000 6000 7500 o 1500 3000 4500 6000 7500 Vertical Section (ft) Azim = 107.75°, Scale = 1(in):1500(ft) Origin = 0 Nt-S, 0 Ef-W 9000 mberger WELL V-118 (P5) Prudhoe Bay Unit - WOA STRUCTURE V -Pa d Ma9netk:~atëlmeters Model BGGM2003 Dip: 80.816' Mag Dac: +24,999' Date: ~ril30,2004 FS: 57564.1oT SutfaœLocation Lat N701941.410 Lon: W1491550.329 NAD27 Alaska State Planes, Zooe 04, US Feet Northing 5970146.49ftUS GridConv: +0.69306719" Eastir.g: 590752.78ftUS Scale Fact: 0,999909356 Miscellaneous Slo\: Plan V-118 (N-X) Plan: V-118 (P5) TVDRef RoIaryTabla {82.10/\atxweMSL) SrvyDale: March16.2004 o 1000 2000 3000 4000 5000 6000 7000 8000 e o o ^ ^ ^ z :2 -1000 -1000 (5 0 0 ~ g ~ II () ro ü r.fJ -2000 -2000 e r.fJ V V V -3000 -3000 o 1000 2000 3000 4000 5000 <<< W Scale = 1 (in):1000(ft) E >>> 6000 7000 8000 e e Oilfield Services, Alaska Schlumberger Drilling & Measurements Schlu erger 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8357 Tuesday, March 16,2004 Jim Smith Prudhoe Bay V-118 (P5) BP Exploration Alaska Nabors 7ES Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analvsis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey Proqram: Instrument Type MWD -IFR- MS Start Depth 28.50'md End Depth 11,503.11'md Close Approach Analvsis results: Under method (2), all wells may flow. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drillinq Aids to be provided: A drilling map and a traveling cylinder, will be provided. Checked by: Scott Delapp 03/16/04 e BPX AK Anticollision Report e NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation MethodMD Interval: 50.00 ft Depth Range: 28.50 to 11503.11 ft Maximum Radiu~DOOO.OO ft Reference: Error Model: Scan Method: Error Surface: Survey Program for Definitive Wellpath Date: 3/9/2004 Validated: No Planned From To Survey ft ft 28.50 11503.11 Planned: Plan #5 V1 Version: 3 Toolcode Tool Name MWD+IFR+MS MWD + IFR + Multi Station Casing Points PB Chev Tr K071112 K071112V1 11469.05 6500.00 1200.02 236.68 963.34 Pass: Major Risk PB Chev Tr K071112R K071112R V1 11469.05 6500.00 1200.02 236.68 963.34 Pass: Major Risk PB V Pad Plan V-01 (S-N) Plan V-01 ST OP (V-116 347.35 350.00 235.10 6.19 228.91 Pass: Major Risk PB V Pad Plan V-01 (S-N) Plan V-01 V10 Plan: PI 347.35 350.00 235.10 6.19 228.91 Pass: Major Risk PB V Pad Plan V-02 (N-I) Plan V-02 V5 Plan: Pia 346.43 350.00 265.25 6.07 259.18 Pass: Major Risk PB V Pad Plan V-112 (S-A) Plan V-112 V1 Plan: PI 344.77 350.00 425.68 6.37 419.30 Pass: Major Risk PB V Pad Plan V-115 (S-X) Plan V-115 V2 Plan: PI 496.53 500.00 181.60 8.51 173.09 Pass: Major Risk PB V Pad Plan V-115 (S-X) PlanV-115PB1 V1 Plan: 496.53 500.00 181 .60 8.51 173.09 Pass: Major Risk PB V Pad Plan V-119 (S-F) Plan V-119 V8 Plan: PI 346.48 350.00 358.87 