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Home My WebLink About203-040 ) 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. :1 œ - DLl-o Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 RESCAN ~Olor Items: D Greyscale Items: DIGITAL DATA ~can Needed OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner o Diskettes, No. D Other, No/Type: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Scanning Preparation x 30 = + o Other:: . -It Dateõ /1'# OS- Isl Yl1 P 1- ~ / Dateb 17 os 151 mf = TOTAL PAGES ~,tf . (Count do~s nof' clude cover sheet) íV11. ~ Date! i:) '7 oS' 151 I r I , I· BY: Helen ~ Project Proofing BY: Helen~. BY: HelenCMaria ") Production Scanning Stage 1 Page Count from Scanned File: ~ 5 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: / YE,S._ NO LJ Helen ~ DateS '7 06 Isl yŸ{, If NO in stage 1, page(s) discrepancies were found: YES NO BY: Stage 1 BY: Helen Maria Date: 151 1 I I 1 Date: 151 Quality Checked 111111111 III 111111I Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: • • T,,~,;::,~,. _ MICROFILMED 03101 /2008 DO NOT PLACE ,.~',.~. ~~... ~;Y `~ K ~p+: ~~fi ~i ~ ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_InsertslMicrofilm Marker.doc (QJ ~j '^~u IE rt).) I In',! 1 ë ~.,_....' I. lJ1. L L_::1 ) C ~ !Æ-l!Æ~L«!Æ ) ALASKA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit V-II 0 BP Exploration (Alaska), Inc. Permit No:· 203-040 Surface Location: 4897' NSL, 1547' WEL, Sec. 11, T11N, RIlE, UM Bottomhole Location: 4196' NSL, 2345' EWL, Sec. 01, T11N, RIlE, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness. any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager)~ Sincerely, k~~- Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED thiskf1ðay of March, 2003. cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section tJJGA- 3 í 14/1...0C 5 12. Distance to nearest property line 13. Distance to nearest well / ADL 028238,1083' MD V-03 is 12' away at 450' MD 16. To be completed for deviated wells Kick Off Depth 400' MD Maximum Hole Angle .¡ 8. Casing ~rogram Specifications Size Casina Weiaht Grade Couplina 34" x 20" 91.5# H-40 Weld 9-5/8" 40# L-80 BTC 7" 26# L-80 BTC-M Hole 42" 12-1/4" 8-314" , '\ STATE OF ALASKA ...,~ ALASKÁ .......t AND GAS CONSERVATION COMM¡__..~ION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 82.1' Prudhoe Bay Field I Borealis 6. Property Designation Pool (Undefined) ADL 028240 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number V-110 /' 9. Approximate spud dat~/ 04/01/03 I Amount $200,000.00 14. Number of acres in property 15. Pro~sed depth (MD and TVD) 2560 9531' MD / 6908' TVD o 17. Anticipated pressure {sey20 AAC 25.035 (e) (2)} 52 Maximum surface 2725 psig, At total depth (TVD) 6826' I 3408 psig Setting Depth Top Bottom MD TVD MD TVD Surface Surface 108' 108' Surface Surface 3469' 2772' Surface Surface 9531' 6908' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work II Drill 0 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 590753, Y = 5970146 4897' NSL, 1547' WEL, SEC. 11, T11 N, R11 E, UM At top of productive interval x = 594525, Y = 5974700 4123' NSL, 2284' EWL, SEC. 01, T11 N, R11 E, UM At total depth x = 594586, Y = 5974773 4196' NSL, 2345' EWL. SEC. 01, T11 N, R11 E, UM Number 2S 100302630-277 Lenath 80' 3441' 9503' Quantity of Cement (include staae data) 260 sx Arctic Set (Approx.) ./' 579 sx PF 'L', 312 sx Class 'G' , 308 sx Class 'G', 155 sx Class 'G' ./ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD ;~ 'J 'l3 Perforation depth: measured ~~C.~~~~ .}~~ ,,~':.I;~L~:<_:~,.~::= ~~ "~~'"uL~,;sL~:'~~ true vertical 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 AAC 25.050 Requirements Contact Engineer Name/Number: Rob Tirp, k, 564-4166 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that th forego' g is true and :P6r¡ect to the best of my ~nowl~~ge . Signed Lowell cra~ ~ /é£ Title Senior Dnlhn,g Engineer Date ,"'1"..-( 3 -;oJ p~~.~U~b~ ~ 0 ~:I ~~~ _: ;:j~~\ijP~iøì\lý(¡';i~l;o/j~e"·· ... ~~~~:re;~~~~ments Conditions of Approval: Samples Required 0 Yes JSa No Mud Log Required 0 Yes I2J No Hydrogen Sulfide Measures 0 Yes 12šI No Directional Survey Required 18 Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: "Te.s t-'IS i.' P E fo '100 C f" J . Approved By ~~'1 ;I2~dt.,~ Commissioner Form 10-401 Rev. 12-01-85 / by order of the commission Date Ò¥ff/03 Submit In Triplicate (~:j//Î It') ~ " ' '\ I ) ) IWell Name: IV-110 Drill and Complete Plan Summary I Type of Well (service 1 producer 1 injector): I Producer Surface Location: As-Built Target Location: Top Kuparuk Bottom Hole Location: x = 590,752.78' Y = 5,970,146.49' 4897 FSL, 1547' FEL, Sec. 11, T11 N, R11 E X = 594,525.00' Y = 5,974,700.00' 41231 FSL,2996IFEL,Sec.01,T11N,R11E X = 594,585.60' Y = 5,974,773.12' 41961 FSL,2934IFEL,Sec.01,T11N,R11E I AFE Number: I BRD5M409S1 I Estimated Start Date: 14/1/2003 I I I MD: 19531' I TVD: 16908' r-' r /" /' I RiQ: I Nabors 9ES I OperatinQ days to complete: 113.6 I BF/MS: 153.6' I RKB: 182.1' I Well DesiQn (conventional, slim hole, etc.): I Ultra slim I Objective: I Kuparuk Formation Mud Program: 12-1/4" Surface Hole (0-3469'): Initial below Permafrost interval TD Densitv (ppg) 8.5 - 9.2 9.0 - 9.5 / 9.5 max /" Viscosity (seconds) 250-300 200 150-200 8-3/4" Production Hole (3469' - 9531 '): Interval Density Tau 0 YP (ppg) 9.7 Upper Interval Top of HRZ 4-7 10.3/ 3-7 V -110 Permit to Drill - Final Yield Point (lb/100ft") 50 - 70 30 - 45 20 - 35 Fresh Water Surface Hole Mud Tau 0 APIFL PH (mls/30min) 15-20 <8 <8 >20 >15 >15 8.5 - 9.5 8.5 - 9.5 8.5- 9.5 PV pH Fresh Water LSND API HTHP Filtrate Filtrate 6-10 27 -32 8.5-9.5 1 0-15 17-25 1 0-15 8.5-9.5 4-6 <10 by HRZ Page 1 ") Directional: Ver. Anadrill P10 Slot NX KOP: 400' Maximum Hole Angle: Close Approach Wells: Survey Program: Logging Program: Surface Production Hole Formation Markers: Formation Tops SV6 SV5 SV4 Base Permafrost SV3 SV2 SV1 UG4A UG3 UG1 Ma WS2 (Na sands) WS1 (Oa sands) Obf Base CM2 (Colville) CM1 THRZ BHRZ (Kalubik) K-1 TKUP Kuparuk C LCU Kuparuk B Kuparuk A TD MD 982' 1724' 1892' 1912' 2551' 2792' 3308' 3984' 4307' 5193' 5628' 6006' 6272' 6868' 7392' 8390' 8954' 9172' 9210' 9253' 9253' 9381' 9508' 9531' TVD 977' 1642' 1772' 1787' 2202' 2352' 2672' 3092' 3292' 3842' 4112' 4347' 4512' 4882' 5207' 5892' 6372' 6572' 6607' 6647' 6647' 6767' 6887' 6908' V-110 Permit to Orill- Final ) 51.6~ at 2221' MD All Wells Pass Major Risk Criteria V-03 - 15' well centers at surface V-03 - 12' Ctr-Ctr @ 550' MD V-102 - 75' Ctr-Ctr @ 450' MD Gyro from surface to -1000' MD Standard MWD surveys (IFR+MSA Correction) to TD Drilling: Dir / GR Open Hole: None Cased Hole: None Drilling: Dir / GR / PWD Open Hole: PEX/BHC Sonic Cased Hole: USIT TVDss 895' 1560' 1690' 1705' 2120' 2270' 2590' 3010' 3210' 3760' 4030' 4265' 4430' 4800' 5125' 5810' 6290' 6490' 6525' 6565' 6565' 6685' 6805' 6826' Estimated Pore Pressure 8.8 ppg 8.8 ppg 8.8 ppg 8.8 ppg 8.8 ppg 8.8 ppg 8.8 ppg 8.4 ppg 8.4 ppg 8.4 ppg Hydrocarbon Bearing, 8.7 ppg Hydrocarbon Bearing, 8.7 ppg Hydrocarbon Bearing, 8.7 ppg Hydrocarbon Bearing, 8.7 ppg 8.6 ppg 8.6 ppg 8.6 ppg 8.6 ppg 8.6 ppg Hydrocarbon Bearing, 9.1 ppg Hydrocarbon Bearing, 9.1 ppg Hydrocarbon Bearing, 9.1 ppg Hydrocarbon Bearing, 9.1 ppg 150' below Kup B 10.; Page 2 ") ') , ; CasingITubing Program: Hole Csgl WtlFt Grade Conn Length Top Btm Size TbQ O.D. MDITVD MDITVD bkb 42" Insulated 91.~ H-40 WLJ" 80' GL 108/108 34"x20" 12-1/4" 9-5/8" 40# L-80 BTC 3441' GL 3469'/2772' 8-3/4" 7" 26# L-80 BTC-m 9503' GL 9531 '/6908' Tubing 3-1/2" 9.2# L-80 TC-II 9072' GL 9100'/6505' Integrity Testing: Test Point Depth Surface Casing Shoe 20' min from surface shoe Test Type LOT EMW 12.0 ppg (minimum for a 55bbl kick tolerance) Cement Calculations: The following surface cement calculations are based upon a single stage job The production cement calculation assumes cement will be required to cover 500' TVD above the top of the Schrader Ma sands with 1000 psi ultimate compressive strength and covering the entire Kuparuk interval with 2000 psi/24 hours compressive strength cement. Casinq Size 19-5/8" Surface I Basis: Lead: Based on 1912' of annulus in the permafrost @ 2500/0 excess and 757' of open hole from top of ta' lur y to base permafrost @ 30% excess. Lead TOG: To rfa Tail: Based on MD open hole volume + 30% excess + 80' shoe track volume. Tail TOG: At -2669' MD (500' TVD above Shoe) Total Cement Volume: Lead 428 bbl I 2403fe I 579 sks of Halliburton Permafrost L at 10.7 ppg and 4.15 cf/sk. Tail 64 bbl I 359 fe I 312 sks of Halliburton Premium 'G' at 15.8 ppg and 1.15 cf/sk. Casinq Size 17" Production Longstring I Basis: Lead: Based on TOG 500' TVD above the top of the Schrader Bluff Ma formation + 30% excess to the base of cement 500' TVD above top of Kuparuk formation. 51 2- f' Tail: Based on TOG 500' TVD above top of Kuparuk formation + 30% excess + 90' shoe track volume. Total Cement Volume: Lead 129 bbl I 726fe I 308sks of Halliburton Premium 'G' + 15 Ibs/sk Microlite at 12.5 ppg and 2.36 cf/sk. 32 bbl I 180 fe I 155 sks of Halliburton Premium 'G' (KUP Latex Design) at 15.8 ppg and 1.16 cf/sk. Tail V-110 Permit to Orill- Final Page 3 ) \) Well Control: Surface hole will be drilled with diverter. The production 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 planned casing test for future frac job considerations, 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: · Planned BOP test pressure: · Planned completion fluid: 3408 psi @ 6826' TVDss .,~ KU P-A 2725 psi @ surface /' /' (based on a full column of gas @ 0.10 psi/ft) 4000 psi (for future frac stimulation treatments) 8.6 ppg filtered seawater / 6.8 ppg Diesel Disposal: · No annular injection 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. H2S: · H2S has not been recorded on V-Pad wells. As a precaution Standard Operating Procedures for H2S should be followed at all times. V-110 Permit to Drill - Final Page 4 ) ) DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor was installed March 2003 at Slot NX. 1. Weld a FMC landing on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. V-03 well house should not have to be removed for the rig move. Rig Operations: 1. MIRU Nabors 9ES on Slot NX. /' 2. Nipple up diverter spool and riser. PU 4" DP as required and stand back in derrick. Test diverter line. 3. MU 12-1/4" drilling assembly with Dir/GR and directionally drill surface hole to approximately 90' TVD /' above anticipated SV1 sands (see Anadrill directional plan). An intermediate bit trip to surface will be performed prior to exiting the Permafrost. 4. Run and cement the 9-5/8", 40# L-80 surface casing back to surface. A Tam port collar will be run as /" a contingency on the chance that cement returns are not seen at the surface. " 5. ND diverter spool and NU casing 1 tubing head. NU BOPE and test to 4000 psi. / 6. MU 8-3/4" drilling assembly with drill ~iII and Dir/GR/PWD and RIH to float collar. Test the 9-5/8" casing to 3500 psi for 30 minutes. /' 7. Drill out shoe joints and displace well to 9.7 ppg LSND drilling fluid. Drill new formation to 20' below 9- 5/8" shoe and perform Leak Off Test. 8. Drill to ±200' above the HRZ, ensure mud is in good condition at 10.3 ppg and perform short trip as /' needed. During this time hold the 'Pre-Reservoir' meeting highlighting kick tolerance and detection. Drill ahead to -150' below Kup B. 9. Perform open hole logging program. PEX/BHCSonic. If the logging run is unsuccessful on the first e- line attempt, the logs are to be run on drill pipe. 10. If necessary, RIH and condition hole for running longstring. POOH. 11. Run and cement the production casing as required from TD to 500' TVD above the Schrader Ma /" sands. Displace the casing with filtered seawater during cementing operations and freeze protect the 7" x 9-5/8" annulus as required. 