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Home My WebLink About206-015• Image Prcaject Well t-li~tcary file ~c~ver Page xl-IVZ~ This page identifies those items that were not scanned during the initial production scanning phase. "1-hey are available in the original File, niay be scanned during a special rescan activity or are viewable by direct inspection of the file. (~ ~- ~ 1 ~ Well History File Identifier Organizing (done> RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Two-sided III (I'IIIIIIII VIII DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: ~~ ~es~.~~~aed iuuiiiiiuiiio OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Nan-Scannable) ^ Logs of various kinds: ^ Other:: ^ Other: NOTES: BY: ~~ Maria ~;' Date: ~ ~ ~ (~~ (~(~ /s/ ~ `/ Project Proofing I BY: Maria Date: ~ 11n ~/~', ~ lsl • ~ Scanning Preparation x 30 = + =TOTAL PAGES (Count does not include cover sheet) ; BY: Maria Date: ~ ~~~~'~ ~'~ ls/ Production Scanning Stage 1 Page Count from Scanned File: _~~ (Count does include covers eet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria ~' Date: ~ ~ ~ /s/ ~~i Stage 1 If 1;1O in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II'I II i II II I I III ReScanned II I II ~I II ~ I III I I III BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III III III III 10/6/2005 Well History Fiie Cover Page.doc ~: ~~ , ~"~~ ~l ~. ~ ~, .. :-k~~ ~: ~~~ ,, . ~. ~` MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE. C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc Page 1 of 1 Okland, Howard D (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Wednesday, March 04, 2009 4:16 PM To: Okland, Howard D (DOA) Subject: RE: PBU K-10C Na, there have been no drilling operations on this well, and we are aware the Permit has expired. Thanks! Terrie From: Okland, Howard D (DOA) [mailto:howard.okland@alaska.gov] Sent: Wednesday, March 04, 2009 3:27 PM To: Hubble, Terrie L Subject: PBU K-10C Terrie, The permit for drilling the following well has expired. Have any drilling operations been done on this well? PBU K-10C PTD 206-015 API 50 029 21762 03 TNX Howard 3/5/2009 ~ • ~: a ~ ~ ~~ ,~+ ~ ~ ~ ~{ , "11~ ~ ~ ~ ~ ~ ~ FRANK H. MURKOWSKl, GOVERNOR 1 ~~ ~ ~ ~ ~ ~~ ~~ ~~ ~~++ 3~ AiIL7•-7~ OiJII ~ ~-7 333 W. 7T" AVENUE, SUITE 100 COI~TSER~A'rIO1~T COMI~'II5SIOI~T ~+'~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay, PBU K- l OC BP Exploration (Alaska), Inc. Permit No: 206-015 Surface Location: 2007' SNL, 4817' WEL, SEC. 04, T 11 N, R 14E, UM Bottomhole Location: 4041' SNL, 3308' WEL, SEC. 04, T11N, R14E, UM Dear Mr. Wesley: 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 an approval 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Cathy . Foerster ~fi Commissioner DATED this ~JI day of January, 2006 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~D STATE OF ALASKA ALASKA AND GAS CONSERVATION CO~ISSION PERMIT TO DRILL 20 AAC 25.005 ,IAN 3 0 2006 Alaska Oil & Gas Cans. Gorrrnission Anchorage 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development Oil ^ Multiple Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU K-10C "~~P~~'a 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11592 TVD 8700 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 4817' WEL 2007' SNL 04 T11N R14E UM ~ SEC 7. Property Designation: ADL 028303 Pool , , , , , . Top of Productive Horizon: 3858' SNL, 1963' WEL, SEC. 04, T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spu rate: Marc , 2006 T al epth: 4 4 SNL, 3308' WEL, SEC. 04, T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 19,500' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 670732 - 5975196 Zone- ASP4 10. KB Elevation plan (Height above GL): 54.g feet 15. Distance to Nearest Well Within Pool 588' 16. Deviated Wells: Kickoff Depth: 3150 feet Maximum Hole Angle: 91 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3270 Surface: 2412 ~ 113. using rogram: Size Specffications Setting Depth To Bottom uantity o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M 6437' 3000' 2999' 9437' 8188' 73 sx LiteCrete, 168 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 2307' 9285' 8043' 11592' 8755' 85 sx Class 'G' i9. PRESENT WELLCONDITION SUMMARY (To be completed for Redrill AND Re-e ntry Operations) Total Depth MD (ft): 11302 Total Depth TVD (ft): 8763 Plugs (measured): None Effective Depth MD (ft): 11268 Effective Depth TVD (ft): 8761 Junk (measured): None Casin Len h Size Cement Volume MD TVD r Con r 110' 20" cu ds Concrete 110' 110' 2694' 13-3/8" 1860 cu ft AS III, 1860 cu ft AS II 2694' 2694' 9479 9-5/8" 1973 cu ft Class 'G' 9479' 8639' 403' 7" 345 cu ft Class 'G' 9197' - 9600' 8384' - 8747' Liner 1325' 3-1/2" x 2-7/8" 0 cu ft Class'G' 9200' - 9619' 8387' - 8765' Liner 2-3/8" 67 cu ft Class 'G' 9111' - 11302' 8306' - 8763' Perforation Depth MD (ft): 10300' - 11255' Perforation Depth TVD (ft): 8763' - 8761' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®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 Matt MaN.yn, 564-4101 Printed Name a Wesley Title Senior Drilling Engineer / Prepared By Name/Number: Si nature Phone 564-5153 Date //z?~~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: .. ~ API Number: 50- 029-21762-03-00 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Samples Required ^ Yes j~No Mud Log Required -,. Yes ~No L Hydrogen Sulfide Measures "Yes ^ No Directional Survey Required Yes ;J No Other: ~ 2S~C [30 (~ E ~-0 3 Sor7 hS~' . 7.~,, 2 ~ ~`t-L 25.0 3 S (~) ~ ~ ~ ~ 0..~~~t.[.c~-~ ~~ ~~ tPh~ ~l't~G2a!ux.