6.01 352.86 Pass: Major Risk PB V Pad Plan V-203 (N-A) Plan V-203 VO Plan: V 345.58 350.00 385.42 7.53 377.89 Pass: Major Risk PB V Pad Plan V-204 (S-O) Plan V-204 V1 Plan: PI 395.42 400.00 225.38 6.88 218.51 Pass: Major Risk PB V Pad Plan V-205 (S-P) Plan V-205 V2 Plan: PI 347.70 350.00 217.25 6.13 211.12 Pass: Major Risk PB V Pad Plan V-206 (S-S) Plan V-206 V1 Plan: PI 348.24 350.00 195.93 6.47 189.46 Pass: Major Risk PB V Pad Plan V-207 (N-E) Plan V-207 V1 Plan: V 346.23 350.00 325.21 7.59 317.62 Pass: Major Risk PB V Pad Plan V-208i (N-C) Plan V-208 V1 Plan: V 345.91 350.00 355.17 7.59 347.58 Pass: Major Risk PB V Pad Plan V-209 (N-G) Plan V-209 V2 Plan: PI 346.10 350.00 295.13 6.11 289.02 Pass: Major Risk PB V Pad Plan V-211 (S-Q) Plan V-211 V1 Plan: PI 1169.82 1250.00 123.04 20.61 102.42 Pass: Major Risk PB V Pad Plan V-212 (S-D) Plan V-212 VO Plan: V 391.30 400.00 385.93 8.49 377.44 Pass: Major Risk PB V Pad Plan V-213 (S-W) Plan V-213 V2 Plan: PI 971.24 1000.00 135.65 16.92 118.74 Pass: Major Risk PB V Pad Plan V-213 (S-W) Plan V-213PB1 V2 Plan: 971.24 1000.00 135.65 16.81 118.84 Pass: Major Risk PB V Pad Plan V-214 (N-R) Plan V-214 V3 Plan: V 348.96 350.00 90.16 7.36 82.81 Pass: Major Risk PB V Pad Plan V-216 (N-T) Plan V-216 V4 Plan: PI 398.08 400.00 60.50 6.86 53.64 Pass: Major Risk PB V Pad Plan V-2a06i (N-M) Plan V-2a06i VO Plan: 348.05 350.00 165.54 7.83 157.71 Pass: Major Risk PB V Pad Plan V-3a06 (S-U) Plan V-3a06 V1 Plan: P 1517.86 1550.00 77.28 26.67 50.62 Pass: Major Risk PB V Pad V-03 V-03 V7 399.75 400.00 13.46 6.10 7.36 Pass: Major Risk PB V Pad V-100 V-1 00 V7 298.50 300.00 184.12 5.00 179.12 Pass: Major Risk PB V Pad V-101 V-101 V7 345.80 350.00 337.38 5.77 331.62 Pass: Major Risk PB V Pad V-102 V-1 02 V5 347.31 350.00 218.46 6.87 211.59 Pass: Major Risk PB V Pad V-103 V-1 03 V6 348.65 350.00 74.40 5.84 68.55 Pass: Major Risk PB V Pad V-104 V-104V13 346.44 350.00 280.59 5.68 274.90 Pass: Major Risk PB V Pad V-105 V-105 V13 396.03 400.00 151.20 6.46 144.74 Pass: Major Risk PB V Pad V-106 Plan V-106A V2 Plan: P 396.71 400.00 103.15 6.10 97.05 Pass: Major Risk PB V Pad V-106 V-106 V10 396.71 400.00 103.15 6.10 97.05 Pass: Major Risk PB V Pad V-107 V-107 V5 393.80 400.00 250.41 5.82 244.59 Pass: Major Risk PB V Pad V-108 V-1 08 V7 249.78 250.00 372.25 4.23 368.02 Pass: Major Risk PB V Pad V-109 V-109 V2 346.49 350.00 372.90 5.91 366.99 Pass: Major Risk PB V Pad V-109 V-109PB1 V5 346.49 350.00 372.90 5.91 366.99 Pass: Major Risk PB V Pad V-109 V-109PB2 V2 346.49 350.00 372.90 5.91 366.99 Pass: Major Risk PB V Pad V-111 V-111V25 399.20 400.00 42.23 7.20 35.03 Pass: Major Risk PB V Pad V-111 V-111PB1 V8 399.20 400.00 42.23 7.20 35.03 Pass: Major Risk PB V Pad V-111 V-111PB2V2 399.20 400.00 