12. RU E-Line. Run USIT log from TD to TOC. RD E-line. 13. Run the 3-1/2", 9.2#, L-80, TCII gas lift completion assembly. Set packer and test tubing to 4000 psi / and annulus to 4000 psi for 30 minutes. Release tubing pressure and shear DCK valve. 14. Install TWC and test from below to 1000 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. / 15. RU hot oil truck and freeze protect the well by reverse circulating in a sufficient volume of diesel to reach the lower GLM. 16. Rig down and move off. V -110 Permit to Drill - Final Page 5 ) ') V-110 Drilling Program Job 1: MIRU Hazards and Contingencies ~ V-Pad is not designated as an H2S site. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. ~ The closest surface location will be V-03. V-03 will be -15' wellhead to wellhead. The well is expected to be on production and will require a surface shut-in during move in. ~ Check landing ring height on V-110, the BOP nipple up may need review. /" Reference RPs .:. "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" ~,~.,,\~,~a,a,W.;,',I,r,;,\~~I,~~I,~:,;':,:,r,~,<!,;,I,:,1~1,\:m,I,'I',:,'I,I,:,\~~_~:~",...,~.x."Jo:((«.:v.>:o:o:~(':::;,'"",:,;,1,\1,1,1,1,1,,; :::,:~:::"""l:G:'.f;e:¡,:,':,;;:.:":,'¡.'¡,;"¡,~,'¡,i';,¡,:,1,;,¡,¡,;;,¡,¡,';,~:;:,;',:':,:,;,',*",~;~:.<;,¡~,=AAC:C,:.~:~~:,'""\:"!(~.x(.x~~~""" .:~::1AA~,:,:,;:::x.;~:,;:,~m,:,r.l,;,\I,mr,<t,_,i~I,,\I_',:,U:,~;'-,I;,"I),';,:,I.I,:m\I,\:.I.<:,',I,:,IA:,;r.I,I,'II,'I,,1\1,I,ll,\\I,I,IJ,¡¡,:,I,I,r,II.;,\I,I,:;,1 Job 2: DrillinQ Surface Hole Hazards and Contingencies ~ One fault is expected to be penetrated by V-11 0 in the surface interval. The fault is expected to be crossed at 2500'MD/2182' TVD. It has an estimated throw of 100' to the West. This fault has been crossed before with out incident. ~ Drilling Close Approach: The nearest well is V-03, which will have a center-center distance of approximately 15' at the surface and 12' at 550' MD. The next closest well is V-102. It has a center to center distance of 75' at 450' MD. ~ A limited amount of gas hydrates have been observed on the surface holes drilled on V-Pad from 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 Baroid mud recommendation ~ Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. Reference RPs .:. uPrudhoe Bay Directional Guidelines" .:. UWell Control Operations Station Bill" ':;..";,~~,~~,,,,,~,~---:<::',,">:,,,,,,~'~~--",~ ~,~~,:;I;:,',:,-m"-,:,-,'-,:,:':,:;.,:,!;X;-,:,-;,':~,-,',:>.':,\I¡,:.~wn:<,~~ V -110 Permit to Drill - Final Page 6 ) ) Job 3: Install Surface Casinq Hazards and Contingencies þ> It is critical that cement is circulated to surface for well integrity. Plan 250% excess cement through the permafrost zone and 30% excess below the permafrost. A 9-5/8" port collar will be positioned at ±1 OOO'MD to allow a secondary circulation should cement to surface not be achieved. þ> "Annular Pumping Away" criteria for future permitting approval for annular injection. Note: Annular Injection not planned for this well Reference RPs .:. UCasing and Liner Running Procedure" .:. uSurface Casing and Cementing Guidelines" .:. uHalliburton Cement Program" .:. uSurface Casing Port Collar Procedure" ~,~~ ,~,;,;,;~~·?:,'~¡.,'w~~x'':<~(~~~(~~."¡('':'w,ç.'':>:-''o:.,~m<',t:l:: ~.~.<w'io.«-:.~~,,,., Job 7: Drillina Production Hole Hazards and Contingencies þ> KICK TOLERANCE: The reservoir pressure of the Kuparuk has been estimated to be 9.1 ppg due to production in the area. For the kick tole~ce calculations, a 9.6 ppg reservoir pressure was used. Assuming gauge hole, a fractu~re gf~~if¡.,.d. ient of 12.0 ppg at the surface casing shoe, 10.3 ppg mud in the hole the kick tolerance is 5 ~.øIS. An accurate LOT will be required as well as heightened awareness for kick detectio :'. tontact Drilling Manager if LOT is less than 12.0 ppg. ~ One fault is expected to be penetrated by V-110 in the production hole. This fault is near the base of the Colville at -8575'MD/6032' TVD. The throw is estimated @ -70' and is considered a risk for loss circulation. It is feasible however that losses may also be encountered when running the /" production casing string if adequate precautions are not taken including running speed, staging in and optimal mud properties. ~ V-Pad development wells have kick tolerances in the 35-50 bbl range. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. þ> There are no "Close Approach" issues with the production hole interval of V-113. þ> During the drilling of the Kuparuk reservoir do not add LCM (including Walnut sweeps, Barofibre) other than Baracarb for losses <50 BPH without prior discussions with the Drilling Engineer/Asset Production Engineer. Significant mud losses, >50 BPH may include the use of Barofibre to arrest losses. See modified LCM Decision Chart in Baroid Mud Program. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. uShale Drilling- Kingak & HRZ" ----.........-..-., .........-.".,.. .....'!At:IIt.....·.. y".w.....'..l_.(....·.....(."'..._......,. -'U "'....~_. ..",..- ,..... _" ..... \.~..._"'_ ._-._".. ....I>- ·......·-...._-.....-._.::o...-..;to,.......u ,_.... _y, _ ~ ..".'"..'"-.....:.<...._....""-,:......"'..~ ...01 __ """,_A< .___........."..--.,,-0("..,......(... V-110 Permit to Drill - Final Page 7 i ) ) Job 8: LOQ Production Hole Hazards and Contingencies )0> Ensure the hole is in optimal condition prior to logging to ensure a successful logging program. Review the use of lubricant pill across logging interval. )0> If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 7" longstring casing. Reference RPs .:. Follow Schlumberger logging practices and recommendations. .:. "Drillpipe Conveyed Logging" mm1imli!mmm:~~m::~~m .I!