-~ G S ~~1-17-t/~ . APPROVED BY A roved B THE COMMISSION Date Form 10-401 Revised Q~/2004 ~ ~ ~~ t Submit In Duplicate • ~ Well Name: K-10C Planned Wetl Summary Horizontal Well K-10C ~ Well Sidetrack Target Zone 1 A Type Producer Objective AFE Number: PBD4P2398 API Number: 50-029-21762-03 Current Status K-10B Shut-In and P&A Procedures commencing Estimated Start Date: 5-March-2006 Time to Com lete: 24.5 Da s Surface Northin Eastin Offsets TRS Location 5,975,196 670,732 2008' FNL / 4818' FEL 11 N, 14E, 4 Northin Eastin TVDss Offsets TRS Target 5,973,397 673,624 -8,665 1407' FSL / 3307' FWL 11 N, 14E, 4 Locations 5,973,213 673,278 -8,660 1231' FSL / 2956' FWL 11 N, 14E, 4 Bottom Northin Eastin TVDss i~Offsets TRS Location 5,973,231 672,293 -8,700 0 'FNL / 1972' FWL 11 N, 14E, 4 a~- Planned KOP: 3150'MD / 3093'TVDss Planned TD: 11,592'MD / 8,700' TVDss Ric : Nabors 9ES ~ CBE: 26.38' RTE: 54.9' Directional - Anadrill P11 KOP: 3150' MD Maximum Hole Angle: ~44° in the 8-1/2" intermediate section (tangent sail angle) --91 ° in the 6-1 /8" horizontal section Close Approach Wells: Only K-06A does not pass BP's anti-collision policy for major risk. The well passes minor risk criteria at 1/200. It will be secured with a tubing tail plug and pressures bled to zero before drilling past. K-20B passes Major Risk criteria, but has acenter-to-center distance of 70.2'. Allowable deviation from Ian at 5200' MD is 13.1 ft. Survey Pro ram: MWD Standard + IFR /Cassandra / MS Nearest Pro ert Line: 19500' to the PBU property line Nearest Well within Pool: K-16A is 588' away from planned well K-10C at 11,578' planned MD. K- l OC Drilling Program Page • • Formation Markers K-lOC (Based on SOR) ormation Estimated Estimated Formation Tops Pore Press. (PPg (TVDss) (MDbkb) E uivalant) (Psi) SV5 -2931 SV4 -3180 3238.55 UG4 -4666 4916.92 UG3 -4896 5236.29 UG1 -5413 5956.12 CM3 -6391 7316.09 CM1 -7287 8535.63 CM2 -7445 8716.41 Fault #1 -7500 8777.07 THRZ -7811 9103.41 BHRZ/LCU -7908 9203.83 TJD -8018 9317.71 TJC -8073 9374.65 TJB -7953 9250.42 TJA -8043 9343.59 TSGR -8133 9436.77 TSH U -8200 9506.02 TSAD -8216 9522.5 42S6 -8268 9576.03 TCGL -8327 9637.1 BCGL -8378 9690.09 21 TS -8524 9855.93 TZ7 B -8583 9940.63 7.33 3270 TZ1 AlTDF -8628 10026.55 BSAD/Kavik -8665 10874.49 Casinq/Tubinq Program Hole Csg / Wt/Ft Grade Conn Burst Collapse Length Top Bottom Size Tbg (psi) (psi) MD / MD / O.D. TVDrkb TVDrkb 8-1/a" 7" 26# L-80 BTC-M 7,240 5,410 6,437' 3000' / 9,437' / 2,999' 8,188' 6-1/8" 41/z" 12.6# L-80 IBT-M 10,160 10,530 2,307' 9,285' / 11,592' / 8,043' 8,755' Tubing 41/z" 12.6# L-80 IBT-M 10,160 10,530 9,263' 22' / 22' 9,285' / 8,043' K-lOC Permit to Drill Application Page • • Mud Program Whipstock Millina Mud Properties: LSND Whip Stock Window 9-5/8". 47# Densi PV YP API FL HTHP FL MBT PH 9.4 8-16 30-35 <10 N/C <15 9.5-10 Intermediate Mud Properties: LSND 8-1/2" hole section De th Interval Densit PV YP API FL HTHP FL MBT PH 3,140'-8,500' 9.4 10-18 22-26 <5 N/C <18 9.5-10 8,500'-9,435' HRZ & KNG 0. 12-22 18-24 3.0-4.0 <8.0 <20 9.5-10 Production Mud Properties: FL~PRO SF Reservoir Drill-in Fh~id 6-1 /8" hole section De th Interval Densit PV YP LSVR API FI H Con or404 9,435-11,625 8.4 - 8.5 6-12 24-30 >25,000 <8.0 9.5 >5000 m Logging Program 8-1/2" Intermediate: Sample Catchers -None Drilling: Dir/GR/Res/PWD Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - as required by Geology Drilling: Dir/GR/Res/Neu/ABI (Neu/Den realtime MAD pass after trip for bit then recorded mode for drillin . Open Hole: None Cased Hole: None Cement Program Casing Size: 7" 26#, L-80 Intermediate Liner Basis: Lead: 5285' o p hole w/ 40% excess, 150' 7" X 9-5/8" lap, and 200' of 9-5/8" X 4" DP excess. Lead TOC: 8 MD 200' above Liner To Tail: 1,000' ` open hole with 40% excess, plus 80' shoe track Tail TOC: 8437' MD Total Cement Volume: Spacer 30 bbls of Viscosified Sp weighted to 10.7 ppg (M Push II) Lead 182.5 bbls, 1025 cuft, sks 11.5 LiteCrete, ,7~-tft3/sa Tail 34.7 bbls, 195 cuft, 67 sks 15.8 Ib/ al Class G + adds -~ .1 ft/sk Temp BHST = 200° F, BH 142° F estimated by Schlumberger Casin Size 4.5" 12.6#, L-80 Production Liner Basis: Lead: None Tail: 2,156' of open hole with 40% excess, 8 7"x4"DPe s. Tail TOC: 9 085' D (200' above Liner Top) Total Cement Volume: Spacer 20 bbls of Viscosif Lead None Tail 59.2 bbls, 333 cuf Temp BHST = 210° F. BI 150' 4-'/z" x 6-1/8" liner lap, to 10.0 iA sks 15.8 Ib/gal Class G + adds - 150° F estimated by Schlumberoer K- l OC Permit to Drill Application Page 3 . Surface and Anti-Collision Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. At surface K-07 is nearest at 37' away. Close Approach Shut-in Wells: Well K-06A passes 42 feet from the planned trajectory of K-10C P11 at 3,900' MD. Before drilling past 3,600' md, verify that K-06A has been plugged and the IA and tubing pressures have been bled to zero. Hydrogen Sulfide K Pad is not designated as an H2S site. Recent H2S data from the pad is as follows: #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H25 on Pad/Facility Date of Wel_1_Name H25 Level ~ Reading K-07C 10 m 08/12/00 K-05A No sam les - K-16AL2 20 m 01/02/05 K-04B 5 m 05/03/05 K-16AL2 20 m 01/02/05 Other Relevant H2S Data K-Pad is not an H2S drill site. H2S readings are typically 10 ppm or less. (H2S alarms from rigs, etc.) Faults One mapped seismic fault is expected in this well. Fault #1 is a large, 200 ft. (at BSAD level), down to the north fault which also acts as the bounding fault for the block we will be developing with K- l OC. This fault was crossed before by K-20 in 1995 approximately 1400 ft. to the west of the K-lOC crossing point without incident and by K-317A in 2003 without incident. Since we are crossing this fault at a shallow enough depth to avoid interference from Ivishak production, and the K-20 history, we expect a low risk of fault losses on this well. Additionally, K-16 and K-14, which crossed this fault in a more shallow horizon than K-20, also had no losses when they were drilled. Details are listed below for reference: Fault 1 -above HRZ 8800' MD -7500' TVDss 50 ft. Down to the N +/- 200 ft. MD K- l OC Permit to Drill Application Page 4 • • Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to/~00 si. Due to Max Anticipated WHP not exceeding 3,000psi it will not be necessary to have two sets` pipe rams installed at all times. BOP regular test frequency for K-lOC will be 14 days. Below is an excerpt from the permit to drill application requesting a variance to the requirements of 20 AAC 25.035 (e)(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285 (f)(2) TUBING WORKOVERS; or, 20 AAC 25.286(e)(1) WORKSTRING SERVICE OPERATIONS "BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment." Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP 3270psi @ 8583' TVDss 7.3 pp EMW) Maximum surface ressure 2412- si (.10 si/ft as radient to surface) ~ Kick tolerance 0. > bbls with a 12.0 pp FIT Planned BOP test pressure ms test to 3,000 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin Test 3500 si surface pressure "" Inte rit Test - 8-1/2" hole 12.0 FIT after drillin 20' from middle of window Production Interval Maximum antici ated BHP 3270 psi ~ -8583' TVDss (7.3 pp EMW) Maximum surface ressure 241.2- i .10 si/ft as radient to surface) Kick tolerance fi with a 10.0 pp FIT Planned BOP test pressure Rams test to 3,000 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin "Liner Test 3500 si surface pressure Inte rit Test - 6-1/8" hole 10.0 p FIT after drillin 20' of new hole Planned com letion fluids 8.5 Seawater / 7.2 p 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. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. K- l OC Permit to Drill Application Page 5 ~ • Drilling Hazards and Contingencies PO5T THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Ivishak in this fault block is expected to be under-pressured at 7.20 ppg EMW. This pressure is estimated based on offset well pressures. II. Lost Circulation/Breathing A. Lost circulation is unlikely. If it occurs, follow the LCM decision tree. B. K Pad has a history of lost circulation events while drilling in the reservoir section and normally occur when crossing faults. There are two expected fault crossings identified for this directional trajectory. I11. Kick Tolerance/Integrity Testing A. The Kick Tolerance for the intermediate hole section is 50.3 bbls with 9.4 ppg mud, 12.0 ppg FIT, and an 8.8 ppg pore pressure. This FIT should prove up adequate formation strength for expected ECD's. B. The Kick Tolerance for the production hole section is infinite with 8.5 ppg mud, 10.0 ppg FIT, and an 8.8 ppg pore pressure. This FIT should prove up adequate formation strength for expected ECD's. C. Integrity Testing Test Point Test Depth Test EMW (lb/gal) t `e 9 5/8" 20-ft minimum from the 9 5/8" FTT 12.0 minimum window window 7" shoe 20-ft minimum from the 7" shoe FIT 10.0 minimum IV. Stuck Pipe A. We do not expect stuck pipe. B. There could be slight differential sticking issues within the reservoir. Centralizers will be run to mitigate. VI. Hydrogen Sulfide A. K Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. H2S levels across the pad are in the 10 PPM range based on the last samples taken in 2005. Recent H2S data from the pad is as follows: • Adjacent producers at Surface: K-07C 10 ppm K-05A no samples • Adjacent producers at TD: K-16AL2 20 ppm K-04B 5 ppm VII. Faults A. One fault is expected to be crossed in K-10C. No losses are expected to be associated with this fault. Details are listed below for reference: Fault 1 -above HRZ 8800' MD +/- 200 ft. MD -7500' TVDss Throw 50 ft. Down to the N B. The directional plan is pinched out near TD by two large bounding faults. Though TD is planned to be before the crushed zone in between these faults, losses are possible. VIII. Anti-Collision Issues Well K-06A passes 42 feet from the planned trajectory of K-10C P11 at 3,900' MD. Before drilling past 3,600' md, verify that K-06A has been plugged and the IA and tubing pressures have been bled to zero. K-20B passes Major Risk criteria, but has acenter-to-center distance of 70.2'. Allowable deviation from plan at 5200' MD is 13.1 ft. CONSULT THE K-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION K- l OC Permit to Drill Application Page 6 • • Operations Summar Current Condition: / SI since June 2005. / Drift 4- i/2", 12.6#, L-80 tubing to liner 9,100 ; Drifted 2-3/8"liner to 9, 625' SLM (H.A. W.) / 06/22/05: MITOA Passed to 2000 psi / 12/04/05: PPPOT-T Passed to 5000 psi, Internal Check Passed to 3500 psi, LDS cycled / 12/19/05: M/T/A Passed to 3000 psi. / 12/19/05: P&A Perfs, Load and Kill Well with 1 % KCL, freeze protect tbg with 60/40 methanol to 2500' / 12/27/05: Drifted w/3.625 cent., Tagged TOC C~3 9,085' SLM / 1/07/06: Jet cut 4.5" Tubing @ 4275' MD. / 01/14/06: CM/T-TxIA Passed to 3000 psi; MITOA Passed to 2000 psi. Freeze protect w/ 152 bbls diesel. Scope * Notify the field AOGCC representative with intent to plug and abandon Pre-Riq Work: 1. Rig up slick-line. Drift 4 1/2" tubing to tag. 2. Fluid pack tubing and inner annulus. 3. R/U coiled tubing. RIH and plug and abandon the perforations with 15.8ppg `G' slurry, from PBTD to ~9,100'md. The estimated cement volume required is 13.Obbls. This is based upon 2,157' of 2 3/8", 4.6# tubing, ~10' of 41h", 12.6# tubing, plus ~5bbls to squeeze the open perforations from10,300'md to 11,255'md. POOH. 4. R/U slick-line, drift the 4'/2" tubing to tag TOC. POOH. 5. RU E-line. Cut the 4-1/2" tubing with an explosive jet cutter in the middle of a joint at -- 4,250' MD. If unable to reach 4,250' MD, choose a shallower cut depth but cut no higher than 3,200' MD. Tie in using CCL (no GR necessary) 6. Circulate the well to seawater through the tubing cut, until returns are clean. Attempt a CMIT T X IA to 3,500psi for 30 minutes. 7. Bleed casing and annulus pressures to zero. Freeze protect the well to ~2,200'md with diesel. 8. Function all tubing and lock down screws. Test both the 9 5/8" casing and the tubing pack-off. 9. Set a BPV. Remove the well house and the flow line. If necessary, level the pad. Please provide total well preparation cost on the handover form. Riq Operations: 1. MIRU Nabors rig 9ES. 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull the 4 1/2" tubing from the pre-rig tubing cut at 4,275' MD. 5. M!U an 8'/z" mill assembly. RIH, picking up 4" drill pipe, drift the 9 5/8" casing to the tubing stump at 4,275'md. POOH. 6. R/U E-line and GR/CCL. M/U a HES 9 5/8" CIBP. RIH and set the CIBP at ~3,160'md, such that a collar will not be cut while milling the window. POOH. 7. Test the 9 5/8" casing to 3,500psi against bridge plug. 8. M/U a Baker 9 5/8" whip stock assembly. RIH, orient whip stock and set on CIBP. 9. Shear free from the whip stock. Displace the well to the 9.4ppg LSND milling and drilling fluid. 10. Mill window in 9 5/8" casing at ~3,140'md, plus drill/mill ~20' beyond the middle of the window. 11. Circulate the well clean. Pull up into the 9 5/8" casing and attempt an FIT to 12.Oppg EMW. POOH. ~ 12. M/U an 8-1/2" drilling assembly with Dir/GR/Res/PWD. RIH to window. , 13. Drill 8-1/2" intermediate hole, building to ° hold angle. 14. Prior to cutting the HRZ, weight up to 1~pg LSND mud (9.6 needed for HRZ, but 10.0 needed for Kingak Drilling) 15. Drill ahead to casing point at the top of the Sag River, estimated at a depth of 9,435'md. 16. Circulate and condition hole as needed. POOH. UD assembly. 17. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing with 150' of overlap. Displace the cement with the 10.Oppg LSND mud. POOH. 18. M/U a 6-1/8" drilling assembly with Dir/GR/RES and an Insert bit. RIH to the landing collar. K-10C Permit to Drill Application Page 7 ~ • 19. Pressure test the well bore to 3,500psi for 30 minutes. Record the test. ~ 20. Drill out cement and float equipment to the shoe. Displace the well to 8.5ppg Flo-Pro fluid. 21. Drill out the shoe, plus 20' of new formation. Conduct an FIT to 10.Oppg EMW. 22. Drill. ahead, per directional proposal, to the end of the high dogleg section, at ~10,520'md. POOH for horizontal assembly once directional requirement has been met. It may be necessary to trip for BHA changing prior to completing the high dogleg section.. 23. Drill ahead to an estimated TD of 11,592'md. 24. Circulate and condition hole as needed. POOH. UD assembly. 25. Run and cement a 4-1/2", 12.6#, L-80 liner. Displace the cement with pert pill and mud. / 26. Release from liner, displace well to clean seawater above the liner top. POOH, UD LRT. 27. Pressure test well bore to 3,500psi for 30 minutes. Record the test. 28. RIH with DPC pert guns. Perf intervals to be determined from LWD logs. Expected interval is 800- 1000ft of horizontal section near well TD. 29. POOH. UD all drill pipe and pert guns. 30. Run 4-1/2", 12.6#, L-80, IBT-Mod completion tying into the 4-1/2" liner top. j 31. Space and land the completion. RILDS. 32. Reverse circulate the annulus to seawater with Corrosion Inhibitor. 33. Drop the ball /rod. Set the packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 34. Install a TWC. 35. Nipple down the BOPE. Nipple up the adapter and tree and test to 5,OOOpsi. Pull the TWC. /~ 36. Reverse in sufficient volume of diesel to freeze protect both the tubing and the IA to 2,200'. Allow the diesel to U-tube to equilibrium. 37. Install a BPV. Secure the well. 38. Rig down and move off. Post-Rig Work: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Re-install the well house, instrumentation, and flow line. K-1 OC Permit to Drill Application Page 8 • ~ Variance Request Issue Compliance with AOGCC testing requirements for BOP rams after they have been used in the normal coarse of operations. Re uest The AOGCC is in the process of developing a guideline document clarifing the intent of the regulations pertaining to function pressure testing ram type BOP's. BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Background AOGCC regulations require rams that have been used in the course of primary drilling & completion, workover and through tubing drilling operations be function pressure tested before the next wellbore entry. This is not a new regulation. The intent of this regulation is to ensure that ram type equipment has integrity after it has been utilized in a wellbore...for example; to ensure integrity if a ram was closed on a tool joint. The exact regulation language is: "if BOP sealing ram type equipment has been used, it must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure;" The pertinent sections are: 20 AAC 25.035 (e)(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d)(4) THROUGH TUBING DRII.LING AND COMPLETION; 20 AAC 25.285 (f)(2) TUBING WORKOVERS; 20 AAC 25.286(e)(1) WORKSTRING SERVICE OPERATIONS This issue has been discussed with Winton Aubert at the AOGCC. The test requirement in the regulation is intended to amply to ram type equipment only. The AOGCC understands that ram type BOP's are utilized for purposes other than well control in the normal coarse of operations. The regulations allowing a variance are at 20 AAC 25.035(h) PRIMARY DRIILING AND COMPLETION; 20 AAC 25.036(f) THROUGH TUBING DRII.LING AND COMPLETION; 20 AAC 25.285(h) TUBING WORKOVERS; 20 AAC 25.286(g) WORKSTRING SERVICE OPERATIONS ...which says generally: 20 AAC 25.035(h)... Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; K-10C Permit to Drill Application Page 9 STANDARD ALASKA PRODUCTIOIJ COMPANY WELLHEAD LOCATION DATA 1) WELL: K-10 FIELD: 7/9/86 2 Well Head Location 20 07 462 'from lyorth 1 i ne 'from West 1 i ne Section 4 T 11 N, R 14 E, UPM X =670,732 Y = 5,975,196 ASP Pone 4 LAT = 70~20~ 17.36 N, LONG = 14--36-52.50 ~~ W 3) Local Benchmark Elevation 4} Top Edge of Cellar 5) Kelly Bushing to Base Flange* 6} Kelly Bushing to Ground Level* 7} Base Flange Elevation 8. Kelly Bushing Elevation *Measured by Drilling Foreman RTES: K-2 21.72 Ft. AMSL i~.F. ~c~rner 25.;3 Ft A1~15L 27.95 Ft. AMSL ~3~~0 Ft AMSL ~~,.33 Ft. AMSL 54.33 Ft. AMSL i} The surveyor should fill in Items 2, 3, and 4. 2) The completed form should be returned to Drilling Dept. for distribution. CIRCULATION: North Slope Production Engineering (North Slope, BOC) - 1 Reservoir Engineering Operations (MB9-2) - 1 North Slope - to Rig for Posting (North Slope, BOC) - 2 Well Records (LR2-1) - 10 Well Files (M612-1) - 1 Drilling, Technical Assistant (M612-1) - 1 Drilling, fompletion Technical Assistant (MB12-1} - 1 Graphic Services, Supv. Cartography (MB2-4)-1 ... ,_ xf>-~, - ..- «,y ~ y'r. {+ k 'y.~_ Yb t1~~w ~kQi~il~ ~.: 7/14/86 __ ae K-10C Proposed CoRipletion ~-~--r-r-r ~. s ~. 2500` ~ ~ 2694` 3000` TBD` L TBD' TBD` EZSV 3160` 4,275` - 6069` 8574' 8997` 9067` 9111 ` 9117` 9135` 9151 ` 9197` 9197` 9210` 9236` 9270` 9479`, 9500` 7" LNR, 26# I D=6.276" L-80 ~X-Nip ID = 3.813 - 13-3/8", 72#, S95, BTRS, ID-12.347 9-5/8"x7" Baker Flex-Lock Liner Hanger w/ C-2 Running Tool 4.5" x 1" KBG-2 GLMs 4-1/2", 12.6#, L-80, IBT-Mod 9225` - 7"x4-1 /2" Baker S-3 Packer 9285` - 7"x4-1/2" Baker HMC Liner Hanger w/ ZXP & HR Running Tool 9436` ~ 7" LNR, 26#, I D=6.276", L-80 Chem Cut 4.5" GLMs " Sldg Sleeve WELLHEAD= McEvoy I ACTUATOR = Axelson KB. ELEV = 54.9' 31501 91 Tubing Tail: -10` Pup Joint -X Nipple (3.813") -20' Pup Joint -Packer -20' Pup Joint -X Nipple (3.813") -20' Pup Joint -XN Nipple (3.725") -10' Pup Joint -W LEG BKR Lnr Top PKR 3-1/2" - 2-3/8" XO 4.5" Tbg Seal Assy 9-5/8" Packer Top of P&A 4.5" X-Ni Cmt @ 9,100` 7" LNR Hanger Top 3-1/2" LNR 4.5" XN-Nip 4.5" TubingTail 4-1/2", 12.6#, L-80 9-5/8" CSG, 47#, L-80 ID=8.681" 11,592` Estimated Top of P&A Cement Existing Perfs 10,300`-11,255` ~,. PBTD 11,268` 10,134` ~ 10,525` 2-3/8" LNR, 4.6#, L-80, .0036 bpf ID=1.92" 2-7/8" LNR, 6.16#, L-80, .0058 bpf ID=2.37" Date Rev By Comments PRUDHOE BAY UNIT 1-26-06 MJM Proposed Completion P11 WELL: K-10C API N0:50-029-21762-03 Permit NO: GPB Rotary Drilling TREE = 6" CNV WELLHEAD = MCEVOY ACTUATOR = AXELSON KB. ELEV - 54.30' BF. ELEV - 26.38' KOP - 3200' Max Angle = 105 @ 9961' Datum MD = 9610' Datum TV D = 8700' SS ~ K-10 B S OTES: ^r., 1967' 4-1/2"CAMCOSSSVN,ID=3.813" 113-3/8" CSG, 72#, S95, BTRS, ID = 12.347" I~ 2694' Minimum ID =1.92" @ 9117' 3-1/2" X 2-3/8" XO OF CEMENT (12/20/05) ~-~ 9112' 7" LNR HGR I~ 9197' 4-1/2" TBG, 12.6#, L-80, ~ 9270' .