42.23 7.20 35.03 Pass: Major Risk PB V Pad V-111 V-111PB3V6 399.20 400.00 42.23 7.20 3503 Pass: Major Risk PB V Pad V-113 V-113V6 345.53 350.00 399.23 5.20 394.03 Pass: Major Risk PB V Pad V-114 V-114V5 300.00 300.00 347.28 4.95 342.33 Pass: Major Risk e BPX AK Anticollision Report e PB V Pad V-114 V-114A V4 300.00 300.00 347.28 4.95 342.33 Pass: Major Risk PB V Pad V-114 V-114APB1 V4 300.00 300.00 347.28 4.95 342.33 Pass: Major Risk PB V Pad V-114 V-114APB2 V2 300.00 300.00 347.28 4.95 342.33 Pass: Major Risk PB V Pad V-117 V-117V9 298.30 300.00 191.17 5.12 186.05 Pass: Major Risk PB V Pad V-117 V-117PB1 V6 298.30 300.00 191.17 5.12 186.05 Pass: Major Risk PB V Pad V-117 V-117PB2 V6 298.30 300.00 191.17 5.12 186.05 Pass: Major Risk PB V Pad V-201 V-201 V8 345.81 350.00 236.21 5.60 230.61 Pass: Major Risk PB V Pad V-202 V-202 V9 346.11 350.00 310.04 6.06 303.98 Pass: Major Risk PB V Pad V-202 V-202L 1 V5 346.11 350.00 310.04 6.01 304.03 Pass: Major Risk PB V Pad V-202 V-202L2 V5 346.11 350.00 310.04 6.01 304.03 Pass: Major Risk PB Z Pad Z-19 Z-19V1 11501.60 9050.00 2705.65 228.41 2477.24 Pass: Major Risk PB Z Pad Z-27 Z-27 V1 11498.00 7500.00 4526.14 231.38 4294.76 Pass: Major Risk PB Z Pad Z-30 Z-30 V7 11495.94 11200.00 1267.24 319.35 947.89 Pass: Major Risk PB Z Pad Z-30 Z-30A V9 11498.61 11200.00 1264.67 319.08 945.59 Pass: Major Risk PB Z Pad Z-31 Z-31 V1 11496.40 9850.00 2555.15 308.54 2246.60 Pass: Major Risk Field: Prudhoe Bay Site: PB V Pad Well: Plan V-118 (N-X) Wellpath: Plan V-118 \ - I '-. Plan V-2a06i ~iW~Iims¥¡J~¡ J 277 200 ]00 v-wan'VJ.o;!) v-,¥!-W¡~Xi~~~) 100 P]';;']",J_ii~~lR\)(~~~':.zO?J) V-107 (V-107) 200 277 V-IOO (Y-100)21 p]anV-Ol~,)!~~~!h) PlahV'105''(S:Þ)'(P]an Y-205) Plan V-206 (S-S) (P]an V-206) Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100ft/in] Site: PB V Pad Drilling Target Conf.: 95% Description: Map Northing: 5967748.00 ft Map Easting : 598630.00 ft Latitude: 70019'16.843N Shape: Rectangle Target: V-1l8 Kup Tgt Well: Plan V-118 (N-X) Based on: Planned Program Vertical Depth: 6600.00 ft below Mean Sea Level Local +N/-S: -2493.83 ft Local +E/-W: 7848.34 ft Longitude: 149° 12'0 l.288W Sides: L300 W300 ft on 0° Azi. .. o o 0 o 0 ø CJ CJ I CJ CJ m CJ CJ U CJ CJ CJ CJ CJ -2100 -2200 e -2300 N -24-00 -2500 e -2500 -2l00 -2800 CJ CJ N P 055261 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 3/2/2004 PR022604C DATE 3/2/2004 CHECK NO. 055261 PERMIT TO DRILL PPLlCATIONS POUCH TO TERRI UBBLE MB7-5 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE. AK99519-6612 PAY: B.iPJ~J· ~:::j TO THE ORDER OF: STATE 017 ALASKA AOGCC 333 WEST7TI-lf\VEN9E SUITE 100 ANCHORAGE AK 99501 V-~1 \0 RECEIV D APR - 2 20 4 lasks Oil & Gas Cons. Anchorage NATIONAL CITY BANK Ashland, Ohio No. P 055261 56-389 412 CONSOLIDATED COMMERCIAL ACCOUNT DATE 3/2/2004 1110 5 5 2 b ¡. III I: 0 I. . 