~m .Imnll'- .1.1..1 :1::- .1_ -T:::~lumm~nmm+IWI~I:::lImmmm:'::~_1I :::11. .1:U_~U!l: --uno, 1:-1::111I:-:1. -:::CIi r-:lln:I!I"':'N.xN:'¡~~H·m:~-· ........._'::_I:I!T-:t:I::T-II!I~!!!!::-_I!::n!:II!lm Job 9: Case & Cement Production Hole Hazards and Contingencies )0> The 7" casing will be cemented to 500' TVD above the top of the Schrader Bluff Ma sands with a single stage-two slurry cement. Getting casing to bottom while maintaining returns is a critical operation. )0> Considerable losses during the running and cementing of the production casing has occurred on L and V-Pad. A casing running program will be jointly issued by the ODE and Drilling Supervisor detailing circulating points and running speed. In addition, a LCM pill composed of "Steel Seal" will be placed across the Schrader and Ugnu to help arrest mud dehydration. )0> Ensure the upper production cement has reached at least a 70BC thickening value prior to freeze protecting. After freeze protecting the 9-5/8" x 7" casing outer annulus with dead crude to 2200' MD, 1984'TVD, the hydrostatic pressure will be 7.7 ppg vs 8.8 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 50 psi underbalance to the open hole. r; )0> Ensure a minimum hydrostatic equivalent of ;0fJpg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Loss ~~r1ole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. )0> The well will be under-balanced after displacing the cement with sea-water. Verify that the floats are holding before continuing operations and hold pressure on the well if they are not holding. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Halliburton Cement Program" Attached. .:. "Freeze Protecting an Outer Annulus" _'I::re:::- ~....-....-_-..:__~_ .t._1 "1_ -_-;·:'I:L':I:nl:I_I:.\!~IL':·I"t:II·""·.~..¥«·111 \ 1_ .1~::····_'C:·:.I~_·__"'m..n___m_"'~')I;1 V-110 Permit to Drill - Final Page 8 ) ') 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 will be under-balanced if there is a casing integrity problem. ~ Shear valves have been failing at lower than the 2500 psi differential pressure. When testing 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. Reference RPs .:. "Completion Design and Running" .:. "Freeze Protection of Inner Annulus" :T~--;llm*",+:::Y,ol::"··"··"·J.n·NjjJ.'-,j·"I·_'.··~_~m~IIII·.:IT::I~H«+r_oO«!lliT!_I. -:1:::. :1: -:-:::-:«LI:::X'W"'J'^",,~ .. ·...~,·,';"....--.,.~I:II:lml\:-!·· ...........-,.:.....,,_......"'.................,.''1(. ..,.........~*K.(*::.........,,(....... ··N4I-'_I:::I:-llml:lllmm~:~~~·:NIIII'I!!IT!::T!lm::I_:11111:-r!II::,::u:nlmnlll:TilIT::I: Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Standard practices apply. .:. Freeze Protection of Inner Annulus. ..·····..···NN~'^'W"U"'·· :·J....'...".n~«:H'::.I«,~¡~;; ;;t,m__r::,'I::::I:lllrlll:n::-.:...·WJn,.......·.,............'(.........I'''""..w'"f"m,:;:::::~¡:a'II:I:I':I:IU::I:~::::X+!~...._::::w·.......v.......,.....~._...,,~.·~:,_~ V-110 Permit to Drill - Final Page 9 ) ) V-110 Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates may be encountered near the base of the Permafrost at 1912' MD and near the TD hole section as well. · 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. · One fault is expected to be penetrated by V-11 0 in the surface interval. The fault is expected to be crossed at 250Q'MD/2182' TVD. It has an estimated throw of 100' to the West. This fault has been crossed before with out incident. · Drilling Close Approach: The nearest well is V-03, which will have a center- center distance of approximately 15' at the surface and 12' at 550' MD. The next closest well is V-1 02. It has a center to center distance of 75' at 450' MD. Production Hole Section: · A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential "1thile drilling/tripping the intermediate/production intervals. KICK TOLERANCt¡s 55 bbls ../' · One fault is expected to be penetrated by V-11 0 in the production hole. This fault is near the base of the Colville at ....8575'MD/6032' TVD. The throw is estimated @ ....70' and is considered a risk for loss circulation. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. · The production section will be drilled with a recommended mud weight of 10.3 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 10.0 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 will contribute to favorable hole conditions. 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. CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V-110 Permit to Drill - Final Page 10 TREE = WELLHEAD = ACTUATOR; .".." ,.""" '" ",,, ."........ KB. ELEV = BF:'äE\r;'" , I.n..............",......,.. . KOP= 'MaxÄrÏgie';'" ·OaiÙm··MÖ;······ Datum ìVD = 4-1/16" CrN FMC ... "'i\iA' 82' ."","""",;"""""". NA 300' .. ... .m"S2°" ) 8800' SS 19-5/8" Csg, 40#, L-80, BTC, ID=8.835" @ 3469'1 ~ Minimum ID = 2.813" @ 2200' 3-1/2" HES X NIPPLE 13-1/2" Tbg, 9.2#, L-80, TCII, 0.0087 bpf, ID=2.992" ÆRFORA TION SUMMARY REF LOG: TCP ÆRF ANGLE A T TOP ÆRF: xx @ xxxx' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE V-110 - =--1 I I I ~ L I I I /- ~I :8: ~ t ) 1000' 1-1 9-5/8" TAM PORT COLLAR 1 1-1 3-1/2" HES X NIP, ID = 2.813" 1 2200' GAS LIFT MANDRELS DEV TYÆ VLV LATCH PORT I MMG DCK-3 BTM 3.5x1.5 MMG Dummy BTM 3.5x 1.5 MMG Dummy BTM 3.5x1.5 MMG Dummy BTM 3,5x1,5 ST MD ìVD 1 5300' 2 4500' 3 3500' 4 1 jt above CMD 8970' 1-13-1/2" BKR CMD SLIDING SL V, ID = 2.813" 9000' II 7"X3-1/2" BKR Premier PKR,ID= 3.875" gm 3-1/2' HBXIIP, 0=2813' \ 9HJ 3-1f2' I-ESX~ Ð=2813' 9BJ Il 3-1f2' ~ Ð=2r03' I . 9220' 1-17" 26# x 20' PUP JT W/ RA TAG XXXX' 1-1 ELMD RA TAG LOGGED XXlXXlXX . 