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" ~- j 9479• PERFORATION SUMMARY REF LOG: SWS GR/CCUCNL ON 06/27/01 ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 10300 - 11255 S 12/20/05 7" LNR, 26#, L-80, ID = 6.276" I-I 10134' 2-718" LNR, 6.16#, L-80, .0058 bpf, ID = 2.37" ~-~ 10525' ~- 11300' 4275' ~ET CUT (1-7-06) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3018 2945 6 LBD DMY T2 16 12/19/05 3 6069 5657 35 LBD DMY T2 20 12/19/05 2 8574 7787 25 LBD DMY RA 0 12/08/00 1 8997 8150 24 LBD DMY RA 0 12/08100 9067 4112" BKR L SL~JG SLV, ID = 3.813" 9111' CTM BKR'KB' LNR TOP PKR w / X PROFILE, ID = 2.39" 9111' 3.625" BKR OEPLOYAIENT SLV, ~ = 3.0" 9117' 3-1 /2" X 2-3/8" XO, ID = 1.92" 9135' 41/2" TUBNVG SEAL ASSY 9151' 9-5/8" TNV HBBP PKR, ID = 4.750" ' ' " Behind 9197 41/7 OTIS X MP, ~ = 3.813 9201' 3.75" BKR DEPLOY SLV, 1D = 3.fl" CT LN 9210' TOP OF 3-112" LNR, m = 2992" 9236' 41/2" OTiS XN N~, Mft.1EO TO 3.80" ~ 9271' 4112" TNV TUBING TA ~, ~ = 3.95$" MILLOUT WgJDOW 9619' -9627 2-3/8" LNR, 4.6#, L-80, .0036 bpf, ID = 1.92" DATE REV BY COMMENTS DATE REV BY COMMENTS 11/19/87 INITIAL COMPLETION 09/25/05 TWS/TLH PXX PLUG SET' (06120/05) 05/18/01 CWKAK P8A CTD SIDETRACK 12/31/05 /TLH PLUG PULLED (12/10/05) 06/28/01 CTDSIDETRACK(K-10A) 12/31/05 KSB/TLH GLV GO (12/19/05) 12/08/03 TMWKK CTDSIDETRACK(K-10B) 12/31/05 KEY/TLH P&A (12/20/05) 01/02/04 DAV/KK GLV GO 01/07/06 DFR/PJC JET CUT @4275' 03/28/04 JLG/KAK SET BKR KB LNR TOP PKR 11268' H PBTD PRUDHOE BAY UNff WELL: K-10B PERMIT No: 82031450 API No: 50.029-21762-02 SEC 4, T11 N, R14E, 2007' SNL & 462' EWL BP Exploration (Alaska) by K-10C (P111 Proposal Schlumberger Report Date: January 16, 2006 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 110.000° Field: Structure 1 Slot: Prudhoe Bay Unit - WOA K-PAD ! K-10 ~ ~~ Vertical Section Origin: ~y TVD Reference Datum: S 0.003 ft, E 0.001 ft Rotary Table Well: Borehole: K-10 ~~ ~~''~ Plan K-10C ~ea TVD Reference Elevation: Sea Bed I Ground Level Elevation: 54.88 ft relative to MSL 26.38 ft relative to MSL UWIIAPI#: 500292176203 Magnetic Declination: 24.667° Survey Name I Date: K-10C (P11) I January 16, 2006 Total Field SVength: 57610.910 nT Tort 1 AND 1 DDI 1 ERD ratio: 259.228° / 5392.33 ft / 6.267 10.61E Magnetic Dip: 80.927° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Declination Date: February 28, 2006 Location LatlLong: N 70.33815418, W 148.61458596 Magnetic Declination Model: BGGM 2005 Location Grid NIE YIX: N 5975196.000 ftUS, E 670732.000 ftUS North Reference: True North Grid Convergence Angle: +1.30466606° Total Corr Mag North -> True North: +24.667° Grid Scale Factor: 0.99993311 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft de de ft ft ft k ft de 1100 ft de de 1100 ft de 100 k ftUS ftUS IIC-111 JUIVCy J~w.JO a.ii cw.oi JV44.J1 3Vyy.ly -L/.Ob l4.yl -L4.Ul 3.U1 U.UVU L.84 -/.OU b`J/OCI V.3O b/V/V/.Ob N/U.338-I `J4`JL VV l4t3.b14/tSU/4 Top Whipstock 3150.00 9.74 296.61 3093.06 3147.94 -35.73 18.55 -31.27 1.15 84.99G 1.15 0.00 5975213.83 670700.32 N 70.33820485 W 148.61483962 KOP Crv 4/100 3170.00 10.23 310.20 3112.76 3167.64 -39.07 20.45 -34.13 12.00 118.OOG 2.45 67.94 5975215.67 670697.41 N 70.33821006 W 148.61486290 3200.00 9.72 316.48 3142.31 3197.19 -43.84 24.01 -37.91 4.00 111.81 G -1.69 20.95 5975219.14 670693.55 N 70.33821977 W 148.61489356 SV4 3238.21 9.26 325.34 3180.00 3234.88 -49.24 28.88 -41.88 4.00 1O3.OSG -1.20 23.16 5975223.92 670689.47 N 70.33823307 W 148.61492577 3300.00 9.03 340.86 3241.01 3295.89 -56.35 37.55 -46.30 4.00 87.75G -0.38 25.13 5975232.48 670684.86 N 70.33825676 W 148.61496162 3400.00 10.01 4.50 3339.67 3394.55 -63.63 53.63 -48.19 4.00 64.42G 0.98 23.64 5975248.52 670682.60 N 70.33830070 W 148.61497696 3490.00 12.01 20.30 3428.03 3482.91 -65.67 70.22 -44.33 4.00 1O9.82G 2.22 17.55 5975265.18 670686.09 N 70.33834600 W 148.61494561 3500.00 11.88 22.13 3437.81 3492.69 -65.63 72.14 -43.58 4.00 1O8.O4G -1.30 18.29 5975267.13 670686.79 N 70.33835127 W 148.61493954 3600.00 11.29 41.94 3535.82 3590.70 -61.59 88.97 -33.16 4.00 88.63G -0.59 19.81 5975284.18 670696.83 N 70.33839722 W 148.61485498 3700.00 12.06 61.44 3633.78 3688.66 -51.02 101.25 -17.44 4.00 69.52G 0.77 19.50 5975296.82 670712.26 N 70.33843077 W 148.61 3 3800.00 13.96 77.15 3731.24 3786.12 -33.96 108.93 3.51 4.00 54.2OG 1.90 15.71 5975304.97 670733.03 4 N 70.33845176 W 148.61 0 3900.00 16.62 88.56 3827.72 3882.60 -10.51 111.97 29.57 4.00 43.19G 2.65 11.41 5975308.61 670759.01 N 70.33846007 W 148.61. 3 4000.00 19.72 96.70 3922.74 3977.62 19.23 110.36 60.63 4.00 35.46G 3.10 8.14 5975307.70 670790.10 N 70.33845567 W 148.61409403 4100.00 23.09 102.62 4015.84 4070.72 55.10 104.11 96.53 4.00 29.94G 3.37 5.92 5975302.27 670826.13 N 70.33843859 W 148.61380275 4200.00 26.62 107.08 4106.57 4161.45 96.94 93.24 137.10 4.00 25.89G 3.54 4.46 5975292.33 670866.94 N 70.33840890 W 148.61347361 4300.00 30.27 110.54 4194.49 4249.37 144.54 77.81 182.14 4.00 22.85G 3.65 3.46 5975277.93 670912.31 N 70.33836674 W 148.61310819 4400.00 33.99 113.32 4279.16 4334.04 197.67 57.90 231.43 4.00 2O.49G 3.72 2.78 5975259.15 670962.04 N 70.33831233 W 148.61270830 4500.00 37.76 115.60 4360.18 4415.06 256.07 33.59 284.73 4.00 18.64G 3.77 2.29 5975236.06 671015.88 N 70.33824593 W 148.61227587 4600.00 41.56 117.53 4437.15 4492.03 319.45 5.02 341.79 4.00 17.16G 3.81 1.93 5975208.80 671073.56 N 70.33816787 W 148.61181302 End Crv 4664.01 44.02 118.61 4484.12 4539.00 362.50 -15.45 380.14 4.00 O.OOG 3.83 1.70 5975189.21 671112.37 N 70.33811195 W 148.61150181 UG4 4916.92 44.02 118.61 4666.00 4720.88 536.26 -99.61 534.42 0.00 O.OOG 0.00 0.00 5975108.59 671268.51 N 70.33788199 W 148.61025021 UG3 5236.75 44.02 118.61 4896.00 4950.88 755.99 -206.05 729.51 0.00 O.OOG 0.00 0.00 5975006.63 671465.97 N 70.33759118 W 148.60866750 WeIlDesign Ver SP 1.0 Bld( doc4Ox_56) K-10\K-10\Plan K-1OC\K-1OC (P11) Generated 1/16/2006 1:50 PM Page 1 of 3 Measured Vertical Comments Inclination Azimuth Sub•Sea TVD TVD NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft d de ft ft ft ft ft de 1100 ft de de 1100 ft de 1100 ft ftUS ftUS uv~ UaUU.oo 44.uc no.o~ J47s.vu D40/.tSis 7L4`J.`JU -440.Yy 770tl.U0 V.UU V.VVIi U.VU V.VU D`J/4///.4.7 d/7yVy.2f7 IV /V.3Jby3/44 W742f.0Ub77000 CM3 7315.63 44.02 118.61 6391.00 6445.88 2184.24 -897.86 1997.62 0.00 O.OOG 0.00 0.00 5974343.91 672749.41 N 70.33570057 W 148.59838096 Crv 4/100 8250.26 44.02 118.61 7063.13 7118.01 2826.36 -1208.89 2567.75 0.00 177.67G 0.00 0.00 5974045.96 673326.43 N 70.33485039 W 148.59375690 8300.00 42.03 118.74 7099.49 7154.37 2859.90 -1225.18 2597.52 4.00 177.58G -4.00 0.24 5974030.36 673356.56 N 70.33480588 W 148.59351543 8400.00 38.03 119.01 7176.05 7230.93 2923.44 -1256.22 2653.84 4.00 177.37G -4.00 0.27 5974000.61 673413.57 N 70.33472101 W 148.59305869 8500.00 34.04 119.34 7256.90 7311.78 2981.51 -1284.89 2705.20 4.00 177.10G -4.00 0.33 5973973.13 673465.56 N 70.33464266 W 148.59264217 CM1 8536.03 32.60 119.47 7287.00 7341.88 3001.03 -1294.60 2722.43 4.00 176.99G -3.99 0.38 5973963.81 673483.02 N 70.33461610 W 148.59250236 8600.00 30.04 119.74 7341.65 7396.53 3033.82 -1311.03 2751.35 4.00 176.76G -3.99 0.42 5973948.04 673512.29 N 70.33457119 W 148.59226788 8700.00 26.05 120.26 7429.89 7484.77 3080.11 -1334.52 2792.07 4.00 176.31 G -3.99 0.51 5973925.49 673553.53 N 70.33450698 W 148.59193765 CM2 8716.78 25.38 120.36 7445.00 7499.88 3087.28 -1338.19 2798.35 4.00 176.21 G -3.99 0.60 5973921.96 673559.90 N 70.33449694 W 148.59188669 Fault Crossing 8777.07 22.97 120.76 7500.00 7554.88 3111.55 -1350.74 2819.61 4.00 175.84G -3.99 0.68 5973909.90 673581.44 N 70.33446263 W 148. 4 8800.00 22.06 120.94 7521.18 7576.06 3120.17 -1355.25 2827.15 4.00 175.68G -3.99 0.77 5973905.57 673589.08 5 N 70.33445032 W 148.5 0 8900.00 18.07 121.91 7615.09 7669.97 3153.80 -1373.11 2856.44 4.00 174.77G -3.99 0.97 5973888.38 673618.76 N 70.33440149 W 148.59141559 End Crv 8977.23 15.00 123.00 7689.12 7744.00 3175.27 -1384.89 2875.00 4.00 O.OOG -3.98 1.41 5973877.02 673637.58 N 70.33436929 W 148.59126511 THRZ 9103.41 15.00 123.00 7811.00 7865.88 3207.09 -1402.67 2902.38 0.00 O.OOG 0.00 0.00 5973859.87 673665.37 N 70.33432067 W 148.59104300 BHRZ / LCU 9203.83 15.00 123.00 7908.00 7962.88 3232.41 -1416.83 2924.18 0.00 O.OOG 0.00 0.00 5973846.21 673687.48 N 70.33428197 W 148.59086623 TJD 9317.71 15.00 123.00 8018.00 8072.88 3261.13 -1432.88 2948.90 0.00 O.OOG 0.00 0.00 5973830.73 673712.56 N 70.33423809 W 148.59066577 TSAG 9436.76 15.00 123.00 8132.99 8187.87 3291.16 -1449.66 2974.74 0.00 O.OOG 0.00 0.00 5973814.54 673738.77 N 70.33419222 W 148.59045621 7" Csg Pt 9436.77 15.00 123.00 8133.00 8187.88 3291.16 -1449.66 2974.74 0.00 O.OOG 0.00 0.00 5973814.54 673738.77 N 70.33419222 W 148.59045620 Crv 13/100 9457.23 15.00 123.00 8152.76 8207.64 3296.32 -1452.55 2979.19 0.00 98.01G 0.00 0.00 5973811.76 673743.28 N 70.33418433 W 148.59042018 9500.00 15.23 144.42 8194.09 8248.97 3306.35 -1460.14 2987.10 13.00 77.32G 0.54 50.08 5973804.35 673751.37 N 70.33416359 W 148.59035599 TSHU 9506.13 15.42 147.35 8200.00 8254.88 3307.67 -1461.48 2988.01 13.00 74.49G 3.17 47.70 5973803.03 673752.30 N 70.33415992 W 148.59034862 TSAD 9522.76 16.13 154.86 8216.00 8270.88 3311.06 -1465.43 2990.19 13.00 67.26G 4.27 45.20 5973799.13 673754.57 N 70.33414912 W 148.59033099 42S8 9577.41 19.96 174.38 8268.00 8322.88 3320.49 -1481.61 2994.33 13.00 48.67G 6.99 35.73 5973783.05 673759.08 N 70.33410492 W 148.59029743 9600.00 22.00 180.28 8289.10 8343.98 3323.58 -1489.68 2994.69 13.00 43.17G 9.06 26.09 5973774.99 673759.62 N 70.33408287 W 148.59029457 End Crv 9624.44 24.41 185.54 8311.56 8366.44 3326.39 -1499.29 2994.18 13.00 O.OOG 9.86 21.54 5973765.37 673759.33 N 70.33405663 W 148.59029874 TCGL 9641.40 24.41 185.54 8327.00 8381.88 3328.14 -1506.26 2993.50 0.00 O.OOG 0.00 0.00 5973758.39 673758.81 N 70.33403758 W 148.59030425 BCGL 9697.40 24.41 185.54 8378.00 8432.88 3333.92 -1529.30 2991.26 0.00 O.OOG 0.00 0.00 5973735.30 673757.10 N 70.33397464 W 148.59032247 Crv 16/100 9769.75 24.41 185.54 8443.88 8498.76 3341.38 -1559.06 2988.37 0.00 28.66G 0.00 0.00 5973705.49 673754.89 N 70.33389334 W 148.59 9 9800.00 28.75 190.37 8470.93 8525.81 3344.16 -1572.45 2986.46 j 16.00 24.34G 14.33 15.95 5973692.06 673753.28 N 70.33385677 W 148.59 7 21 TS 9863.69 38.24 197.13 8524.00 8578.88 3347.72 -1606.44 2977.87 16.00 18.67G 14.91 10.62 5973657.89 673745.47 N 70.33376392 W 148.59 3 9900.00 43.78 199.82 8551.39 8606.27 3348.32 -1629.02 2970.30 16.00 16.65G 15.25 7.39 5973635.14 673738.41 N 70.33370225 W 148.59049286 TZ18 9946.71 50.98 202.57 8583.00 8637.88 3347.56 -1661.02 2957.84 16.00 14.78G 15.41 5.88 5973602.87 673726.68 N 70.33361484 W 148.59059401 10000.00 59.25 205.09 8613.46 8668.34 3344.59 -1700.94 2940.15 16.00 13.33G 15.52 4.73 5973562.55 673709.91 N 70.33350578 W 148.59073762 TZ1A/TDF 10030.62 64.02 206.35 8628.00 8682.88 3341.90 -1725.21 2928.46 16.00 12.74G 15.59 4.10 5973538.03 673698.77 N 70.33343951 W 148.59083253 10100.00 74.87 208.87 8652.33 8707.21 3333.27 -1782.66 2898.35 16.00 11.85G 15.64 3.63 5973479.91 673669.99 N 70.33328258 W 148.59107688 BSAD /Kavik 10193.85 89.58 211.92 8664.99 8719.87 3316.50 -1862.62 2851.41 16.00 11.43G 15.67 3.25 5973398.91 673624.88 N 70.33306420 W 148.59145789 10196.52 90.00 212.00 8665.00 8719.88 3315.95 -1864.89 2850.00 16.00 88.55G 15.68 3.17 5973396.61 673623.52 N 70.33305800 W 148.59146937 10200.00 90.01 212.56 8665.00 8719.88 3315.21 -1867.83 2848.14 16.00 88.55G 0.40 15.99 5973393.63 673621.73 N 70.33304996 W 148.59148445 10300.00 90.41 228.55 8664.62 8719.50 3280.21 -1943.56 2783.33 16.00 88.61 G 0.40 16.00 5973316.45 673558.67 N 70.33284314 W 148.59201032 10400.00 90.78 244.55 8663.58 8718.46 3220.86 -1998.50 2700.17 16.00 88.78G 0.37 16.00 5973259.63 673476.79 N 70.33269313 W 148.59268500 WeIlDesign Ver SP 1.0 Bld(doc40x_56) K-10\K-10\Plan K-10C\K-10C (P11) Generated 1/16/2006 1:50 PM Page 2 of 3 Measured Vertical Comments Inclination Azimuth Sub•Sea TVD TVD NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft de de ft ft ft ft ft de 1100 ft de de 1100 ft de 1100 ft ftUS ftUS 1 V5UU.UU y1.U`J Z6U.55 23661.y4 is/11i.25Z 3141./4 -ZU"Ltf.3y 26U5.1U 1ti.UU tS9.U4Ci U.31 16.UU 5y /3Z'L /.5y 6/33SL.4'L N /U.33L1i1157 W 14tf.59345623 End Crv 10522.53 91.14 264.15 8661.50 8716.38 3121.79 -2031.39 2582.77 16.00 O.OOG 0.26 16.00 5973224.08 673360.18 N 70.33260340 W 148. 59363730 Crv 7/100 10589.26 91.14 264.15 8660.16 8715.04 3061.75 -2038.18 2516.41 0.00 -172.38G 0.00 0.00 5973215.78 673293.99 N 70.33258489 W 148. 59417561 10600.00 90.40 264.05 8660.02 8714.90 3052.09 -2039.29 2505.72 7.00 -172.38G -6.94 -0.93 5973214.43 673283.33 N 70.33258189 W 148. 59426227 10605.76 90.00 264.00 8660.00 8714.88 3046.91 -2039.89 2500.00 7.00 105.66G -6.94 -0.93 5973213.70 673277.62 N 70.33258026 W 148. 59430872 10700.00 88.22 270.35 8661.46 8716.34 2960.10 -2044.53 2405.93 7.00 105.56G -1.89 6.74 5973206.92 673183.69 N 70.33256767 W 148. 59507167 End Crv 10738.09 87.51 272.92 8662.88 8717.76 2923.98 -2043.44 2367.89 7.00 O.OOG -1.87 6.75 5973207.14 673145.64 N 70.33257067 W 148. 59538022 TD / 4-1 /2" Lnr 11592.40 ~ 87.51 272.92 8700.00 8754.88 2108.10 -1999.89 1515.50 0.00 O.OOG 0.00 0.00 5973231.27 672292.53 N 70.33269025 W 148. 60229384 • ~_.~ WeIlDesign Ver SP 1.0 Bld(doc40x_56) K-10\K-10\Plan K-10C\K-10C (P11) Generated 1/16/2006 1:50 PM Page 3 of 3 •' bP Schlumberger `~L` K-100 (P11) FIDLD Prudhoe Bay Unit - WOA s~DCnRE K-PAD Alagne6c Parameters Suriaca Luwl~un NAD21 AlasNa Stalo Planes. 3nne 04, US Fael MixxlNnrous Moeel aGDA12008 Dro 8092]° Dale FaMUary 202006 L.n M110 20 12 356 Nonning - 6'9600INS Gnfi Donv •130466806' Slot. N~!0 ND RaI. Rotary Table 15a B8 ttaeove l,ISLI Alag Dec -246fi 1' FS'. 5]610.9 nT Lon 1146 16 83 609 Easln9 ]0»2~01NS Sala FaM.099993J11J1 Plan: K~IOC IPI') Srvy Dale January tfi. 20Cfi 0 800 1600 2400 3200 3200 4000 4800 O O ~ 5600 c a~ U Cn H 6400 7200 8000 8800 -tD - Tie-in Survey Top Whipstock KOP Crv 41100 ...-..-..-..~.. ~..~.. 5~..-..-..-..~..~..-..-..-<.-..-..-..-..-..-..~..-..-/.-..~..-..~..~..-..~..-..y..~..-..~..-..~..-..-..-..4.....-..-. ................ ............. .................................:..................................i..................................~..................................:............................... End Crv K-10 ...-..-..-..-..-..-..- - .-..-..-..-..- 4 .- -..-..-..-.._..-..-..-. -..-..-..-..-..-..-..-. ~ -..-..-..-..-..-..-..- - -..-..-..-..~..-..- -.. .. .............................. i.......................... .......j..................................~..................................i...................................i.............................. ..............................t..................................:....................... .........:..................................Y................................................................ ...-..-..-..-..-..-..- ..-..-..~..~..~..~..-..- -..-..-..-..~..-..-..-. - -..-.._..-..-..- .~..- -..-..-..-..-..-..-..- - -..-..-..-..-..-..- Crv 4tl100 .....................................................................................................t........................................................ ............................................ ...-..-..-..-..-..-..- .-..-..-..~..~..-..-..- -..-..-..-..-..-..-..-.-i.-..-..-..~..-..-..~..-..~..-..-..-..-..-..- M1' FaultCrossin9..- End Crv . -..... -.. -.. -.. -.. -.. -.. -.. -.. ~ <. r..... -.. -.. - .. - .. - ................. .tOG (P.1 L}........................ ... :......... TD / d-1/2" Lnr End Crv End Crv Crv 71100 3200 4000 4800 5600 6400 7200 8000 8800 0 800 1600 2400 3200 Vertical Section (ft) Azim = 110°, Scale = 1(in):800(ft) Origin = -381.78 N/-S, -627.93 E/-V L L O.~ _~ r CA l^.l. y 0 Q a Y Q ~` ca m d a` T a_ U O r Y Z O O ~ ~ A~ z~ rc ~ > 2 O O N ~ Y ZJ~ia O O N LL~m 'o ~~ G~ - O H ~ X80 m~ O O o ~ ~ 3z3 Y 3J rm O 2 0 In S n O ~ F ~m o 3 ~ a F z • O O o O O O o O o u~ o O ~ i ~ N w c '" a N n:Z ~ - o U t ~ ~ W LL U ' W II .................i..................................~................... ................i ......... .... .. .... .... ...................:........ ...... ....... i I ~ U LL ~ W ~ i o Y U a t Z u U v W . r LL .Y .... .. ...I I ....... .. .. .. . ................7..................................:........ .......... ...............3....................... ...........:.......... I I ............... ...... . ... ...... C J d 0 F ..... ......... U C W Z N C ........ ...... ~...........:-m....................~................... H ................j....................... ...........j............ ...................... ~...... .... ............... 0 1 Z U a u Y H O O O O O O O O O ~ O N O r N O M O N O O O N n A W O O O ~ O C r ~_ ~~ Q) m U >~ O V O V O V O °o ~~ BP Anticollision Report Company: BP Amoco field: Prudhoe Bay Reference Site: PB K Pad. Reference Well: K-10 ReferenceWell'path: Plan K-10C NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD + Stations Interval: 20.00 ft ', Depth Range: 3150.00 to 11625.44 ft Maximum Radius:10000.00 ft Survey Program for Definitive Wellpath Date: 1/16/2006 Validated: No Planned From To Survey ft ft 100.58 3150.00 1 : Sperry-Sun BOSS gyro multi 3150.00 11592.40 Planned: plan #11 V72 Casing Points :Date: 1/1.6!2006 Timc: 13:37:04 Page: ~~ Co-ordinate(Nl:) Reference: Well: K-10, True North Vertical ('fVD) Reference: 26.38+28.5 54.9 Db: Oracle Reference: Principal Plan & PLANNED PROGRAM ' Error Model: ISCWSA Ellipse Scan Method: Trav Cylinder North Error Surface: Ellipse + Casing Version: 2 Toolcode Tool Name BOSS-GYRO Sperry-Sun BOSS gyro multishot MWD+IFR+MS MWD +IFR + Multi Station MD TVD Diameter Hole Size Name ft ff in in' 2694.00 2693.91 13.375 17.500 13 3/8" ', 3150.00 3147.94 9.625 12.250 9 5/8" ' ', 9436.77 8187.88 7.000 8.500 7" j 111592.30 8754.88 4.500 6.125 4 1 /2" I Summary <------------------ Offset Wellpath ------------> Reference Offset Ctr-f'h~ Vo-Go ,allowable l' 'Site WeN Wellpath MD MD ~ ~ -Distance 4rca Deviation Warning ft ft ft ft ft PB K Pad K-01 K-01 V1 3499.88 3540.00 1727.41 84.45 1642.96 Pass: Major Risk PB K Pad K-01 Plan K-01A VO Plan: K- 3504.79 3540.00 1731.46 84.59 1646.87 Pass: Major Risk PB K Pad K-02A K-02A V3 3188.92 3320.00 917.61 87.89 829.72 Pass: Major Risk ', PB K Pad K-02A K-028 V1 3187.68 3320.00 917.37 87.84 829.52 Pass: Major Risk PB K Pad K-02A K-02C V1 3187.68 3320.00 917.37 87.84 829.52 Pass: Major Risk PB K Pad K-02 K-02 VO Out of range PB K Pad K-03A K-03A V4 4071.69 3820.00 803.21 50.51 752.70 Pass: Major Risk PB K Pad K-03AP61 K-03APB1 V3 4071.69 3820.00 803.21 50.51 752.70 Pass: Major Risk PB K Pad K-03AP62 K-03APB2 V3 4071.69 3820.00 803.21 50.51 752.70 Pass: Major Risk PB K Pad K-03 K-03 V1 4071.73 3820.00 803.21 50.51 752.70 Pass: Major Risk i~ PB K Pad K-03 K-03B V1 4082.51 3820.00 803.27 50.69 752.58 Pass: Major Risk ', PB K Pad K-03 K-03BP61 V6 4082.51 3820.00 803.27 50.69 752.58 Pass: Major Risk 'i PB K Pad K-04 K-04 V1 5038.57 4820.00 251.21 58.46 192.75 Pass: Major Risk PB K Pad K-04 K-04A V1 5038.57 4820.00 251.21 58.46 192.75 Pass: Major Risk I ', PB K Pad K-04 K-04AP61 V1 5038.57 4820.00 251.21 58.46 192.75 Pass: Major Risk ', PB K Pad K-04 K-04APB2 V1 5038.57 4820.00 251.21 58.46 192.75 Pass: Major Risk ', PB K Pad K-04 K-04AP63 V1 5038.57 4820.00 251.21 58.46 192.75 Pass: Major Risk '~ PB K Pad K-04 K-046 V10 5030.47 4800.00 251.01 58.20 192.81 Pass: Major Risk PB K Pad K-05 K-05 V4 3150.00 3360.00 749.37 61.27 688.11 Pass: Major Risk ', ', PB K Pad K-05 K-05A V5 3150.00 3360.00 749.59 61.27 688.32 Pass: Major Risk ', PB K Pad K-05 K-05B V1 3150.00 3360.00 750.11 61.27 688.83 Pass: Major Risk PB K Pad K-05 K-056PB1 V12 3150.00 3360.00 750.11 61.27 688.83 Pass: Major Risk ', PB K Pad K-05 K-05C V6 3150.00 3360.00 750.11 61.27 688.83 Pass: Major Risk ~! ', PB K Pad K-06 K-O6 V4 3880.34 3900.00 43.75 66.07 -22.32 FAIL: Major Risk , PB K Pad K-06 K-06A V1 3888.89 3900.00 43.04 65.60 -22.56 FAIL: Major Risk PB K Pad K-07 K-07 V2 3718.41 3720.00 67.01 56.26 10.75 Pass: Major Risk ', PB K Pad K-07 K-07A V3 3718.39 3720.00 67.50 56.27 11.23 Pass: Major Risk PB K Pad K-07 K-07AP61 V3 3718.39 3720.00 67.50 56.27 11.23 Pass: Major Risk PB K Pad K-07 K-07APB2 V5 3718.39 3720.00 67.50 56.27 11.23 Pass: Major Risk ', PB K Pad K-07 K-07B V3 3718.39 3720.00 67.50 56.27 11.23 Pass: Major Risk PB K Pad K-07 K-07C V8 3151.67 3160.00 53.51 43.57 9.94 Pass: Major Risk ~, PB K Pad K-07 K-07D V2 3151.67 3160.00 53.51 42.67 10.84 Pass: Major Risk PB K Pad K-08 K-08 V3 3509.28 3480.00 158.86 55.14 103.73 Pass: Major Risk PB K Pad K-08 K-08A V2 3509.30 3480.00 159.25 55.16 104.09 Pass: Major Risk PB K Pad K-09 K-09 V1 3155.19 3180.00 205.47 45.13 160.34 Pass: Major Risk PB K Pad K-09 K-09A V1 3163.44 3200.00 207.93 45.28 162.64 Pass: Major Risk ~I PB K Pad K-09 K-09APB1 V1 3163.44 3200.00 207.93 45.28 162.64 Pass: Major Risk I PB K Pad K-09 K-096 V2 3157.14 3180.00 206.14 45.17 160.97 ~ Pass: Major Risk PB K Pad K-09 K-096P61 V2 3157.14 3180.00 206.14 45.17 160.97 Pass: Major Risk ', PB K Pad K-09 K-09C V2 3157.14 3180.00 206.14 45.17 160.97 Pass: Major Risk ', PB K Pad K-10 K-10 V1 3160.58 3160.00 0.12 0.91 -0.79 FAIL: NOERRORS • BP • Anticollision Report Company: BP Arnoco Date: 1/1,6/2006 Fieltlt Prudhoe Bay Reference Site: PB K Pad Cowrdinate(NE) Reference Reference ~~ell: - ~ K-10 ~ Vertieal~(T'~D) Reference: Reference ~~'ellpath: PIanK,-10C Summur~ <---------- ------- Offset Wellpath ------- --------> Site Well Wellpath PB K Pad K-11 K-11 V1 PB K Pad K-12 K-12 V5 PB K Pad K-12 K-12A V7 ', PB K Pad K-12 K-12APB1 V3 I PB K Pad K-13 K-13 V1 PB K Pad K-13 Plan K-13A V1 Plan: K- PB K Pad K-14 K-14 V1 ', PB K Pad K-16 K-16 V3 PB K Pad K-16 K-16A V1 1 ' PB K Pad K-16 K-16AL1 V2 ', PB K Pad K-16 Plan#5 K-16AL2 V2 Plan PB K Pad K-17 K-17 V2 PB K Pad K-17 K-17A V2 PB K Pad K-17 K-17AP61 V2 ', PB K Pad K-17 K-17AP62 V1 PB K Pad K-17 K-17PB1 V1 PB K Pad K-17 K-17P62 V2 PB K Pad K-17 K-3176 V7 PB K Pad K-19 K-19 V1 PB K Pad K-19 K-19A V1 PB K Pad K-19 K-19AL1 V2 PB K Pad K-20 K-20 V1 PB K Pad K-20 K-20A V1 ' PB K Pad K-20 K-206 V2 PB K Pad K-20 K-20P61 V3 Time: 13:37:04 Well: K-10, True North 26.38+28.5 54.9 Reference Offset Ctr-Ctr MD SID Distance ft ft ft 3182.68 3360.00 845.24 4749.66 4600.00 407.30 4749.66 4600.00 407.30 4749.66 4600.00 407.30 3156.42 3520.00 467.73 3159.67 3460.00 402.23 3154.13 3540.00 1051.15 4940.88 4580.00 520.14 1592.55 10540.00 598.04 4944.31 4580.00 520.17 4944.31 4580.00 520.17 5261.93 4980.00 228.59 5261.93 4980.00 228.59 5261.93 4980.00 228.59 5261.93 4980.00 228.59 5261.93 4980.00 228.59 5261.93 4980.00 228.59 5261.93 4980.00 228.59 3160.72 3200.00 215.19 3150.28 3180.00 212.98 3150.28 3180.00 212.98 5195.36 4940.00 70.26 5186.89 4920.00 69.57 5186.89 4920.00 69.57 5195.31 4940.00 70.20 No-Go ~rca ft 68.55 53.57 53.57 53.57 62.21 61.53 62.33 56.78 159.91 56.84 56.95 58.52 58.52 58.52 58.52 58.50 58.52 58.53 40.68 40.53 40.53 57.10 56.41 56.41 57.09 :~Ilowable Deviation ft 776.70 353.73 353.73 353.73 405.52 340.69 988.82 463.37 438.14 463.34 463.23 170.07 170.07 170.07 170.07 170.08 170.07 170.06 174.51 172.45 172.45 13:16 13.17 13.17 13.10 Fage: llb: Oracle Warning 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 r ~ BP ~ Anticollision Report Company: BP AmoCO Date: 1/16!2006 'lime: 1'3:39:48 Page: I Field: Prudhoe Bay Reference Site: PB KPad Co-ordinate(NE) Reference: Well: K-10, True North Reference Well: K-10 ~ Vertical (TVI)) Reference: 26.38+28.5 54.9 ~ Reference ~y'ellpath: Plan K-10C Dla: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD + Stations Interval: x!0.00 ft Error Model: ISCWSA Ellipse i Depth Range: 3150.00 to 11625.44 ft Scan Method: Trav Cylinder North ', ', Maximum Radius:10000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 1/16/2006 Validated: No Version: 2 Planned From 'Co Survey Toolcode Tool Name ', ft ft - 100.58 3150.00 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 3150.00 11592.40 Planned: plan #11 V72 MWD+IFR+MS MWD +IFR + Multi Station ', Casing Points MD TVD 'Diameter ' Hole Size Name _, ft - -.- ft _- in in I 2694.00 2693.91 13.375 17.500 13 3/8" ~ ' 3150.00 3147.94 9.625 12.250 9 5/8" 9436.77 8187.88 7.000 8.500 7" ', 11592.30 -- 8754.88 -- 4.500 6.125 _ _ 4 1 /2" _ _- -- -- - - - _ I Summary <_______~~__ ___.__~ OfTset Wellpath -------------> - Reference Offset' Ctr-Ctr No-Go 111owabte Site Well Wellpath MD MD Distaixce Area Deviation ~b'arning ft ft ft. ft ft PB K Pad K-06 K-06 V4 3898.64 3920.00 42.64 17.41 25.23 Pass: Minor 1/200 PB K Pad K-06 K-06A V1 3888.89 3900.00 43.04 17.81 25.23 Pass: Minor 1/200 • • SONDRA D STEWMAN as-sii25z 139 BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 ,., l _ ANCHORAGE, AK 99519-661.2 pArE ~ ~ ~ ~~^ ~~ PAY TO THE c~ ~ ~ ~ l ' ~J ~-./ ORDER OF ~~~--~~AY1~~' ~-C~. ~,V U~J.. DOLLARS First National Bank. Alaska Anch rage, AK 99501. MEMp 1 ~ ~/~. ~ ~ ~ V ~ 1 2 5 2 0 0 0 6 D ~: 9 9 1 4 ~~~ 6 2 2 7 ~~~ 1 5 6 t, n• 0 1 3 9 J. • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ 1~ - ~d PTD# _ .Z~~ S' ~/ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing exception, assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (CompanX NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/25/06 C : \j ody\transm ittal_checkl ist r • : ( ~ ; ~ o : N O , : y : 0 ~ ~ ~ ~ ~ ,. E O ~ ~ ~ ~ ~ ~ f0 ~ ~ ~ ~ O ~ ~ ~ ~ ~ ~ ~ _ ~ ~ ~ ~ ~ ~ ~ f ~ ~ d ~ o ~ °°~ ~ o ~ j : f ~ ui o ~ ~ ~ y ~, ~ n o. ° m, ~ . ~' o ' m C7 ~ ~ ~ ~ ~ ~? rn °o: ~ v, ?j: M 2. Z ~ ~ ~ ~ ~ ~ ~ 7• W. N ~ ~: ~, O: C. W : (A: N, fA~ N, VY N. N~ N. N, N, N~ fA N' N, N, N, N~ N' N~ N~ N, N: N, N, qk ~ N. Q, Q. Q; Q, ~ Q. ~ ~ tlY Q, N, - VA N~ N~ N, N, N, N' V1' N N' N' N~ Q, N, N, N: N, ' N' O, Q, N, Z ' Z O, Z Q, Z Q, Q, Z Z Q, Z ~ d ~, }, ~', ~', }, ~',. }, ~, },. }, ~', ~', }, Z. Z. 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