2 0 318 q 5 I: o. 2 7 8 q b III H e e . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAMEfYt'Ú !/ ~/J( PTD# 2ðC/- (5~~ Development X Service Exploration Stratigraphic CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new weJlbore segment of LATERAL existing well . Permit No, API No. . (If API number Production. should continue to be reported as last two (2) digits a function' of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for the pilot bole must be clearly differentiated In both name (name on permit plus PH) .' and API :Dum ber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance with 20 AAC 25.055~ Approval to perforate and produce is contingent upon issuance of;J conservation order approving a spacing ex ception. (Companv Name) assumes the liability of any protest to tbe spacing . exception that may occur. DRY DITCH AU dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater tban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and 10' sample intervals tbrougb target zones. Administration Appr Date RPC 4/6/2004 Engineering Appr Date WGA 4/5/2004 Geology Appr RPC Date 4/5/2004 1 Ee(l1)il fee <!ttache.d Yes 2 Le<!s_e_numberappropri<lle_ _Y_es 3 _Unique weltnam_e_and o!'!mb.er _ _Yes _ _ _ _ _ 4 WellJoc<lled ina_defjrJe_d_ppoL Yes 5 WelUQc<lled p(oper_distance_ from driJling urJilboUrJd_alY_ _Yes 6 Wellloc<lt.ed p(oper _dlstan~ from otber welJs_ yes 7S_utfjcierJtacre<!ge_ayaitable indrilliog unjt_ Yes 8 Itd_evi<!ted, js_ weJlbQre pl<ltirJcJuded _Yes 9 Qpe(ator orJly <!ffected party _ Yes 10 _Qpe(ator bas apprppriate bond inJorce yes 11 Pj¡rmil Gan be iss!,!ed wjtbQut co_nservatiOrJ order Yes 12 Pj¡rmil Gan be iss!,!ed .wjtbQut <!dmirJist(atille_appr_oval Yes 13 _C_an permjt _be <lpprovj¡d before J 5-d<!y wait Yes 14 WeIlJQc<lt.ed withirJ <!rea <!nd_str¡;¡t<l_authorized by_lnjectipo Ord_er # (PulIO# in_com[11_ents) (For_ yes 15 _AJI welJs witJ1in _114_ mile_area_oJ reyiew jdentified (Fpr servjGe well OrJly) _ yes 16 Pre-produced injector; _dur<lt.ion_oJ pr.e-pro_ductipo tess th<!n_ 3 mOrJths (For_service well onJy) NA 17 ACMPJ'ïndin~Lof Con_sistency_h_as bee_nJssued_ fo( tbis p(oject _ _ _NA_ _Cpnduct.or string_provided Y_es _S_urfaGe_casirJ9.proteGts all_k)lown USDWs _ Y_es _ _ _ _ _ _ _ _ CMT vpl adeQl!ate_ to circ_utate OJl_corJd_uctO( & surt C$g yes .ð.de_quate excess, _CMT v91 ad.eQ!,!ate_ to tie-inJQngstring to_surf csg_ No_ _CMT wil] coyeraJlkOQWRPrQductiye bQrizons yes Casing designs <!deç¡uate tor C. T. B _&_ permafi'ost yes Adequ<ltet<!n_k¡;¡ge_or reserye pit Yes ItaJe-_drill. has a 10A0;3 JQr <lbandonment be_en <lpproved }~A Adequate_we]!b.ore sep<lr¡;¡ijo_nproposed_ Yes Itdjverter re~uired, does jt _me.et reguJatiorJs_ Y_es .Drilliog fJujd_ program sGhem¡;¡ticß! e~uip Jistadequ<lle _ Yes SØP_Es._dpthey meet. reguJatiorJ yes .SØP_E_press rating appropriate; Jest lO.