9350' 1-17" 26# X 20' PUP JT W/ RA TAG XXXX' 1---1 ELMD RA TAG LOGGED XXlXXIXX I PBTD 1-1 9451' 1 ~Jt. 17" Csg, 26#, L-80, BTC-m, 0.0383 bpf, ID=6.276" ~ DA TE REV BY COMMENTS 03/07/03 RBT PROPOSED COMP - w P 10 DA TE REV BY COMMENTS GPB BOREA LIS WELL: V-110 ÆRMIT No: A PI No: SEC 11, T11 N, R11 E 4896' NSL & 1547' WEL BP Exploration (Alas ka) ,-¡ - - - - - -l- - E Š.)¡",,:~ - - r - - - - - -l- - ì ï I II 15 " GRID I ..,11 '00'00" ( I PLANT .r-Z - I I I I I I I I ~ V-110 t V-03 : I + . V-10Oi I I V-400 I . V-ST I . V-103 I I . V-10B I I I I I I . V-105i I ï . SLOT NM I I I I I I g . V-102 I I d = V-201 I I; V-107 01 I . V-104i ~I I . V-111 enl ï zl I . · V-109 I V-101 .., I . V-113 I I . V-10B I I I I I I I I I ï \ : $" : V-PAD ~ I I /.... /l NOTE S 1. DATE OF SURVEY: MARCH 4, 2003. 2. REFERENCE FIELD BOOK: W003-01 PGS. 52-53. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD-27. 4. BASIS OF HORIZONTAL CONTROL IS V-PAD OPERATOR MONUMENTA~ON. 5. BASIS OF ELEVATION IS KUPARUK PIPELINE CONTROL. ELEVATIONS ARE BP MSL DATUM. 6. THE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. I ;> i'',J;: ,: h"\A\ J\.~ ~D" 34t,,' \I( ~', . ,/,,1. , ~ ~ t·, , ~ 'Ii , (.." ",... , ,~ .~ \ \ \,,,,,..,/1,., 0,)' . \ ~P7iWUK ~ STATE \\ 03-11-11. \ "I' \ '" ,I " ~ ";\"," ï~;,\"" /',~~; ~j "'9N' . \'~ "1\ ",.,,<, , \~i~;I,\~~~:r,(;,~" t~\k,,~\ \I \~ ~\ "1 ' ~\ ,.'~\ \:~. \, Tfi1;N 1~\ /J':f'::" ~": "'1 ~'~f:,~ c "\\.'~PROJECli"\!':, : "" ....'~1O,;:\S:~~~·1. \C~ !\::E~. ~;; ~~I>, (, ~A¡i>1, ", ""\'1 \ rl:~>' "\~I' 12 ,.i' . \..:¿~"J:~$, (~~'~):jii. ",...,.~/:J,\ 'C~}" ,;>,~', "..,~,<"" ',,' (Î ',\ \;,,( ',\\ ""\ ,I' ,,\, I ¡ \ .~ u " . ," t !v ,. "¡'IL ",.1'. :. y i ~ \. VICINITY MAP N.T.S. LEGEND + AS-BUILT CONDUCTOR . EXISTING CONDUCTOR 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. 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=10,180.39 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 Y=5,970,134.34 N=10,179.82 70'19'41.296" 70.3281378' 53.3' 4,886' FSL X= 590,709.62 E= 4,970.15 149·15'51.593" 149.2643314· 1,591' FEL WELL NO. V-110 V-400 F. RObett 1 -- I l]u '" I ~ ~~~rnœo DRAWN: JACOBS CHECKED: HACKELMAN DATE: 2/17/03 DRAWING. FRB03 WOY 01-02 JOB NO. o 3/06/03 ISSUED FOR INFORMAl1ON NO. DATE REVISION [NQNEERS AND LAND SURVEYORS 1!I01 'M:ST F1RtWtCO LANE: ANCHORAC[. ALASKA g9~ SCALE: 1-=150' JJC RFA BY CHK ObP WOA V-PAD AS-BUILT CONDUCTORS WELLS V-110 & V-400 SHEET: 1 OF 1 õ V-110 Proposed Well Profile - Geodetic Report Schlumberuer March 4, 2003 Survey / DLS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Prudhoe Bay Unit - WOA (Drill Pads) dy Vertical Section Ong," V-Pad 1 PlanV-110 (N-X) .1.... Stu ~Refere~ceD~~~ V-110 S·lbl I.~ TVDReferenceElevation: V-110 Fea Sea Bed/Ground Level Elevation: 50029 Magnetic Declination: V-110 (P10) 1 March 4, 2003 Total Field Strength: 83.260° 16008.81 ft 15.8391 0.87C Magnetic Dip: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: N 70.32816839, W 149.26397935 Magnetic Declination Model: N 5970146.110 flUS, E 590752,890 ftUS North Reference: +0.69306799° Total Corr Mag North -> True North: 0.99990936 Local Coordinates Referenced To: Report Date: Client: Field: Structure / Slot: Well: Borehole: UWUAPI#: Survey Name / Date: Tort / AHD / DDI/ ERD ratio: Grid Coordinate System: Location LatILong: Location Grid HIE YIX: Grid Convergence Angle: Grid Scale Factor: I KBE Base Gubik KOP Bid 1.5/100 Station ID Bid 3/100 SV6 SV5 V-110 (P10) report.xls Minimum Curvature 1 Lubinski 40.330° N 0.000 ft, E 0.000 fl KB 82.0 ft relative to MSL 54.000 ft relative to MSL 25.608° 57513.319 nT 80.mo April 04, 2003 BGGM 2002 True North +25.608° Well Head '-' Grid Coordinates Geographic Coordinates MD I Incl Azim TVD I vSec N/·S EJ·W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (o/10Oft) (ftUS) (ftUS) 0.00 0.00 37.81 0.00 0.00 0.00 0.00 0.00 5970146.11 590752.89 N 70.32816839 W 149.26397935 327.00 0.00 37.81 327.00 0.00 0.00 0.00 0.00 5970146.11 590752.89 N 70.32816839 W 149.26397935 400.00 0.00 37.81 400.00 0.00 0.00 0.00 0.00 5970146.11 590752.89 N 70.32816839 W 149.26397935 500.00 1.50 37.81 499.99 1.31 1.03 0.80 1.50 5970147.15 590753.68 N 70.32817120 W 149.26397286 600.00 3.00 37.81 599.91 5.23 4.14 3.21 1.50 5970150.29 590756.05 N 70.32817970 W 149.26395332 700.00 6.00 39.14 699.59 13.07 10.26 8.11 3.00 5970156.47 590760.87 N 70.32819641 W 149.26391358 800.00 9.00 39.58 798.72 26.12 20.34 16.40 3.00 5970166.64 590769.04 N 70.32822395 W 149.26384636 900.00 12.00 39.81 897.04 44.33 34.35 28.03 /3.00 5970180.79 590780.50 N 70.32826223 W 149.26375205 982.15 14.46 39.92 977.00 63.13 48.78 40.09 3.00 5970195.37 590792.38 N 70.32830165 W 149.26365425 1000.00 15.00 39.94 994.26 67.67 52.26 43.00 3.00 5970198.88 590795.25 N 70.32831115 W 149.26363065 <c~ 1100.00 18.00 40.03 1090.14 96.06 74.02 61.25 3.00 5970220.86 590813.23 N 70.32837060 W 149.26348266 1200.00 21.00 40.10 1184.39 129.43 99.55 82.73 3.00 5970246.64 590834.40 N 70.32844035 W 149.26330847 1300.00 24.00 40.15 1276.77 167.69 128.81 107.39 3.00 5970276.20 590858.70 N 70.32852028 W 149.26310849 1400.00 27.00 40.19 1367.02 210.74 161.70 135.15 3.00 5970309.42 590886.06 N 70.32861013 W 149.26288337 1500.00 30.00 40.22 1454.90 258.44 198.13 165.94 3.00 5970346.21 590916.41 N 70.32870965 W 149.26263368 1600.00 33.00 40.25 1540.15 310.68 238.01 199.69 3.00 5970386.50 590949.67 N 70.32881860 W 149.26235998 1700.00 36.00 40.27 1622.56 367.31 281.23 236.28 3.00 5970430.15 590985.73 N 70.32893667 W 149.26206324 1724.14 36.72 40.27 1642.00 381.62 292.15 245.53 3.00 5970441.18 590994.85 N 70.32896650 W 149.26198823 Schlumberger Private Page 1 of 3 3/4/2003-3:39 PM Grid Coordinates Geographic Coordinates Station ID MD I Incl I Azim I TVD vSec I NJ-5 I E/·W I DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (It) (0/10Oft) (ftUS) (ftUS) 1800.00 39.00 40.29 1701.89 428.18 327.66 275.63 3.00 