The URL can be used to link to this page

Home My WebLink About200-024Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (do.e) RESCAN [] Color items: ,~¢"~-ra ysca le item s: [] Poor Quality Originals: © Other: DIGITAL DATA Diskettes, No. [] Other, No/Type TOTAL PAGES: NOTES: ORGANIZED BY: BEVERLY BRE~HERYL MARIA LOWELL Project Proofing OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DATE: /S/ [] Staff Proof By Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE /SI Scanned (done T)AGES: SCANNED BY. BEVERLY BREN VINCE~ARIA LOWELL ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL M4RtA LOWELL DA~E /si General Notes or Comments about this file' PAGES: Quality Checked (done) RevlNOTScanned.wpd ! • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 t -, Post Office Box 196612 Anchorage, Alaska 99519 -6612 00 9J1 ep— • March 06, 2011 . a) Mpg 1 6 2,01 RECEIVEC Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Asks Oil & r ions. Cozzi Anchorage, Alaska 99501+zi 'Inchon* Subject: Corrosion Inhibitor Treatments of GPB D Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 03/04/11 Corrosion • Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement pumped cement date inhibitor sealant date ft bbls ft na gal 0-01A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 D -05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 D -07B 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 D -08A 2021230 50029203720100 NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 D -10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 D -11 B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 0-12 1800150 50029204430000 NA 1.3 . NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 D -14A 1961530 50029204500100 NA 0.2 NA 0.85 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 • D -17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -19B 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 D -20 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 D -21 1820520 50029207880000 NA 0.2 NA 3.40 2/10/2011 0-22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 D -24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 D -27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 D -29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 D -30B 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D -31A 1960950 50029226720100 NA 3.3 NA 27.20 1/19/2011 0-33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 A STATE OF ALASKA I AL~ OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Comnission Anchorage o Re-Enter Suspended Well o Other . 1. Operations Performed: o Abandon RECEIVED JUL 1 1 2006 181 Repair Well 181 Pull Tubing o Operation Shutdown o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: 71.74' ADL 028285 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Liner Tieback Perforation Depth MD (ft): Perforation Depth TVD (ft): Length 110' 2715' 10032' 848' 2117' 5586' 11750 9028 11687 9028 o Plug Perforations 0 Stimulate o Perforate New Pool 0 Waiver o Perforate o Time Extension 99519-6612 4. Well Class Before Work: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 200-024 6. API Number: 50-029-21522-01-00 9. Well Name and Number: PBU D-25A 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) 9657 feet Junk (measured) None feet Size MD TVD Burst 20" x 30" 110' 110' 13-3/8" 2715' 2690' 4930 9-5/8" 10032' 8417' 6870 7" 9769' - 10617' 8195' - 8897' 8160 2-718" 9633' - 11750' 8082' - 9028' 13450 7" 3936' - 9522' 3709' - 7991' 7240 c: "': COllapse 2670 4760 7020 13890 5410 11360' - 11670' 9020' - 9028' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Signature Form 1 0-404 Revised 04/2006 4-1/2", 12.6# fi-1/2" 17# 9-5/8" x 5-1/2" TIW packer; 7" x 4-1/2" Baker 'S-3' packer L-80 I-RO 9533' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 13. 9549'; 9390' RBDMS BFl ,JUL 1 1 2U06 Oil-Bbl Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 181 Daily Report of Well Operations 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Doug Cismoski, 564-4303 306-215 Printed Name Terrie Hubble Title Technical Assistant Phone 564-4628 Date D'7jrv/00 Terrie Hubble, 564-4628 Submit Original Only Prepared By Name/Number: e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-25A D-25A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/6/2006 Rig Release: 6/26/2006 Rig Number: Spud Date: End: 6/26/2006 6/512006 04:00 - 06:00 2.00 MOB P PRE Rig Pulled to Edge of D-Pad BID, Shut Down Motors, and Evacuated Location for Well Operations On D-11. Standing By To Resume Operations. 06:00 - 00:00 18.00 MOB P PRE Crews are Performing Maintenance and Cleaning Operation on Rig Camp Located On Price Pad. 6/6/2006 00:00 - 06:00 6.00 MOB P PRE Standing By to Resume Operation On D-25. 06:00 - 00:00 18.00 MOB P PRE Standing By to Resume Operations on Well D-25. Crews Performing Maintainance and Cleaning Rig. Little Red Services Rigged Up on Well. 6/7/2006 00:00 - 06:00 6.00 MOB P PRE Standing By to Resume Operations on Well D-25. Crews Performing Maintainance and Cleaning Rig. Little Red Services Rigged Up on Well 06:00 - 23:00 17.00 MOB P PRE Standing By to Resume Operations on Well D-25. Little Red and SWS Pre-Rig Work Finished. Remove Well house and Flowline. 23:00 - 00:00 1.00 MOB P PRE Level and Prep Location Around Well D-25A. 6/8/2006 00:00 - 02:00 2.00 MOB P PRE Level and Prep Location Around Well D-25A. 02:00 - 04:00 2.00 MOB P PRE Lay Herculite and Mats Around D-25A. Spot Rig Over D-25A. 04:00 - 06:00 2.00 MOB P PRE Lay Herculite and Spot Cuttings Tank. Spot #2 Mud Pump. Hook Up Lines. Rig Accepted at 06:00 Hrs. 06:00 - 08:00 2.00 KILL P DECOMP Take on Seawater, RlU Circulating Lines. 08:00 - 09:00 1.00 KILL P DECOMP RlU DSM Lubricator and Pull BPV. 09:00 - 12:30 3.50 KILL P DECOMP Displace Diesel Freeze Protect from Well. Pump 40 bbl Safe Surf Sweep Followed by 850 bbls of 120 Degree Seawater. Pump Pressure 1020 psi at 11 bpm. 12:30 - 13:00 0.50 WHSUR P DECOMP Set TWC and Test from Below to 1,000 psi. 13:00 - 13:30 0.50 WHSUR P DECOMP BID and RID Lines. 13:30 - 14:30 1.00 WHSUR P DECOMP NID Tree and Adaptor Flange. Check Hanger Threads and Function Lock Down Screws. 14:30 - 16:00 1.50 BOPSU DECOMP N/U BOPE. 16:00 - 16:30 0.50 BOPSU DECOMP RlU BOP Test Assembly. 16:30 - 18:00 1.50 BOPSU SFAL DECOMP Attempt to Test BOPE. Leaking by TWC. RID Test Assembly. 18:00 - 20:00 2.00 BOPSU DECOMP Test Choke Manifold to 250 psi Low and 3,500 psi High Pressure, While Waiting on DSM. 20:00 - 21 :00 1.00 BOPSU SFAL DECOMP RlU DSM Lubricator, Pull TWC and Replace with Second TWC. 21 :00 - 22:00 1.00 BOPSU SFAL DECOMP RlU and Attempt to Test BOPE. Second TWC Leaking. 22:00 - 00:00 2.00 BOPSU SFAL DECOMP RlU DSM Lubricator and Pull TWC. Redress and Set TWC. 6/9/2006 00:00 - 04:00 4.00 BOPSU DECOMP Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Kill Line HCR Valve Failed. Perform Accumulator Test. AOGCC Witness of Test Waived by John Crisp. Test Witnessed by Doyon Toolpusher and BP WSL. 04:00 - 06:00 2.00 BOPSU RREP DECOMP BID Lines, Replace Kill Line HCR Valve. 06:00 - 07:00 1.00 BOPSU DECOMP Test kill line HCR valve, no test. Valve not holding. 07:00 - 08:00 1.00 BOPSU DECOMP Remove and replace kill line HCR valve. 08:00 - 09:00 1.00 BOPSU DECOMP Test kill line HCR valve. Test to 250 low and 5000 psi high test, OK. 09:00 - 10:00 1.00 PULL P DECOMP Remove bell nipple & air boot flange from top of the annular preventor. Install 5000 psi shooting flange with 7" OTIS quick connect. 10:00 - 11 :00 1.00 PULL P DECOMP RlU DSM lubricator & pull TWC valve. 11 :00 - 18:30 7.50 PULL P DECOMP Hold PJSM with drill crew & SWS. RlU lubricator & SWS BOPE. RIH with 41/16" chemical cutter & cut the 5 1/2" tubing Printed: 7/5/2006 10:09:22 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-25A D-25A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/6/2006 Rig Release: 6/26/2006 Rig Number: Spud Date: End: 6/26/2006 6/912006 11 :00 - 18:30 7.50 PULL P DECOMP @ 9509'. RID SWS Equipment. 18:30 - 20:00 1.50 PULL P DECOMP RID 5,000 psi shooting flange with 7" OTIS quick connect. RlU Boot flange and riser. 20:00 - 21 :00 1.00 PULL P DECOMP M/U Landing joint, BOLDS and pull hanger to floor. Hanger came off seat at 185,000# and string came free at 245,000# 21 :00 - 22:00 1.00 PULL P DECOMP BIO and UD landing joint and tubing hanger 22:00 - 23:00 1.00 PULL P DECOMP Circulate bottoms up. 1,100 psi at 11 bpm. 23:00 - 00:00 1.00 PULL P DECOMP Monitor Well, Well Static. POOH, laying down 5 1/2" tubing from 9,509' to 9,032' 6/10/2006 00:00 - 12:00 12.00 PULL P DECOMP POOH laying down 51/2" tubing from 9,032'. Recovered 225 jts. of 51/2" tbg, SSSV, 5 GLM's, Sliding Sleeve, 20.82' cutjt, 26 rubber clamps and 4 stainlees steel bands. 12:00 - 13:00 1.00 PULL P DECOMP Clear and clean rig floor. 13:00 - 13:30 0.50 CLEAN P DECOMP Install Wear Bushing. 13:30 - 14:30 1.00 CLEAN P DECOMP MIU BHA #1. 8 1/2" MM Rotary Shoe, 2x 8 1/8" TSWP Ext, Washover Boot Basket, XO, 2 x 7" Boot Basket, 95/8" Casing Scraper, XO, Bumper Sub, Oil Jar, XO, 9 x 6 1/4" Drill Collars, XO. Total BHA length = 335.06' 14:30 - 23:00 8.50 CLEAN P DECOMP P/U 4" Drill Pipe from 335' to 9,456' 23:00 - 00:00 1.00 CLEAN P DECOMP M/U Top Drive, Establish Parameters, Up Weight 195,000#, Down Weight 150,000#, Rotating Weight 168,000#. Rotary Torque 5,000 ftllbs at 40 rpm. 350 psi at 4 bpm. Wash down tag top of tbg at 9,516' 6/11/2006 00:00 - 00:30 0.50 CLEAN P DECOMP Wash over Top of Tbg Stub from 9,516' to 9,526'.40 rpm and 5,000 ftIIbs Torque. 350 psi at 4 bpm. 00:30 - 01 :30 1.00 CLEAN P DECOMP Circulate 40 bbl Hi - Vis Sweep around. 3,500 psi at 14 bpm. 01 :30 - 05:00 3.50 CLEAN P DECOMP POOH with BHA #1 from 9,516' to 335' 05:00 - 06:30 1.50 CLEAN P DECOMP UD Dress Off BHA 06:30 - 07:30 1.00 CLEAN P DECOMP RIH with 6 1/4" drill collars. POH UD collars. 07:30 - 08:00 0.50 CLEAN P DECOMP Clear & clean rig floor. 08:00 - 08:30 0.50 CLEAN P DECOMP P/U 95/8" HES retrievable bridge plug. 08:30 - 12:00 3.50 CLEAN P DECOMP RIH with RBP to 9462'. 12:00 - 12:30 0.50 CLEAN P DECOMP Set RBP @ 9462'. Release from plug & POH 3 stands of drill pipe. 12:30 - 13:00 0.50 CLEAN P DECOMP RlU & test 9 5/8" casing to 3500 psi. Test did not hold. 13:00 - 14:30 1.50 CLEAN P DECOMP Position and set RBP at 9,435', would not test. Unseat and monitor well, well static. 14:30 - 16:30 2.00 CLEAN P DECOMP POOH from 9,435' to 4,600'. 16:30 - 17:30 1.00 CLEAN P DECOMP Set RBP at 4,600' and test to 2,500 psi. Test held. Unseat RBP. 17:30 - 19:00 1.50 CLEAN P DECOMP RIH from 4,600' to 9,200'. 19:00 - 22:00 3.00 CLEAN P DECOMP Set RPB and attempt to test casing at 9,200',9,000',8,800' and 8,300'. All tests failed. Trouble releasing RBP at 8,300'. Excess drag, RBP would not reset. Decision made to POOH. 22:00 - 00:00 2.00 CLEAN P DECOMP Monitor well, well static. POOH from 8,300' to 4,800' 6/12/2006 00:00 - 02:00 2.00 CLEAN P DECOMP POOH from 4,800' 02:00 - 02:30 0.50 CLEAN P DECOMP UD RBP and P/U second RBP. 02:30 - 05:30 3.00 CLEAN P DECOMP RIH with RBP to 7,000'. 05:30 - 07:00 1.50 CLEAN P DECOMP Get parameters,circ through kill line. Set RBP at 7,000' and test casing to 3500 psi for 30 min, OK. 07:00 - 08:30 1.50 DHB P DECOMP Release from RBP & POH 3 stands of drill pipe. M/U HES storm packer & set 102' below wellhead. Test packer to 1000 psi, OK. Printed: 7/5/2006 10:09:22 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-25A D-25A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/6/2006 Rig Release: 6/26/2006 Rig Number: Spud Date: End: 6/26/2006 Pull wear ring. M/U running tool & engage 9 5/8" pack off. Work pipe in attempt to pull packoff. Pulled 30K, pack off parted & left bottom section in wellhead. 09:30 - 12:00 DECOMP NID BOPE. Remove tubing spool. Remove bottom section of pack off. 12:00 - 14:30 DECOMP Prep new tubing spool, install spool & new pack off. Test void to 5000 psi for 30 min, OK. 14:30 - 16:00 1.50 DECOMP N/U BOPE. 16:00 - 17:30 1.50 DECOMP Install test plug, M/U test assembly and test Spool and Adaptor Flange break to 250 psi Low and 3,500 psi High. RID test assembly and pull test plug. Install Wear Ring. 17:30 - 18:30 1.00 DHB P DECOMP M/U Running tool and retrieve Storm Packer. UD Storm Packer. 18:30 - 20:00 1.50 CLEAN P DECOMP RIH to 7,000', Latch and release RBP. RIH to 9,000'. 20:00 - 21 :30 1.50 CLEAN P DECOMP Set RBP at 9,000', Pressure test casing, test failed. Establish injection rate, 2 bpm at 2,500 psi. Unseat RBP and set at 8,900'. Test casing, test failed, Monitor well, well static. POOH to 8,600' 21 :30 - 22:30 1.00 CLEAN P DECOMP Slip and cut 81' of drilling line. 22:30 - 00:00 1.50 CLEAN P DECOMP POOH to 8,000' and set RBP, test casing, test failed. Release RBP. POOH to 7,500' set RBP. 6/13/2006 00:00 - 00:30 0.50 CLEAN P DECOMP Test casing at 7,500', test failed 00:30 - 03:30 3.00 CLEAN P DECOMP Monitor well, well static. POOH from 7,500' 03:30 - 04:00 0.50 CLEAN P DECOMP UD RBP and running tool. 04:00 - 13:30 9.50 CLEAN X DECOMP Change in Scope of Work. Clean and Clear Rig Floor, Derrick Inspection, Hang New Rig Tongs, Strap and Drift 7", Clean Prime and Paint Draw Works. Service Top Drive. 13:30 - 15:30 2.00 EVAL P DECOMP RlU E-line Sheaves, Shooting Nipple, Pump - In Sub, and Pack Off / Line Wiper. 15:30 - 00:00 8.50 EVAL P DECOMP RIH wI US IT to 9475' and Log Up to Surface - Looking at Corrosion and Cement. Evaluate Log. Top of Cement at 2,040'. RIH and Log in High Resolution Mode. 6/14/2006 00:00 - 03:30 3.50 EV AL P DECOMP RIH with USIT Log and Log up in High Resolution Mode. 03:30 - 05:00 1.50 EVAL P DECOMP RID Wireline Equipment. 05:00 - 06:30 1.50 CASE P DECOMP RlU to Run 7" Scab Liner. PJSM on Running Liner. 06:00 - 07:30 1.50 CASE P DECOMP M/U and RIH wI 9-5/8" x 5-1/2" Unique O/S, 10' 5-1/2" Pup wI Saker Insert Float Collar, 10' 5-1/2" Pup wI Baker Type II Landing Collar, 5-1/2" x 7" XO, 1 Jt of 7" 26# L-80 BTC-M, 7" HES ES Cementer w/ 8rd x BTC-M XO's. MIU All Connections wI Baker Loc. 07:30 - 15:30 8.00 CASE P DECOMP M/U and RIH wI 7" 26# L-80, BTC-M Casing wI Free Floating Centrilizer on Every Joint. Fill Pipe Every 5 Jts while RIH. Average M/U Torque = 8,000 ft-Ibs. 133 Joints Run above ES Cementer, 134 Joints Total. 15:30 - 16:00 0.50 CASE P DECOMP M/U Baker Liner Hanger, Liner Top Packer, and Tie Back Sleeve. Total Length of Liner including all components = 5586.5'. 16:00 - 18:30 2.50 CASE P DECOMP RIH wI Liner Assembly on 4" DP from Derrick. 18:30 - 19:30 1.00 CASE P DECOMP Establish Parameters, Up Weight 237,000#, Down Weight 165,000#,3 bpm at 140 psi. Wash over Top ofTubing Stub at 9,516'. Pressured up to 300 psi When Swallowing Tubing Stub. Pressured up to 550 psi when Stacking Out. P/U to Up Weight then Additional 2'. Printed: 7/5/2006 10:09:22 AM e e .II Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-25A D-25A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/6/2006 Rig Release: 6/26/2006 Rig Number: Spud Date: End: 6/26/2006 6/14/2006 19:30 - 20:30 1.00 CASE P DECOMP M/U Baker Cementing Head. 20:30 - 20:30 24.00 CASE P DECOMP Attempt to Set Liner Hanger. Pressure Up to 2,000 psi and Hold. Slack Off on Hanger. No Indication of Setting. Re-position Liner Hanger. Pressure Up to 2,100 psi, ES Cementer Opened. 20:30 - 21 :30 1.00 CASE P DECOMP CBU, 6 bpm at 720 psi. Hold PJSM with All Personnel Involved. 21 :30 - 00:00 2.50 CASE P DECOMP Test Lines to 4,500 psi, Pump 25 bbls of 11.5 ppg Lite Crete, 50 bbls of 11.5 ppg Lite Crete with .75#/BBL Cell Flake, 45 bbls of 11.5 ppg Lite Crete with .25#/bbl Cell Flake, and 50 bbls of 15.8 ppg Class G Cement. Displace with 252 bbls of Seawater. Did Not Bump Plug. Over Displace as per Precedure. Did Not Bump Plug. Discuss Options With Anchorage. 6/15/2006 00:00 - 00:30 0.50 CASE P DECOMP Continue to Displace Cement additional 5 bbls. Did Not Bump Plug. CIP 00:15 hrs. Release from Liner, Weight Set Liner. Saw Indication That Packer Set. 00:30 - 01 :30 1.00 CASE P DECOMP Circulate Cement from Top of Liner, Pump 20 bbl Sapp Pill and 20 bbl Biozan Pill. 12 bpm at 2,320 psi. Appx 50 bbls of Cement back to Surface. 01 :30 - 02:00 0.50 CASE P DECOMP BIO and UD Cement Head. 02:00 - 02:30 0.50 CASE P DECOMP Circulate 20 bbl Hi-Vis Sweep. 12 bpm at 2,300 psi 02:30 - 04:00 1.50 CASE P DECOMP POOH with Liner Running Tool. 04:00 - 04:30 0.50 CASE P DECOMP UD Liner Running Tool. Dogs were Sheared on Tool. 04:30 - 05:00 0.50 CASE P DECOMP P/U Cement Head from Pipe Shed. Break Down Cementing Head. 05:00 - 05:30 0.50 CASE P DECOMP Clear Rig Floor. 05:30 - 06:00 0.50 CASE P DECOMP P/U Flushing Tool and Flush BOP Stack, Clean Out Drip Pan and from Under Shakers. 06:00 - 07:00 1.00 CASE P DECOMP P/U 3 stands of 4-3/4" DC's from Pipe Shed and Stand Back. 07:00 - 10:00 3.00 CASE P DECOMP WOC, Inspect, Maintain and Clean Rig. 10:00 - 11 :00 1.00 CASE P DECOMP Load Additional DC's and HWDP in Pipe Shed. Strap, Caliper, and Tally Pipe. 11 :00 - 13:00 2.00 CASE P DECOMP M/U BHA#2- 7" Drill Out BHA. 6-1/8" Bit, 2 x Boot Baskets, XO, Bumper Sub, Oil Jars, XO, 18 x 4-3/4" DC's, 21 x HWDP. Total BHA Length 1,223.65' 13:00 - 14:00 1.00 CASE P DECOMP RIH to 3911' on 4" DP. 14:00 - 15:30 1.50 CLEAN P DECOMP M/U TD and Establish Parameters. 5 bpm @ 370 psi, 80 rpm's at 3,000 ft-Ibs, P/U Wt = 114,000 #, SIO Wt = 105,000 #, Rotating Wt = 108,000 #. RIH to Top of Liner at 3935' and Continue in hole. Tag at 3985'. Wash and Ream to 3988' in 1 hour. Able to Get through 3' of cement, and then spinning on something. Vary parameters from 0-25,000 Ibs WOB, 10-90 rpm's, and pump rate 2.5 - 10 bpm. Unable to make hole. 15:30 - 17:30 2.00 CLEAN P DECOMP POOH and Stand Back DP, HWDP, and Collars. UD 6-1/8" Bit and Boot Baskets. Found Pieces of Aluminium and Black Rubber in Baskets. No wear on Bit. 17:30 - 19:00 1.50 CLEAN P DECOMP M/U BHA #3 - Reverse Circulating Junk Basket, Bumper Sub, Oil Jars, XO, 18 x 4.75" DC's, 21 x HWDP. Total BHA Length 1,218.92' 19:00 - 20:00 1.00 CLEAN P DECOMP RIH with 4" DP from 1,218' to 3,812' 20:00 - 20:30 0.50 CLEAN P DECOMP Pump Pipe Volume 480 psi at 5 bpm. Drop Ball and Open Reverse Circulating Junk Basket. Wash Down and Tag at 3,988'. Establish Parameters Up Weight 114,000#, Down Printed: 7/512006 10:09:22 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-25A D-25A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/6/2006 Rig Release: 6/26/2006 Rig Number: Spud Date: End: 6/26/2006 6/15/2006 20:00 - 20:30 0.50 CLEAN P DECOMP Weight 105,000, Rotating Weight 108,000#. 80 rpm at 3,000 ftllbs Torque. 5 bpm at 480 psi. 20:30 - 22:00 1.50 CLEAN P DECOMP Wash and Ream from 3,988' to 4,300'. 22:00 - 00:00 2.00 CLEAN P DECOMP RIH from 4,300' to 6,500'. Circulate and Rotate Every Third Stand. 6/16/2006 00:00 - 01 :30 1.50 CLEAN P DECOMP RIH from 6,500' to 7,940'. Rotate and Circulate Down Every Fourth Stand. Taking 10,000# Weight While Washing Down. 01 :30 - 02:30 1.00 CLEAN P DECOMP Pump 20 bbl Hi-Vis Sweep Around. 9.5 bpm at 2,810 psi. 02:30 - 07:00 4.50 CLEAN P DECOMP POOH from 7,940' stand back DP, HWDP and DC's. 07:00 - 08:00 1.00 CLEAN P DECOMP UD Reverse Circualting Basket and M/U BHA#4- 7" Drill Out BHA. 6-1/8" Bit, 2 x Boot Baskets, XO, Bumper Sub, Oil Jars, XO, 18 x 4-3/4" DC's, 21 x HWDP. Total BHA Length 1,223.65' 08:00 - 09:30 1.50 CLEAN P DECOMP POOH wI Drill Out Assembly BHA Stand Back HWDP and DC's. CIO Bit to 6" 09:30 - 12:30 3.00 CLEAN P DECOMP RIH wI Drill Out Assembly BHA to 7,848'. 12:30 - 17:30 5.00 CLEAN P DECOMP M/U Top Drive and Wash to 7,940'. Drill Cement from 7,940 to 8,903'.15,000 to 20,000# WOB, 80 rpm at 8,000 ftllbs of Torque, 2,020 psi Pump Pressure at 8 bpm. 17:30 - 19:00 1.50 CLEAN P DECOMP Circulate High-Vis Sweep Around at 2,020 psi at 9 bpm. 19:00 - 20:30 1.50 CLEAN P DECOMP POOH 5 Stands and P/U 9 5/8" RTTS and Set 1 Stand Below Rotary. Test RTTS to 1,000 psi. 20:30 - 21 :00 0.50 BOPSU P DECOMP Pull Wear Ring and Install Test Plug. 21 :00 - 00:00 3.00 BOPSU P DECOMP Test BOPE, IBOP's, Choke Manifold and Floor Valves to 250 psi Low Pressure, 3,500 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by Jim Regg. Test was Witnessed by Doyon Toolpusher and BP WSL. Accumulator Test, 2,950 psi Starting Pressure. Pressure After Actuation 1,800 psi, First 200 psi Increase in 14 Seconds, Back to Full Pressure in 1 Minute and 9 Seconds. 5 Nitrogen Bottles at 2,150 psi Average Pressure. 6/17/2006 00:00 - 01 :00 1.00 BOPSU P DECOMP Continue to Test BOPE to 250 psi Low and 3,500 psi High. No Failures. Pull Test Plug and Set Wear Ring. 01 :00 - 02:00 1.00 BOPSU P DECOMP Release and Pull RTTS. 02:00 - 02:30 0.50 BOPSU P DECOMP RIH to 8,903' 02:30 - 06:30 4.00 CLEAN P DECOMP Drill Cement from 8,903' to 9,442'. Pumping at 8 bpm, 1700 psi. 80 rpm's at 9,500 ft-Ibs torque wI 15-20K WOB. 06:30 - 07:30 1.00 CLEAN P DECOMP Circulate 20 bbl High Visc Sweep around Surface to Surface at 12 bpm. 07:30 - 08:30 1.00 CLEAN P DECOMP RlU Pressure Test Equipment and Chart. Pressure to Test Casing to 2500 psi. Casing Failed Pressure Test. Establish LLR of 1.0 bpm at 2490 psi, 1.6 bpm at 2810 psi, and 2.0 bpm at 2985 psi. Pumped 22 bbls while pressure Testing. Shut-In Pressure Blead down to 1250 psi in -10 mins after shutting pressure after LLR of 2.0 bpm. 08:30 - 09:00 0.50 CLEAN P DECOMP RID Pressure Test Equipment and BID Lines. RlU to POOH. 09:00 - 10:00 1.00 CLEAN P DECOMP Begin POOH and Pipe Pulling 10-15K over. Circulate around another 20 bbl High Visc Sweep at 12 bpm, Surface to Surface. 10:00 - 13:00 3.00 CLEAN P DECOMP POOH and Stand Back 4" DP 13:00 - 14:00 1.00 CLEAN P DECOMP POOH wI HWDP and Collars, Stand Back in Derrick. Clean Out Boot Baskets and UD 6" Bit. Boot Baskets contain a large volume of cement and a few pieces of aluminium. Bit in good shape, very little if any wear. Printed: 7/5/2006 10:09:22 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-25A D-25A WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 6/6/2006 6/26/2006 Spud Date: End: 6/26/2006 6/17/2006 14:00 - 14:30 0.50 CLEAN P DECOMP P/U BHA #4; 6-1/8" Bit, 7" Csg Scraper, Boot Baskets, Bumper Sub, Jars, DC's, and HWDP. Total Length = 1226.98'. 14:30 - 19:00 4.50 CLEAN P DECOMP RIH wI BHA #4 on DP from 1,226' to 9,388'. Break Circulation at liner top and continue in hole. No problems going through top of liner section. 19:00 - 20:30 1.50 CLEAN P DECOMP Wash to 9,440', Pump Hi-Vis Sweep Around 2,770 psi at 10 bpm. 20:30 - 00:00 3.50 CLEAN P DECOMP POOH and Stand Back 4" DP. 6/18/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP Stand Back HWDP and DC's. 01 :00 - 03:00 2.00 EV AL P DECOMP RlU SWS E-Line Unit, Shooting Nipple and Lubricator. 03:00 - 07:00 4.00 EV AL P DECOMP RIH with USIT Log on E-Line to 9400'. Log up to 3900' for cement evaluation in 7"x9-5/8 annulus. Found good to decent cement in annulus up to -7700', almost no cement in annulus above that point. 07:00 - 08:00 1.00 EVAL P DECOMP RID E-line equipment, Shooting Nipple and Lubricator. 08:00 - 09:00 1.00 REMCM P DECOMP Wait on HES Fasdrill Cement Sqz Packer to arrive on location. Clear and Clean Rig Floor and Service Drawworks. 09:00 - 10:00 1.00 REMCM P DECOMP MIU HES Fasdrill Sqz Packer and Setting Tool to 4"DP. 1 0:00 - 15:00 5.00 REMCM P DECOMP RIH wI Packer on 4" DP from Derrick. 15:00 - 15:30 0.50 REMCM P DECOMP Set HES 7" Fasdrill Sqz Packer at 9217'. RlU Pressure Test Equipment and Circulating Head. 15:30 - 16:30 1.00 REMCM P DECOMP With FasDrill Packer Set. With Sleeve in the closed position Pressure Test From Above to 2500 psi. Test Failed - LLR = 1.5 bpm at 2560psi. Pressure Test Below FasDrill Plug to 3500 psi for 15 mins. Good Test. 16:30 - 17:00 0.50 REMCM P DECOMP RID Test Equipment 17:00 - 20:00 3.00 REMCM P DECOMP POOH wI 4" DP. 20:00 - 21 :00 1.00 REMCM P DECOMP Change Out Running Tools, M/U HES 7" FasDrill. 21 :00 - 23:30 2.50 REMCM P DECOMP RIH wI Packer on 4" DP from Derrick. Set 7" FasDrill at 3,970'. Set 20,000# Down on FasDrill. 23:30 - 00:00 0.50 REMCM P DECOMP Service Top Drive. 6/19/2006 00:00 - 01 :00 1.00 REMCM P DECOMP Slip and Cut Drilling Line. 01 :00 - 02:30 1.50 REMCM P DECOMP POOH with 4" DP. 02:30 - 03:00 0.50 REMCM P DECOMP BIO and UD 7" Running Tool, MIU 95/8" Running Tool and 9 5/8" FasDrill Plug 03:00 - 05:00 2.00 REMCM P DECOMP RIH with 9 5/8" FasDrill Plug on 4" DP 05:00 - 05:30 0.50 REMCM P DECOMP Set 9 518" FasDrill at 3,907'. Test FasDrill to 3,500 psi. 05:30 - 07:00 1.50 REMCM P DECOMP RlU Circulating Head. Establish Injection Rate of 1.65 bpm at 2350 psi. Unsting From Sqz Pkr and Circulate around 20 bbl High Visc Pill and 20 bbl Sapp Pill and Chase out the end of DP. 07:00 - 08:00 1.00 REMCM P DECOMP PJSM with Rig Crew and Dowell on Sqz Job. RlU Dowell and Batch Mix 106 bbls of Class G Cmt wI Latex Additive. 08:00 - 08:30 0.50 REMCM P DECOMP Pump 5 bbls of water with Dowell and PT lines to 5000 psi with CMT Truck. Circulate 25 bbls of Cmt down DP at 2.0 bpm and 150 psi pump pressure. 08:30 - 09:30 1.00 REMCM P DECOMP Stab In to Sqz Packer and Pump 106 bbls of Class G Cmt wI Latex additive. Vol Pumped Rate WH Press 27.5 1.6 77 30.0 1.6 128 43.5 2.0 1935 53.3 2.3 1600 Printed: 7/512006 10:09:22 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-25A D-25A WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 6/6/2006 6/26/2006 Spud Date: End: 6/26/2006 6/19/2006 08:30 - 09:30 1.00 REMCM P DECOMP 70.0 2.5 1496 80.0 2.5 1459 90.0 2.5 1400 100.0 2.5 1325 106.0 2.5 1300 09:30 - 10:00 0.50 REMCM P DECOMP Displace Cement with Seawater. Vol Pumped Rate WH Press 4.0 2.7 1363 8.0 2.7 1400 10.0 2.6 1505 14.0 2.5 1675 16.0 2.5 1635 19.0 2.5 1610 10:00 - 11 :00 1.00 REMCM P DECOMP Hesitate Sqz Cement after pumping First half of Displacement Volume. Shut-in after pumping 19 bbls. First Shut in for 30 minutes. Pressure Drops from 1610 to 40 psi. After 30 mins come back on line with pumps and Displace another 9 bbls. Pressure Built from up to 860 psi from 40 psi. With 28 bbls of Displacement Pump Shut-in for 20 mins. Pressure Dropped from 860 psi to 270 psi. Bring Pumps on line again at 0.5 bpm and displace 5 bbls. Well Head Pressure up to 865 psi at 33.0 bbls displaced. Shut-in Pump in and pressure dropped to 505 psi in 15 minutes. Displace final 4 bbls of cement at 0.5 bpm. Final Pump Pressure Up to 1090 psi. Shut-in Pumps and pressure down to 775 psi after 1 min. 11 :00 - 12:30 1.50 REMCM P DECOMP P/U and Unsting From Sqz Packer. WH Pressure Drop from 690 psi to 0 psi Rapidly. BIO and BID Cement Hose. UD Circulating Head and POOH wI 2 Stands. M/U Circ Head and Reverse Circulate 280 bbls at 8 bpm. Small Volume of Cement Back on Circulation. 12:30 - 14:00 1.50 REMCM P DECOMP POOH wI DP and UD Setting Tool from 9-5/8 Sqz Packer. 14:00 - 15:00 1.00 CLEAN P DECOMP Clear and Clean Rig Floor. 15:00 - 16:30 1 .50 CLEAN P DECOMP P/U BHA #6, Bit, Bit Sub, XO, 9 x 6.25" DC's, XO Total BHA Lenght = 285.11' 16:30 - 17:30 1.00 CLEAN P DECOMP RIH from 285' to 3,660'. 17:30 - 18:00 0.50 CLEAN P DECOMP M/U Top Drive and Break Circulation 5 bpm at 210 psi. 18:00 - 21 :30 3.50 CLEAN P DECOMP Wait on Cement. 21 :30 - 00:00 2.50 CLEAN P DECOMP Wash down and tag at 3,895', Drill Cement and 9 5/8" FasDrill Plug. Up Weight 105,000#, Down Weight 98,000#, Rotating Weight 104,000#, 50 rpm with 2,000 ftllbs Torque Off Bottom 4,000 ftllbs On Bottom Torque, 7 bbls at 430 psi Pump Pressure. 6/20/2006 00:00 - 01 :30 1 .50 CLEAN P DECOMP Drill 95/8" FasDrill Plug and Cement to 3,944'.25 rpm with 3000 - 5,000 ftllbs Rotary Torque. 15,000 - 20,000# WOB. 7 bpm at 440 psi. 01 :30 - 02:00 0.50 CLEAN P DECOMP Circulate 20 bbl Hi-Vis Sweep around at 18 bpm with 2,750 psi. 02:00 - 03:00 1.00 CLEAN P DECOMP POOH with 4" DP. 03:00 - 04:00 1.00 CLEAN P DECOMP UD 8 1/2" Clean Out BHA. 04:00 - 05:00 1.00 CLEAN P DECOMP M/U BHA #7,6" MiII,2 x Junk Subs, Bit Sub, Bumper Sub, Fishing Jar, XO, 18 x 4 3/4" DC's, 21 x 4" HWDP. BHA Length = 1225.24' Printed: 7/512006 10:09:22 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-25A D-25A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/6/2006 Rig Release: 6/26/2006 Rig Number: Spud Date: End: 6/26/2006 6/20/2006 05:00 - 06:30 1.50 CLEAN P DECOMP RIH with 4" DP. 06:30 - 07:00 0.50 CLEAN P DECOMP Establish Paramters; Up Wt = 110,000 Ibs, Down Wt = 100,000 Ibs, Rot Wt = 105,000 Ibs. Rotating at 60 rpm's, 3,500 ft-Ibs torque. Pump Rate 7.0 bpm at 850 psi. Drill Cement to 3963' . 07:00 - 07:30 0.50 CLEAN P DECOMP Circulate 20 bbl High Visc Sweep Surface to Surface at 14 bpm and 2750 psi. 07:30 - 09:30 2.00 CLEAN P DECOMP RlU Pressure Test Equipment, Chart and Circulating Head. Pressure Test TOL to 3500 psi for 30 minutes - Good Test. 09:30 - 10:00 0.50 CLEAN P DECOMP RID Pressure Test Equipment and Circ Head and M/U Top Drive. 10:00 - 11 :00 1.00 CLEAN P DECOMP Continue to Drill Cement from 3963' to 3970'. Drill 7" HES Composite Bridge Plug w/10-15K wt on mill, 50-80 rpm's, 4,000 - 6,000 ft-Ibs torque and 4-5 bpm pump rate. Once through bridge plug, continue to washed down remaining 30' of stand. 11 :00 - 12:00 1.00 CLEAN P DECOMP Circulate Bottoms Up at 14 bpm and 3000 psi from 4009'. 12:00 - 14:00 2.00 CLEAN P DECOMP RIH From 4,009' to 9,192'. 14:00 - 19:00 5.00 CLEAN P DECOMP M/U T/D Establish Parameters, Up Weight 210,000#, Down Weight 131,000#, Rotating Weight 170,000#, 80 rpm, 9,000 to 12,000 ft-Ibs Torque. Drilled Fas-drill @ 9,217'. Continue to RIH to 9,440' and Drill Remaining Cement and ES Cementer, Continue to Wash and Ream to 7"x 5.5" XO at 9,491'. 19:00 - 21 :00 2.00 CLEAN P DECOMP PJSM with Rig Crews, Mud Engineer, Veco Driver On Up Coming Displacement and Spill Prevention. Displace Well To Clean Sea Water. 21 :00 - 21 :30 0.50 CLEAN P DECOMP RlU to Test Casing. 21 :30 - 00:00 2.50 CLEAN P DECOMP Attempt to Test Casing to 3,500 Psi. Numerous Attempts. 6/21/2006 00:00 - 01 :30 1.50 CLEAN P DECOMP Continue to Obtain Casing Test to 3,500 Psi for 30 Minutes. 01 :30 - 02:00 0.50 CLEAN P DECOMP BID Lines Rig Down Test Equipment. 02:00 - 06:30 4.50 CLEAN P DECOMP POOH f/9,481' UD HWDP and 9 Drill Collars. 06:30 - 07:30 1.00 CLEAN P DECOMP RlU Pressure Testing Equipment and PT Casing to 3500 psi for 30 mins wI Blinds shut - fail 07:30 - 08:00 0.50 CLEAN P DECOMP Rig Down Test Equipment 08:00 - 09:00 1.00 CLEAN P DECOMP Begin MI U BHA with 4-3/4" Mill and CleanOut Assembly. Re-Direction From Town. 09:00 - 11 :00 2.00 CLEAN P DECOMP Pressure Test Casing to 1500 psi for 30 mins and 2500 psi for 30 mins while waiting on orders. 11 :00 - 12:00 1.00 CLEAN P DECOMP M/U 6-1/8 Bit and Scraper BHA and RIH. 12:00 - 15:00 3.00 CLEAN P DECOMP RIH on 4" DP. Wash and Ream 3936' - 3990' and 9150' - 9491'. 15:00 - 16:30 1.50 CLEAN P DECOMP Circulate 20 bbl High Vlsc Sweep for surface to surface at 11.0 bpm and 2200 psi. 16:30 - 19:30 3.00 CLEAN P DECOMP POOH and Sand Back 4" DP 19:30 - 20:30 1.00 CLEAN P DECOMP BIO and UD BHA #8 20:30 - 21 :00 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 21 :00 - 21 :30 0.50 CLEAN P DECOMP M/U RTTS Assembly. 21 :30 - 00:00 2.50 CLEAN P DECOMP RIH to 5,090'. 6/22/2006 00:00 - 01 :30 1.50 CLEAN P DECOMP Continue to RIH to 9402'. 01 :30 - 02:00 0.50 CLEAN P DECOMP Set RTTS @ 9402' Up Weight 200,000#, Down Weight 133,000#, RlU to Test. 02:00 - 03:00 1.00 CLEAN P DECOMP Tested to 3,500 psi, from 9402' to Surface for 30 minutes. Good Test. RlU to Test Below 9402'. 03:00 - 03:30 0.50 CLEAN P DECOMP Tested Below 9402' to 3,500 psi, Lost 600 psi in 10 Minutes. Printed: 7/5/2006 10:09:22 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-25A D-25A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/6/2006 Rig Release: 6/26/2006 Rig Number: Spud Date: End: 6/26/2006 Bled Off Pressure, RID Test Equipment, Unseat RTTS. P/U Two Jts DP Set RTTS at 9467'. RlU to Test, Pressure Tested f/9467' to Surface. To Include ES Cementer, Liner Top Packer. Tested to 3,500 psi f/30 minutes, Lost 400 psi. Bled Off Pressure, RID Surface Test Equipment, RlU to Test Below 9467'. Tested to 3500 psi f/30 Minutes, Lost 325 psi. Release RTTS and POOH with 2 joints. Reset RTTS at 4904' Pressure Test below RTTS. Pressure Up to 3500 psi. Lost 625 psi in 10 mins. Rig Up to Test above the RTTS. Test above RTTS, TOL and Surface. Pressure Up and Record Pressure Test. Pressure Up to 3500 psi and Monitor for 30 mins. Lost -35 psi in 30 mins. Results from Pressure Test, Leak Points are throught The ES Cementer at 9446' and Through the 5-1/2" Shoe Track. Good Pressure above the ES Cementer to Surface. DECOMP RID Pressure Testing Equipment. Lubricate Rig. DECOMP Release RTTS and POOH. Stand Back DP. DECOMP UD RTTS and Pick Up 4-3/4" Mill Drill Out BHA. 4-3/4" Superloy Mill, 5 joints 2-7/8 PAC, 7" Casing Scraper, 2 Boot Baskets, Bumper Sub, Fishing Jars, 94-3/4" DC's. Total Length = 470.79 ft. DECOMP RIH wI BHA to 7" 5-1/2" XO at 9491'. DECOMP M/U TID Wash and Ream fl 9398' to 9604' Drilling Float Equipment. Parameters: 130,000# Down Weight, 207,000# Up Weight, Rotating Weight 163,000#, at 50 rpms, 8,000 ft-Ibs off Bottom Torque, Circulating at 5 bpm, 790 psi, Tagged up at 9,491 '. Drilled Out Landing Collar w/WOM 3,000#, 40 rpms, With 9 - 10,000 ft-Ibs Torque, Slowed to 25 rpms w/8 - 10,000 ft-Ibs 5,000# WOM, Pumping at 3 bpm with 290 psi. Tag up at 9,512' On Float Collar. Drilled Float Collar and Washed down to X Nipple at 9,604'. Washed and Reamed Interval x 2. Pumped 40 bbl Hi-Vis Sweep at 10 bpm and 2760 psi. BIO BID TID POOH f/9,604' to 1,527'. POOH f/1 ,527' UD BHA. Clear and Clean Rig Floor, Pull Wear Ring, Set Test Plug. RlU BOP Test Equipment. Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by Chuck Sheve. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- Hydril, Choke HCR, Kill HCR, Upper IBOP. Test #2- Manual Choke, Manual Kill, Lower IBOP. Test #3- Choke Valves 1,12,13, 14 Test #4- Lower Pipe Rams, Koomey. Test #5- Blinds, Choke Valves 9, 11. Test #6- Choke Valves 5, 8,10, TIW Valve. Test #7- Choke Valves 4, 6, 7, Dart Valve. Test #8- Choke Valve 2 Test #9- Choke Valve 3 Test #10- Lower Rams with 4.5" tbg. 6/22/2006 03:30 - 04:00 0.50 CLEAN P DECOMP 04:00 - 04:30 0.50 CLEAN P DECOMP 04:30 - 05:00 0.50 CLEAN P DECOMP 05:00 - 06:00 1.00 CLEAN P DECOMP 06:00 - 06:30 0.50 CLEAN P DECOMP 06:30 - 08:00 1.50 CLEAN P DECOMP 08:00 - 08:30 08:30 - 12:00 12:00 - 13:00 0.50 CLEAN P 3.50 CLEAN P 1.00 CLEAN P 13:00 - 16:30 16:30 - 20:00 3.50 CLEAN P 3.50 CLEAN P 20:00 - 21 :00 1.00 CLEAN P DECOMP 21 :00 - 00:00 3.00 CLEAN P DECOMP 6/23/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP 01 :00 - 02:00 1.00 CLEAN P DECOMP 02:00 - 02:30 0.50 CLEAN P DECOMP 02:30 - 05:30 3.00 CLEAN P DECOMP Accumulater Test- 3,000 psi Starting Pressure, 1,800 psi After Printed: 7/5/2006 10:09:22 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-25A D-25A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/6/2006 Rig Release: 6/26/2006 Rig Number: Spud Date: End: 6/26/2006 6/23/2006 02:30 - 05:30 3.00 CLEAN P DECOMP Actuation, First 200 psi in 13 seconds, Full Pressure in 1 Minute 15 Seconds. 5 Nitrogen Bottles at 2,150 psi. 05:30 - 06:00 0.50 CLEAN P DECOMP RID BOP Test Equipment. 06:00 - 07:30 1.50 CLEAN P DECOMP M/U 4-5/8" Reverse Basket BHA; 4-5/8" Reverse Jet Basket wI 4-3/4" Head, 6 Joints of 2-7/8" PAC, 2 4-3/4" Boot Baskets, Bumper Sub, Fishing Jars, 9 4-3/4" DC's. Total Length = 507.26 07:30 - 12:30 5.00 CLEAN P DECOMP RIH wI BHA on DP to Top of 7" x 5-1/2" XO at 9491'. 12:30 - 14:00 1.50 CLEAN P DECOMP Initial Parameters: Up Wt = 195,000 Ibs, Down Wt = 132,000 Ibs. Rot Wt = 157,000 Ibs. 40 rpms at 7,500 ft-Ibs torque. Pump Pressure 5.0 bpm at 770 psi. Wash Down to Top of X Nipple. Tag Up initally at 9591' on junk. Work Down Hole. Washing and Reaming Fill and Junk down to 9602'. Pump Pressure rising, Basket getting full. Decide to POOH. 14:00 - 17:00 3.00 CLEAN P DECOMP POOH wI DP and Stand Back in Derrick. 17:00 - 18:30 1.50 CLEAN P DECOMP Stand Back DC's and 2-7/8" Pack DP. BIO Boot Baskets and Reverse Jet Basket. Reverse Jet Basket Failure. Jet Nozzle Unseated But Was Recovered. 18:30 - 19:30 1.00 CLEAN P DECOMP Service Rig, Top Drive, Iron Rough Neck, and Draworks. 19:30 - 21 :00 1.50 CLEAN P DECOMP Waiting On Baker, Repairing Reverse Jet Basket In Dead Horse. 21 :00 - 22:00 1.00 CLEAN P DECOMP M/U 4-518" Reverse Basket BHA; 4-5/8" Reverse Jet Basket wI 4-3/4" Head, 6 Joints of 2-7/8" PAC, 24-3/4" Boot Baskets, Bumper Sub, Fishing Jars, 9 4-3/4" DC's. Total Length = 510.78' 22:00 - 00:00 2.00 CLEAN P DECOMP RIH to 7,231'. 6/24/2006 00:00 - 02:00 2.00 CLEAN P DECOMP Continue to RIH f/7,231' to 9,439', CBU at 6.5 bpm and 2500 psi, Obtain Drilling Parameters: Down Weight=133,000#, Up Weight=195,000#, Rotating Weight=157,000#, 20 rpms with 8,000 ft-Ibs Torque, 40 rpms with 9,500 ft-Ibs Torque, Pump Rate 5 bpm with 1,170 psi. 02:00 - 03:30 1 .50 CLEAN P DECOMP Dropped 9/16" Steel Ball, Pumped Down at 5 bpm. Ball On Seat Pressure Increased to 2,020 psi. Rotated Down to 9,601', Worked Pipe From 9,535' to 9,604' Three Time Without Rotation, Rotated and Worked Pipe 2 More times. 03:30 - 04:00 0.50 CLEAN P DECOMP POOH f/9,604' to 9,152'. 04:00 - 05:00 1.00 CLEAN P DECOMP Cut and Slip Drillling Line. 05:00 - 08:30 3.50 CLEAN P DECOMP POOH f/9, 152' to BHA. Stand Back DP and Collars 08:30 - 10:00 1.50 CLEAN P DECOMP BIO 4-5/8" Reverse Jet Basket and Boot Baskets. Collected -1 gallon of fines from Boot Baskets. Jet Basket empty. UD 4-5/8" Reverse Jet Basket and P/U 3-518" Reverse Jet Basket, 6 Joints of 2-7/8" PAC DP, 2 Boot Baskets, Bumper Sub and Jars, 94-3/4" DC's. Total Length = 503.1' 10:00 - 12:30 2.50 CLEAN P DECOMP RIH wI 3-5/8" Reverse Jet Basket BHA. 12:30 - 13:30 1.00 CLEAN P DECOMP Service Rig 13:30 - 15:00 1.50 CLEAN P DECOMP Continue to RIH wI Reverse Jet Basket BHA. 15:00 - 17:30 2.50 CLEAN P DECOMP Take Initial parameters. Up Wt = 202,000 Ibs, Dw Wt = 130,000 Ibs, Rot Wt = 162,000 Ibs. 20 rpms and 7000 ft-Ibs torque. 40 rpms and 7500 ft-Ibs torque. Pump rate 6.0 bpm at 2560 psi. Wash Down Through X Nipple at 9604' to 9630'. Pump 40 bbl High Visc Sweep and Pick Up to above X-Nipple. Printed: 7/5/2006 10:09:22 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-25A D-25A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/6/2006 Rig Release: 6/26/2006 Rig Number: Spud Date: End: 6/26/2006 6/24/2006 15:00 - 17:30 2.50 CLEAN P DECOMP Drop Ball for Reverse Basket and Wash and Ream Down and Tag Liner Top Deployment Sleeve at 9633'. Large Torque Jump at 9633'. Shut Down Pump and Rotary, Dry Tag TOL at 9633' Three Times and Confirm. 17:30 - 00:00 6.50 CLEAN P DECOMP POOH and UD DP. 6/25/2006 00:00 - 03:30 3.50 CLEAN P DECOMP POOH. UD 4" DP and BHA. Recovered a very small amount of fine debris from Boot Baskets and 3 pieces of aluminium from Reverse Basket. 03:30 - 04:00 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 04:00 - 06:00 2.00 RUNCO RUNCMP Pull Wear Ring. Rig Up Torque Turn, PowerTonges, Compensator. 06:00 - 19:00 13.00 RUNCO RUNCMP PJSM on Running Tubing. P/U and RIH with 220 joints 4-1/2", 12.6#, 13Cr80 Vam Top Tubing, 3 - 4.5" x 1" 9 Cr KBG GLM, 1 - 4.5" x 1.5" 9Cr MMG GLM, 3- 4.5" X Nipples ID = 3.813",1- 7"x4.5" Baker S-3 9Cr Packer. All Connections below Packer M/U with Baker- Loc, Torque Turn all Connections to 4440 ft-Ibs, Jet Seal Lube Guard Pipe Dope. 19:00 - 20:30 RUNCMP Picked Up Jt #221 MIU Jt #222 and Tagged Up Mule Shoe Collar On 5.5" XO at 9,491'. UD Jt # 222, #221 and #220, Picked Up 32' of Pup Jts MIU Jt #220 and 13 5/8"x 7" Hanger, M/U Landing Joint, Landed Out Hanger. Tubing Mule Shoe at 9,534'. 20:30 - 21 :30 1.00 RUNCMP RILDS, RlU to Circulating Equipment. Test Lines to 3,500 psi. 21 :30 - 00:00 2.50 RUNCMP Reverse Circulate 145 bbls of 140 deg Seawater and 315 bbls of Corrosion Inhibited Seawater at 3 bpm with 220 psi. 6/26/2006 00:00 - 00:30 0.50 RUNCMP Continue Pumping Corrosion Inhibited Sea Water at 3 bpm with 200 psi. 00:30 - 01 :00 0.50 RUNCMP RID Circulating Equipment, Drop Ball and Rod, MIU Circulating Equipment. 01 :00 - 01 :30 0.50 RUNCMP Waiting for Ball and Rod to Seat in RHC. 01 :30 - 02:00 0.50 RUNCMP Pressure Up to 2,500 psi to Set Packer Continue To Pressure Up to 3,500 psi to Test Tubing. Failed Test. 02:00 - 02:30 0.50 RUNCMP RID Landing Jt and 7" TCII XO, RlU to Test Tubing Under Blind Rams. 02:30 - 03:30 1.00 RUNCMP Pressured Up to 3,500 psi on Tubing and Held for 30 minutes, Good Test. Bled Pressure Down to 2,000 psi. RlU to Test Annulus Side. 03:30 - 04:00 0.50 RUNCMP Pressured Up to 3,500 psi on Annulus Side and Held for 30 minutes, Good Test 04:00 - 04:30 0.50 RUNCMP Bled Down Pressure on Tubing to 0 psi, Sheared DCR . Lined Up and Pumped Down Tubing at 2 bpm and 100 psi, Lined Up and Pumped Down Annulus Side at 2 bpm and 80 psi. 04:30 - 05:00 0.50 WHSUR P RUNCMP Set TWC and Tested to 1,000 psi for 5 minutes, RID Lines. 05:00 - 06:30 1.50 BOPSU P RUNCMP PJSM With Rig Crews and Cameron Hands. N I D BOP's. 06:30 - 08:00 1.50 WHSUR P RUNCMP N/U Mc Evoy DX 2 MS 13-5/8 x 7-1116" 5K Adapter Flange. N/U 7-1/16" x 6-3/8" 5K Carbon Tree. 08:00 - 10:00 2.00 WHSUR P RUNCMP Test Neck Seal and Void to 5000 psi for 30mins· Good Test. RlU to Test Tree. Test Tree to 5000 psi for 30 mins -Good Test. Tree Test Charted. 10:00 - 10:30 0.50 WHSUR P RUNCMP P/U DSM Lubricator and Pull TWC. UD Lubricator. 10:30 - 12:00 1.50 WHSUR P RUNCMP PJSM with Crews and LRS. PT Lines. Pump 150 bbls of Diesel Down 4-1/2" x 9-5/8" annulus, 3 bpm at 500 psi 12:00 - 13:00 1.00 WHSUR P RUNCMP U-Tube Freeze Protect. Printed: 7/512006 10:09:22 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-25A D-25A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/6/2006 Rig Release: 6/26/2006 Rig Number: Spud Date: End: 6/26/2006 6/26/2006 13:00 - 14:00 1.00 WHSUR P RUNCMP BID and RID Lines. Set BPV. Test BPV wI 1000 psi from below wI LRS. WHDTRE Secure Well, Install Gauges and Prep Rig For Move. Release Rig at 14:30 hrs 6/26/2006. 14:00 - 14:30 0.50 WHSUR P Printed' 7/5/2006 10:09:22 AM Scblumbel'gel' NO. 3868 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503·2838 A TTN: Beth [)t;O-ÕJ1 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 'oj ., f' '\,;:C' f1,.¡..jí'\\FÜ ":;;.¡!"V;i"'<! ...",....~<^ Field: Prudhoe Bay WI! J b# D CI CD L BL e 0 og DescriptIon ate o or 01-17B 11209602 MCNL 04/27/06 1 1 D-25A 11;':1 r;'tI'" usn 06/13/06 1 D-25A 11212869 USIT 06/18/06 1 D.S.04-31 11243929 SCMT 06/14/06 1 L5-28 11212867 USIT 06/15/06 1 2-18/L-16 11212871 SCMT 06/20/06 1 L5-28 11212872 SCMT 06/25/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 06/26/06 e e e -roo .- 0(9'-{ í.·..-n. "'. '1. ;.;;1,/' .' r. .\ \ ':.:¡-::J, j..... .'.'.'. 'r' \""J .' /. I: \:1 ¡ : ",'" ! ; i. '\ ";;;;1 j \ ,I '. 'I!.J. ,', " ¡-.,,~ .1' ¡ ;-'\'J ¡,I \:~/ ,1J i.J \J :]: ~"'~ "..--, .-, J .n ), '1 ,._" i.! 11 I .Ii ;1 .,1 ;::1 ,11' -I :It 'I, J ]1 \~j ih.:! C\ rj' j-\ i~\ .n 17t-\ /"\' '.' ,,\ \ \ .' \1..; "i ;' .1' , .1\ >; In \ \,' 'I', ¡. j\ ,fLJ\IJ di\' "', 1\ì ¡d\ f, 't "I f "~' :i", "1 'I :j:., \ : "~ . '.\ !f1: \¡....., ! /"1; 11... .' ! j. ,,'\ ' 'I'ì. "j ""'"' '"",¡ ,,--.,~ :""".J '._,", ~ '..' 't-1 ,"...J __ FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVAnONCO~SSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Doug Cismoski Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU D-25A Sundry Number: 306-215 Dear Mr. Cismoski: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this /þ day of June, 2006 Encl. f)tJ:J '- (J';)q Ð-rS &>I/c,/k. ~p~ 6//t>/òh CP}!) {II RECE,~~öot>~ I~ I STATE OF ALASKA · 'f\\i . \ ~~ ALASKA L AND GAS CONSERVATION C01!t1ISSION . JUN 1 5 2006 \~ \t\ APPLICATION FOR SUNDRY APPR0'l~hi' & Gas Cons. Commission \J' 20 AAC 25.280 Anchorage 1. Type of Request: 0 Abandon 181 Repair Well o Plug Perforations o Stimulate o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension o Re-Enter Suspended W 2. Operator Name: 4. Well Class Before Work: /' 5. Permit To Drill Number BP Exploration (Alaska) Inc. 1'81 Development 0 Exploratory 200-024 ,/' 3. Address: o Stratigraphic o Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21522-01-00 7. KB Elevation (ft): 71.74' 9. Well Name and Number: PBU D-25A / 8. Property Designation: 10. Field / Pool(s): ADL 028285 Prudhoe Bay Field / Prudhoe Bay Pool 11;·.! ) ... .. XiX'..))!! ·····..X ·.·i.··.·i !i .. '·.X.iJJJ·J.iJ.')))iiX, iX);X)i)) > Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): I Effective Depth TVD (ft) Plugs (measured): Junk (measured): 11750 9028 11687 / 9028 None None Casing Lenath Size MD ./ TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2715' 13-3/8" 2715' 2690' 4930 2670 Intermediate 10032' 9-5/8" 10032' 8417' 6870 4760 Production Liner 848' 7" 9769' - 10617' 8195' - 8897' 8160 7020 Liner 2117' 2-7/8" 9633' - 11750' 8082' - 9028' 13450 13890 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 11360' - 11670' ../ 9020' - 9028' 5-1/2", 17# / L-80 9682' Packers and SSSV Type: 9-5/8" x 5-1/2" TIW packer packers and SSSV MD (ft): 9549' / 12. Attachments: 13. Well Class after proposed work: 7 1'81 Description Summary of Proposal 0 BOP Sketch o Exploratory 1'81 Development o Service o Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: In ProgresV\ 1'81 Oil o Gas o Plugged o Abandoned 16. Verbal Approval: Date: ~006 o WAG OGINJ OWINJ o WDSPL Commission Representative: Winton A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Doug Cismoski, 564-4303 Printed Name Doug Cismoski Title Drilling Engineer Siç¡nature ¡-::;/~ ¿., /J~ L. / I._I",; Prepared By Name/Number: Phone 564-4303 Date Terrie Hubble, 564-4628 ¿/ Commission Use Only , Conditions of approval: Notify Commission so that a representative may witness I Sundry Number:,W/J -el15 o Plug Integrity @BOP Test o Mechanical Integrity Test o Location Clearance T-t~+- 8,0 r E to ~~oo ft.\.· Other: RBDMS BFl jUN 2 0 Zo06 Subsequent Form Required: to - rìJ Æ~ APPROVED BY ~./'-ð6 Approved By: T'" "/ / ,If ..ÇOMMISSIONER THE COMMISSION Date Form 1Q-4Q3 Revised 07/2005 ...,~( tþ/[ ,........ Submit In Duplicate " , , . . . D-25A Rig Workover / Original Scope of Work: Pull the 5-1/2" completion, changeout the 9-5/8" packoffs, and run a 4-1/2" chrome completion. 9-5/8" Production casing failed a pressure test below 7000' while the workover is in progress. The rig has /' pulled the 5-1/2" completion and changed out the 9-5/8" packoffs. Revised Scope of Work: Run 7" scab liner from top of 5-1/2" tubing stub (-9509') to 4000', fully *~ cemented. Run 4-1/2" chrome completion. MASP: (2~psi Well Tyþe: Producer Estimated Start Date: Workover In-Progress Pre-Ri o 1 F 2 S 3 E 4 F 5 o 6 o 7 Work: Check tubing and casing-hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage. PPPOT - T & IC. Well has passing MIT-OA 2000 si 05/14/2005. Well has confirmed TxlA communication. CMIT- TxlA to 3500 si. FAILED - Win valve leakin b. Pull 5-W' XX TTP from tubing @ 9604 MD, Drift tubing for FASDRILL plug and chemical cutter down to TOL 9633'. DONE 6/4/2006 Set 2-7/8" Fas Drill plug at -9663' MD (approx. 30' below top of 2-7/8" liner). MIT-TxIA to 1000 psi. Run string shot and tbg punch for chemical cut. Done. Chemical cut 5-W' tubing in middle of first joint (-9505' MD) above production packer to be done on the rig. Reference tubing tally dated 01/18/86. DONE 614/2006 Circulate well bore with clean seawater through chemical cut. Freeze-protect w/diesel to 2200'. Bleed WHPs to 0 psi. DONE 6/6/2006, CMIT TxlA Failed. LLR <1/4 bpm @ 1500 psi. Suspected 2-7/8" liner la . Set a BPV in the tubin han er. Remove well house & flow line. Level the ad as needed for the ri . Proposed Procedure /' 1. MIRU. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 5-W' tubing string to the cut. 3. RIH wI RBP to tubing stub @ 9509', pressure test 9-5/8" casing " 4. Replace 9-5/8" packoff. / 5. RIH wi 7" scab liner~r top of tubing stub to 4000' 6. Cement 7" liner wI 170 bbls of Class G cement wI Schlumberger "GasBlok" 7. Drill out shoe track, rse circulate down to the top of the 2-7/8" liner. / 8. Run 4-W' 13Cr80 stacker packer completion with 7" x 4-1/2" Baker S-3 packer at 9425' MD. 9, Displace the IA to packer fluid and set the packer. 10. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 11. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = WELLHEA{).= ACTUATOR = KB, ELEV = BF, ELEV = KOP= Max Angle = Datum MD = Datum ND = 6" MCEVOY MCEVOY OTIS 71.74' 42,89' 2161' 94 @ 11638' 10584' 8800' SS . D-25A s~ NOTES: HORIZONTAL WELL. 70° @ 1 oW AND 90° @ 10924' . 2166' -15-1/2" OTIS SSSV LAND NIP, ID = 4,562" I 113.3/8" CSG, 72#, L·80, ID = 12,347" I PORT DATE 16 03/30/00 20 03/30/00 Minimum ID = 2.37" @ 9633' TOP OF 2·7/8" LINER 1 TOP OF 2-7/8" LNR I 9633' 15-1/2" TBG, 17#, L80, ,0232 bpf, ID=4,892 I 9682' TOPOF7" LNR I 9762' 19.5/8" CSG, 47#, L-80, ID = 8.681" I 10032' ÆRFORA TION SUMMARY REF LOG: Sperry Sun MWD/GR ON 03/20/00 ANGLEATTOPÆRF: 86 @ 11360' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 11360 - 11521 C 03/23/00 2" 4 11550 - 11600 C 03/23/00 2" 4 11628 - 11670 C 03/23/00 10614' I CEMENTED WHIPSTOCK PBTD I 10927' 17" LNR, 29#, L-80, ,0371 bpf, ID = 6,184" I 10970' DATE 01/18/86 03/22/00 01/10/02 09/24/05 06/04/06 06/05/06 REV BY COMMENTS ORIGINAL COMPLETION CJS SIDETRACK COM PLETION RNlTP CORRECTIONS MORlTLH XX TIP SET (04/07/05) RRD/PAG SET 2-7/8" HES PLUG @ 9657' JCMlPAG PULLED XX TIP@ 9604' DATE I I GAS LIFT MANDRELS ST MD NO DEV TYÆ VLV LATCH 5 3259 3093 34 OTIS·LBD DOME RA 4 5856 5145 44 OTIS-LBD SO RA 3 7796 6540 39 OTIS-LBD RA 2 8962 7471 38 OTIS-LBD RA 1 9401 7820 36 OTIS-LBD RA 9473' -15-1/2" OTIS XA SLIDING SLY, 10 = 4,562" 9534' 9549' -19-5/8"X5-1/2"TIWPKRID=4,75" I 9604' -i 5-1/2" OTIS X NIP, 10 = 4,562" I 9633' -12,7/8" LNR G5 DEPLOYMENT SUB 9643' -15-1/2" OTIS XN NIP, ID = 4.455" (BB-IIND PIPE) -12-7/8" HES FASDRILL PLUG (06/04/06) I -15-1/2" TIW TBG TAIL (BB-IIND PIPE) H ELMO TT LOGGED 01/29/86 I MILLOUT WINDOW 10617' -10623' 12-7/8" LNR, 6,16#, L-80, ,0058 bpf, 10 = 2,37" I REV BY COMMENTS PRUDHOE BAY UNIT WELL: D-25A ÆRMIT No: "2000240 API No: 50-029-21522-01 SEe 23, T11 N, R13E BP Exploration (Alaska) TREE = 6" MCEVOY D-2S.Proposed ComplA>n W8... LHIfI. ìJ'= MCEVOY Rev 1 ACTUATOR = OTIS KB, ELEV = 71,74' BF. ELEV = 42,89' KOP= 2161' I -2100 1-14-1/2" HES X NIP, ID = 3,813" I Max Angle = 94 @ 11638' I Datum MD = 10584' Datum TVD = 8800' SS 113-3/8" CSG, 72#, L-80,ID= 12.347" I 2715' r---4 ~ GAS LIFT ~NDRELS - ST MD TVD DEV TYÆ VLV LATCH PORT DATE U 4 TOP OF 7" SCAB LINER I -4000 3 2 PLANNED TOP OF CEMENT I -4000 1 I I r---i 1-14-1/2" HES X NIP, ID = 3.813" I 8 ~ f--I -9425 1-17" X 4-1/2" BAKER S-3 PKR, ID- I I 1-14-1/2" HES X NIP, ID = 3.813" I 14-1/2" TBG, 12,6#, 13CR80 I J "\ 1-1 UNIQUE ~CHINE OVERSHOT I ( I 7" CSG, 26#, L-80, ID = 6.276" H -9509 I I 9534' I-lTBG SEAL ASSY I 9549' H9-5/8" X 5-1/2" TIW PKR, ID = 4,75" I . I 9604' 1-1 5-1/2" OTIS X NIP, ID - 4,562" I TOP OF 2-7/8" LNR I 9633' I 9633' H2-7/8" LNRG5 DEPlOYMENT SUB I - . II 9643' 1-15-1/2" OTIS XN NIP, ID - 4.455" (BEHIND PIPE) I 15-1/2" TBG, 17#, L80, .0232 bpf, 10=4,892 I 9682' t:-r---r j 9682' 1-15-1/2" TIW TBG TAIL (BEHIND PIPE) I 1 TOP OF 7" LNR I 9762' I I II I 9685' H ELMD TT LOGGED 01/29/86 I 19-5/8" CSG, 47#, L-80, ID = 8.681" I 10032' ... ~ ÆRFORA TION SUM~RY REF LOG: Sperry Sun MWD/GR ON 03/20/00 MILLOur WINDOW 10617' -10623' ANGLEAT TOP ÆRF: 86 @ 11360' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2" 4 11360 - 11521 C 03/23/00 / ~ 2" 4 11550-11600 C 03/23/00 2" 4 11628 - 11670 C 03/23/00 I PBID H 11687' I I 10614' I CEMENTED WHIPSTOCK r / 1 PBID I 10927' I ~ ~ 17" LNR, 29#, L-80, ,0371 bpf, ID = 6.184" I 10970' I / 12-7/8" LNR, 6,16#, L·80, ,0058 bpf, ID = 2.37" I 11750' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/18/86 ORIGINAL COM PLETION WELL: D-25A 03122100 CJS SIDETRACK COM PLETION ÆRMIT No: "2000240 01/10/02 RNlTP CORRECTIONS API No: 50-029-21522-01 09/24/05 MORITLH XX TTP SET (04/07/05) SEC23, T11N, R13E 06/04/06 RRD/PAG SET 2-7/8" HES PLUG @ 9657' 06/05/06 JCMlPA G PULLED XX TTP @ 9604' BP Exploration (Alaska) D-25A (PTD #2000240) Classified as Problem Well ) ~:Uþj.~C:t;.,~,·tf~..~.··.·.(?W<~···#2~()Of.4(»··.·.~.~~~~i·fiê4·.·.é:\s·..I'tq~l~Ít1·.··~ëll·········· '~~~:·'.'~~~~f~,~~~P~'f~4~~s#~~~~.~9m~········ '.' . " J])~~~: ·.1?htg·~tJMtät4ØQ5:l:0:5Qfl~~QQQº:. ) · .....". :......... ". . ;. .... .... ....:. . .".." . ........... ......::.:.:.: "':., -;-:": .... ::::" "'.:. .; : ....... '.' . .: ".'.'.... "::... .' ":' " '.' ;....:.:...:.:: :.. .: :. .' -:. . : ~.. .".. -: :: :..... · . . .... .." . '". ........ .'.. ".' · ," "." ........ ..... .. .:..... . . ::".:: ".":: .....:.:,...:....: . ...... ... . . All, Well D-25A (PTD #2000240) has sustained casing pressure on the IA and is classified as a Problem well. TIO's on 03/30/05 were 2320/2290NAC. The plan forward for this well is as follows: 1. SL: Run DGLV's, caliper tubing 2. DHD: Re-TIFL Attached is a well bore schematic. Please call if you have any questions. «D-25A.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.eom SCANNED I\PH !~l ?OO\l Content-Description: D-25A.pdf Content-Type: application/octet-stream Content-Encoding: base64 /\A.1"( f . sCf .¿ 4 ~,LiJy -çbl:" ..,'\ ò~ 6<370 r; 53S0f5 j ¿¿(to < )->1 1es ( 3;iv' I J..-A- V:tre-.- Jßf- A \1 1 os- 1 of 1 4/1/2005 8:14 AM .. - ') 6" MCEVOY MCEVOY ···············ö'f"is 71.74' ...................... ............. . 42.89' ........... "'21"(31' ....~~,,~1~.§.~.~.'. 10584' 8800' SS TREE = W8..LHEAD = "ACiUÄ'r'ÖR; KB. ELEV = ï3ï=. ELEv' = köÞ';" ,.~ax".~ng ~.~ Datum MD = Datu m ND = D-25A (I) 113-3/8" CSG, 72#, L-80, 10 = 12.347" 1---1 2715' ~ L Minimum 10 = 2.37" @ 9633' TOP OF 2-7/8" LINER I I i :8: i :8: I ITOP OF 2-7/8" LNR 1-1 9633' 1 5-1/2" TBG, 17#, L80, .0232 bpf, 10=4.892 1-1 9682' 1 1 TOP OF 7" LNR 1-1 9762' I I ~ 19-5/8" CSG, 47#, L-80, 10= 8.681" Ii 10032' ~ ÆRFORA TON SUMVlARY RB= LOG: Sperry Sun IVWD'GR ON 03/20/00 ANGLE AT TOP PERF: 86 @ 11360' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA.TE 2" 4 11360' -11521' 0 03/23/00 2" 4 11550' -11600' 0 03/23/00 2" 4 11628' -11670' 0 03/23/00 1 10614' l-i CErIlENTED WHIPSTOCK I ÆllD 1--1 10927' M,.. 17" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" 1--1 10970' ) SAÆTYNOTES: HORIZONTAL WB.L. 70° @ 10794' AND 90° @ 10924' 2166' 1-15-1/2" OTIS SSSV LAND NIP, 10 =4.562" I ~ GAS LIFT MANDRELS ST MD lVD DEV TYPE VLV LATCH PORT DA.TE 5 3259 3093 34 OTIS-LBO RA 4 5856 5145 44 OTIS-LBO RA 3 7796 6540 39 OTIS-LBO RA 2 8962 7471 38 OTIS-LBO RA 1 9401 7820 36 OTIS-LBO RA 9473' 1-15-1/2" OTIS XA SLDING SLV, 10 = 4.562" 9534' I-1TBG SEAL ASSY I 9549' 1-19-5/8" X5-1/2"TIWPKR, 10=4.75" 9604' 1-15-1/2" OTIS X NIP, 0 =4.562" I 9633' 1-12-7/8" LNR G5 DEA..OYMENT SUB 9643' 1-15-1/2" OTISXN NIP, 10= 4.455" 1 9682' 1---15-1/2" llWTBGTAIL 1 9685' 1-1 B..MDTT LOGGED 01/29/86 MILLOUTWlNDOW 10617' -10623' 1 2-7/8" LNR, 6.16#, L-80, .0058 bpf, 10 = 2.37" H 11750' 1 DATE REV BY OOMVI8\lTS [)d. TE RBI BY eOMIVENTS ffiUDHOE SA Y UNIT 01/18/86 ORIGINAL OOI'vPLETION W8..L: D-25A 03/22/00 CJS SIDErRA CK COfII1A..ETION PERv1IT No: 200-0240 02/08/01 SIS-SLT OONVERTSJ TO CANVAS API No: 50-029-21522-01 03/08/01 SIS-MD RNAL SEC23, T11N, R13E 01/10/02 RNlTP OORRECTIONS BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well /f~" /7c C-29A /J7·· 13j E-25 ¡qð"ð2:J G-02A 1.fjf/It,f£f W-27 A '~e-D%* D-25A r'---- /qq·Ol;v OS 15-25A' . '" 2Pf..Ø"'E-39A "\ 02-16B I C¡tj~ () (I C-25A :ì.oL{4J..Di E-17 A J.Üi/.. i<Ó~ C-41A j ~~¡~~ ~~~;~~ ':f../.;J.{.i(;1 02-28A !1j·-{t¡,3 -D-11A 2{JI-i¡c¡) DS 05-24A Job # 10715422 10715423 10715424 10670031 10854314 10715428 10715430 10928597 10928598 10928602 10928606 10715445 10715446 10928607 10928608 10928609 (Prints--. only-Job not complete) SCANNED JUN 1 7 2005 Log Description MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ¡;Zhloj / ./; ~ðV ~ r9 ~cf 01/24/05 NO. 3318 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ~/ Color Date Blueline Prints CD 08/20/04 1 08/21/04 1 08/23/04 1 08/24/04 1 08/27/04 1 09/11/04 1 09/13/04 1 10/02/04 1 10/03/04 1 10/30/04 1 11/24/04 1 12/09/04 1 12/11/04 1 12/11/04 1 12/16/04 1 12/22/04 1 '- Alaska Data & Consulting Services 2525 Gambell Street. S::OO Î ~~hr:~rag:. AK09950}-~38 ...1 '~/ t / \ / 1/ /'/ Rece v.~d by: . I;.v /1' < {/' . - / 'v / / (// V MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to DrilINo. 2000240 DATA SUBMITTAL COMPLIANCE REPORT 3/21/2002 Well Name/No. PRUDHOE BAY UNIT D-25A Operator BP EXPLORATION (ALASKA) INC AP1 No. 50-029-21522-01-00 MD 11750 TVD 9028 Completion Date 3/23/2000 ~ Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey No -- __ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name Interval Log Log Run OH / Scale Media No Start Stop CH (data taken from Logs Portion of Master Well Data Maint) Dataset Received Number Comments D R pt Ver R tED D Ver SRVY LSTNG SRVY RPT 45 11750 OH 1 10537 11719 Ope 45 11750 OH I 10537 11719 Ope 4/21/2000 BHI 10510.. 1/11/2002 4/21/2000 SPERRY 10510.. 1/11/2002 10531 Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y ~) Chips Received? .o~:~&N ~ Analysis Received? Daily History Received? ~ N Formation Tops Receuived? Comments: Compliance Reviewed By: To: RE: WELL LOG TRANSMI-I-I-AL State of Alas ka Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 21,2002 MWD Formation Evaluation Logs · D-25A, AK-MW-90268 D-25A: 2"x 5" MD Gamma Ray Logs · 50-029-21 522-01 2" x 5" TVD Gamma Ray Logs · 50-029-21 522-01 1 Blueline 1 Blueline PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF TRANSMI-I-I-AL LE-I-I-ER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn' Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 9951 8 BP Exploration (Alaska)Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 THE RECEIVED Date' Sig ned WELL LOG TRANSMITFAL To: January 08, 2002 State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7m Avenue, Suite 100 Anchorage, Alaska · - - ' ~' s D-25A, AK-MW-90268 1 LDWG formatted Disc with verification listing. APl#: 50-029-21522-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atto: Jan Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Signed:~ RECEIVED J: ,hl 1i 2OO2 Alaska O~l & Gas Cons, Commission ~orage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, ~i Commissioner,.-.,,.^~ .,.~.9~ Tom Maunder, ! P. I. Supervisor ~1'-~'-~ DATE: April 20, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit D Pad Friday, A~)ri! 20. 2001: ! traveled to BPXs D Pad and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 20 wells and 40 components with 1 failure. The surface safety valve on well D-06 had a slow leak when pressure tested. This valve was serviced and the retest witn~sed On this date. Merv Liddiow performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and ali equipment appeared to be in fair conditions. Summary;. I witnesSed the semi annual SVS testing at BPXs D-Pad. PBU D Pad, 20 wells, 40 components, 1 failure 2.5% failure rate 25 wellhouse inspections Attachment: SVS PBU D Pad 4-20-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS PBU D Pad 4-20-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: Prudhoe/PBU / D Pad Separator psi: LPS 154 Date: 4/19 & 4/20 HPS 660 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI T,rip Code Code Code Passed GAS or CYCLE D-01A 1970780 154 ' 125 125 P P ' ' oil D-03A 2001340 154 125 125 P P OIL D-04A 1871250 D~05 "1700060 660 550 450 P ' P ' '0IL D-06A 1970430 660 550 600 P 4 OIL D'-07A 1931570 '660 550 525 P P ' 4/20/0'1 oIL D-08 1790360 D-09A 1990850 ~60 550 525 P P ' OIL D-10 1790530 660 5~0 525 P P ' OiL D-11A 1951830 660 550 525 P P OIL D-12 1800150 660 550 . 530 'P P 0IL D-13A 2000810 D-14A' 1961530 ......... , D-15A 1972120 D-16 1811710 660 550 '500 '' P P OIL D-17A 1960460 ' D-18 '1811880 D-20 ' 1820440 154 125 120 P P ' OIL D-21 1820520 154 125 125 P P oIL D-22A 1972040 D-23A 1961880 660 550i 525 P P ' " oiL D-24 1852990 D-25A 2000240 154 125i 100 P P ' OIL D-26A 1970870 660 550i '525 P " P OIL D-27 1860330~ 660 550i 550 P P OIL D-28A 1952130 660 550 550 P P OIL D-29 1852530 154 125 110 P P OIL D-30 1960260 D-3iA 1960950! 660 550 550 P P " OIL D-33 '1960360 660 550 550 ' P P OIL RJF 1/16/01 Page 1 of 2 SVS PBU D Pad 4-20-01 CS Well Permit ! SePar Set Number Number ! PSI PSI Wells: ~: . 20 Components: I . I ~ _ I I II I II I I III I L/P Test I~est I~t I Date Trip Code I C°del C°del Passed 40 Failures: 1 Failure Rate: Oil, WAG, GINJ, GAS or CYCLE 2.50% ~ 90 Day Remarks: The surface safety vane on well D-6 had slow leak when pressure tested. Valve was serviced and retested same day .............................. RJF 1/16/01 Page 2 of 2 SVS PBU D Pad 4-20-01 CS STATE OF ALASKA ALASKA _ ,_ AND GAS CONSERVATION COMM,,.,~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 200-024 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21522-01 4. Location of well at surface ~ ~:;":~'~' '!' ? :':.i . 9. Unit or Lease Name 1746'SNL, 1068'WEL, SEC. 23, T11N, R13E, UM ~~i ! ¥~ P rudhoeBayUnit At top of pr°ductive interval i ~~ i. i'i~.~ 3284' NSL, 105' WEL, SEC. 14, T11N, R13E, UM 10. Well Number At total depth .... . ,~,.~,~,~.~.,~.' D-25A 4012' NSL, 724' WEL, SEC. 14, T11N, R13E, UM .................. L:: 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 71.74' ADL 028285 ate pud e ,l , 000 I I 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set121. Thickness of Permafrost 11750 9028 ETI. 11687 9028 ETI. []Yes [] NoI (Nipple) 2166' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run GR, MWD 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" x 30" Insulated Conductor Surface 110' 36" 8 cu )/ds Concrete 13-3/8" 72# L-80 Surface 2715' 17-1/2" 3755 cu ft Permafrost 9-5/8" 47# L-80 Surface 10032' 12-1/4" 2150 cu ft Class 'G' 7" 29# L-80 9769' 10617' 8-1/2" 342 cu ft Class 'G' 2-7/8" 6.16# L-80 9633' 11750' 3-3/4" 87 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 5-1/2", 17#, L-80 9682' 9549' MD TVD MD TVD 11360' - 11521' 9020' - 9025' 11550' - 11600' 9027'- 9030' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 11628' - 11670' 9030' - 9028' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with 40 bbls MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 0 [ olNAL March 31,2000 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MOF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing ~Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED APR 2 1 2.000 Form 10-407 Rev. 07-01-80 Gas Cons. Commission Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. 25N 10556' 8849' 26P 10564' RECEIVED 24N / 24P 10606' 8889' APR 2 1 2000 23N / 23P 10634' 8910' Alaska 0il & Gas Cons. Commission 22N 10658' 8927' Anchorage 22P 10672' 8936' 21N 10720' 8962' 21 P 10740' 8972' 31, List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is tr.u~ and correct~ to the best of my knowledge ~ Signed TerrieHubble ./~~ Title TechnicalAssistantlll Date 0~'~''' "(~) D-25A 200-024 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM ,5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28.' If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 APR 2 1 2000 Well: D-25A Accept: 03/17/00 Field: Prudhoe Bay -~$ita ui~ ~ ~as Cons. Commission Spud: 03/19/00 A PI: 50-029-21522-01 Anchorage Release: 03/22/00 Permit: 200-024 CTD Unit: Nordic #1 03/18/00 1 10617' Finish move DS/N #1 from N-08ai to D Pad. Standby for well house removal. Move rig over D-25. Accept for operations at 1700 hrs 3/17/00. NU BOPE. General RU. Attempt BOP test and swab leaked. Grease swab and master. Fill CT with SW. Open well to 1200 psi. HB&R liquid pack well with 600 bbls SW. Service swab and wing. Resume BOP test. Wing leaking LDF gas thru leaking swab. WO Pad operator to depressure FL. 03/19/00 2 10618' Wait on Pad operator to bleed down flowline. Heat and grease lock all valves in tree. De-pressure again and grease block valve in skid. Perform initial BOPE pressure / function test. Fax test report to AOGCC. Bleed off 350 psi WHP. M/U Cementing BHA #1. RIH with BHA #1 to whipstock pumping 1.5 bpm with no returns. DS cementers Icad CT with 31 bbls 13.8 ppg Class G cement with bentonite and 20#/bbl Perfect Seal. Displace to perfs and leave in 7" liner. Apply 500 psi pressure for 30 min. Jet out cement to 20' above whipstock. POOH jetting excess cement to surface. LD cementing BHA. MU milling BHA. RIH with 3.80" diamond window mill with 3.80" string reamer. Drill 20' of cement above whipstock. Mill window from first casing contact at 10617'. 03~20~00 3 10910' Continue milling window. Milled 3.80" window in 7" Liner from 10,617 - 10,623 ft. Circulated well to reconditioned FIoPro while milling. Drilled formation to 10,627 ft. Reamed window area several times. Clean window. Shot inner annulus fluid level at 60 ft. POOH with milling BHA. L/O Baker milling BHA. M/U DS CTC. M/U MWD BHA #3, with M-09 Bit #1 and 1.75 degree short radius motor. RIH with BHA #3. Tie-in to BHCS. Drill from 10627-10910' building angle to 90° at 8940' TVD. POOH for horizontal BHA. Change bit and motor. RIH with BHA #4 (1.4° motor). 03/21/00 4 11750' RIH with Horizontal Drilling BHA #4. Correct CTD to Flag at 10594 ft. [-16 ft]. RIH to TD. Drilled horizontal hole from 10,910 - 11,047 ft. Short trip to window. RIH and orient to right. Drilled horizontal hole from 11,047 - 11,189 ft. Short trip to window, clean hole. RIH and drilled horizontal hole from 11,189 - 11,340 ft. Short trip to window, clean hole. RIH and drilled horizontal at 88° from 11,340 - 11,500 ft. while swapping to new mud. Short trip to window, clean hole. Tied-in with BHCS/GR, added 13 ft. Drill horizontal at 87° from 11500-640'. Penetrated 14N at 11600' at 8959' TVD. Wiper to window. Drill horizontal at 91° from 11640-745'. Wiper to window. Tie-in, add 7.0'. Drill to final TD at 11750' (8956' TVD). POOH for liner. LD drilling BHA. RU to run liner. 03122/00 5 11705' RIH with 70 Jts of 2 7/8", 6.16#, L-80, STL Liner with float equipment. M/U Baker CTLRT and CTC. RIH with liner on CT. Correct CTD to flag at 9500' EOP. [-14 ft CTD]. Tag TD on depth at 11,750 ft BKB. Pump 5/8" steel ball and release from liner. Set down weight and circulate well to 2 % KCL water. Recover FIoPro and send to MI. Rig up DS Cement pumper. Safety Meeting. Pump 15.5 BBLS, 15.8 PPG CMT with Latex. Pump Baker Dart. Displace with 2% KCL water at 2.9 BPM. Dart on LWP at 57.9 BBL. Shear LWP and displace cement at 3.1 BPM. LWP on seat at 69.4 BBLS. Press test with 2000 psi. Wash top of liner at 9632 ft. POOH jetting. LD Baker CTLRT. MU 2.25" nozzle on 34 stands CSH workstring. RIH with CT. Wash to PBTD at 11687', correct depth (-4'). Spot FIo-Pro in liner. POOH, stand back I ¼" CS Hydril. WOC to test liner top. D-25A, Coil Tubing Drilling Page 2 03/23/00 6 11750' Pressure test liner lap at 1000 psi. MU 2" SWS CTC perf guns. RIH with 30 stands CSH workstring. RIH with CT to PBD. Position guns. Drop ball and perforate 11360-521', 11550-600' and 11628-670' w/4 spf. POOH with CT. Stand back workstring. LD perf guns-all shots fired. RIH with nozzle to 2000' and freeze protect wellbore. Purge CT w/N2. Change pack-off. ND BOP, clean pits and cuttings tank. Install Tree Cap and pressure test to 3000 psi-OK. Release rig at 19:30 hrs. 3-22-00. North Slope Alaska Alaska State Plane 4 PBU_ WOAD Pad D-25A Surveyed: 21 March, 2000 SURVEY REPORT 11 April, 2000 Your Ref: API-500292152201 Surface Coordinates: 5959254.60 N, 654087.11E (70° 17' 44.1401" N, 148° 45' 08.1408" W) Kelly Bushing: 71.74ft above Mean Sea Level R CbivED APR 2 1 2000 A~a~ka Oil & Gas Cons. Commission Anchorage DRILLING SI~FIVIr' ES Survey Ref: svy9732 R CEIVED APR 2 1 2.000 Oii A Gas Cons. Cor,~mis~ion North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for D-25A Your Ref: API-500292152201 Surveyed: 21 March, 2000 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 10510.45 37,100 11.010 8741.51 8813.25 10614.00 38.470 9.830 8823.34 8895.08 10644.44 45,640 1.990 8845.95 8917.69 10671.94 51,680 356.390 8864.11 8935.85 10705.06 58.710 350.800 8883.01 8954.75 10743.74 63.720 345.180 8901.64 8973.38 10764.43 66.400 342.480 8910.37 8982.11 10793.68 72.120 337.440 8920.73 8992.47 10822.68 75.760 331.760 8928.76 9000.50 10850.71 79,360 323,500 8934.80 9006.54 10887.04 85,600 315.240 8939.56 9011.30 10924.40 90.880 305.400 8940.71 9012.45 10951.90 91.320 301.350 8940.19 9011.93 10987.83 92.200 295.550 8939.08 9010.82 11018.83 91.580 291.160 8938.06 9009.80 11052.90 89.470 289.580 8937.75 9009.49 11083.42 87.270 294.320 8938.62 9010.36 11118.33 88,330 300.300 8939.96 9011.70 11147.83 88,770 306.450 8940.70 9012.44 11177.47 88.330 311.900 8941.45 9013.19 11211.77 89.740 318.050 8942.03 9013.77 11249.17 88.860 324,210 8942.49 9014.23 11299.67 86.660 331.760 8944.47 9016.21 11333.42 86.480 339.150 8946.49 9018.23 11370.42 86.220 343.720 8948.85 9020.59 4870.13 N 954.94 E 4932.52 N 966.41E 4952.77 N 968.41 E 4973.39 N 968.07 E 5000.37 N 964.98 E 5033.49 N 957.89 E 5051.51N 952.67 E 5077.18 N 943.28 E 5102.33 N 931.32 E 5125.41N 916.67 E 5152.70 N 893.24 E 5176.82 N 864.81 E 5191.94 N 841.85 E 5209.04 N 810.29 E 5221.32 N 781.85 E 5233.18 N 749.92 E 5244.58 N 721.63 E 5260.58 N 690.65 E 5276.79 N 666.03 E 5295.50 N 643.07 E 5319.73 N 618.82 E 5348.83 N 595.37 E 5391.58 N 568.63 E 5422.21N 554.65 E 5457.20 N 542.89 E Global Coordinates Dogleg Northings Eastings Rate (ft) (fi) (°/lOOft) 5964143.29 N 654942.01 E 5964205.90 N 654952.19 E 1.496 5964226.19 N 654953.78 E 29.161 5964246.79 N 654953.02 E 26.746 5964273.71 N 654949.38 E 25.337 5964306.68 N 654941.61 E 18.158 5964324.58 N 654936.02 E 17.543 5964350.05 N 654926.11 E 25.333 5964374.95 N 654913.63 E 22.619 5964397.73 N 654898.51 E 31.507 5964424.53 N 654874.52 E 28.329 5964448.07 N 654845.61 E 29.871 5964462.71 N 654822.35 E 14.811 5964479.16 N 654790.44 E 16.320 5964490.86 N 654761.76 E 14.294 5964502.06 N 654729.59 E 7.737 5964512.88 N 654701.07 E 17.116 5964528.24 N 654669.77 E 17.384 5964543.94 N 654644.83 E 20.894 5964562.18 N 654621.49 E 18.441 5964585.90 N 654596.75 E 18.392 5964614.52 N 654572.70 E 16.636 5964656.71 N 654545.09 E 15.560 5964687.04 N 654530.48 E 21.864 5964721.79 N 654518.01E 12.346 Alaska State Plane 4 PBU_WOA D Pad Vertical Section (ft) Comment 3452.86 3497.54 3513.02 3530.14 3554.05 3585.29 3603.06 3629.50 3656.97 3684.29 3720.07 3756~11 3781.63 3813.69 3840.01 3867.98 3893.49 3924.31 3951.68 3980.15 4013.88 4051.17 4101.53 4134.66 4170.10 Tie-on Survey Window Point MWD Magnetic Continued... 11 April, 2000 - 9:36 - 2 - DriilQuest 1.05,05 Sperry-Sun Drilling Services Survey Report for D-25A Your Ref: API-500292152201 Surveyed: 21 March, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 11403.85 87.100 348. 990 8950.79 9022.53 5489.62 N 535.03 E 11437.82 88.510 345.470 8952.10 9023.84 5522.72 N 527.52.E 11467.95 89.560 339.320 8952.60 9024.34 5551.42 N 518.42 E 11508.27 89.470 335,280 8952.94 9024.68 5588.61 N 502.86 E 11537.92 85.960 330.360 8954.13 9025.87 5614.95 N 489.33 E 11569.30 84.810 326.490 8956.65 9028.39 5641.60 N 472.96 E 11608.65 89.650 319,990 8958.56 9030.30 5673.05 N 449.45 E 11637.70 93.950 315,770 8957.64 9029.38 5694.58 N 429,99 E 11669.20 91.580 309,090 8956.12 9027.86 5715.80 N 406,78 E 11704.00 89.120 301.880 8955.91 9027.65 5735.98 N 378,47 E 11727.85 89.470 298.890 8956.20 9027.94 5748.04 N 357.90 E 11750.00 89,470 298.890 8956.41 9028.15 5758.74 N 338.50 E 5964754.04 N 654509.48 E 5964786.98 N 654501.30 E 5964815.49 N 654491.61 E 5964852.35 N 654475.29 E 5964878.41N 654461.23 E 5964904.71 N 654444.32 E 5964935.68 N 654420.17 E 5964956.81 N 654400.27 E 5964977.54 N 654376.63 E 5964997.14 N 654347.91 E 5965008.78 N 654327.09 E 5965019.08 N 654307.48 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 27.126° (20-Mar-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 325.180° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11750.00ft., The Bottom Hole Displacement is 5768.68ft., in the Direction of 3.364° (True). Dogleg Rate (°/100fi) 15.956 11.155 20.704 10.022 20.371 12.827 20.575 20,732 22.477 21.889 12.621 0.000 Alaska State Plane 4 PBU_WOA D Pad Vertical Section (ft) Comment 4201.21 4232.66 4261.42 4300.84 4330.19 4361.41 4400.66 4429.44 4460.11 4492.85 4514.50 4534.35 Projected Survey CEiYED APR 2 1 2000 Alaska 0il & Gas r...,, .. · Ancho~'age Continued... 11 April, 2000 - 9:36 - 3 - DrillQuest 1.05,05 Sperry-Sun Drilling Services Survey Report for D-25A Your Ref: AP1-$00292152201 SurVeyed: 21 March, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA D Pad Comments Measured Depth (ft) 10510.45 10614.00 11750.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8813.25 4870.13 N 954.94 E 8895.08 4932.52 N 966.41 E 9028.15 5758.74 N 338.50 E Comment Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 10614.00 8895.08 To Measured Vertical Depth Depth (ft) (ft) 10614.00 8895.08 11750.00 9028.15 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gyro MWD Magnetic ,-b ,iVED APR 2 1 2000 o]~ & Gas Co,qs. Commission Anchorage 11 April, 2000 - 9:36 - 4 - DrillQuest 1.05.05 8300 8400- 8500- 8600 8700 8800 8900 9OOO 9100 B.P Exploration (TFue) Structure : Pad D Field : Prudhoe Bay Well : D-25A, 50-029-21522-01 Location : North Slope, Alaska East (feet) Cre(lted by potnis Dcte plotted : 5-Apr-2000 Plot Reference ~s D-25A. Ceordlnotes ere in feet reference 0-25. rue Vertlcal Depths ere reference RKB - MSL = '/1.7 ft. Brij Potnis 267-6613 --- nakar Hughe~ INT£O --- 300 200 100 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 I t I I I f I I t I J I I I I I I I I I I I I I I I I I I I I I RECEIVED APR 2 1 2000 Alaska Oi~ & G~s Cons. Commission Projected to TD I D-25A Case101 Plan ORIGINAL Tie-in Point Projected to TO ] D-25A Case101 Plan J 100 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 Verticol Secf[on (feet) -> Azimuth 324.00 with reference 4870.15 N, 954.92 E from D-25 59O0 58O0 57O0 56OO 55OO 5400 5300 5200 5100 500O 4900 480O 4700 B.P. Exploration (True) Pad D D-25A D-25 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : D-25A Our ref : s~-y322 License : 50-029-21522-01 Date printed : 3-Apr-2000 Date created : 3-Apr-2000 Last revised : 3-Apr-2000 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 655230.717,5955744.049,999.00000,N Slot location is n70 17 44.144,w148 45 8.115 Slot Grid coordinates are N 5959255.000, E 654088.000 Slot local coordinates are 3534.05 N 1070.08 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED APR 2 1 2000 Aiaska Oil & Gas Co~s. Corr~mis~ion .Anchorage B.P. Exploration (True) Pad D,D-25A Prudhoe Bay,North Slope, Alaska Measured Inclin Azimuth Subsea Depth Degrees Degrees Depth RECTANGULAR COORDINATES 10510.45 37.10 11.01 8741.55 10609.95 38.43 9.88 8820.20 10614.00 38.47 9.83 8823.38 10644.44 45.64 1.99 8845.98 10671.94 51.68 356.39 8864.14 4870.13N 954.92E 4930.06N 965.96E 4932.54N 966.39E 4952.78N 968.38E 4973.40N 968.05E 10705.06 58.71 350.80 8883.05 10743.74 63.72 345.18 8901.68 10764.43 66.40 342.48 8910.40 10793.68 72.12 337.44 8920.76 10822.68 75.76 331.76 8928.79 SURVEY LISTING Page 1 Your ref : D-25A Last revised : 3-Apr-2000 10850.71 79.36 323.50 8934.84 10887.04 85.60 315.24 8939.60 10924.40 90.88 305.40 8940.75 10951.90 91.32 301.35 8940.22 10987.83 92.20 295.55 8939.11 Dogleg Vert G R I D C O O R D S Deg/100ft Sect Easting Northing ' 11018.83 91.58 291.16 8938.09 11052.90 89.47 289.58 8937.78 11083.42 87.27 294.32 8938.65 11118.33 88.33 300.30 8939.99 11147.83 88.77 306.45 8940.74 2.22 0.00 654942.12 5964143.45 1.51 41.99 654951.92 5964203.59 1.25 43.75 654952.30 5964206.08 29.16 58.95 654953.88 5964226.36 26.75 75.83 654953.12 5964246.96 11177.47 88.33 311.90 8941.49 11211.77 89.74 318.05 8942.06 11249.17 88.86 324.21 8942.52 11299.67 86.66 331.76 8944.50 11333.42 86.48 339.15 8946.52 5000.39N 964.96E 25.34 99.48 654949.47 5964273.88 5033.51N 957.87E 18.16 130.44 654941.71 5964306.84 5051.52N 952.65E 17.54 148.08 654936.11 5964324.74 5077.19N 943.26E 25.33 174.37 654926.19 5964350.21 5102.34N 931.30E 22.62 201.74 654913.72 5964375.11 11370.42 86.22 343.72 8948.88 11403.85 87.10 348.99 8950.83 11437.82 88.51 345.47 8952.13 11467.95 89.56 339.32 8952.64 11508.27 89.47 335.28 8952.98 5125.43N 916.65E 5152.71N 893.22E 5176.83N 864.79E 5191.96N 841.83E 5209.06N 810.27E 11537.92 85.96 330.36 8954.16 11569.30 84.81 326.49 8956.69 11608.65 89.65 319.99 . 8958.59 11637.70 93.95 315.77 8957.68 11669.20 91.58 309.09 8956.15 5221.34N 781.83E 5233.19N 749.90E 5244.59N 721.61E 5260.59N 690.63E 5276.81N 666.01E 11704.00 89.12 301.88 8955.94 11727.85 89.47 298.89 8956.24 11750.00 89.47 298.89 8956.44 5295.52N 643.05E 5319.75N 618.80E 5348.85N 595.35E 5391.60N 568.61E 5422.22N 554.63E 31.51 229.03 654898.60 5964397.88 28.33 264.88 654874.61 5964424.68 29.87 301.10 654845.69 5964448.21 14.81 326.83 654822.42 5964462.85 16.32 359.22 654790.52 5964479.29 14.29 385.87 654761.84 5964490.98 7.74 414.23 654729.67 5964502.18 17.12 440.08 654701.15 5964512.99 17.38 471.23 654669.85 5964528.34 20.89 498.82 654644.91 5964544.05 18.44 527.45 654621.56 5964562.28 18.39 561.31 654596.82 5964586.00 16.64 598.64 654572.77 5964614.61 15.56 648.94 654545.16 5964656.80 21.86 681.93 654530.55 5964687.12 5457.22N 542.87E 12.35 717.15 654518.08 5964721.86 5489.64N 535.01E 15.96 748.01 654509.54 5964754.11 5522.74N 527.50E 11.16 779.19 654501.36 5964787.05 5551.44N 518.40E 20.70 807.77 654491.66 5964815.55 5588.62N 502.84E 10.02 847.00 654475.34 5964852.41 5614.97N 489.31E 5641.61N 472.94E 5673.07N 449.43E 5694.60N 429.97E 5715.81N 406.76E 20.37 876.26 654461.28 5964878.46 12.83 907.44 654444.36 5964904.76 20.58 946.70 654420.21 5964935.73 20.73 975.56 654400.31 5964956.85 22.48 1006.37 654376.67 5964977.57 5736.00N 378.45E 21.89 1039.34 654347.94 5964997.17 5748.06N 357.88E 12.62 1061.19 654327.13 5965008.80 5758.76N 338.48E 0.00 1081.24 654307.52 5965019.10 RECEIVED APR 2 1 2000 Oii & Gas Cons. Commission Anchorage Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from D-25 and SSTVD from RKB - MSL = 71.7 ft. Bottom hole distance is 5768.70 on azimuth 3.36 degrees from wellhead. Vertical section is from tie at N 4870.13 E 954.92 on azimuth 324.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad D,D-25A Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 2 Your ref : D-25A Last revised : 3-Apr-2000 Comments in wellpath MD SSTVD Rectangular Coords. Comment 10510.45 8741.55 4870.13N 954.92E Tie-in Point 11750.00 8956.44 5758.76N 338.48E Projected to TD NO Targets associated with this wellpath APR 2 1 2000 Alaska Oil & Gas ,,ohs. Commission Anchol'age TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COH~IISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE; (907) 279-1433 FAX: (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Prudhoe Bay Unit D-25A BP Exploration (Alaska) Inc. Permit No: 200-024 Sur. Loc. 1746'SNL, 1068'WEL, Sec. 23, T1 IN, R13E, UM Btmhole Loc. 3953'NSL, 672'WEL, Sec. 14, T11N, R13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P.E. Chair BY ORDER OF THE_COMMISSION DATED this lq &'~ day of March, 2000 dlf/Enclosures cc: Department of Fish & Gmne. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,-.,,, STATE OF ALASKA -- ALASK/ iL AND GAS CONSERVATION COM ~SION PERMIT TO DRILL 20 AAC 25.005 07J 2j, la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI ... [] Service [] Development Gas [] Single Zone [] Multiple Zone ......... ..... 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE - 71.74 Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028285 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1746' SNL, 1068' WEL, SEC. 23, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 2943' NSL, 162' WEL, SEC. 14, T11N, R13E, UM D-25A At total depth 9. Approximate spud date Amount $200,000.00 3953' NSL, 672' WEL, SEC. 14, T11N, R13E, UM 03/21/00 i21 Distance to nearest property line113. Distance to nearest 'well 14. Number of acres in property 15. 'Proposed depth iMD and -I'VD) ADL 028280, 1326' MD I No Close Approach 2560 11674' MD / 8959' TVD i6. To be"compJ'et'ed i'~'r deviated ~v'ell'~ .... 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)} Kick Off Depth 10620 Maximum Hole Angle 89° Maximum surface 2274 psig, At total depth (TVD) 8800' / 3330 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement .......... Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 2050' 9624' 8003' 11674' 8959' E~4 cuft Class 'G' ...................................... 19. ::i:'~'"~'~'"~mplet~d for Redrill, Re-entry, and Deepen Operations. Total depth: measured 10970 feet Plugs (measured) '~.J ~,~ true vertical 9167 feet Effective depth: measured 10927 feet Junk (measured) true vertical 9135 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8 cu yds Concrete 110' 110' Surface 2672' 13-3/8" 3755 cu ft Permafrost 2715' 2690' Intermediate 9989' 9-5/8" 2150 cu ft Class 'G' 10032' 8417' Production Liner 1201' 7" 342 ca ft Class 'G' R E C E I ~]F~'D~0970' 8195' - 9167' Perforation depth: measured 10730'- 10800' (two open intervals) true vertical 8985' - 9039' Alaska 0ii & G&s Cons. Anchorage 20. Attachr~ents [] Filing Fee [] Property Piat'' [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~_~~~ Ted Stagg Title CT Drilling Engineer Date , .. Commission Use/Only Permit Number I APl Number ~ Approval Date J See cover letter ~ --"(~3 ?_.,~// 50-029-21522-01 ,~----/ '~ ~- ~-~d_.J for other requirements Conditions of Approval: Samples Required [] Yes,~]~'~lo Mud Log Required [~Tes Hydrogen Sulfide Measures J~Yes []No Directional Survey Required ~J~es Il'No Required Working Pressure fo~'BOPE I-]2K; []3K; 1~4K; r-15K; [] 10K; [] 15K Other: ORIGINAL SIGNED'BY by order of Approved By Robert N. Christensort Commissioner the commission Date~7" Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX D-25a Sidetrack Summary of Operations: D-25 is being sidetracked to target lower Zone 2 (21P), reserves. This sidetrack will be conducted in two phases. Phase 1: Set Whipstock, cement perfs, mill window: Planned for March 6-8, 2000. · A Mechanical Integrity Test was successfully performed on 2/5/00. · A whipstock drift and PDS caliper were run on 2/13/00. · E-Line will be used to set the whipstock at approx. 10,610' MD. · Service coil will be used to cement perfs and mill the window. Phase 2: Drill and Complete sidetrack: Planned for March 21, 2000. Drilling coil will be used to drill and complete the directional hole as per attached plan. Mud Program: · Phase l& 2: Seawater · Phase 3: FIo-Pro (8.6- 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 9,624' MD and cemented with approx. 15 bbls. cement to bring cement 200 ft above the window. The liner will be pressure tested to 2200 psi and perforated with coiled tubing conveyed guns. Well · · · Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. Hazards No faults or lost circulation are expected. Res. pressure is normal. Reservoir Pressure Res. pressure is approx. 3330 @ 8800ss. Max. surface pressure with gas (0.12 psi/fi) to surface is 2274 psi. RECEIVED TREE: 6" McEVOY WELLHEAD: McEVOY 3~3/8", 72#/ft, BTRS 2715, KOP: 1700' MAX ANGLE: 46°/6600' 5-1/2", 17#/ft, L-80, BTRS TUBING (IPC) TUBING ID: 4.892" CAPACITY: .0232 BBL/FT NOTE: TUBING TAIL IS ABOVE 7" LINER TOP. TOP OF 19762' I 7" LINER 9-5/8", 47#/It, ~ L~80, BTRS Pro FOC Corn 4etlon KB. ELEV = 71.74' BF. ELEV = 42,89' SSSV LANDING NIPPLE 12166, I ( OTIS)( 4.562" ID) GAS LIFT MANDRELS (©TI~ I RD W/F A I ATQH) N~ MD(B KB.) TVDss 5 3259' 3093' 4 5856' 5145' 3 7796' 6540' 2 8962' 7471' I 9401' 7820' SLIDING SLEEVE OTIS "XA" (4.562" ID) TUBING SEAL ASSY. 9-5/8" PACKER ( TIW ) (4.750"1D) [9473' [9534' [9549' -- 5 1/2", 17 #/ft, L-80 TAILPIPE -- 5 1/2" "X" NIPPLE (OTIS) (4.562" ID) -- 5 1/2" "XN" NIPPLE (OTIS) ( 4.455" ID) 5 1/2" TBG TAIL ( TIW)( "ID) (ELMD) 9604' 9643' 9682' 9685' 2 7/8" Liner Cemented to appr°X' 200 ft above window. Top of Whipstock approx. 10,610' PERFORATION SUMMARY REF LOG: SWS-BHCS- SPF NTERVAL O! 4' 4 110,547- 10,557 s 4' 4 ~ 10,730' 10,770' 4" 4 / 10.784-10.800' 1-14-86 ~EN/SQZ'D zd 11/09/96 zd 11/09/96 OPEN/7-26*86 PBTD I 10,927'I 29 #/~ L-80. BTRS I 10,970' I 6,000 5,500 5,000 4,500 D-25 8,960 500 1,000 X distance from Sfc Loc 1,500 JWell Name D-25 J CLOSURE J DistanCeAz 5,713 ft3 de~ J NEW HOLE E/W (X) N/S (Y) Kick Off 866 4,955 , TD 273! 5,706 State Plane 654,361 5,964,961 Surface Loc 654,088 5,959,255 DLS deg/100 Tool Face Length Curve 1 ' 6 0 30 Curve 2 26 -20 60 Curve 3 26 -40 169 Curve 4 10 -90 399 Curve 5 10 90 399 ! ,057 Drawn: 2/19/2000 9:30 Plan Name: Case 101 D-25 Vertical Section 0 8600 8650 8700 8750 ---" 8800 8850 8900 500 Path Distance (Feet) 1,000 1,500 I I Angle @ K.O.= 39 deg MD:10620 2,000 8950 ~ - Tot Drld:1054 ft --8,960 ......................................................................................................................................................................................................................... 11674 TD · · 9000 - Marker Depths ~::)ri~l Wellbore IKick Off I 8,8281ftTVD 10,6201ft MD IDeprtr @KO 5,045 ft MD KO Pt 10,620I MD New Hole 1054I I Total MD 11,674I TVD TD 8,9591 DLS de~t/100 Tool Face Lenqth Curve 1 6 01 ~,0 Curve 2 26 -20 60 Curve 3 26 -40 169 Curve 4 10 -90 399 Curve 5 10 90 399 I 1,057 Drawn: 2/19/2000 9:30 Plan Name: Case 101 2 3t8!! CT Lul 10,000 psi Pack-Off D-25a CT Ddllin§ & Completion BOP 36~ 22.5' Blind/Shear 7 1/16" Pipe/Slip Slips 7 1/16" Pipe 2 3/8" 2 7/8" __ ~ 2 3/8" SWAB OR MASTER VALVE STATE OF ALASKA ALASK~ )ILAND GAS CONSERVATION C IMISSlON APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1746' SNL, 1068' WEL, SEC. 23, T11N, R13E, UM At top of productive interval 2337' SNL, 162' WEL, SEC. 14, T11N, R13E, UM At effective depth 1893' SNL, 72' WEL, SEC. 14, T11N, R13E, UM At total depth 1864' SNL, 68' WEL, SEC. 14, T11N, R13E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 71.74 7. Unit or Property Name Prudhoe Bay Unit 8, Well Number D-25 9. Permit Number 185-320 10. APl Number 50- 029-21522 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 10970 true vertical 9167 Effective depth: measured 10927 true vertical 9135 Casing Length Structural Conductor 110' Surface 2672' Intermediate 9989' Production Liner 1201' feet Plugs (measured) feet feet Junk (measured) feet Size Cemented MD TVD 20" x 30" 8 cu yds Concrete 110' 110' 13-3/8" 3755 cu ft Permafrost 2715' 2690' 9-5/8" 2150 cu ft Class 'G' 10032' 8417' 7" 342 cu ft Class 'G' 9769' - 10970' 8195' - 9167' Perforation depth: measured 10730' - 10800' (two open intervals) true vertical 8985' - 9039' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 9549' with 5-1/2" tailpipe to 9682' Packers and SSSV (type and measured depth) 9-5/8" TIW packer at 9549'; 5-1/2" SSSV Landing Nipple at 2166' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation Mamh 7, 2000 16. If proposal was verbally approved Name of apl)rover Contact Engineer Name/Number: Date approved Ted Stagg, 564-4694 15. Status of well classifications as: [] Oil [] Gas [--1 Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~~,~ Ted Stagg Title CT Drilling Engineer Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance Mechanical Integrity Test Subsequent form required 10- I Approval No._~ ~)~ ..- 0,'~ ~ Approved by order of the Commission Commissioner Form 10-403 Rev. 06/15/88 Date Submit In Triplicate / DATE ] [ CHECK NO. ] VENDOR ALASKAST 14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET )20300 CK0203'00 100. O0 100. O0 HANDLING INST: S/H TERRIE HUBBLE E ATTACHED CHECK IS IN PAYI~NT FOR ITEm DESCRIBED ABOVE. ~ ! OO. OO 1OO. OO : BP EXPLORATION (ALASKA),JNC, .:.~: '! '~.0,.i~:~dX::.196612 ~::':.::..'::~ii.::~:, .... :.::~ :::'.' 'ANCHO~GE;ALAS~?... .. . . ..... :..... :-::.... 99519-6612 :!?:' :~AY ro::The:.:. ALASKA STATE DEP'T OF R~ENUE 3RDER.::' ':!i~ ~occi::::.::.. :o¢ :~ : 3oo'1 .:PORCUPINE:::~DR:::~i: · : :...... "" ], r= 8 ?t q l, "" ~:O[,~803Rq5~: OORt, t,~q," WELL PERMIT CHECKLIST COMPANY ~" FIELD & POOL ~.~.~ .~ / ~ INiT (~LASS :ADMINISTRATION A._~ DATE ENGINEERING DATE WELL NAM~4/~'~i~'~-~PROGRAM:. _ exp ~ /~i/_ 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ GEOLOGY DATE g' Z_.~. ~D dev z/" redrll v/ serv GEOLAREA ~:~>/__._.~ ..... "-)N N 14. 15. 16. 17. 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. UNIT# Y N 30, Permit can be issued w/o hydrogen sulfide measures ..... Y(.~.~ 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............ ~"'.~,,¢ Y N 33. Seabed condition survey (if off-shore) ............ .'~"~ 34. Contact name/phone for weekly progress reports [exploratory onlyjr,_~N ANNULAR DISPOSAL35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ~ wellbore seg ann. disposal para req ~ ON/OFF SHORE GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: TEM~ L;U~ Comments/Instructions: z Z -r c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Jan 08 10:58:58 2002 d-25a.tapx Reel Header Service name ............. LISTPE Date ..................... 02/01/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/01/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD D-25A 500292152201 BP Exploration (Alaska) Inc. Sperry Sun 04-JAN-02 MWD RUN 1 MWD RUN 2 AK-MW-90268 AK-MW-90268 S. LATZ S. LATZ WHITLOW, SEV WHITLOW, SEV 23 liN 13E 1746 1068 71.74 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT} 1ST STRING 3.750 7.000 10614.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. ALL TRUE VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (TVDSS). Page 1 d-25a.tapx 3. D-25A KICKS OFF FROM D-25 AT WHIPSTOCK, WITH TOP SET AT 10614' MD, 8823.6' TVDSS. MWD RUNS 1-2 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. 5. DEPTH SHIFTING WAIVED PER THE E-MAIL OF 10/09/2001 FROM D. SCHNORR OF BP EXPLORATION (ALASKA) INC. 8. MWD RUNS 1-2 REPRESENT THE MWD DATA FOR WELL D-25A WITH API# 50-029-21522-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11750' MD, 8956' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRD = SMOOTHED GAMMA RAY - SCINTILLATION DETECTORS $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10537.0 11719.5 ROP 10628.5 11750.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 1 10628.5 MWD 2 10910.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 10909.5 11750.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Page 2 Name Service Unit Min Max DEPT FT 10537 11750 ROP MWD FT/H 2.45 669.6 GR MWD API 16.92 153.92 First Reading For Entire File .......... 10537 Last Reading For Entire File ........... 11750 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 d-25a.tapx Mean Nsam 11143.5 2427 111.782 2244 31.544 2366 First Reading 10537 10628.5 10537 Last Reading 11750 11750 11719.5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10537.0 10879.0 ROP 10628.5 10909.5 $ LOG HEADER DATA DATE LOGGED: 20-MAR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 10909.9 TOP LOG INTERVAL (FT) : 10626.0 BOTTOM LOG INTERVAL (FT) : 10910.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 45.6 MAXIMUM ANGLE: 85.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE PB02100HWRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT) : # BOREHOLE CONDITIONS MUD TYPE: Flo Pro Page 3 d-25a.tapx MUD DENSITY (LB/G): 8.65 MUD VISCOSITY (S) : 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 25000 FLUID LOSS (C3) : 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 .0 137.5 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 10537 10909.5 10723.3 746 ROP MWD010 FT/H 3.65 133.72 74.0808 563 GR MWD010 API 16.92 80.05 29.9622 685 First Reading For Entire File .......... 10537 Last Reading For Entire File ........... 10909.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Reading 10537 10628.5 10537 Last Reading 10909.5 10909.5 10879 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Page 4 d-25a.tapx Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10879.5 11719.5 ROP 10910.0 11750.0 $ LOG HEADER DATA DATE LOGGED: 21-MAR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 11750.0 TOP LOG INTERVAL (FT) : 10910.0 BOTTOM LOG INTERVAL (FT): 11750.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.8 MAXIMUM ANGLE: 93.9 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE PB02100HWRG6 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT) : # BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9.5 MUD CHLORIDES (PPM) : 25000 FLUID LOSS (C3): 6.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 146.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel Page 5 DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 d-25a.tapx 0 4 8 Name Service Unit Min Max DEPT FT 10879.5 11750 ROP MWD020 FT/H 2.45 669.6 GR MWD020 API 17.41 153.92 Mean 11314.8 124.408 32.1886 First Reading For Entire File .......... 10879.5 Last Reading For Entire File ........... 11750 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 First Last Nsam Reading Reading 1742 10879.5 11750 1681 10910 11750 1681 10879.5 11719.5 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/01/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/01/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 6