(pl!t psig in_cpmmerJts). Yes C.hokemanjfold complies w/APt RF>-53 (May 84>- yes WQrk wi]! occ_ur withputoper<ltioJl_sbutdow.n_ _Yes Is presence Qf H2$ g<lS. probable _ _N.o_ .Mecbanic<ll. cpodition pt wells withirJ .ð.OR veriJied (FO( service welJ only) _ Yes _ _ _ .ð.IQ2A_ K!,!p_aruk 7- tH 2 !p&_a'd _explor¡;¡tory well)J08Q' form y~t18 <lUbe K!'!p<lruk Fm, TQP_ .... 18 19 20 21 22 23 24 25 126 27 28 29 30 31 32 33 34 N<!bors_9_ES, New welL M¡;¡x MW 10,2ppg._ Test loAOOQ psLMSF> 2192 psi. "',.4# No wells jn AOR. 35 P_ermil Gan be iss!,!ed .wIQ hydrogen_ sulfide meas.ures _ 36 .Data preseoted on potential pverpressur_ezOrJes_ 37 .S_eismicaJl¡;¡lysis_ of sballow gas_z_ooes_ 38Sj¡¡;¡bed _corJdjtipo s!'!rvey _(if off-shore) 39 . CQntact rJamelp_honeJorwe.ekly prpgress_reports (exploratpryonlYl Yes NA N.A NA NA Geologic Commissioner: Date: Engineering Commissioner: Date DTS Public Commissioner Date 4/14/2004 4/14/2004 JKN Field & Pool PRUDHOE BAY, BOREALIS OIL - 640130 PRUDHOE BAY, ORION SCHR Well Name: PRUDHOE BAY UN BORE V-118 Program SER Well bore seg D PLORATION (ALASKA) INC Initial ClassfType SER 12WINJ GeoArea Unit On/Off Shore On Annular Disposal D Administration Permit fee attacl)e.d. . _ . - - - - - - · Yes - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - 2 .Lease .number ~ppropriate. . . . . · Yes - - - - - - - - - - - - - - - - - - - - - - - 3 _U_niqueweltn.ame_a[1d oumb_er . _ _ . . _ _ _ _ . . . _ _ _ . . . . . . . _ _....... Yes ~ - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 4 WeJlJocated ina d.efines:t .ppol · Yes - - - - - - - - - - - - - - - - - - - - 5 WeUJQcated proper .distance. from driJling unitb.oundary . · Yes - - - - - - - - -- - - - - - - - 6 WellJQcated pr.operdistance. from other welJs - - - - - . · Yes - - - - - - - - - - - - - .. - - 7 .S~tficientacreaQ.e .aYail~ble in driUioQ. unjt · Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 Jfdeviated, js. wellbQre plaUncJuded . · Yes - - - - - - - - - - - - - - - - - - - - - - - - - 9 Operator only att.ected party . - - - - - - - - · Yes - - - - - - - - - - - - - - - - - 10 _Operator has_appr.opriate_ Qond in.fQrce _ _ _ . . . . . _ _ _ . . . . . ____..___Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - . - - - - - - - - -- 11 Permit Cé![1 be issued withQut co.nservation order. . . . . . . . . .Yes - - - - - - - - - - - -- Appr Date 12 Permit c.a[1 be issued witbQut ad.ministratÌlle.appr.ovaJ . - - - - - - ......... Yes - - - - - - - - - - - - - - - - - - - - - RPC 4/5/2004 13 Can permit be approved before 15-day wait Yes 14 WellJQcated within area and_strata ~uthorized by.lojectipo Order # (putlO# in.c.o01meotsHFQr. Yes AI024 e 15 AJlwelJs_wit!1iJl.1l4_mite_area_ofreyiewideotlfied(F.orservjcewellonly). _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes .0.