5970477.05 591024.51 N 70.32906351 W 149.26174412 SV4 1892.04 41.76 40.30 1772.00 487.80 373.14 314.19 3.00 5970522.99 591062.51 N 70.32918775 W 149.26143140 1900.00 42.00 40.31 1777.92 493.11 377.19 317.63 3.00 5970527.08 591065.91 N 70.32919882 W 149.26140351 Base Perm 1912.25 42.36 40.31 1787.00 501.33 383.46 322.95 3.00 5970533.41 591071.15 N 70.32921595 W 149.26136036 2000.00 45.00 40.32 1850.46 561.93 429.67 362.16 3.00 5970580.09 591109.79 N 70.32934218 W 149.26104237 2100.00 48.00 40.34 1919.29 634.46 484.96 409.09 3.00 5970635.94 591156.05 N 70.32949322 W 149.26066176 2200.00 51.00 40.35 1984.23 710.49 542.91 458.31 3.00 5970694.47 591204.56 N 70.32965153 W 149.26026257 End Crv 2221.06 51.63 40.35 1997.39 726.92 555.43 468.95 3.00 5970707.12 591215.04 N 70.32968573 W 149.26017627 SV3 2550.67 51.63 40.35 2202.00 985.34 752.37 636.27 0.00 5970906.05 591379.95 N 70.33022372 W 149.25881921 SV2 2792.31 51.63 40.35 2352.00 1174.79 896.75 758.93 0.00 5971051.89 591500.85 N 70.33061812 W 149.25782433 '--' SV1 3307.81 51.63 40.35 2672.00 1578.94 1204.75 1020.60 0.00 5971363.00 591758.75 N 70.33145947 W 149.25570181 9-5/8" Csg Pt 3468.91 51.63 40.35 2772.00 1705.24 1301.01 1102.38 0.00 5971460.24 591839.35 N 70.33172241 W 149.25503842 UG4A 3984.41 51.63 40.35 3092.00 2109.40 1609.01 1364.05 0.00 5971771.35 592097.25 N 70.33256372 W 149.25291567 UG3 4306.60 51.63 40.35 3292.00 \ 2361.99 1801.51 1527.60 0.00 5971965.80 592258.45 N 70.33308953 W 149.25158882 UG1 5192.61 51.63 40.35 3842.00 3056.64 2330.90 1977.35 0.00 5972500.54 592701.72 N 70.33453549 W 149.24793971 Ma 5627.57 51.63 40.35 4112.00 .3397.64 2590.78 2198.14 0.00 5972763.05 592919.33 N 70.33524529 W 149.24614812 Na 6006.14 51.63 40.35 4347.00 3694.44 2816.97 2390.31 0.00 5972991.52 593108.73 N 70.33586306 W 149.24458865 Oa 6271.94 51.63 40.35 4512.00 3902.84 2975.79 2525.24 0.00 5973151.95 593241.72 N 70.33629682 W 149.24349364 Obf Base 6867.99 51.63 40.35 4882.00 4370.14 3331.92 2827.80 0.00 5973511.68 593539.92 N 70.33726944 W 149.24103807 CM2 7391.55 51.63 40.35 5207.00 4780.61 3644.74 3093.56 0.00 5973827.66 593801.85 N 70.33812375 W 149.23888097 Drp 2/100 7671.54 51.63 40.35 5380.81 5000.13 3812.03 3235.69 0.00 5973996.64 593941.94 N 70.33858061 W 149.23772727 7700.00 51.06 40.35 5398.58 5022.35 3828.96 3250.08 2.00 5974013.74 593956.12 N 70.33862684 W 149.23761046 7800.00 49.06 40.35 5462.78 5099.02 3887.39 3299.72 2.00 5974072.77 594005.05 N 70.33878641 W 149.23720751 7900.00 47.06 40.35 5529.61 5173.40 3944.08 3347.88 2.00 5974130.03 594052.51 N 70.33894122 W 149.23681657 8000.00 45.06 40.35 5599.00 5245.40 3998.95 3394.50 2.00 5974185.45 594098.46 N 70.33909106 W 149.23643812 8100.00 43.06 40.35 5670.86 5314.94 4051.94 3439.52 2.00 5974238.98 594142.83 N 70.33923577 W 149.23607265 8200.00 41.06 40.35 5745.10 5381.92 4103.00 3482.89 2.00 5974290.55 594185.58 N 70.33937521 W 149.23572057 '-" 8300.00 39.06 40.35 5821.63 5446.28 4152.04 3524.56 2.00 5974340.09 594226.65 N 70.33950913 W 149.23538229 CM1 8389.50 37.27 40.35 5892.00 5501.58 4194.19 3560.37 2.00 5974382.67 594261.94 N 70.33962423 W 149.23509158 8400.00 37.06 40.35 5900.37 5507.92 4199.02 3564.47 2.00 5974387.55 594265.98 N 70.33963742 W 149.23505829 8500.00 35.06 40.35 5981.20 5566.78 4243.88 3602.58 2.00 5974432.86 594303.54 N 70.33975992 W 149.23474891 8600.00 33.06 40.35 6064.04 5622.79 4286.56 3638.84 2.00 5974475.97 594339.28 N 70.33987647 W 149.23445453 8700.00 31.06 40.35 6148.79 5675.86 4327.01 3673.21 2.00 5974516.83 594373.16 N 70.33998693 W 149.23417550 8800.00 29.06 40.35 6235.34 5725.95 4365.18 3705.64 2.00 5974555.39 594405.12 N 70.34009117 W 149.23391222 8900.00 27.06 40.35 6323.58 5772.99 4401.02 3736.09 2.00 5974591.59 594435.13 N 70.34018904 W 149.23366500 Schlumberger Private V-110 (P10) report.xls Page 2 of 3 3/4/2003-3:39 PM Grid Coordinates Geographic Coordinates I Station ID MD I Incl I Azim I TVD I vSec N/-5 I EI·W I DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/10Oft) (ftUS) (ftUS) Top HRZ 8954.12 25.98 40.35 6372.00 5797.15 4419.44 3751.73 2.00 5974610.19 594450.55 N 70.34023934 W 149.23353803 9000.00 25.06 40.35 6413.41 5816.92 4434.50 3764.53 2.00 5974625.41 594463.16 N 70.34028046 W 149.23343411 9100.00 23.06 40.35 6504.71 5857.68 4465.57 3790.93 2.00 5974656.79 594489.18 N 70.34036531 W 149.23321977 Base HRZ 9172.74 21.60 40.35 6572.00 5885.32 4486.64 3808.82 2.00 5974678.07 594506.81 N 70.34042284 W 149.23307453 9200.00 21.06 40.35 6597.39 5895.24 4494.19 3815.24 2.00 5974685.70 594513.14 N 70.34044346 W 149.23302240 K-1 9210.29 20.85 40.35 6607.00 5898.92 4497.00 3817.62 2.00 5974688.54 594515.49 N 70.34045113 W 149.23300308 Top Kup/C 9252.97 20.00 40.35 6646.99 5913.81 4508.35 3827.27 2.00 5974700.00 594525.00 N 70.34048213 W 149.23292473 End Orp 1 Tgt 9252.98 20.00 40.35 6647.00 5913.82 4508.35 3827.27 2.00 5974700.00 594525.00 N 70.34048213 W 149.23292473 9380.67 20.00 40.35 6766.99 5957.49 4541.63 3855.55 0.00 5974733.62 594552.87 N 70.34057300 W 149.23269513 LCU 1 Kup B 9380.68 20.00 40.35 6767.00 5957.49 4541.64 3855.55 0.00 5974733.63 594552.87 N 70.34057303 W 149.23269513 -",-,"-' KupA 9508.38 20.00 40.35 6887.00 6001.17 4574.92 3883.83 0.00 5974767.25 594580.74 N 70.34066391 W 149.23246552 TO 1 7" Csg pt 9530.67 20.00 40.35 6907.94 6008.79 4580.73 3888.76 0.00 5974773.11 594585.60 N 70.34067977 W 149.23242550 Leaal Description: Surface: 4896 FSL 1547 FEL S11 T11 N R11 E UM Target: 4123 FSL 2996 FEL S1 T11N R11E UM BHL: 4196 FSL 2934 FEL S1 T11N R11E UM Northina IV) rftUSl 5970146.11 5974700.00 5974773.12 Eastina (X) rftUSl 590752.89 594525.00 594585.60 -' V-110 (P10) report. xis Schlumberger Private Page 3 of3 3/4/2003-3:39 PM : KOP BId 1.51100400 MD 400 TVD ip~i~;;~_ u~~~ _ _c_~_~~__ _ _ -;t- -'':'._~~:~~~ :,"" - - - - 51.63' 40.35' az 1705 departure -SI/ó 1724 IJO 1ir.