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Home My WebLink About197-017Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. iCrC.. O J~ File Number of Well History File PAGES TO DELETE Complete RESCAN r'l [3 Color items - Pages: GraYScale, halftones,-pictures, graphs, charts - Pages: Poor Quality Odginal- Pages: Other - Pages: DIGITAL DATA n Diskettes, No. Other, No/Type .OVERSIZED a Logs of various kinds n Other COMMENTS: Scanned b~.' ~ev,~,~r~.D'ar~t~ Nathan Lowell TO RE-SCAN Notes: ~ - ~ ..... ,.i I.,,,. ,-, ....~. ,,'-..~..~! r~=,.=,,h= Nnthnn Lowell Date: /s/ STATE OF ALASKA ~ RECEIVED ALASKA ",L. AND GAS CONSERVATION COMf\t. .lION OCT 1 92004 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil &. Gas Cons. Commission ~ ^ .....1,........... 1a. Well Status: D Oil DGas D Plugged a Abandoned D Suspended DWAG 1 b. Well Class: 20MC 25.105 2OMC 25.110 a Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 9/18/2004 197-017 304-319 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 05/04/1997 50-029-22235-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 05/07/1997 PBU 15-26A 1030' SNL, 202' EWL, SEC. 22, T11N, R14E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 775' SNL, 622' WEL, SEC. 21, T11N, R14E, UM 68' Prudhoe Bay Field I Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 439' NSL, 4080' WEL, SEC. 16, T11N, R14E, UM 9878 + 8852 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 676130 y- 5960456 Zone- ASP4 12483 + 8898 Ft ADL 028306 TPI: x- 675299 y- 5960691 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 671811 y- 5961825 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey aNo DYes N/A MSL 1900' (Approx.) 21. Logs Run: MWD, GR 2. CASING, LINER AND CEMENTING RECORD CASING """ "", "~ .,",'",,', \ /," fj) T\ID: i AóŒ' -: "\ 'AMOUNT SIZE WT. PER FT. GRADE TOP I BOTTOM TOP BOTTOM SIzE CEMENTING RECORD PULLED 20" Conductor Surface 115' Surface 115' 13-3/8" 68# K-55 I L-80 Surface 3510' Surface 3509' 16" 1425 ax CS III, 400 ax 'G', Top Job: 200 ax CS II 9-5/8" 47# L-80 Surface 8557' Surface 8305' 12-1/4" 1070 sx Class 'G', 546 sx 'G' 7 29# L-80 8289' 10330' 8134' 8899' 8-1/2" 450 sx Class 'G' 4-1/2" 12.6# L-80 10028' 11549' 8877' 8914' 6" Uncemented Slotted Liner 2-3/8" 4.6# FL4S 11450' 12483' 8915' 8898' 2-3/4" Uncemented Slotted Liner 23. Perforations oRen to Production (MD + TVD of Top- and I"""",: .i":'C/ TUSING RECORD Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) None None MD TVD MD TVD ,i/.".., ,~" CTt'" DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9878' SetEZSV j 9878' P&A with 31.5 Bbls Class 'G' / \~ 9877' Set Whipstock ,/ 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-Bel GAs-McF WATER-BBl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... OIL-BBL GAS-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ORIGiNAL ~ç ,"-.A.- Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ., ~U\~ - r;¡¡¡,.- '--'?T "\ (.,\< ~~ .~ 28. NAME From 15-26: Sag River Shublik Sadlerochit GEOLOGIC MARKERS 29. ~ JRMATION TESTS MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None", None 8492' 8267' 8561' 8308' 8676' 8374' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date /0 ..¡8-ol( PBU 15-26A Well Number 197-017 304-319 Permit No. I A roval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Phil Smith, 564-4897 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska, ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEMS: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ~ ~ Well: Field: API: Permit: 15-26B Prudhoe Bay Unit 50-029-22235-02-00 204-159 Accept: Spud: Release: Rig: 09/10/04 09/20104 09/26/04 Nabors 2ES PRE-RIG WORK 08/21/04 RIG UP. VALVE CREW CIO SWAB VALVE, PRESSURE TEST. 08/22/04 ATTEMPT TO EQUALIZE TTP. TOOLSTRING STUCK @ 7615. UNABLE TO FREE TOOLS WI PUMP, DROP TIME CUTTER. RETRIEVE CUTTER & APPROX 5200' OF WIRE. APPROX, 2400' OF WIRE AND TOOL-STRING REMAIN IN HOLE. RAN 2.75" IMPRESSION BLOCK TO 5178' SHOWING POSSIBLE TUBING PARTI WIRE MARKS. NOTIFY DSO OF WELL STATUS, (TOOL-STRING HAS 1.75" F.N., 30' LONG) 08/24/04 WELL SHUT IN UPON ARRIVAL, SSSV DUMPED. RAN 2.5 BAIT SUB WITH 3,5 WIRE BRUSH AND 2.25 2 PRONG WIRE GRAB TO 5178 SLM. RAN 2.5 GS TO ATTEMPT TO LATCH FISH. UNABLE TO LATCH FISH, RAN 2,50 CENTRALIZER AND 2.25 LIB. LIB SHOWS PARTED TUBING AT 5167 SLM. 2.5 BAIT SUB, 3.5 WIRE BRUSH AND 2.25 2 PRONG WIRE GRAB LEFT IN THE HOLE. NOTIFIED PAD OPERATOR OF WELL STATUS. SSV DUMPED. WELL SHUT IN. 08/26/04 RAN 2.75 ON 12' DECENTRALIZER BARBELL ASSEMBLY. SD @ 5176 SLM JAR DOWN 1 TIME. LIB SHOWS A HALF MOON COVERING 1/3 OF LIB. IMPRESSION IS @ 10:00. ON LIB. NOTIFY DSO OF DEPARTURE, LEFT WELL SHUT IN, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 9/10/2004 9/11/2004 Date ~ ~ Page 1 ~ BP EXPLORATION Operations Summary Report 15-26 15-26B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES From - To Hours Phase 00:00 - 02:00 02:00 - 04:00 04:00 - 05:00 05:00 - 06:30 06:30 - 10:30 10:30-11:00 11:00 - 11:30 11:30-12:00 12:00 - 18:00 18:00 - 18:30 18:30 - 19:00 19:00 - 20:00 20:00 - 22:00 22:00 - 00:00 00:00 - 02:30 02:30 - 03:30 03:30 - 05:00 05:00 - 06:00 06:00 - 15:30 15:30 -16:00 16:00 - 16:30 16:30 - 17:00 Task Code NPT 2,00 MOB 2,00 MOB 1.00 RIGU P P P PRE PRE PRE 1.50 RIGU P PRE 4.00 RIGU P PRE 0.50 RIGU P PRE 0.50 WHSUR P 0,50 WHSUR P DECOMP DECOMP 6.00 KILL P DECOMP 0,50 WHSUR P 0,50 WHSUR P 1,00 WHSUR P 2.00 BOPSUE P 2,00 BOPSUE P DECOMP DECOMP DECOMP DECOMP DECOMP 2,50 BOPSUE P DECOMP 1.00 BOPSUE P 1.50 PULL P DECOMP DECOMP 1.00 PULL P DECOMP 9.50 PULL P DECOMP 0.50 PULL P 0.50 BOPSUF P 0.50 BOPSUF P DECOMP DECOMP DECOMP Start: 8/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 12/25/1991 End: 9/26/2004 Description of Operations Moved pit module. Prepared rig module for moving. Moved and spotted rig module over DS 15-26B Set in pit module, Raised and pinned derrick, Raised cattle chute. Unbridlled and pinned blocks, Hung off blocks and tied off lines. Rigged up floor, Spotted cuttings tank. Spotted and connected shops and out buildings. Strung geronimo line. Completed pre-spud check list. Held pre-spud safety meeting. Rig accepted at 10:00, Rigged up DSM lubricator and pulled BPV. Installed secondary annulus valve and rigged up circulating lines Circulated diesel from well with sea water at 3 BPM with 180 psi. Pumped soap pill and circulated seawater at 13 BPM and 2200 psi. Lost 376 BBLS while circulating. Ran BPV and tested from below with 1000 psi. Bled off control lines and chemical injection lines, Nippled down tree and adaptor flange. Installed blanking plug. Installed double stud adaptor and BOPS, Pressure testing upper rams and choke manifold to 3500 psi high and 250 psi low. BOP test witness waived by Chuck Shevie - AOGCC. Completed testing upper pipe rams, blind rams, manifold & valves, TIW valve, inside BOP & top drive to 250 psi low and 3500 psi high. Tested annular to 250 psi low and 2500 psi high. Pulled blanking plug and rigged down test joint. Rigged up DSM lubricator and pulled BPV. Picked up hanger running tool on 1 joint of 5' DP and engaged hanger. Backed out lock down screws, Picked up and pulled hanger up to rig floor with 77,000 Ibs pick up weight. Had no overpull, Pick up weight correlated to estimated depth of parted tubing at +/- 5178'. Held PJSM to discuss potential corrosion inhibitor inside chemical injection line. Rigged up for spooling injection line and SSSV line. Laid down tubing hanger. Rigged up tubing running equipment and spooling equipment for control lines. Filled hole with 125 BBLS. Held PSJM to discuss laying down tubing. Laid down 3 1/2' tubing and spooled control line and injection line to SSSV. Laid down SSSV and continued to lay down tubing and injection line to 3485'. Injection line started to slide on tubing. Spooled up remaining injection line, unable to determine quantity of injection line recovered, Rigged down line spooler. Continued laying down 3 1.2' tubing. Recovered 163 joints of tubing, 1 SSSV, 1 GLM and one pup joint parted at the pin end. 167 clamps and pins and 3 steel bands were also recovered. Overall length recovered was 5172'. Top of fish estimated at 5197' (5203' orig RKB), Some corrosion was seen on the tubing joints. The pup joint was extremely corroded with multiple holes. Laid down running tools for tubing. Cleared floor. Ran and set test plug in wellhead on 5'. Tested top and bottom pipe rams and annular with 5' and Printed: 9/27/2004 10:02:26 AM ~ ~ BP EXPLORATION Page 2 - Operations Summary Report Legal Well Name: 15-26 Common Well Name: 15-26B Spud Date: 12/25/1991 Event Name: REENTER+COMPLETE Start: 8/17/2004 End: 9/26/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/26/2004 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operåtions 9/11/2004 16:30 - 17:00 0.50 BOPSUF P DECOMP tested 5" TIW valve and inside BOP valve to 250 psi and 3500 psi (annular - 2500 psi). 17:00 - 17:30 0.50 BOPSUF P DECOMP Pulled test plug and installed wear bushing, 17:30 - 18:00 0.50 FISH P DECOMP Made up overshot with overshot extension. 18:00 - 22:30 4.50 FISH P DECOMP Tripped in hole with overshot picking up 5" DP. Hit obstruction in casing at 4076'. Unable to work through with 25,000 Ibs down. Attempted to wash with 2 to 3000 Ibs and 25 RPM w/o sucess. Had no overpull picking back up, 22:30 - 20:00 21.50 FISH P DECOMP Tripped out of hole with offshot to 1329' at report time. 9/12/2004 00:00 - 01:30 1,50 FISH P DECOMP Completed pulling out of hole with overshot. Recovered ball of injection line jammed inside overshot bowl. 01 :30 - 02:00 0.50 FISH P DECOMP Leveled rig while wating on wireline spear. 02:00 - 04:00 2.00 FISH P DECOMP Made up wire line spear assembly. Having trouble with tilt arm while picking up 6 1/2" DCS. 04:00 - 13:00 9,00 FISH N RREP DECOMP Repair tilt arm on top sub. 13:00 - 13:30 0.50 FISH P DECOMP Completed picking up DCS and BHA. 13:30 - 14:30 1,00 FISH P DECOMP Picked up 5" singles to 1372', 14:30 - 15:30 1,00 P DECOMP Ran in hole to 4076', Pushed spear to 4090', Had 10,000 Ibs drag, 15:30 - 17:00 1.50 FISH P DECOMP Pulled out of hole to BHA. 17:00 - 17:30 0.50 FISH P DECOMP Laid down jars and stood back DCS. 17:30 - 18:00 0,50 FISH P DECOMP Broke out wireline spear. Spear was full of tightly balled injection line. 18:00 - 18:30 0,50 FISH P DECOMP Made up new wireline spear. 18:30 - 19:00 0,50 FISH P DECOMP Ran in hole with DCS and picked up jars. 19:00 - 20:00 1.00 FISH P DECOMP Slipped and cut drilling line 20:00 - 21:30 1.50 FISH P DECOMP Tripped in hole to 4090', Continued in hole slowly to 4883', drag increased to 10,000 Ibs. 21:30 - 23:00 1,50 FISH P DECOMP Pulled out of hole to BHA, 23:00 - 23:30 0.50 FISH P DECOMP Laid down jars and stood back DCS. 23:30 - 00:00 0,50 FISH P DECOMP Broke out wireline spear. Spear was 100% full of balled injection line. 9/13/2004 00:00 - 02:00 2.00 FISH P DECOMP Made up new wireline spear. Tripped in hole to 4883'. 02:00 - 02:30 0,50 FISH P DECOMP Engaged chemical injection line and pushed to 5197'- estimated top of fish, Had 10,000 Ibs drag up. 02:30 - 04:30 2.00 FISH P DECOMP Pulled out of hole. Broke out wireline spear. Spear was 100% full of balled injection line, 04:30 - 06:30 2.00 FISH P DECOMP Made up new spear. Tripped in hole to top of fish at 5197'. 06:30 - 07:00 0.50 FISH P DECOMP Worked spear 07:00 - 09:00 2.00 FISH P DECOMP Pooh out of hole, Broke out wireline spear. Recovered +/- 50' of injection line. 09:00 - 10:30 1.50 FISH P DECOMP Made up new spear. Tripped in hole to 4598'. 10:30-11:00 0.50 FISH P DECOMP Serviced rig. 11:00 - 11:30 0.50 FISH P DECOMP Tripped in hole to top of fish at 5197'. Worked spear. 11:30 -13:30 2.00 FISH P DECOMP Pulled out of hole to BHA. 13:30 - 14:30 1.00 FISH P DECOMP Laid down BHA. No recovery on spear. 14:30 - 15:00 0.50 FISH P DECOMP Cleared floor. 15:00 - 16:30 1.50 FISH P DECOMP Made up short catch overshot. Tripped in hole to 5197'. 16:30 - 17:00 0.50 FISH P DECOMP Engaged fish with overshot. Verified with 15000 Ibs overpull. 17:00 - 20:00 3.00 FISH P DECOMP Rigged up slickline unit. Tested lubricator to 1000 psi. 20:00 - 22:30 2.50 FISH P DECOMP Ran 2.75 impression block, Unable to work thN safety valve. Started running 2.5" impression block. Schlumberger became concerned about getting wireline fish past smaller block. Pulled Printed: 912712004 10:02:26 AM ~ ~ BP EXPLORATION Page 3- Operations Summary Report Legal Well Name: 15-26 Common Well Name: 15-26B Spud Date: 12/25/1991 Event Name: REENTER+COMPLETE Start: 8/17/2004 End: 9/26/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/26/2004 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations , 9/13/2004 20:00 - 22:30 2.50 FISH P DECOMP LIB. Broke out TlW valve. Installed swab valve and tested with 1000 psi top and 500 psi below. 22:30 - 23:30 1.00 FISH P DECOMP Ran 2.75 impression block with brush sub, Tagged top of fish at 5206' WLM. Worked into top of fish. Tools stopped at 5226' WLM. Pulled impression block. Had small marks on bottom possibly indicating junk from injection line or parted wireline, Had no indication of top of bait sub left in hole. 23:30 - 00:00 0.50 FISH P DECOMP Ran in hole with wireline grab, brush sub and bait sub, 9/14/2004 00:00 - 02:00 2,00 FISH P DECOMP Ran in hole with wireline grab, brush sub and bait sub. Tagged obstruction at 5026', Worked down and pushed down 6' with slight drag up. Obstruction worked free with no drag, Ran in hole to 8276' WLM (possible top of XN plug), checking pick up weight every 100'. Pulled back up and worked thru spot at 5026' several times w/o drag. Pulled out of hole. No recovery on spear. 02:00 - 03:30 1,50 FISH P DECOMP Made up 2.75" impression block with brush sub, Ran in hole to 8276' to check for junk on top of plug, Pulled impression block. Had good impression of clean XN plug top. 03:30 - 05:00 1.50 PULL P DECOMP Made up equalizing assembly. Ran in hole to equalize pressure accross plug, Attempted to hold pressure on tubing w/o success, Circulated down Dp with 200 psi. Unable to get a pressure or rate change to indicate that plug was equalizing. Pulled tool. Marks on tool showed that equalizer prong had gone down inside XN plug. 05:00 - 07:00 2.00 PULL P DECOMP Run in hole with GR retrieving tool for XN plug. Latch onto XN plug. Attempt to pull free. POH with GR tool - no plug, 07:00 - 10:30 3,50 PULL P DECOMP Run in hole with GR retrieving tool for XN plug, Latch onto XN plug. Jar plug free, POH with GR tool and XN plug 10:30 - 13:00 2.50 PULL P DECOMP PJSM. RU Schlumberger E-line. 13:00 - 15:00 2.00 KILL P DECOMP Rig up to reverse circulate, Reverse circulate - 5 bpm, 350 psi for 3000 strokes (135 bbls). Shut in and flow check the well - stable. 15:00 - 18:00 3.00 PULL P DECOMP RIH with SLB chemical cutter and cut the 3-1/2" 9.2# 13Cr tubing below GLM # 7 @ 8,200' ELM. POH. RD SLB wireline. 18:00 - 18:30 0.50 PULL P DECOMP Pull on the 3-1/2" string in an attempt to pull from the cut. Applied 20K overpull to the string and PU weight went to hanging string weight of 135K, 18:30 - 19:30 1.00 PULL P DECOMP Circulate botoms up. Flow check - stable, 19:30 - 21 :30 2.00 PULL P DECOMP POH from 5,211' to the overshot. 21 :30 - 22:00 0.50 PULL P DECOMP Break and LD short catch overshot, cut joint, GLM #2, 6.05' of parted pup joint - total length 14,69'. 22:00 - 22:30 0.50 FISH P DECOMP MU 3.77' 8-3/8" OD overshot, 1.6' extension, 3.26' extension and XO, 22:30 - 00:00 1.50 FISH P DECOMP RIH with overshot assembly to top of parted tubing stub @ 5,211'. 9/15/2004 00:00 - 03:00 3.00 FISH P DECOMP Attempt to engage fish. Slowly rotated the overshot over the top of the stub. Tubing stub took an intermittent weight of - 5K while attempting to engage. Stopped rotation and downward movement of the overshot - believe the tubing was collapsing while trying to engage. POH and check the overshot. Pulled out -8' of balled up chemical injection line in the bottom of the overshot. LD Overshot and extensions. Clear floor. 03:00 - 04:30 1.50 FISH P DECOMP Service the top drive and slip and cut drilling line. Printed: 9127/2004 10:02:26 AM ~ ~ BP EXPLORATION Page 4 - Operations Summary Report Legal Well Name: 15-26 Common Well Name: 15-26B Spud Date: 12/25/1991 Event Name: REENTER+COMPLETE Start: 8/17/2004 End: 9/26/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/26/2004 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/15/2004 04:30 - 06:30 2,00 FISH P DECOMP MU Washover Fishing BHA w/Guide Shoe, Rolling Dog Sub, 2 x joints washpipe, pup joint, boot basket, bumper sub, jars, 9 x drill collars to 376'. 06:30 - 08:30 2.00 FISH P DECOMP RIH with fishing BHA on 5' DP to 5,213', PU - 150K 08:30 - 09:30 1.00 FISH P DECOMP Engage fish @ 5,213'. Swallow 42' of fish to 5,255'. Latch fish. PU - 175K. 09:30 - 10:30 1.00 FISH P DECOMP Circulate bottoms up at the chemical cut depth - 8,200' ELM. 12 bpm, 600 psi. Monitor well - stable. Blowdown the top drive. 10:30 - 12:30 2.00 FISH P DECOMP POH standing back 5' DP and 9 drill collars from 8,200' (ELM) to 3,045', 12:30 - 13:00 0.50 FISH P DECOMP LD jars. bumper sub and boot basket to 3,025'. 13:00 - 14:00 1.00 FISH P DECOMP RU 3-1/2' tubing handling equipment. Cut chemical injection line and rig up Camco spooling unit 14:00 - 15:00 1.00 FISH P DECOMP Back out 3-1/2' tubing from washpipe & rolling dog sub. LD remaining fishing tools to 2,945', 15:00 - 19:00 4,00 FISH P DECOMP LD 3-1/2' completion string from chemical cut from 2,945' to surface. Recovered parted 4.75' corroded L-80 pup, 86 joints of 3-1/2' L-80, 3 joints of 3-1/2' 13Cr, 5 GLM's, 10 SS bands, 91 clamps w/pins and 23,3' cut 13Cr joint. Also recovered slickline fishing tools (bait sub, wire brush, 2 prong wire grab) left in the hole during pre-rig work. 19:00 - 20:00 1.00 FISH P DECOMP Clear and clean the floor. Remove Camco spooling unit. 20:00 - 20:30 0.50 FISH P DECOMP MU Spear BHA #3, Rope Spear, drain sub, bumper sub, oil jar, 9 x drill collars, xo to 313' 20:30 - 22:30 2,00 FISH P DECOMP PU 4" HT40 DP from 313' to 3,397'. 22:30 - 00:00 1.50 FISH P DECOMP RIH with 5' DP from 3,397' to 6,700' 9/16/2004 00:00 - 00:45 0.75 FISH P DECOMP RIH with Spear BHA #3 on 5' DP from 6,700' to 8,198', PU- 195K, SO - 175K, Tag up on 3-1/2' tubing stub @ 8,198'. 00:45 - 02:00 1.25 FISH P DECOMP Circulate bottoms up @ 12 bpm - 1,000 psi. Blow down top drive. 02:00 - 05:30 3,50 FISH P DECOMP POH with 5' DP from 8,198' to 3,397'. Change out handling equipment. POH w/4' DP from 3,397' to 311'. Stand back 9 drill collars, POH with jars, bumper sub, drain sub and spear. Upper half of the spear had slickline wrapped around it with the lower half clean. 05:30 - 06:00 0.50 FISH P DECOMP LD Spear and section of balled up slickline. Clear the floor. 06:00 - 06:30 0.50 FISH P DECOMP MU Spear BHA #4 - rope spear, 2 x xo, drain sub, bumper sub, jars, 9 x drill collars, xo - to 307'. 06:30 - 07:30 1.00 FISH P DECOMP RIH with Spear BHA #4 on 4' DP from 307' to 3,492' 07:30 - 08:30 1.00 FISH P DECOMP Lubricate the rig and service the top drive. 08:30 - 10:30 2.00 FISH P DECOMP RIH with 5' DP from 3,492 to 8,184'. PU -195K, SO -185K. 10:30 - 11:00 0,50 FISH P DECOMP RIH from 8,184' to tag the top of the 3-1/2' tubing stub @ 8,200'. Looked to be pushing something ahead. Worked the spear and saw no dmg. Monitor the well - stable. Slug pipe and blow down the top drive. 11 :00 - 14:45 3.75 FISH P DECOMP POH with 5' DP from 8,200' to 3,492'. POH with 4' DP from 3,492' to 307'. Stand back BHA, Break and LD Spear assembly - no wire recovered. 14:45 - 15:30 0.75 FISH P DECOMP MU Double Bowl Overshot BHA - double bowl overshot, xo, bumper sub, jars, 9 x drill collars, accelerator jars, xo - to 322'. 15:30 - 18:30 3.00 FISH P DECOMP RIH with Spear BHA #4 on 4' DP from 322' to 3,405'. RIH with 5' DP from 3,405 to 8,200'. PU - 195K, SO - 190K. Printed: 912712004 10:02:26 AM ~ ~ BP EXPLORATION Page 5- Operations Summary Report Legal Well Name: 15-26 Common Well Name: 15-26B Spud Date: 12/25/1991 Event Name: REENTER+COMPLETE Start: 8/17/2004 End: 9/26/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/26/2004 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/16/2004 18:30 - 19:00 0.50 FISH P DECOMP Slowly rotated ahead with pumps on - 4.5 bpm, 200 psi. Observed a pressure increase of 150 psi when going over the top of the 3-1/2' tubing stub. Swallowed 5' of the fish, PU on the fish - free - 10K additional weight. 19:00 - 20:00 1.00 FISH P DECOMP Circulate bottoms up. Monitor the well - stable. 20:00 - 23:00 3,00 FISH P DECOMP POH standing back 5' DP from 8,200' to 3,405' (at 18 stands of 5' out, rotated 10 turns to the right in an attempt to hook remaining wireline fish - no additional drag seen), POH standing back the 4' DP from 3,405' to 322'. 23:00 - 00:00 1.00 FISH P DECOMP LD Fishing BHA to the top of the overshot - 322' to 11' 9/17/2004 00:00 - 01:00 1.00 FISH P DECOMP LD overshot and 20' cut joint. 01:00 - 02:30 1.50 FISH P DECOMP Clean and clear the floor. Change out the handling equipment for 3-1/2' 13CR 9.2# tubing. 02:30 - 05:00 2.50 FISH P DECOMP Hold PJSM. LD remaining 3-1/2', 9,2#, 13Cr, Fox from 1,705' to surface. Recovered 41 joints 3-1/2', 9.2#, 13Cr tubing + 20' cut joint and overshot. 05:00 - 06:00 1.00 FISH P DECOMP Rig down the tubing handling equipment and clear the floor. 06:00 - 07:30 1.50 FISH P DECOMP MU Spear BHA #5 to 327' - rope spear, drain sub, string magnet, xo, 2 x boot basket, XO, bumper sub, jar, 9 x drill collars, XO, 07:30 - 08:30 1.00 FISH P DECOMP RIH with Spear #5 BHA on 4" DP from 327' to 3,410'. 08:30 - 09:30 1.00 FISH P DECOMP Slip and cut drilling line, 09:30 - 10:30 1.00 FISH P DECOMP RIH with 5' DP from 3,410' to 8,278'. 10:30 - 11:00 0.50 FISH P DECOMP Circulate at the 7' liner top @ 8,278'. Set down 5K and rotate. PU with no over pull. Repeat 4 times without additional overpull. 11 :00 - 11 :30 0.50 FISH P DECOMP Circulate bottoms up. 11:30-14:30 3.00 FISH P DECOMP POH with 5' DP from 8,278' to 3,410'. POH with 4' DP from 3,410' to 327'. 14:30 - 16:30 2.00 FISH P DECOMP LD Spear BHA #5 from 327', No recovery of any fish. Clear the floor. 16:30 - 18:30 2.00 FISH P DECOMP MU Mill and Scraper BHA to 1,050' - mill, 2 x boot baskets, scraper, XO, bumper sub, jar, 3 x drill collars, string magnet, 9 x drill collars, 21 x hwdp, XO. 18:30 - 19:30 1.00 FISH P DECOMP Lubricate rig and service the top drive. 19:30 - 23:00 3.50 FISH P DECOMP RIH with 4' DP from 1,050' to 4,132'. PU 4' DP from 4,132' to 5,069', Change out elevators, RIH with 5' DP from 5,069' to 9,886'. Observed intermittent drag from 9,150' to 9,839'. Set down @ 9,839'. Worked pipe and got obstruction to move down to 9,886' and then had no further progress. 23:00 - 00:00 1.00 FISH P DECOMP Circulate bottoms up - 13 bpm, 3,300 psi. 9/18/2004 00:00 - 04:00 4.00 FISH P DECOMP Pump dry job. POH with 5' DP from 9,886' to 5,069'. Change out the handling equipment. POH with 4' DP from 5,069' to 1,050'. No additional drag seen on trip out of the hole. 04:00 - 06:00 2,00 FISH P DECOMP LD Mill and Scraper BHA from 1 ,050' - standing back drill collars and HWDP, Clear the floor. Small section of wire recovered in boot basket. 06:00 - 10:30 4.50 PXA P DECOMP MU EZSV BHA, RIH on 4' DP to 4,687', Change out handling equipment. RIH on 5' from 4,687' to 9,875'. PU - 197K, 50- 185K. 10:30-11:30 1.00 PXA P DECOMP MU cement head pin and break circulation @ 3 bpm, 280 psi. Printed: 9/2712004 10:02:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/18/2004 9/19/2004 ~ ~ Page 6- BP EXPLORATION Operations Summary Report 15-26 15-26B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES 10:30 - 11 :30 From - To Hours DECOMP 11 :30 - 12:00 12:00 - 13:15 13:15 - 14:00 14:00 - 17:30 17:30 - 22:30 22:30 - 00:00 00:00 - 01:30 01 :30 - 05:30 05:30 - 06:00 06:00 - 06:30 06:30 - 07:30 07:30 - 14:00 14:00-15:30 15:30-16:00 Task Code NPT 1.00 PXA P 0.50 PXA P DECOMP 1.25 PXA P DECOMP 0.75 PXA P DECOMP 3,50 PXA P DECOMP 5,00 BOPSUF P DECOMP 1,50 STWHIP P WEXIT 1.50 STWHIP P WEXIT 4.00 STWHIP P WEXIT 0.50 STWHIP P 0.50 STWHIP P WEXIT WEXIT 1.00 STWHIP P WEXIT 6.50 STWHIP P WEXIT 1.50 STWHIP P WEXIT 0.50 STWHIP P WEXIT Phase Start: 8/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 12/25/1991 End: 9/26/2004 Description of Operations "" Set EZSV @~7~ Shear off EZSV with 48K Overpull, Establish ~~rates: 1 bpm - 40 psi 2 bpm - 130 psi 3 bpm - 340 psi 4 bpm - 560 psi 5 bpm - 920 psi Test the 9-5/8' x 7' casing to 3,500 psi and hold for 30 minutes - good test. Sting into the top of the EZSV@ 9,875'. se~wn K, Pumped 5 bbls fresh water ahead. Pumped 1.5 Is of 15,8 ppg + adds cement plug slurry. Pumped 5 resh water behind. Displace with the rig pumps with 130 bbls of seawater - under displaced. CIP - 1315 hours. Unsting from the EZSV and reverse circulate @ 8,5 bpm - 2,230 psi. POH with 5' DP from 9,875' to 4,672'. Change out handling equipment. POH with 4' DP from 4,672'. LD EZSV setting tool. Clean and clear the floor. MU test joint. Pull wear ring. Set test plug. Test BOPE and related equipment to 250 psi/3,500 psi and the annular to 250 psi/2,500 psi. Pull the test plug. Set the wear ring. RD the test joint. .,...1--- l-- Witness of the BOP test was waived by John Crisp of the AOGCC. MU Whipstock BHA to 108' - anchor, whipstock, window mill, lower watermelon mill, upper watermelon mill, 1 x HWDP, float sub, mwd. Download MWD tools and shallow test - good test. MU remaining Whipstock BHA to 1,128' - bumper sub, 12 x drill collars, 21 x HWDP, xo. RIH with whipstock on 4' DP from 1,128' to 5,147'. Change out handling equipment and RIH with 5' DP from 5,147 to 9,805', Fill pipe every 3,000'. Service the top drive and crown. Orient 60 degree~s. U - 200K, SO - 180K. Set anchor - - and shear lug @ ,8 Displace the well r to 8.4 ppg FloPro drilling fluid from seawater. 320 gpm - 1,250 psi. Mill 6-1/16' window from 9,859' to 9,871', Drill new formation to 9,885'. PU - 195K, SO - 175K. TO off - 4K, TO on - 7K. 318 gpm -1,350 psi. TOW - 9,859' BOW - 9,871' Circulate hi-vise sweep and bottoms up while cleaning up the window. 325 gpm - 1,375 psi. Pull into the casing and monitor the well - stable. Perform FIT to 10.0 ppg EMW with 8.4 ppg fluid and 735 psi surface pressure at 8,843' TVD. Good test. Pump a dry job and blow down the surface equipment. Remove the blower hose. Printed: 9/27/2004 10:02:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/19/2004 9/20/2004 9/21/2004 9/22/2004 9/23/2004 ~ ~ Page 7. BP EXPLORATION Operations Summary Report 15-26 15.26B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES 16:00 - 20:00 From - To Hours 4.00 STWHIP P 20:00 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 02:30 02:30 - 05:15 05:15 - 06:00 06:00 - 07:00 07:00 - 08:00 08:00 - 08:30 08:30 - 00:00 00:00 - 12:00 12:00 - 15:00 15:00-16:00 16:00 - 16:30 16:30 - 17:00 17:00 - 20:00 00:00 - 12:00 12:00 - 19:30 19:30 - 21:00 21 :30 - 23:00 23:00 - 00:00 00:00 - 01 :30 01:30 - 04:30 04:30 - 05:30 05:30 - 06: 06:00 - Q . 0 09: 11:00 - 12:00 12:00 - 13:00 13:00-16:30 Task Code NPT 2.00 STWHIP P 1.00 STWHIP P 1.00 STWHIP P 0.50 STWHIP P 2.00 STWHIP P 2.75 STWHIP P 0,75 STWHIP P 1.00 STWHIP P 1.00 STWHIP P 0,50 STWHIP P 15,50 DRILL P 12.00 DRILL P 3,00 DRILL P 1.00 DRILL 0.50 DRILL 0.50 DRILL 3.00 DRILL P P P P 12,00 DRILL P 7.50 DRILL P 1.50 DRILL P 1.50 DRILL P P P 0.50 DRILL 3.50 DRILL 1.50 DRILL 1.00 CASE 1,00 CASE 3.50 CASE P P P P P P Phase WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 RUNPRD RUNPRD RUNPRD Start: 8/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 12/25/1991 End: 9/26/2004 Description of Operations POH with 5. DP from 9,885' to 5,129'. Change out the handling equipment. POH with 4. DP from 5,129' to 1,110', LD Whipstock BHA from 1,110'. Mills in gauge, Clear the floor. ~ Flush the stack, rams, flowline and shakers, Service the wear ring MU 6. Drilling BHA to 175' - 6. Security FM2631 RR w/6 x 10's. 5. motor (1.5) 6/7 stage w/ABI,non-mag float sub, GR/Res, DM HOC, TM HOC, 3 x non-nag flex collars, circ sub, Continue MU remaining 6. Drilling BHA to 363' - 3 x HWDP, jar, 2 x HWDP. xo. Shallow test MWD - good test. RIH with 6. BHA on 4. DP from the derrick from 363' to 4,380'. Fill pipe every 3,000'. PU 4. DP from 4,380' to 8,211'. Fill Pipe every 3,000'. Change out handling equipment. RIH with 5. DP from the derrick from 8,211' to 9,734', Cut and slip 110' of drilling line. Adjust brakes. Service the top drive and change out the lube pump. Orient BHA to 60 RHS. Slide through window and ream under au e hole from 9,883' to 9,885', Drill 6. hole directionally from 9,885' to 10,630'. PU - 1 5K, SO - 160K, ROT - 175K. TO off - 5K. AST - 9,28, ART - 0,22, Drill 6. hole directionally from 10,630' to 11,632'. PU - K, SO - 160K, ROT - 175K, Circulated bottoms up at 325 GPM with 1850 '. Monitored well - static. Short tripped out from 11,632' to 9,85' ad no excess drag. Serviced rig and top drive, Tripped in from 9,859' to 11,6 . No problems, Directionally drilled 6. hol om 11,632' to 11,917'. PU - 190K, SO - 160 K, RT - 178 . Directionally drill. hole from 11917' to 12700', Sliding for right hand tu . PU - 190K, SO - 160K, RT - 180K Directio y drilled 6. hole from 12700' to 13345' TMD. Sliding for' t hand tum and angle drop. PU - 190K, SO - 160K, RT- K Pumped 50 BBL high viscosity sweep and circulated bottoms up. Short tripped 20 stands from 13345 to 11537'. Had 20,000 Ibs overpull at 12545' and 12790'. Tripped back in to 13345' TMD. Had 15000 Ibs drag at 13025'. Pumped 50 BBL high viscosity sweep, Circulate bottoms up. Circulated high viscosity sweep. Spotted 130 BBLS of clean liner running pill. Laid down 5. DP from 13345' to 9829'. (111 stands) Dropped wiper/rabbit dart and displaced to circulating sub, Sub did not shear. Pulled one stand. Unable to shear sub. Pump dry job. Pulled wet pipe to 9450'. Opened circulating sub. Tripped out of hole to BHA to 363'. Laid down BHA. Flushed out MWD. Cleared floor. Rigged up liner running equipment. Held PJSM. Picked up float equipment. Checked floats - okay. Picked up 106 joints of 41/2.12.6# L-80 BTC-MOD casing to Printed: 9/2712004 10:02:26 AM ~ ~ ~lr~lrŒ lID~ ~~~~[ß~ / / A IfASIiA. OIL AND GAS / CONSERVATION COMMISSION / / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 August 23, 2004 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 "f)~ Re: Prudhoe Bay 15-26A 304-319 Dear Crane: 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. 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 ofthis letter, or the next working day if the 23rd day falls on liday or weekend. Enclosure ~ ~ W61t. ! (1'1 ( l..DC)Cf or! lfJ If) f/-- RECEIVED AUG 1 7 2004 I1llUka Oil & Gas Cons, Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SU N DRY APPROVAL 20 MC 25.280 1. Type of Request: B Abandon 0 Repair Well B Plug Perforations 0 Stimulate 0 Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 68' 4. Current Well CI,š-: IBI Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To ~I Number 197-017 6. API Number: / 50- 029-22235-01-00 99519-6612 9. Well Name and Number: PBU 15-26A ./ 8. Property Designation: 10. Field / Pool(s): ADL 028306 Prudhoe Bay Field / Prudhoe Bay Pool 11. .. . PRESENT WaL CONDITION SUMMARY. Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 12483 8898 12483 8898 None . L' " . ~ ".. ~:]I T\/n . BÙI'St . Junk (measured): None 3510' 8557' 13-3/8" 9-5/8" 3510' 8557' 3509' 8305' 3450 6870 1950 4760 Liner Liner 2042' 1521' 1033' 7" 4-1/2" 2-3/8" 8288' - 10330' 10028' - 11549' 11450' - 12483' 8134' - 8899' 8877' - 8914' 8915' - 8898' 8160 8430 7020 7500 Liner Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: 10050' - 12452' 8880' - 8898' 3-1/2",9.2# Packers and SSSV Type: 3-1/2" Camco 'TRDP-2A-SSA' SSSV Nipple Tubing Grade: I Tubing MD (ft): 13Cr 10028' Packers and SSSV MD (ft): 2197' 12. Attachments: IBI Description Summary of Proposal 0 Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Reoresentative: 17. I hereby certify that tl)é foregoing is true and correct to the best of my knowledge. Printed Name Lo'¥" Crane Title Senior Drilling Engineer Sian~ ~ /~ - Phone 564-4089 Date ~ 'I'-J~ {/ . .. .. . . ,~ Conditions of approval: Notify Commission so that a representative may witness 0 BOP Sketch 13. Well Class after proposed work: 0 Exploratory IBI Development 0 Service August25,2004 Date: 15. Well Status after proposed work: 0 Oil 0 Gas 0 WAG 0 GINJ 0 Plugged / IBI Abandoned 0 WINJ 0 WDSPL Contact Phil Smith. 564-4897 Prepared By NamelNumbe~ Terrie Hubble, 564-4628 ".'" ... I Sundry NumberSoÇ/- 3/9' 0 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ArJprol/e d Çó ý W\.. 10 - 40 l ~~tM'N'J Other: 60 p£ test-... fre~~'l~ is sNel-L (,v~du -\-Lv{ c.. \if- 4o~, SO_",", F";"",~; <\ 0 ì . Approved II ~ ~ [)t Form 10-403 ~ ...".-- n ,D. Lo~tion Ç;learance . { I - t.ø 1> -\..P (' ~ cle fý~K- W-i l s. 2. c , d ~ ç L Y Î Hi CJ¡'w¥C"Lh 1'1,<;' Ctf P J 0 1,/tJ j .... Bf L AU6 ~~) IlIU~ COMMISSIONER APPROVED BY THE COMMISSION Date &; 't3 It, l/ ,,- Sðbmit IrfDupllCate ORiGiNAL /"' ~ To: Winton Aubert - AOGCC Date: August 13, 2004 From: Phil Smith - BPXA GPB Rotary Drilling Subject: Reference: DS15-26A Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-22235-01 Approval is requested for the proposed P&A of PBU well DS15-26A. A PDS caliper run in April 2003 / indicated damage severe enough to warrant a tubing replacement to put the well back into service. At the time that the annular communication was identified, the well was making 650 BOPD at a GOR of 34,200 / (22 MMSCFD), with approximately 220 MBO (black) remaining reserves. A RWO was judged to be uncompetitive and a rig ST found to be the well's best option. This well targets the Western part of DS15 immediately to the West of the DS15 facilities. The sidetrack is currently scheduled for Nabors rig 2ES, beginning around September 101h, 2004, after the completion of the 15-26B sidetrack. The pre-rig work for this sidetrack will begin at the Well's Group earliest convenience after sundry approval. Current Condition: .¡' Confirmed badly corroded tubing with Kinley caliper log 4/26/03. Kinley log nearly stuck at 5180'. .¡' Left XXN plug in XN nipple 4/26/04. Plug did not pass pressure test. .¡' Passed PPPOT-IC to 3000 psi and tubing to 5000 psi on 4/12/04 .¡' Failed combo MITlAxT 7/29/04, possible tubing plug or liner top/packer leak. Scope Pre-RiQ Work: 1. RU Slickline and pull the tubing plug from the XN nipple at 8276'. Drift to as close to the top of 4 W' liner at 10,028' MD as hole inclination will allow (-70° at 9500'). 2. Fluid pack as necessary for cement plug. 3. R/U and RIH with coil tubing and spot an LCM pill in the liner. 4. R/U E-line. RIH with tubing punch and punch holes in the center of the first full joint of tubing above /" the deepest allowable wireline depth (:t9400'). 5. Displace the well to clean seawater by circulating down the tubing through the punched tubing holes. Freeze protect to -2,100' MD with diesel. 6. Bleed casing and annulus pressures to zero. 7. Cycle the tubing hanger LDS. 8. Set a BPV and test to 1000 psi from tubing annulus. Secure the well. Level the pad as necessary. RiCl ODerations: 1. MI I RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displac ell to seawater. Set BPVrrWC. 3. Nipple down tree. Nipple up and test BOPE to ,5 si. Pull BPVrrWC. 4. R/U. Pull 3 W' tubing from the seal assembly ,028'. 5. RIH wI 6" bit I memory CNUGR and 7" casing scraper to top of 4 W' liner. POH, download CNL data. 6. RIH with 7" cement retainer and set at :t99~.0 lIow for a 9900' whipstock KOP. Fully cement the liner below the retainer (estimated volume 2 bls). 7. Pressure-test the 9 5/8" casing to 3,500psi r 30 minutes. Record test. Tlt ~ I 0 ~ 40) ~ p KJ\JO\.I. DS15-26A Application for Sundry ~ ,,--... ~ 8. P/U and RIH with 7" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. 9. Displace the well to 8.4 ppg Flo-Pro milling I drilling fluid. Completely displace the well prior to beginning milling operations. 10. Mill window in 7" casing at :t 9,900' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 11. Pull up into 9 5/8" casing and conduct an FIT to 10.5 ppg EMW. POOH. 12. M/U 6" Dir/GR/Res/ABI assembly. 13. RIH, drill build and horizontal section to planned TO, short trip andlor bit trip as necessary. 14. Circulate, short trip, spot liner running pill, POOH. 15. Run and cement a 4 W', 12.6#, L-80 solid production liner. POOH UD all drill pipe. 16. RIH with 2 7/8" perf guns and perforate :t1000'. 17. R/U and run 41/2",12.6#, 13Cr-80 completion tubing. Land the tubing RILDS. 18. Set a TWC and test to 1000 psi 19. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. 20. Reverse circulate inhibited seawater to the packer depth. Set packer and individually test the tubing and annulus to 3,500psi 30 minutes. Record each test. 21. Shear the DCK valve and freeze protect the well to -2,100'. Secure the well. 22. Rig down and move off. Post-RiQ Work: 1. Install well house and instrumentation 2. MI I RU slick-line. Pull the ball and rod I RHC plug from landing nipple below the production packer. Install gas lift valves. 3. POP well to test unit until cleaned up. Estimated Pre-rig Start Date: Estimated Spud Date: 08/25/04 09/10104 Phil Smith Operations Drilling Engineer 564-4897 DS15-26A Application for Sundry TREE = FMC GEN 4 ~ WELLHEAD = McEVOY ACTUATOR = AXELSON KB. ELEV = 68' BF. ELEV = ? KOP= 6969' Max Angle = 94 @ 11863' Datum MD = 9967' DatumTVD= 8800' SS 15-26A 113-3/8" CSG, 68#, K-55, ID = 12.415" I . TOPOF 13-3/8" CSG I 113-3/8" CSG, 68#, L-80, ID = 12.415" I Minimum ID = 1.995" @ 11481' TOP 2-3/8" LN R 13-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" 1 I TOP OF 3-1/2" TBG I I TOP OF 7" LNR 1 9-5/8" CSG, 47#, L-80, ID = 8.681" I 13-1/2" TBG, 9.2#, 13-CR, .0087 bpf, ID = 2.992" l-i I TOP OF 4-1/2" LNR H 10028' I 10028' I I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I I TOPOF4-1/2"LNR-SLTO I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I I TOP OF 2-3/8" LNR I 4-1/2" LNR- SLTD H 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I~ 11481' I 11525' :---j 11549' r--- ~ 'ETY NOTES: 70° @ 9507' & 90° @ 10962' CHROMETBG 2197' 3-1/2" CAMCOTRDP-2A-SSA SSSV NIP, ID = 2.81" GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 1 3206 3205 1 MMG-2 RK 2 5206 5205 1 MMG-2 RK 3 6517 6515 4 MMG-2 RK 4 7515 7494 17 MMG-2 RK 5 7888 7826 32 MMG-2 RK 6 8010 7926 39 MMG-2 RK 7 8168 8045 42 MMG-2 RK -i 3-1/2" OTIS XN NIP, ID = 2.75" ~ 8276' 10018' 10028' 10038' 11450' -i 3-1/2" TIVV OVERSHOT SEAL ASSY 1 -i 3-1/2" TBG TAIL 1 H ELMD TT NOT LOGGED I -i 4-1/2" PORTED JOINT (38.61') I "G" LNR TOP- 3-1/2" GS FISHNECK LNR TOP SUB W/30' OF 3-1/2 TBG BELOW 11481' H 2-3/8" X 3-1/2" XO I ÆRFORATION SUMMARY REF LOG: GRlCCL ON 06/20/92 ANGLE AT TOP PERF: 83 @ 10050' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-1/2" 6 10050 - 10320 0 03/14/00 4-1/2" 6 10244 - 11525 0 01/19/92 , , , , , , , , , , , , , , , , , , , , , , , ..<::::::::::....., 12-3/8" LNR, 4.6#, L-80, .00387 bpf, ID = 1.995" H 12451' ~,} TO H 12483' ~ DATE REV BY COMMENTS DATE REVBY COMMENTS 1992 ORIGINAL COMA-ErION 04/27/03 RLrrp ADD #7 GLV 05/07/97 SIDETRACK COMA-EriON 12/14/00 SIS-isl CONVERTED TO CANVAS 01/23/01 SIS-LG REVISION 03/01/01 SIS-MD FINAL 03/30/02 RNlTP CORRECTIONS PRUDHOE BA Y UNIT WELL: 15-26A ÆRMIT No: 1970170 API No: 50-029-22235-01 SEC 22, T11 N, R14E. 4078.66 FEL & 4836.85 FNL BP Exploration (Alaska) 15-~6B Proposed I ~NOTES' 1r{EE = FMC GEN 4 W8.LHEAD - McEVOY ACTUATOR = AX8.S0N KB. 8.EV = 68' BF. 8.EV = ? KOP- Max Angle - Datum MD - Datum 1VD = 8800' SS 1'3-318'CSG"68#"K-55.D~12.4'5. ~ 113-3/8" CSG, 68#, L-80, ID= 12.415" I ¡Minimum ID =3.725" @XN 3510' I TOP OF 7" LNR I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 14-1/2" TBG, 12.6.#, 13-CR. .0152 bpf, ID = 3.958"'-1 9753' ÆRFORA TlON SUMMARY REF LOG: ANGLE AT TOP ÆRF: Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-1/2" 6 10050 - 10320 S 03/14/00 4-1/2" 6 10244-11525 S 01/19/92 I Cement Retainer H I TOP OF 4-1/2" LNR H 10028' , I TOP OF 4-1/2" LNR- SLTD I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" l-i 11549' 9920' H 4-1/2" X NIP, ID = 3.813" 2100' GAS LIFT MANDR8.S ST MD 1VD DEV 1YPE VLV LATCH PORT DATE 4 3 2 1 H 4-1/2" X NIP, 10=3.813" 9675' 9695' 7" x 4-1/2" Baker S3 Packer 9720' 4-1/2" X NIP, 10=3.813" 9740' 4-1/2" XN NIP, 10 = 3.725" 9750' 4-1/2" LINER TOP / TBR 9753' 4-1/2" WLEG 1-1 7" Top of Window 4 1/2" Liner Shoe 4 1/2" Liner PBTD 13,283' 13,200' 11450' H "G"LNRTOP-3-1/2"GSFISHNECKLNR 1 11481' H 2-3/8" X 3-1/2" XO I ,'. ::.... , - ... , , .. ~, , ,...ii>~, , '4Y'~.t:' H 12451' I ~i I 2-3/8" LNR, 4.6#, L-80 DATE REV BY COMMENTS DATE REV BY COMMENTS 1992 ORIGINAL COMA-EriON 05/07/97 SIDETRACK COMA-ErION 12/14/00 SIS-isl CONVERTED TO CANVAS 08/09/04 PGS Proposed Rig Sidetrack PRUDHOE BA Y UNIT W8.L: 15-26B PERMIT No: 1970170 API No: 50-029-22235-02 SEC 22, T11 N, R14E, 4078.66 F8. & 4836.85 FNL BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, 4)~1~ Commissioner Tom Maunder, P. I. Supervisor DATE: May 15, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit DS 15 Tuesday, May. !..5,. 20.0..!: I traveled to BPXs Drill Site 15 and witnessed the safety valve system testing on cycle producers 15-6, 15-26 and 15-30. The above mentioned well had recently been cycled on production. All components functioned properly and passed their tests. Mike Hensel performed the testing today; he demonstrated good test procedures and was a pleasure to work with. Su. mm..ary_;. ! witnessed the testing of the safety valve systems on 3 cYcle producers at BPXs DS 15. PBU DS-15 3 well 6 components 0 failures Attachment: SVS Cycle PBU DS 15 5-15-01 CS Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS Cycle PBU DS15 5-15-01 CS Alaska Oil and Gns Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Mike Hensel AOGCC Rep: Chuck Scheve Submitted By: Chuck SCheve Field/Unit/Pad: Prudhoe / PBU / DS 15 Date: 5/15/01 Separator psi: LPS 174 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS o.r,CycLE. I~'-0iA ' ' 1982220 ' ' ' 15-02A ~ 1961630 ' ' ' ,............ i5-05 "i'820300 ............................ · 15-04 1820370 15-05A 19503~0 ............................... ' 15'-i)6A '" 1982540 ...... 174 ' 150 150 P p .......... CYCLE 15-67B'' 2000980 ........................ 15-08B ' 19~18~b ............................... 15'-09A 193'1386 .................................. 15-10A 1880850 15-1 i A..... 1'985480 .............................. 15'12A 2000610 15-13A 1991240 15-14 ~'18'11700 .......................... 15-15A 1982410 ..................................... 15-16 1840740 1 ~.~17 '1840890 ................................. 15.18 '" 1920660 ......................... i15-19A 1990990 iL20^' ' 1990480 ...................... 15'21A 1990290 ............ ' ~ " .15-22 1800970 15,23 ' 1911350 ................... 15-24 '' 1911580 .... ................ ' ......... 15-'253, 1~90860 ......................... 1970150 174 150 120 P P 'CYCLE 15-27 1920060 1'5-28 1920150 15-29 '1920350 .................................. 15'30 ..... 1920780 ..... i74 ' ' 3~0 250 '13 P ................. CYCLE 15-31 1920870 __ 15-32 1940470 1523A i990~'i)0 .............................. 15.34A" 2601370 ......................... · 15-35 1940880 15-36 1940720 ............... t .......... ;0067' 1~/~ ~/, ~ 2 20 Pa_'2. Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI , ,,psI ..... Trip C0d,e Code Code, Pass,ed ,, GAS or cYC,,LE,,, 15' 38 1941040 ~i5-~39 1941150 15-40A 1980980 15-42 1951850 15-42A 2000690 15-43 1960830 15-44 1961100 15-45 1960690 · 15-45A 2000680 15-46 1960610 ..................... 15-47 1951740 15-48 "1955080 ...................... 15-49A 2001130 Wells: ~. 3 Components: 6 Failures: 0 Failure Rate: 0.00% I-Ioo oar _,-, ,,,,,L ' _ ' - ' ........ ' Remarks: RJF 1/16/01 Page 2 of 2 SVS Cycle Wells PBU DS 15 5-15-01 CS THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE PL E M ATE IA L U W N D E R TH IS M ARK E R C:LORI~ILM.DOC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1027' FNL, 5076' FEL, Sec. 22, TllN, R14E, UM At top of productive interval 4526' FNL, 745' FEL, Sec.21, T11 N, R14E, UM At effective depth At total depth 4837' FNL, 4079' FEL, Sec. 16, T11 N, R14E, UM 5. Type of Well: Development __X Explorato~ Stratigraphic~ Service__ (asp's 676128, 5960457) (asp's 675272, 5956941) (asp's 671810, 5961826) Perforate _X Other_ 6. Datum elevation (DF or KB feet) RKB 68 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 15-26A 9. Permit number / approval number 197-017 10. APl number 50-029-22235-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length 12483 feet Plugs (measured) 8898 feet 12483 feet Junk (measured) 8898 feet OR GINAL Size Cemented Measured Depth True vertical Depth Conductor/Surface 3442' Production 8489' Liner 2042' Slotted Liner 1521' Pre-drilled Liner 1033' 13-3/8" 1425 Sx cs III &4co Sx Class G 3510' 3509' 9-5/8" 2858 cubic ft Class G 8557' 8305' 7" 528 cubic ft Class G 10330' 8899' 4-1/2" uncemented 11549' 8914' 2-3/8" uncemented 12483' 8898' Perforation depth: measured 10058' - 10328'; (1044' - 11525' slotted liner); (11481' - 12452' pre-drilled liner). true vertica18881' - 8899'; (8896'-8913'slotted liner); (8914'-8898'pre-drilled liner). RECEIVED Tubing (size, grade, and measured depth) . Packers & SSSV (type & measured depth) 3-1/2", 9.30 L-80 Tubing @ 10028' MD; 3-1/2",9.20 13CR Tubing @ 10028" MD. TIW Overshot Seal Assembly @ 10018' MD. 3-1/2" Camco TRDP-2AH SSSV @ 2197' MD. 28 Alaska 0il & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 992 Subsequent to operation 1224 Representative Daily Averaqe Production orlnjection Data Gas-Mcr W~er-Bbl 23979 0 15877 0 Casing Pressure Tubing Pressure - 605 1016 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ' ~'-~ '~ Title ARCO EngineeringSupervisor Signed ~,,,,~. ~:~,,~. Erin Oba - Date .~/Z ? / ¢ ~ Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 15-26A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 2/23/2000: 3/13/2000: .. RIH & drifted to 9490' SLM (HAW). MIRU work platform & CTU#5. PT'd equip to 3500 psi. RIH W/GR/CCL tools & logged well f/9250'- 10100' MD. Loaded well w/FIo Pro. POOH w/logging tools. RIH w/Coiled Tubing Conveyed perforating guns & shot 270' of Add Perforations to Zone 1 as follows: 10058'- 10328' MD (Zone 1) Reference Log: GR/CCL 6/20/1992. Used 2-1/2" carriers & all shots @ 6 SPF, random orientation, 60° phasing, & balanced pressure. POOH w/guns. ASF. FP'd well. RD. Placed 15-26A on production & obtained a valid welltest. RECEIVED 2 8 000 Aia~a 0il & Gas Cons. Commission Anchorage Page 1 AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA PLUS 97-017 SRVY RPT ~CHLLIM 11503-12483 10-407 ~COMPLETION D~TE @ Are dry ditch samples required? yes ~And received? Was the well cored? yes__.Analysis & description received? Are well tests required? yes ~ .... Received? Well is in compliance Initial COMMENTS Page: 1 Date: 05/24/99 RUN RECVD 08/22/97 ~?,/ ,/ yes yes~fo BOX 8/22/97 Ge'oQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11274 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, Al( 99501 Field: Prudhoe Bay (ANADRILL) MWD Floppy Well Job # Log Description Date Packet Disk D.S. 15-26A MWD DIRECTIONAL SURVEY 9705 07 1 At.J(; 2 2 1997 DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well Oil_X Gas__ Suspended__ Abandoned__ Service__ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 97-17 3 Address 8 APl Number P.O. BOX 100360, Anchorage, AK 99510-0360 _ 50-029-22235-01 4 Location of well at surface ~'~-~"~' 'r 9 Unit or Lease Name ~ ~,-. - ......... 1030' FNL, 202' FWL, Sec 22, T11N, R14E, UM ; ..... ' ,- ' 'a~,~,r~ PRUDHOE BAY UNIT At Top Producing interval ,~~.~.,~. ~' r; 4 m~~ 10 Well Number 757' FSL, 745' FEL, Sec 21, T11N, R14E, UM. i -~'"¢~'/~bT-CE-- ~")-~- i 15-26A J '¥'F~'~!FiED ! 11 Field and Pool At Total Depth 4838' FNL, 4080' FEL, Sec 16, T11N, R14E, UM.~ "~"--~ PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 68' RKB ADL 28306 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, ff offshore 16 No. of Completions 5/4/97 5/7/97 5/8/97 N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 12483' MD / 8898' TVD 12483' MD / 8898' TVD YES_X NO__ 2197' feet MD 1900' feet (approx) 22 Type Electric or Other Logs Run MWD, GR. 23 CASING, LINER AND CEMENTING RECORD SE'I-I'ING DEPTH CASING SIZE w-r. PER FT. GRADE TOP DO'I-rOM HOLE SIZE CEMENTING RECORD AMT PULLED 13-3/8" 68# K-55 Surf 3510' 16" 1425 Sx CS III & 400 Sx Class G - 9-5/8" 47# L-80 Surf 8557' 12.25" 2858 cult CS G - 7" 29# L-80 8288' 10330' 8.5" 528 cult CS G 4-1/2" 12.6¢ L-80 10028' - 11549' 6" Uncemented 2-3/8" 4.6# FL4S 11450' 12483' 2.75" Uncemented 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD 13-1/2" Tbg 10028' 10018' 4-1/2" Slotted Liner: 10244 - 11525' MD; 8896 - 8913' TVD. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 2-3/8" Pre-Drilled Liner: DEPTH INTERVAL MD AMT & KIND MATERIAL USED 11481 - 12452' MD; 8914 - 8898' TVD; (2) - 3/8" holes per ft. 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 5/11/97 Flowing Date of Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE I GOR 5/12/97 3 TEST PERIOD --I 1159 Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (corr) 335 24 HOUR RATE _X 2428 2815 120 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. *This 10-407 submitted as directed per the 10-401 ,ormapproYed2/S/97(,ssuedPermR#97-17).~.?~ ~'~.. ) : . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Sag River Shublik Sadlerochit GEOLOGIC MARKERS MEAS DEPTH 8478' 8553' 8672' TRUE VERT DEPTH 8173' 8192' 8223' FORMATION TESTS Include interval tested, pressure data, and fluids recovered and gravity, GOR, and time of each phase. N/A 31 LIST OF ATTACHMENTS Summary of 15-26A Coil Tubing Wellbore Extension Drilling Operations. 321 hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~ ~ ~ Engineering Supervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases. 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 15-26A DESCRIPTION OF WORK COMPLETED COILED TUBING WELLBORE EXTENSION DRILLING 5/1/97: MIRU Nabors 3S. 5/2/97: RU & NU BOP. C/O CTU reel. Standby for CTU. 5/3/97: MIRU CTU. PT BOPE. RIH w/2.8" milling BHA & loaded the wellbore w/!% KCI Water. Attempted to mill out the 2.75" XN Nipple at 8276' MD. Nipple washed out; reamed XN w/no motor work. RIH & tagged POB at 11552' MD. Attempted to mill POB; no progress. POOH w/BHA. RIH w/milling BHA. 5/4/97: Milled out the shoe at 11553' MD. Swapped well to FIo-Pro & POOH w/BHA. extension wellbore out the shoe to 11711' MD. RIH w/drilling BHA. Drilled 2.75" 5/5/97: Drilled to 11743' MD & staded losing 20 bph to formation. slowed to 3 bph. Drilled to 12062' MD. Swapped to new FIo-Pro & drilled to 11903' MD; losses 5/6/97: Drilled to 12092' MD & stuck pipe. Circulated crude & freed pipe. Drilled to 12381' MD. POOH w/BHA. Drilled to 12184' MD & swapped to new FIo-Pro. 5/7/97: RIH w/drilling BHA. Drilled to TD at 12483' MD. Backreamed sticky shales at 11790 - 11850' MD. POOH w/BHA. 5/8/97: MU & RIH w/pre-drilled 2-3/8" liner assembly. Landed liner at 12483' MD. PU & released liner to leave liner set at 11450 ~ 12483' MD. POOH displacing FIo-Pro w/Seawater & Meth-Water. ND BOPS. NU tree. RD CTU & MOL. Placed the well on production w/gaslift and obtained a valid welltest. 15-26A DIRECTIONAL SURVEY-- API500292223501 Survey Type: SINGLE SHOT Company: SPERRY SUN Survey Date: 1/15/92 Survey Top: 0' MD Survey Btm: 11,459' MD Kickoff Depth: 7,192' MD Max. Dogleg: 23.3°/100' @ 12,284' MD Survey Type: MEASURED WHILE DRILLING Company: ANADRILL Survey Date: Survey Top: 11,503' MD Survey Btm: 12,463' MD Avg. Angle below KOP: 790 Max. Angle: 94.30 @ 11,863' MD MD TVD SS INCLINE AZIMUTH DOGLEG ASPX ASPY 0 0.00 -68.00 0.00 0.00 494 494.00 426.00 0.30 36.90 974 973.99 905.99 0.60 68.10 1,446 1 445.98 1,377.98 0.50 286.30 1,942 1 941.81 1,873.81 2.58 21.90 2,269 2 2,589 2 2,907 2 3,225 3 3,449 3 4,006 4,463 4,937 5,412 5,889 6,080 6,430 6,746 6,969 7,192 7413 7 637 7 860 8 071 8 264 8 502 8743 8 837 8,931 9,028 9,124 8 9,219 8 9,313 8 9,402 8 9,507 8 268.56 2,200.56 2.00 56.40 0.5 588.40 2,520.40 1.78 92.20 0.4 906.26 2,838.26 1.60 102.40 0.1 224.15 3,156.15 1.38 101.50 0.1 448.09 3,380.09 1.38 120.80 0.2 005.02 3,937.02 0.40 124.60 0.2 462.02 4,394.02 0.10 167.40 0.1 936.02 4,868.02 0.20 119.20 0.0 411.00 5,343.00 0.85 68.80 0.2 887.91 5,819.91 1.50 9.10 0.3 0.0 676,128.5 5,960,456.7 0.1 676,129.2 5,960,457.7 0.1 676,132.3 5,960,459.8 0.2 676 132.5 5,960,461.3 0.5 676 134.4 5,960,472.3 676 141.6 676 151.2 676 160.5 676 168.6 676 173.6 676 181.1 676.182.5 676.183.3 676.187.3 676.191.4 O78.88 428.68 743.62 6 010.88 6 360.68 6 675.62 0.60 20.70 0.5 3.40 263.50 1.1 5.90 267.10 0.8 5,960,482.4 5,960,485.6 5,96O,484.6 5,960,483.1 5,960,481.3 6,964.63 7,183.48 7,397.15 7,606.13 7,801.92 7,973.72 8,117.03 6 896.63 7 115.48 7 329.15 7 538.13 7 733.92 7 905.72 8,049.03 9.30 268.50 1.5 12.80 278.30 1.8 16.78 288.00 2.1 25.20 281.50 3.9 31.88 282.10 3.0 39.00 282.60 3.4 45.08 287.80 3.6 8,272.64 8,204.64 53.20 292.10 3.7 8411.43 8,343.43 56.50 287.10 2.2 5,960,476.9 5,960,475.7 5,960,474.9 5,960,475.8 5,960,483.4 461.53 8,393.53 59.08 286.50 2.8 508.19 8,440.19 61.40 284.10 3.3 553.81 8,485.81 62.50 287.70 3.5 597.93, 8,529.93 62.78 287.50 0.4 640.42 8,572.42 64.08 288.80 1.8 679.79 8,611.79 66.40 288.20 2.5 714.22 8,646.22 68.08 287.60 2.0 751.52 8,683.52 70.30 286.70 2.3 676,192.1 5,960,486.8 676,182.4 5,960,487.1 676,156.9 5,960,484.6 676,127.5 5,960,482.9 676,085.0 5,960,485.0 676,030.1 5,960,497.1 675 952.0 5,960,514.8 675847.3 5,960,534.2 675 727.3 5,960,557.6 675 602.1 5,960,588.9 675 431.8 675 244.8 5,960,646.6 5,960,708.1 5,96O,729.3 5,960,749.0 5,960,770.5 675 168.1 675 088.9 675 006.1 674 924.2 674.842.9 674.761.4 674.682.7 674.588.3 674.5O5.O 674,417.3 674,328.1 674,239.0 674,148.4 5,960,794.4 5,960,819.0 5,960,844.1 5,960,867.5 5,960,894.2 9,598 8 780.86 8,712.86 72.08 285.60 2.3 5,960,916.2 9,693 8,808.34 8,740.34 74.30 287.80 3.2 5,960,940.3 9,789 8,832.62 8,764.62 76.40 287.30 2.2 5,960,966.3 9,884 8,853.20 8,785.20 78.58 287.30 2.3 5,960,991.7 9,980 8,870.30 8,802.30 80.90 288.40 2.7 5,961,018.6 10,074 8,883.22 8,815.22 83.30 286.10 3.5 674,058.9 5,961,044.1 Page 1 of 2 ..... 15-26A DIRECTIONAL SURVE' -J MD TVD SS INCLINE AZIMUTH DOGLEG ASPX ASPY 10,160 8,891.55 8,823.55 85.58 285.80 2.7 10,232 8 895.71 8,827.71 87.80 284.60 3.5 10,360 8 899.47 8,831.47 88.83 283.80 1.0 10,456 8 902.80 8,834.80 87.20 283.50 1.7 10,549 8 10,647 8 1 O,742 8 10,838 8 1 O, 933 8 10,962 11,017 11,091 11,185 11 278 11.365 11.395 11 459 11 503 11 581 11 608 11 623 11 643 11 663 11 683 11 7O3 11,731 11,767 11,797 11,824 11,863 11,883 11,903 11,923 11,943 908.32 8,840.32 86.00 284.00 1.4 915.39 8,847.39 85.72 284.30 0.4 921.56 8,853.56 86.83 283.80 1.3 925.54 8,857.54 88.42 284.20 1.7 927.35 8,859.35 89.40 283.70 1.2 8 8 8,924.53 8,920.55 8,917.63 927.54 927.08 8 915.82 8 859.54 8 859.08 8 856.53 8 852.55 8 849.63 8 847.82 89.83 284.00 1.8 91.12 285.20 3.2 92.83 286.30 2.8 92.02 284.50 2.1 91.58 286.50 2.2 90.80 285.40 1.6 673 976.1 673 906.3 673 781.5 673 687.8 673 597.1 673 501.8 673 409.4 673 315.8 673.223.1 673.194.8 673.141.2 673. O69.6 672.978.5 672.888.4 672.804.2 915.34 914.40 914.10 914.44 ,914.48 ,914.34 ,914.15 .913.91 ,913.34 912.51 911.55 910.64 910.13 909.57 8 847.34 8 846.4O 8 846.10 8 846.44 8 846.48 8,846.34 8,846.15 8,845.91 8,845.34 8,844.51 8,843.55 8,842.64 8,842.13 8,841.57 91.02 286.20 2.8 90.67 286.40 0.6 90.10 285.90 1.7 89.40 300.70 19.06 90.45 300.70 3.9 90.65 300.70 1.3 90.45 301.80 5.6 90.90 302.90 5.9 92.35 303.60 8.1 92.40 306.10 12.5 91.50 307.20 5.1 91.40 306.90 0.9 90.55 305.10 6.7 91.85 300.70 17.1 672 775.2 672,713.3 672 670.8 672 598.9 672 575.1 672.562.1 672.544.7 672 527.6 672 510.6 672 494.0 672 471.0 672 441.9 672 417.3 672,394.5 9O7.43 906.14 905.23 904.51 903.73 8,839.43 8,838.14 8,837.23 8,836.51 8,835.73 94.35 301.80 6.9 93.05 301.50 6.7 92.25 299.70 10.0 91.90 296.40 16.6 92.55 296.10 3.6 672,360.3 672,343.0 672,325.8 672,308.0 672,289.8 5,961,065.7 5,961,082.9 5,961,111.4 5,961,131.8 5,961,1 51.8 5,961,1 73.4 5,961,1 94.3 5,961,215.3 5,961 236.0 5,961 242.3 5,961 254.9 5,961 273.3 5,961 296.1 5,961,318.8 5,961 340.8 5,961.348.3 5,961 364.8 5,961 376.0 5,961 405.0 5,961 418.4 5,961 425.7 5,961 435.7 5,961,446.0 5,961,456.6 5,961,467.6 5,961,483.9 5,961,504.8 5,961,521.8 5,961,535.8 5,961,555.5 5,961,565.6 5,961,575.2 5,961,584.2 5,961,592.6 11 973 12 002 12.073 12.106 12 136 12 177 12216 12 243 12 284 12 313 12 343 12 378 12 403 12 433 8,902.62 8,901.43 8,897.36 8,895.63 8,894.48 8,893.26 8,892.22 8,891.81 8,892.18 8,893.12 8,834.62 8 833.43 8 829.36 8 827.63 8 826.48 8 825.26 8 824.22 8 823.81 8 824.18 8 825.12 91.70 293.90 7.9 93.00 291.60 9.1 93.57 286.00 7.9 92.43 286.60 3.9 91.95 288.10 5.2 91.50 291.00 7.3 91.50 293.50 6.3 90.25 295.00 7.3 88.70 304.30 23.34 87.65 299.30 17.31 672,262.4 672,235.4 672,167.8 672,136.0 672,107.0 672,068.6 672,031.5 672,006.9 671,971.3 671,945.9 8,894.46 8,896.09 8,897.15 8,897.95 8,826.46 8,828.09 8,829.15 8,829.95 87.25 303.30 13.4 87.40 306.10 8.0 87.75 307.90 7.3 89.20 311.50 13.0 671,920.0 671,890.8 671,870.4 671,847.0 5,961,604.6 5,961,61 5.2 5,961,636.5 5,961,645.0 5,961 653.3 5,961 665.9 5,961 680.1 5,961 690.5 5,961 709.6 5,961 724.6 5,961 739.5 5,961 758.7 5,961,773.4 5,961,791.9 Page 2 of 2 SURVEY REPORT Client: Field: Well Name: Permanent datum Depth measured from Drill Floor Elevation of kelly bushing Elevation of drill floor Elevation of ground level Magnetic Declination Grid Convergence Total Correction A.P.I. Number ARCO Prudhoe Bay 15-26a MSL 68 FT 68 FT 68 FT FT 28.57 DEG 0.00 DEG 28.57 DEG 50-029-22235-01 Date: TIE IN POINT Measured depth True vertical depth N/S disp (-ye for S) E/W disp (-ve for W) 11503.00FT 8846.10 FT 1000.20 FT -3435.20 FT Minimum Curvature Method Schlumberger ANADRILL Survey Rep 8-MAY-97 MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPTH DEPTH SECTION INCLN. N/-S FT FT FT FT DEG DEG FT 8 -May- 97 RECE%VED AUG 2 2 AJeska Oil & Gas Cons, Inclination 90.10 Azimuth 285.90 Azimuth from TIP to the target 318.10 Origin of Vertical Section TIP DEPARTURE DISPLA-at AZIMUTH E/-W CEMENT FT FT DEG DLS D/HF 11503.00 0.00 8846.10 0 90.10 285.90 1000.20 11580.75 77.70 8846.44 70.34 89.40 300.70 1030.85 11608.00 27.30 8846.48 96.39 90.45 300.70 1044.79 11623.00 15.00 8846.33 110.7 90.65 300.70 1052.44 11643.00 20.00 8846.14 129.84 90.45 301.80 1062.82 -3435.20 3577.85 286.23 0 -3506.36 3654.76 286.38 19.07 -3529.84 3681.21 286.49 3.85 -3542.73 3695.76 286.55 1.33 -3559.83 3715.10 286.62 5.59 11663.00 20.00 8845.91 149.09 90.90 302.90 1073.52 11683.00 20.00 8845.34 168.41 92.35 303.60 1084.48 11703.00 20.00 8844.51 187.86 92.40 306.10 1095.90 11731.14 28.10 8843.55 215.38 91.50 307.20 1112.66 11766.99 35.90 8842.64 250.61 91.40 306.90 1134.28 11~6.89 29.90 8842.14 279.84 90.55 305.10 1151.86 11823.65 26.80 8841.57 305.69 91.85 300.70 1166.41 11863.20 39.50 8839.44 343.43 94.35 301.80 1186.87 11883.23 20.00 8838.15 362.57 93.05 301.50 1197.34 11903.00 19.80 8837.23 381.43 92.25 299.70 1207.39 -3576.73 3734.36 286.71 5.94 -3593.45 3753.52 286.79 8.05 -3609.84 3772.53 286.89 12.49 -3632.37 3798.97 287.03 5.06 -3661.02 3832.71 287.21 0.88 -3685.20 3861.02 287.36 6.66 -3707.69 3886.83 287.46 17.12 -3741.41 3925.15 287.60 6.91 -3758.40 3944.51 287.67 6.67 -3775.43 3963.79 287.73 10.4 11923.00 20.00 8836.51 400.2 91.90 296.40 1216.77 11943.00 20.00 8835.73 418.75 92.55 296.10 1225.61 11973.00 30.00 8834.62 446.32 91.70 293.90 1238.28 12002.00 29.00 8833.43 472.5 93.00 291.60 1249.48 12073.00 71.00 8829.36 534.3 93.57 286.00 1272.32 12106.00 33.00 8827.63 562.3 92.43 286.60 1281.57 12136.20 30.20 8826.48 588.24 91.95 288.10 1290.57 12176.60 40.40 8825.26 623.7 91.50 291.00 1304.08 -3793.08 3983.46 287.79 16.09 -3811.00 4003.23 287.83 3.58 -3838.17 4032.97 287.88 7.86 -3864.89 4061.84 287.92 9.1 -3931.96 4132.69 287.93 7.92 -3963.59 4165.63 287.92 3.9 -3992.39 4195.81 287.91 5.21 -4030.44 4236.17 287.93 7.26 ORIGINAL 12216.34 12243.10 12283 .50 12313.00 12343.00 12378.00 12403.10 39.70 26.80 40.40 29.50 30.00 35.00 25.10 8824.22 8823.81 8824.18 8825.12 8826.46 8828.09 8829.15 659.42 683.92 722.2 750.49 779.18 813.19 837.79 91.50 90.25 88.70 87.65 87.25 87.40 87.75 293.50 295.00 304.30 299.30 303.30 306.10 307.90 1319.11 1330.11 1350.07 1365.61 1381.17 1401.07 1416.16 -4067.17 -4091.60 -4126.67 -4151.72 -4177.33 -4206.07 -4226.09 4275.74 4302.37 4341.90 4370.55 4399.74 4433.28 4457.06 287.97 288.01 288.12 288.21 288.30 288.42 288.53 6.3 7.29 23.34 17.31 13.39 8 7.3 12433.00 12463.98 PROJECTED 12483.00 29.90 31.00 19.00 8829.95 8830.29 8830.44 867.36 898.24 917.21 89.20 89.55 89.55 311.50 315.10 315.10 1435.25 1456.51 1469.97 -4249.09 -4271164 -4285.05 4484.94 4513.13 4530.18 288.66 288.83 288.93 12.98 11.67 0.00 Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349~4511 (907) 349-2487 (fax) May 7, 1997 Lan3' Grant Arco Alaska Inc. Anchorage, Alaska Mr. Grant Enclosed is a copy of the sun, ey program, and performance letter for 15-26a. Please let me know ffyou have any questions regarding this data. ' Bill Pen3' or myself can be reached at (907)-349-4511. Sincerely, Mark Brov, m Cell Manager, Arco CTU RECEIVED AUG 22 1997 Oil & Gas Cons, Commiss~ Anchorage Date: Well Name: Company: APIg: Location: Field: Rig: Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) May 7, 1997 15-26a Axco Alaska Inc. 50-029-22235-01 NSB, Alaska Prudhoe Bay Nabors 3-s / Dowel Anadrill Personnel: Field Crew: Cell Manager: Mark Bro~m Cell Engineers: Steve Barn~, Field Support: Alaska District Manager: Martin Varco Field Ser~4ce Manager: Bill Pen), SERVICES PROVIDED: MWD SHARP Gamma Ray Service Dates 5/3/97 to 5/7/97 OPERATING STATISTICS: Total MWD Pumping hours: Total MWD below rotary hours: Total MWD footage: Total MWD runs: 80 85 903 2 Depth Interval 11580'-12483' JOB PERFORMANCE: Directional: An open hole extension was performed at approximately 11580', using Sharp l~rD gamma my tools. A maximum angel of 93.57 degrees was recorded. The well was geosteered in the sand to a total depth of 12483'. Due to collar crocks in both bha's only 903' was drilled of the 1200' proposed. Measured depth: 12483.00' TVD: 8830.44' Target section: 917.21' Latitude: 1469.97 N Departure: 4285..05 W Shock: Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) Shock readings from the MWD tools enabled the engineers to evaluate downhole drilling conditions. No shocks were recorded on surface or dorm hole. Lessons Learned: Keeping track of total pumping hours on all tools, has lead us to believe that 120+ circulating hours on tools is too much and should be cut back to 80-100 hours. Anadrill appreciates the opportunity to provide Arco Alaska Inc. with MWD and LWD sen'ices. Sincerely, Bill Pen3' Field Service Manager Mark Brown Field Cell Manager MEMORANDUM TO: THRU: Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 2, 1997 FILE NO: ag81ebdf, doc FROM: John S pa uld ing, ~_~z~, SUBJECT: Petroleum Insp.0' BOPE Test Nabors / DS-3ES / CTD ARCO DS 15-42 PTD 97-17 Friday May 2, 1997: I traveled to ARCO's PBU DS-15-26A to witness the BOPE test on the Nabors / DS rig 3ES coiled tubing drilling unit. The AOGCC BOPE Test report is attached for reference. The blind rams failed to hold the pressure test and will be rebuilt and retested within 24 hours. The accumulator has 2 electric pumps, one high pressure, one Iow pressure. The high pressure pump had a malfunction on the reset. This item was immediately repaired and testing continued. Summary: I witnessed the BOPE test on Nabors / DS 3ES coiled tubing drilling unit- Test time 4.5 hours, 2 failures ~ Attachments: ag81ebdf, xls X Unclassified Confidential (Unclassified if document removed) Confidential STATE OF ALASKA OIL K~'D GAS CONSERVATION COMMIt:,--o'ION Coil Tubing Unit BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8" Test: Initial X Workover: Nabors/DS Rig No. 3ES PTD # ARCO Rep.: 15-26A Rig Rep.: Set @ 8, 667' md Location: Sec. Weekly Other DATE: 5/2/97 97-17 Rig Ph.# 448-1334 Eloy Muniz Mike Mooney 22 T. 11N R. 14E Meridian Umiat TEST DATA BOP STACK: Coil Tubinq Unit: Pipe/Slip Rams Pipe/Slip Rams Blind Rams Reel Isolation Valve Deployment: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kilt Line Valves Test Quan. Pressure P/F 250~4,000 P 250/4,000 P 250/4,000 P 250/4,000 P 1 1 I N/A N/A N/A N/A 1 250/4,000 P 2 250/4,000 P 1 250/4,000 CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Quart. Pressure P/F 14 250/4,000 P 37 250/4,000 P 1 P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: Functioned Functioned 2, 750 P 2,100 P minutes 18 3 minutes 18 yes Remote: 4 ea. @ 2000 avg. Psig. MUD SYSTEM: Visual Alarm MISC. INSPECTIONS: Trip Tank OK OK Location Gen.: OK sit Level Indicators OK OK Housekeeping: OK Meth Gas Detector OK OK · Permit to drill: YES H2S Gas Detector OK OK · Standing Order Posted OK sec. sec. yes Well Sign YES Drl. Rig OK Hazard Sec. OK TEST RESULTS Number of Failures: 2 ,Test Time: ~.5~ Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within 1 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Blind rams failed to test and will be rebuilt and retested, the accumulator electric pump did not function well on the high pressure side. Both items will be rebuilt and retested prior to commencing drilling operations. Distribution: orig-Well File c- Oper./Rig c- Database c- Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X' NO 24 HOUR NOTICE GIVEN YES X' NO Waived By: Witnessed By: John H. Spaulding Form Revised 2/20/97 L.G. AG8LEBDF.XLS 5/13/97