(... ß7:¡(Ji h/¡')e.'fI..;Jwl ;';d¡. (,r'~i-lt1,)dJ:NJ 16 Pre-produ.ced i[1jector; s:tl,Jr~tiQn.of pre-pros:tl,Jc;tiolJ less. than 3 months. (Forsel'Vice well QnJy) . . NA . ....... - - - - . . . . ./;t.1í J:3Je;l/. - . 17 A{:MP finding .of Consiste[1CY has bee.n Jssl,Jed for this pr.olect · NA - ~ - - - - . . Engineering 18 .C.o[1ductor string.prQvided . · Yes - - - - ~ - - - - - - - - - - - - - - - - - 19 .Surface .casingpJQtects alLknown USOWs . .Yes - - - - - - - - - - - - - - - - - - - - - 20 .CMTv.oladec¡uate.to circ.ulate.on.conductor& su.rfq;g . . - - - - - - · Yes J\deql,Jate excess, . - - - - - 21 CMT v.ol adequateto tie-in JQng .stri[1g to surf csg. . - - - - - - · N.o - - - - - - - - - - - - - - 22 CMTwill coyer.aU known.produc;tiye hQri;!:on.s · .Yes - - - - - - - 23 Casiog de.sig[1S adeQua.te f.or C,.T, B.&p-ermafrosL Yes - - - - - - - - - 24 As:tequ~tetankage.oJ re_serye pit. . · Ye$ ~abors9ES, . . - - - - - - - . . 25 Jt.aJe-drill" bas a to:403 for ~bandonme.nt beeo ¡¡PPJoved . . . . . . . · NA ~ew welt . - - - - - - - - - - - 26 _Adequ<lte .w.ellbore separ¡¡tio_n .proposep. . . _ _ _ . _ . _ _ . . . . . _ . . . _ _ _Ye$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 27 Jt.diverter required, dQes it.meet reguJations . . . . . - - - - - - - - - · Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 28 .DJiUiog fluid p-rogram sc.hematic& equip JisLadequate. - - - - - - - - . Yes Max MW1Jl2ppg.. . . . . . . . - - - - - - - - - - - - - - - - WGA 4/5/2004 29 BOPEs,.d.oJhey meetreguJation . . . . . . .Ye$ - - - - - - - - - - - - - - -- 30 .B.OPEpre.ss ratiog appropriate; test to.(puJ psig inCOl)1ments). . . . ... Yes Test t.o 4000 psi. .MSFl2792 psi. . . _ _ . . - - - - - 31 Choke manifold compJies w/API RFI-53lMay 84) . ... Ye$ - - - - - - - - - - - - - - - - - 32 WQrk wiU pcc.ur withouLoperation .shutdQwn Yes . . . .. . . . . \¡.£Vtt. .~. - - - - - 33 Js prese[1ce. Qf H2S gas prob.able. . . - - - - - - - - . No. J~1ë. f1~.r 34 Meçhanic¡¡'-c~)I}djt[o[1.ot we.lI$ within J\OR yerified (Fpr.s.ervjce welJ only) . . .Yes ~ )(..1 -11- J:L "º~. ..... Geology 35 Permit c.a[1 be issued wlo hYdrogen. s.ulfide O1eas~res .Ye$ 36 .D.ata.pre.seoted on. pote.ntial oveJpres.Sl,Jre .zone$. . .NA Appr Date 37 Seis01icanalysjs. Qf shallow gas.z.ooes. . .NA RPC 4/5/2004 38 .Seabed .conditioo survey.(if off-sh.ore) . . . · NA 39 . Contact namelp!1oneJorweekly progress.report$ [explor¡¡tpry .only] · NA - - Geologic Date: Engineering Date Date Commissioner: Commissioner: b\:r tl t6 )<t