Î21'\7D - - - - -, - - - - .1:-7- - - - - >- - - - - = = = = = = :;: = = -."',"',.,.,,,,"" '..;;.,;-""...o,iiilW - - - - ý: - - - - - :- - - - -.u .uu ~~~~~ i~~~T~-= ~ =-~ ~ t .._u__~_u )" ò 0- - -"- - - --- - - +-' Q):ì ~ CJ) 2000 - g ~ - o Q) C\I > II ~ c: CO :;:= _0 .r:.~ ã.~ Q) - om -~ ~~ :e Q) Q)CJ:: > ~ ~jjJ L.. I- 4000 ~ ,- ,- 6000 ...; - - '- 8000 - I -4000 - - - - Base Gubik 327 MO: 327 TVD - - - - - '- SV6 982 MD 9771YD VERTICAL SECTION VIEW Client: BP Exploration Alaska Well: V-110 (PlO) Field: Prudhoe Bay Unit - WOA Structure: V-Pad Section At: 40.33 deg Date: March 04, 2003 Schlumberger - - - - - ------------- SV1 3308 MD 2672 TVD ,- - ,- - - - - - - , . . , , , . , , , " , -¡-------~ -~Ið AhgTe"5f:63°¡ -- - - - - - - .- UG4A 3984 MO 3092 TVD' ------ UG3 4307 MD 3292 TVD - -- ---------,-_.._-- - - .- - - - - - - - -- --------------"-- -'- - - - - - - - ,- ____ _..J.Y.G.L 519:uA-º--~2 ~__+_ ------ . , . , ----- - --------------~--------:.--~._--~-------_._-- , , Ma 5628MO 4112TVD _ Llia ºº-06MD .1}47...IVD_ _ : Oa 6272 MO 4512 ïVD '- · , , , · . - !obfBãseS86Sþ.1D-4882ïVD ,- - "- - - - - - - - - - -- ¡ CM2 7392 MD 5207 TVD - - , , · ' _:-::~MLThOMD~TIID-=--_=:--!'=-=----=--_.=:_-=_=:_-=_.f=-=-=-_.=-__-=-m - !roPHRl 8954MO 6372ìVD- ¡- - - - - - - r- - - - - - ~ 1:=1=5:~~ ~o~ ~7~op!up~ ~3~ ~7~~ : : Kup A 9508 MD 6887 TVD ¡ ¡ HÇ>ld Angle 20.00° TDfrCsgPt 9531 MD 6908 TVD 20.00· 40.35' az 6009 departure ------- ~~Drp~Tgt_ 1.... _ 9253 MD 6647 TVD 30.1HP iB.3s::az$= =: ~9f!.de~ +- on ~ . u_ ............nn_..._ __on_n _non___n.nu__. nunnn.___ __._0__ ."_... ..___nnn_." ______u__n__ I -2000 I o I 6000 I 8000 t 2000 I 4000 Vertical Section Departure at 40.33 deg from (0.0, 0.0). (1 in = 2000 feet) - -~"" ._..._______.__nn..L-..nn_____ - - - -- - __...n_n______u__n_____nn__ I 10000 I 4000 --1000 ·-0 .......-... - 1000 I 3000 EAST »> I 2000 I 1000 «< WEST End CrY 2221 MD 1997TVD 51.63· 40.35· 8Z '·..·555'N'..469·E·.... 8-&18" CalJ pt 3469 MD ' 2772 TVD 51.63· 40.35· 8Z 1301 N 1102 E .'..--".... ,". .'.........'.... .....h....n.........._.___......._____;.....__....__....... 4000 ........ ............,..l-...................,...... 6000 i I i I TO/7"Call~ 9531 MD 6~08 TVD 20.00' 40.¥' 8Z End Drp I Tilt 4581 N 3889 E ...,.~~.~~.~º-...6.6.4.7..T.y-º.,...,.. '..,..,'.. ....."......1.,..., :~å~O~ ~å~~·E8Z " Q i ..... - 2000 ....- 3000 i Drp 2/100 7672 MDi 5381 TVD 51.63· 4þ.35· 8Z 3612 N ~236 E - 4000 .........- 5000 Schlumbøruør .".... ........,.. ........, .....?\'b~..... n" .. §' ~~ ?t~ ~ .... f"........ ,........",.............. ~ True North Mag Dee ( E 25.61° ."."."...".....",.......... 1000 ....,.......t.... "............ 2000 , 3000 PLAN VIEW Client: BP Exploration Alaska Well: V-110 (P10) Field: Prudhoe Bay Unit - WOA Structure: V-Pad Scale: 1 in = 1000 ft Date: 04-Mar-2003 ) ) I o -1000-.. 0-.... 1000 _... 2000 _....... 3000 _.......... ,. 4000 _.............. 5000 -...,... 6000 _........... o ö I I- ::> o en V V V ^ ^ ^ I I- a:: o z ) BP Exploration Alaska Anticollision Report Company: BP Amoco Field: Prudhoe Bay Reference Site: PB V Pad Reference Well: Plan V-110 (N,.X) Reference Wellpath: Plan V-110 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 9530.67 ft Maximum Radius: 3000.00 ft Date: 3/4/2003 Time: ' 15:00:25 .) Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan V-f1 o (N-X), True North V-110Plan82.0 Page: Survey Program for Definitive Wellpath Date: 9/13/2001 Validated: No Planned From To Survey ft ft 28.50 1000.00 Planned: Plan #10 V1 1000.00 9530.67 Planned: Plan #10 V1 Casing Points MD ft 3468.91 9530.67 Summary < Site PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad TVD ft 2772.00 6907.95 Diameter in Hole Size In 12.250 8.750 Name 9.625 7.000 95/8" 7" Offset Wellpath Well >- Wellpath Plan V (2-03HAW) (NPlan V (2-03HAW) VO PI Plan V (2-04HAW) (SPlan V (2-04HAW) VO PI Plan V (2-05HAW) (SPlan V (2-05HAW) VO PI Plan V (2-07i) (N-G) Plan V (2-07i) V1 Plan Plan V (2-08i) (N-C) Plan V (2-08i) V1 Plan Plan V (2-11 i) (S-J) Plan V (2-11 i) VO Plan Plan V (2-12i) (S-D) Plan V (2-12i) VO Plan Plan V (2-14i) (N-R) Plan V (2-14i) V3 Plan Plan V (2-15i) (S-P) Plan V (2-15i) VO Plan Plan V (2-16i) (N-T) Plan V (2-16i) V1 Plan Plan V (2-17i) (S-O) Plan V (2-17i) VO Plan Plan V (2-18i) (S- T) Plan V (2-18i) VO Plan Plan V (2a-06i) (N-M Plan V (2a-06i) VO Pia Plan V (2a-09i) (N-I Plan V (2-09i) V1 Plan Plan V (3a-06) (S-U) Plan V (3a-06) V1 Plan Plan V-01 (S-N) Plan V-01 V8 Plan: V-( Plan V-02 (S-K) Plan V-02 V4 Plan: V-O Plan V-111 (S-G) Plan V-111 V6 Plan: PI Plan V-112 (S-H) Plan V-112 Lat V1 Plan Plan V-112 (S-H) Plan V-112 V6 Plan: PI Plan V-114 (S-R) Plan V-114 V2 Plan: PI Plan V-115 (S-B) Plan V-115 V1 Plan: PI Plan V-116 (S-L) Plan V-116 V3 Plan: PI Plan V-117 (S-X) Plan V-117 V2 Plan: PI Plan V-202 (N-F) Plan V-202 V1 Plan: V- Plan V-400 (N-U) Plan V-400 V5 Plan: PI Plan V-Pi (S-A) Plan V-Pi V1 Plan: Pia V-03 V-03 V7 V-100 V-100 V7 V-101 V-101 V7 V-102 V-102 V5 V-103 V-103 V6 V-104 V-104 V13 V-105 V-105 V13 V-106 V-106 V10 V-107 V-107 V5 V-108 V-108 V7 V-109 V-109 V2 V-109 V-109PB1 V5 V-109 V-109PB2 V2 V-113 V-113 V6 V-201 V-201 V8 Version: 2 Toolcode GYD-GC-SS MWD+IFR+MS Reference MD ft 399.99 769.88 495.73 447.11 446.57 446.27 490.96 449.03 447.45 842.85 350.00 399.99 496.68 542.11 873.92 467.92 492.79 668.22 399.99 399.99 494.97 399.49 446.07 399.49 493.80 646.54 399.49 549.58 398.39 446.43 447.68 448.69 399.69 496.50 448.15 494.62 249.68 537.40 537.40 537.40 445.34 398.48 Offset MD ft 400.00 800.00 500.00 450.00 450.00 450.00 500.00 450.00 450.00 850.00 350.00 400.00 500.00 550.00 900.00 450.00 500.00 700.00 400.00 400.00 500.00 400.00 450.00 400.00 500.00 650.00 400.00 550.00 400.00 450.00 450.00 450.00 400.00 500.00 450.00 500.00 250.00 550.00 550.00 550.00 450.00 400.00 Reference: Error Model: Scan Method: Error Surface: Db: " Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Tool Name Gyrodata gyro single shots MWD + IFR + Multi Station Ctr-Ctr No-Go Distance, Area ft ft 385.82 8.81 216.28 16.21 196.07 10.68 295.43 9.76 355.20 9.75 308.46 9.47 385.78 10.73 90.13 9.18 216.57 9.68 54.13 17.81 208.61 7.65 190.49 8.47 165.68 10.68 266.19 11.61 178.71 18.80 235.09 10.01 297.18 10.55 342.25 12.60 333.50 8.58 333.50 8.48 202.23 9.41 412.17 7.39 284.49 8.04 180.61 7.37 310.84 9.92 33.12 12.05 425.77 7.29 12.40 8.99 184.99 6.78 337.31 7.51 219.09 8.81 74.65 7.85 280.76 6.79 150.29 8.48 101.93 7.08 249.68 7.94 372.26 4.41 373.88 9.05 373.88 9.05 373.88 9.05 399.69 7.03 236.36 6.67 Allowable Deviation ft 377.01 200.31 185.38 285.67 345.44 298.99 375.05 80.95 206.90 36.42 200.95 182.02 155.00 254.59 160.10 225.08 286.63 329.67 324.91 325.02 192.81 404.78 276.45 173.24 300.92 21.08 418.48 3.42 178.21 329.81 210.28 66.82 273.97 141.81 94.85 241.77 367.86 364.85 364.85 364.85 392.67 229.70 Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Polygon I 2 3 4 Site: PB V Pad Drilling Target Conf.: 99% Description: Map Northing: 5974700.00 ft Map Easting : 594525.00 ft Latitude: 70020'25.736N +N/-S ft -218.61 104.24 375.3] -2.72 ) Target: V-I10 Kup Tgt +E/-W ft -117.66 -348.80 -20.46 225.00 )11: Plan V-II0 (N-X) Based on: Planned Program Vertical Depth: 6565.00 ft below Mean Sea Level Local +N/-S: 4508.34 ft Local +E/-W: 3827.27 ft Longitude: 149°13'58.529W Northing ft 5974480.00 5974800.00 5975075.00 5974700.00 Easting ft 594410.00 594175.00 594500.00 594750.00 200 5100 5000 4-900 4-800 4-l00 4-500 4-500 4-4-00 4-300 4-200 4-100 ~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 D D D D ~ ~ -=I- Ln LO r- CD a- D N (I) m m m m m m -=I- -=I- -=I- -=I- .~ ~ IP055010 - -----_.._-----~---_._--- DATE INVOICE I CREDIT MEMO - . -- _._._----~-- - 12/19/2002 INV# CK121702S . ..__.__..__"._ __ _u.~___. _._____~._~_ TOE'. I\TTI\CI 1Ft} ~IEGI( IS IN PAYMENT Fon ITEMS DESCRIBED ABOVE. -- ---.---------. -_..,- ..__.-_. -_.--_._~_._-- --- BP f:D(PLORATlOI\I, (ALASKA) INC. PRUDI·IOF:: BAY UNIT rlQ BOX ·1966'12 ANCHOfV\GE, AI< 99519-66·12 PAY: DESCRIPTION PERMIT TO DRILL FEE ~ .r~~ h)~· {) r~-,~ '1"· 1 r In,! A. ~.¿f .. . ..- .,,,t ..d,. -~------ DATE 12/19/2002 CHECK ¡\!O. P055010 GROSS VENDOR DISCOUNT ¡\JET ~I __ ~-_._- f<f(~ ~ ,,~ .. ì\! ED ~ll ~. . IV\!\D 1.J):7f 'Jon:; \ \"""\ ¡ ,,~;d.J r-\:.. - . ~..,,"...,..--- ,", i~;;~ '/1 '\~~~,~~~~: L;J~~~(!J\1 -' ~·T--~~ NATIONAL CITY BANK Ashland, Ohio NOrnP 055010 56-389 412 CONSOLIDATED COMMERCIAL ACCOUNT ¡feu.~J t--~:' ut¡!.' ,~/~- DATE AMOUNT TO THE ORDER OF: ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501 December 19, 2002 ***************$100.00**1 Ni~Î~;;AYS ~~~~~~-.-------~~-~---~~ 1110 5 5 0 ~ 0 III ~ = 0 ~ ~ 20:1 B g 5 ¡ ~ 0 ~ 2 ? B g b liD ') ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMtTTAL LETTER CHECK WHAT APPLIES Rev: 07/1 0/02 C\j ody\templates WELL NAME PTD# ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to', be reported as a function· of the original API Dumber stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuanceofa conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sam pie intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY 131 X WELL NAME/ða t,J- //0 PROGRAM: Exp _ Dev X Redrll_ Re-Enter _ Serv _ Wellbore seg_ FIELD&POOL b7'CJ/3d INITCLASS £)e-;/ /-0// GEOLAREA ?qr::;> UNIT# //.Á_~t? ON/OFFSHORE~ ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . R N / 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y , N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N ¿;?/)/ ~ /')1.2 ,¿ ::> 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N £.J.iZ-= ..?/ /.;~ 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . , Y ~ N 12. Permit can be issued without administrative approval.. . . . . W N (Service Well Only) 13. Well located wlin area & strata authorized by injection order#-l /LI.;.;:9, (Service Well Only) 14. All wells wlin % mile area of review identified. . . . . . . . .. N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . N 16. Surface casing protects all known USDWs. . . . . . . . . . . n N L 17. CMT vol adequate to circulate on conductor & S, urf csg. . . . . œ ~ Æ-cú q ~L (~'- Ø'I. ef' ~ ç , 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . j(hV 0 19. CMT will cover all known productive horizons. ,. . . . . . . . . N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . N ,, \ 21. Adequate tankage or reserve pit. . . . . . . . . . . . . . . . . N 1\.l~t9rÇ qé~ 22. If a re-drill, has a 10-403 for abandonment been approved. . ,. 71N--1'i/k 23. Adequate wellbore separation proposed.. . . . . . . . . . . . GYj-..N¡N 24. If diverter required, does it meet regulations. . . . . . . . . . ,N " J 25. Drilling fluid program schematic & equip list adequate. . . . . . N ¿IJ1 ~ fIÎ II-l J 0 I'~ P fJ 7 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . "Z;) N 27~ BOPE press rating approp,riate; test to' t.f 000 psig. g¿æ. N iIJIl S ¡/ 7.- 7 ~s {J ~ / . 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N idGA- 311~/o 1. 29. Work will occur without operation shutdown. . . . . . . . . . . ~_',_ 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y (bV 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥--N--/\//k- ~ ;r AJ· Ii I RESERVOIR ENGINEERING APPR DATE APPR DATE (Service Well Only) GEOLOGY APPR DATE /ßJ 3ji65 " (É,zploratory Only) Rev: 2/25/03 \well_perm iC checklist 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . .. ...... 36. Contact namelphone for weekly progress' reports; ...... GEOLOGY: R~ PETROLEUM ENGINEERING: UIC ENGINEER COMMISSIONER: SP ~Æ~' RR ¥"7cJ.,r-\ DS TM JH JR SFD_ WA/ MW ( ( Comments/Instructions: