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181-168
BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 07, 2009 • by C?EC ~ ~0~9 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, ~~ is~-~~s i ~--~-9 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 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, Anna Dube, 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) DS-14 Date: 12/05/09 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na aI to-01A 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292031803 Sealed Conductor NA NA 14-03A 1961290 500292031901 Sealed Conductor NA NA t4-04A 1961640 500292032001 Sealed Conductor NA NA 14-OSA 1920010 500292032701 Sealed Conductor NA NA 14-06A 2040360 500292032801 Sealed Conductor NA NA 14-07 1780660 500292032900 Sealed Conductor NA NA 1a-OSA 2022100 500292033001 Sealed Conductor NA NA 14-09B 1820340 500292053402 Sealed Conductor NA NA 14-t0 1801300 500292052800 Sealed Conductor NA NA 14-11A 2051260 500292052901 Sealed Conductor NA NA 14-12 1811090 500292063100 Sealed Conductor NA NA 14-13 1811010 500292062400 Sealed Conductor NA NA 14-14 1811020 500292062500 Sealed Conductor NA NA 14-15 1810840 500292061100 Sealed Conductor NA NA 14-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 14-188 2071290 500292055102 Sealed Conductor NA NA 14-19 1810450 500292057800 Sealed Conductor NA NA 14-20 1810700 500292059800 Sealed Conductor NA NA 14-21A 2051070 500292075601 Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20/2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 14-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25/2009 is-28 1820120 500292070800 Sealed Conductor NA NA 14-29 1811680 500292068000 Sealed Conductor NA NA 14-30 2050940 500292067901 Sealed Conductor NA NA 14-31 1831110 500292098900 Sealed Conductor NA NA 14-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 14-35 1831420 500292101800 Sealed Conductor NA NA 14-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 14-37 1880490 500292181000 NA 1.3 NA 5.10 10/20/2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 14-4oA 2011350 500292187501 Sealed Conductor NA NA 14-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11/24/2009 ~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION F~~ ~= ~~~~ REPORT OF SUNDRY WELL 1. Operations Performed: ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 181-168 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20680-00-00 7. KB Elevation (ft): 71, _ 9. Well Name and Number: PBU 14-29- 8. Property Designation: ~ 10. Field /Pool(s): , ADL 028312 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9560 ' feet true vertical 9324 ~ feet Plugs (measured) None Effective depth: measured 9250 feet Junk (measured) 8550', Multiple true vertical 9027 .feet Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 76' 76' 1490 470 Surface 2600' 13-3/8" 2600' 2600' 4930 2670 Intermediate 8857' 9-5/8" 8857' 8653' 6870 4760 Production Liner 1026' 7" 8534' - 9560' 8347 - 9324' 8160 7020 ~~~ ~E~ ~ 2D0~ Perforation Depth MD (ft): 8898' - 9188' Perforation Depth TVD (ft): 8692' - 8968' 4-1/2", 12.6# 13Cr80 8428' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1 /2" Baker 'S-3' packer ~ - ~ ~- ° "~ ~ 8309' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. 1 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 David Reem, 564-5743 307-338 Printed Name Terrie Hubble Title Drilling Technologist S e c1 Q Prepared By Name/Number: ~~t ~ ignature Phone 564-4628 Dat o Terrie Hubble, 56a-4628 OPERATIONS~tAtwks Ai! & 6s~ ~~~~* ~~~ At~c~ltit . ; R,~f Form 10-404 Revised 04/2006 ~/ -~ Submit Original Only ~ ~~~. ~~: a ~ '_ ~00~ a ~I:~~~~~ Well History Page 1 of 1 Well Date Summary 14-29 10/21/2007 ***WELL S/I ON ARRIVAL*** (pre rwo) DRIFT W/ 4,5" BARBELL SETUP (45" FROM TOP CENT. TO BTM CENT), S/D ~ 6921' SLM, (UNABLE TO WORK THRU). ***CONTINUE WSR ON 10-22-07*** 14-29 10/22/2007 ***CONTINUE WSR FROM 10-21-07*** (pre rwo) TAG RESTRICTION W/ 3.5" DE-CENTRALIZER, 4.5" LIB,,OBTAIN IMPRESSION OF PARTED TUBING ~ 6921' SLM *CO-REP INFORMED TO RIH W/ 4.25" CENT PAST RESTRI TION* S D 7691' SLMSLM, UNA~3LE TO WORK THRU, POOH...... ATTEMPT TO WORK ROPE SOCKET THRU PARTED TUBING ~ 6966' SLM, NIPPED ~ ROPE SOCKET. ***LEFT WELL SHUT IN*** **** TOOLS IN HOLE: 1.75" RS, 5' 2 5/8" STM, 1.75 OJ'S, 1.75" LSS, 2' 1 7/8" STM, 4.25" CENT, OAL= 22.9 ** 14-29 10/24/2007 ****WELL SHUT-IN ON ARRIVAL**** (E-LINE TUBING CUT). INITIAL T/I/O: 600/600/200. JET CUT s TUBING AT 6818' W/ 4.15" SPC POWER CUTTER. CONFIRMED CUTTER FIRED, DSO AND PE NOTIFIED WELL SHUT-IN AND SECURE. FINAL WHPs 600/600/200. ****JOB COMPLETE**** 14-29 10/26/2007 Circ-Out postponed. Flowline blinded off in manifold building. 14-29 10/26/2007 Fluid Support for Well Circ Out 14-29 10/28/2007 T/I/0=600/600/200 Temp=S/I Circ Out & Freeze Protect well (RWO prep) Pumped 5 bbl Neat meth spear, 717 bbls 1 % KCL down Tbg taking returns up IA through jumper loop into flowline of well 14-30. Started Freeze protect on well pumping 115 bbls 90*F diesel down Tbg. Job in progress. Continued on 10/29/07 FWHP's=50/180/280 14-29 10/29/2007 ***Continued from 10/28/07*** T/I/0=50/180/280 Temp=S/I Circ Out & Freeze ProtectTxlA,,MIT OA PASSED to 2000 psi (RWO prep) Finished pumping 32 bbls 90*F diesel to freeze protect well. Pumped 3 6 s eat meth down return line to freeze protect. U-tube TxIA to put freeze protect in place. MITOA- Pumped 10.9 bbls 50*F crude into OA to reach test pressure, 1st 15 min OA lost 100 psi & 2nd 15 min OA lost 20 psi, for a total loss of 120 psi in 30 min. Bled back 3.5 bbls. Bled well head pressure down. FWHP's=0/0/0. All annulus valves left open to gauges Wing shut, SSV shut, master open. Hard line blocked in. Swab shut on well 14-30 ~1~~~ ~~ ~~~ QTS 14-29 11/3/2007 T/!/O = 0/0/0 Temp = SI MIT th~Tubing to 150 g; ~j,P~SSED. Pumped 18.8 bbls of diesel into the tubing to reach test pressure. MIT Tubing lost 40 psi in the 1st 15 min and 20 psi in the 2nd 15 min for a total loss of 60 psi in the 30 min test. Bled Tubing pressure back down. Final WHP's = 0/0/0 "Annulus casing valves tagged & left open" 14-29 11/3/2007 ***WELL S/I ON ARRIVE*** (set wrp/pre rwo) DRIFT TO SSSV W/ OC, XO, 4.6" NO-GO, XO, 5' x 5.63" WEATHERFORD DRIFT SD ~ 2188' SLM PULL UP HOLE TO 1301' SLM FLAG LINE SET 5.5" WRP ~ 1305' MD. (LEFT IN HOLE 3.58') (4.55' OAL , F/N 2.23" ) N DEPARTURE**** NOTIFIED DSO 12/27/07: WF WRP MONTHLY RENTAL FOR 12/03/07 - 12/25/07, MO 2. FINAL BILL, PLUG PULLED 12/25/07 14-29 11/11/2007 Set 5" gray BPV Print Date: 2/14/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/Wllnfo/Reports/ReportViewer.aspx 2/14/2008 BP EXPLORATION Page 1 of 28 Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Operations Summary Report 14-29 14-29 Spud Date: 2/10/1982 WORKOVER Start: 12/20/2007 End: DOYON DRILLING INC. Rig Release: DOYON 16 Rig Number: Date From - To Hours ' Task 12/20/2007 00:00 - 02:00 2.00 ~ RIGD Code NPT ~, Phase Description of Operations P 02:00 - 03:30 I 1.501 RIGD I P 03:30 - 04:30 1.00 RIGD P 04:30 - 08:00 3.50 RIGD P 08:00 - 10:30 2.50 RIGD P 10:30 - 12:00 1.50 MOB P 12:00 - 13:30 1.50 MOB P 13:30 - 21:00 7.50 MOB P 21:00 - 23:00 2.00 MOB P 23:00 - 00:00 1.00 MOB P 12/21/2007 100:00 - 12:30 12.501 MOB P 12:30 - 15:00 2.50 MOB P 15:00 - 23:00 8.00 MOB P 23:00 - 00:00 1.00 MOB P 12/22/2007 00:00 - 00:30 0.50 RIGU P 00:30 - 01:00 0.50 RIGU P 01:00 - 01:30 0.50 RIGU P 01:30 - 04:30 3.00 RIGU P 04:30 - 06:00 I 1.501 RIGU I P 06:00 - 09:00 I 3.001 WHSUR I N 09:00 - 00:00 I 15.001 WHSUR I N PRE Move rig off of A-12. Inspect well and make sure wellhead valves and tree are left to Pad Operator's satisfaction. PRE Move rig down pad and along well row to allow rig camp to be turned around for move to DS-14. PRE Load BOP stack onto cradle for transport. PRE Clean rig and perform light maintenance while waiting for auxiliary booster wheels from Doyon 14. PRE Prepare rig camp for move to DS-14. PRE Move rig camp from A-Pad to DS-14. Move route went from A-Pad through D-Pad, out to Spine Road, down Spine road past Pump Station #1, and on to DS-14 Access Road. PRE Spot camp on DS-14. PRE Wait on auxillery booster wheels from Doyon 14 before moving rig to DS-14. Glean rig and perform light maintenance while waiting. PRE Lay down herculite and rig mats around well for rig. PRE Continue to wait on Doyon 14 to complete rig move to S-Pad. Continue to clean rig and perform light maintenance while waiting. PRE Continue to clean rig while waiting for auxilliary booster wheels. Move Tioga heater to front of rig and route hose to keep drive wheels warm. Install kill line at mezzanine. PRE R/U Booster Wheels to rear (Driller's end) of rig. PRE Move Doyon 16 from A-12 to DS 14-29. PRE Remove booster wheels. Spot rig closer to well. Install BOP stack on stump in cellar. PRE Finish installing BOP stack in rig cellar. PRE PJSM on raising derrick and pinning derrick in place. Reminder that the new extension means more pull required to lift derrick. PRE Raise derrick and pin in place. Took 365k-Ibs to raise derrick off of supports (40k-Ibs more than before extension). PRE Spot rig over well. Pressures on well when rig spotted T( /IO) 0/500/OCenter up an level rig. Install shims where needed and set rig in place. Drop down cellar walls. Spot slop tank, pit module and 3416. Hook up 2" line to OA PRE Hook up IA to bleed trailer to bleed off pressure. Accept Rig at 05:00 hrs. WAIT DECOMP Temporary S/D of any lifting of manual labor operations to accommodate IMT requirements for response to 14-32 incident. At 0600-hrs, start to bleed off annulus from 500-psi; bleeds off to 375-psi in 1/2-hour, continue to bleed down to 200-psi when liquids come into bleed trailer at 0900-hours. WAIT DECOMP Monitor pressure on IA periodically: 0900-hrs--200-psi; 1030-hrs--275-psi; 1130-hrs--295-psi. 1200-hrs--300-psi; 1230-hrs--300-psi. At 1400-hours, suspect the 5,000-psi gage is faulty. Change out 5,000-psi gage for 600-psi gage and S/I pressure reads 230-psi. At 1600-hrs the IA reads 225-psi. ADW RWO Supt gave go-ahead to bleed down well. At 1630-hrs--225-psi; 1700-hrs--100-psi; 1715-hrs--75-psi; 1730-hrs--0-psi all gas and no liquids to bleed trailer. S/I for Printed: 1/24/2008 2:44:50 PM BP EXPLORATION Operations Summary Report Page 2 of 28 Legal Well Name: 14-29 Common Well Name: 14-29 Spud Date: 2/10/1982 Event Name: WORKOVER Start: 12/20/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 16 Rig Number: Date ~I From - To Hours ~~ Task Code NPT ~, Phase ~ Description of Operations 12/22/2007 09:00 - 00:00 15.00 WHSUR N WAIT DECOMP 1/2-hr and pressure climbs to 75-psi. At 1730-hours, discuss with ADW RWO Supt and agree to Bleed and S/I on a 30-minute build-up cycle until allowed to proceed with planned operations which will be modified to kill the well after temporarily removing the WRP in the 5-1/2" tubing at 1,305'. At 24:00 hrs, SICP= 45 psi. 12/23/2007 00:00 - 18:00 18.00 WHSUR N WAIT DECOMP Continue to stand b waitin on DS 14-32 incident. Continue to _- - periodically bleed pressure of IA. Shut in IA for 30 minute intervals before bleeding down. SICP at 00:00 hrs- 45 psi. SICP at 03:00 hrs- 25 psi after 30 minutes build from 5 psi when shut in. SICP at 1300-hours, 0-psi. SICP at 1700-hours is 0-psi. 18:00 - 00:00 6.00 WHSUR N WAIT DECOMP Continue to stand by while waiting on DS 14-32 operations. Continue to monitor well for pressure. Hang bridle lines, install bails on top drive, install elevators, hang rig tongs, C10 heater core in cellar steam heater, load and strap 4" HT-38 drill pipe in pipe shed. 12/24/2007 00:00 - 15:00 15.00 WHSUR N WAIT DECOMP Continue to stand by while waiting on DS 14-32 operations. Continue to monitor well for pressure. Shut in and monitor IA in 30 minute intervals. Pressure will build to 10-20 psi and bleed off to 0 psi quickly when opened to bleed tank. Load and strap 4" HT-38 drill pipe in pipe shed. R/U rig floor. 15:00 - 17:00 2.00 WHSUR P DECOMP Receive the go-ahead to resume decompletion operations. Prepare to R/U DSM Lubricator when they arrive, to pull the BPV. 17:00 - 18:00 1.00 WHSUR P DECOMP P/U DSM lubricator and install on tree. Test lubricator to 500- si. IA had 25-psi on it so bled it to 0-psi. RIH and thread into the BPV and pull it up into tree. Pressure under the BPV was 15- si. 18:00 - 19:30 1.50 WHSUR N WAIT DECOMP Wait of SWS to finish up on DS14-32 operation. 19:30 - 21:30 2.00 WHSUR P DECOMP PJSM with rig crew and SWS slickline crew. Unload SWS tools and equipment from slickline unit and bring to rig floor. R/U SWS with full pressure control, lubricator extension, pump in sub, W/L BOPE, lubricator, and packoff. 21:30 - 22:30 1.00 WHSUR P DECOMP R/U and test SWS lubricator to 1.2 times expected wellhead pressure of 3000 psi for 5 minutes, good test. 22:30 - 23:30 1.00 WHSUR P DECOMP RIH with Weatherford WRP equalizer/ pulling tool. Tag WRP at 1316' SLMD. Latch up to WRP and attempt to work free. Pulling tool shared free from WRP. POOH with pulling tool. 23:30 - 00:00 0.50 WHSUR P DECOMP Redress Weatherford WRP equilizer/ pulling tool and RIH. 12/25/2007 00:00 - 01:30 1.50 WHSUR P DECOMP Continue attempting to pull 5-1/2" WRP. RIH and tag WRP with Weatherford equalizer/ pulling tool. Tag WRP at 1316' SLMD. Attempt to jar loose without success. Pull free from WRP and POOH. Examination of pulling tool showed some junk with fine metal shavings on pulling tool. 01:30 - 03:30 2.00 WHSUR P DECOMP R/U and RIH with bailer with washpipe to work over WRP fish neck. Tag WRP at 1316' and work bailer several times to clear possible debris on top of WRP. POOH with bailer. Sma{I amount pastic TBG coating in bailer. 03:30 - 04:30 1.00 WHSUR P DECOMP R/U pulling tool without the collet to latch WRP. Pulling tool was rigged with tattle tail to confirm proper depth to retrieve WRP. Worked tool several times over WRP. POOH and examine tattle tail. Indications looked good to latch WRP. Printed: 1/24/2008 2:44:50 PM 2.001 KILL I P Operations Summary Report Legal Well Name: 14-29 Common Well Name: 14-29 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 16 Date ~~ From - To~~Hours ~, Task ~~ Code ~~ 12/25/2007 104:30 - 05:30 I 1.00 WHSUR P 05:30 - 06:00 06:00 - 07:00 0.50 WHSUR P 1.00 KILL P 07:00 - 09:00 09:00 - 10:00 1.00 KILL P 10:00 - 12:00 2.00 KILL P 12:00 - 13:30 1.50 KILL P 13:30 - 14:30 1.00 KILL P 14:30 - 16:30 16:30 - 17:30 17:30 - 19:30 19:30 - 20:30 20:30 - 21:00 BP EXPLORATION Start: Rig Release: Rig Number: NPT I' Phase i 12/20/2007 Page 3 of 28 Spud Date: 2/10/1982 End: Description of Operations DECOMP R/U and RIH with Weatherford equilizer/ pulling tool. Tag WRP at 1316' SLMD. Work WRP free and POOH. L/D WRP. DECOMP R/D SWS and R/U to reverse circulate well. DECOMP Reverse circulate hot seawater at 6.5 bpm with 120 psi. Took 70-bbls to fill the annulus -1 600' to fluid, when returns came to surface. Continue pumping 50-Bbls to push diesel freeze protect out of tubing. Get diesel, crude oil, salt water, and gas in returns. DECOMP Realign valves and circulate seawater at 5-bpm with 125-psi down tubing. Pump 150-bbls see returns of diesel, crude oil, salt water, and gas. Increase rate to 8-bpm when 200-bbls are pumped, pumping with 130-psi on tubing and 80-psi on the casing. 290-bbls pumped: 100-psi tubing, 140-psi casing. 350-bbls pumped: 100-psi tubing, 170-psi casing. 480-bbls pumped: 90-psi tubing, 160-psi casing. S/D pump and wait on water. The returns throughout the long way circulation continued to be diesel, crude oil, salt water, and gas. S/I casing at 0900. DECOMP Wait on seawater. 0900-hrs, tubing 0-psi, casing 110-psi. 0930-hrs, tubing 0-psi, casing 90-psi. 1000-hrs, tubing 0-psi, casing 80-psi. DECOMP Wait on Vac truck load of seawater. Take on seawater to pits. DECOMP Start pumping seawater 6-BPM at 115-psi, CP 40-psi. Took 82-Bbls to reach fluid level or -1 870' to fl .First returns consisted of crude, diesel, and gas to just before bottoms up. Returns progressively cleaned up after bottoms up. Returns were clean at surface to surface. Pumped a total of 570 bbls to get surface to surface returns. DECOMP Open well and monitor for 20 minutes. Continue pumping. 2.00 DHB P DECOMP PJSM with SWS and rig crew. P/U SWS tools and equipment. M/U Weatherford WRP and RIH. SWS reported catching fluid at 1275'. Set W RP at 1304' SLMD, shear off and POOH 1.00 DHB P DECOMP Line up and fill tubing. Pressure test WRP to 1500 psi. Hold pressure test for 10 charted minutes, good test. 2.00 DHB P DECOMP Bleed off and break down firing tool. R/D SWS tools and equipment. 1.00 DHB P DECOMP P/U DSM tools and equipment. R/U DSM lubricator and test to 250 psi low pressure and 1000 psi high pressure. Hold tests for 10 minutes, good test. Set BPV and dart. 0.50 EVAL P DECOMP R/U DHD technician fluid shot equipment to IA. Shoot 3 different shots at 10 minute intervals. Fluid appears to be staving at surface while adding seawater through annulus at 60 21:00 - 22:30 1.50 DHB P DECOMP R/U and test BPV and dart to 250 psi low pressure and 3500 si hi h ressure. Hold test for 10 charted minutes, good test. 22:30 - 00:00 1.50 BOPSU P DECOMP Bleed down control lines and N/D dry hole tree. 12/26/2007 00:00 - 02:00 2.00 BOPSU P DECOMP Continue to N/D dry hole tree and adapter flange. Remove from cellar. Examine HGR condition (good). M/U 5-7/8" MCA pin X/O in Vetco Gray Gen II TBG HGR with 18 turns. Threads appear to be in good condition. 02:00 - 08:30 6.50 BOPSU P DECOMP Set BOP stack on wellhead and N/U BOPE. R/U choke and kill lines. R/U turnbuckles and install bell nipple. Open blind rams Printed: 1/24/2008 2:44:50 PM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: - Date From - To 12/26/2007 02:00 - 08:30 08:30 - 09:00 09:00 - 13:30 13:30 - 14:30 14:30 - 15:30 15:30 - i 8:00 18:00 - 19:00 19:00 - 20:30 20:30 - 21:30 21:30 - 00:00 14-29 14-29 WORKOVER Start: 12/20/2007 DOYON DRILLING INC. Rig Release: DOYON 16 Rig Number: Hours ~ Task Code NPT I Phase _ ~_ _.l_ L __1 Page 4 of 28 Spud Date: 2/10/1982 End: Description of Operations 6.50 BOPSU P DECOMP Clean and inspect blind ram cavities and rams. Inspection found no obvious problems with blocks, rubbers or cavities. 0.50 BOPSU P DECOMP R/U to Test BOP's. Set 4" Test Joint and Fill Stack. M/U Test Manifold and Set Up Test Chart. 4.50 BOPSU P DECOMP Test ROPE 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 Scheve. Test was witnessed by Doyon Toolpusher and BPX WSL. Test 1-Choke Valves 1, 12, 13, 14, HCR Kill, Upper IBOP, and Annular Preventer w/ 4" Test Joint. Test 2- Choke Valves 9, 11, Lower IBOP, and Manual Kill Test 3- Choke Valves 5, 8, 10, and TIW Test 4- Choke Valves 4, 6, 7, and Dart Valve Test 5- Choke Valve 2 Test 6- HCR Choke Test 7- Manual Choke Test 8- Choke Valve 3 and Blind Rams Test 9- Variable Pipe Rams 3-1/3" x 6" with 5-1/2" Test Joint Test 10- Variable Pipe Rams with 4" Test Joint Accumulater Test- Starting Pressure 3000 psi. After Actuation- 1800 psi. First 200 psi recovery in 15 seconds. Full Recovery in 1 minute and 12 seconds. 5 Nitrogen bottles at 2080 psi.. 1.00 BOPSU P DECOMP Rig Down Test Equipment. Nipple Down Flow Riser. 1.00 BOPSU P DECOMP Nipple Up Shooting Flange. 2.50 BOPSU P DECOMP Nipple Up Riser to Rig Floor from Shooting Nipple. Pull Test Dart.. Rig Up DSM Lubricator. Pull Grey K-Plug BPV. Found -75 si under lu Open to Choke /Gas Buster and bleed down. Small amount of fluid seen at gas buster discharge, died off quickly. After bleeding off for ~15 mins shut in and checked gauge at lubricator, showing 5-10 psi with positive pressure at needle valve. Continue to bleed through choke and gas buster. Contact Willingham and Reem in town. 1.00 BOPSU P DECOMP Check pressure on DSM lubricator. Pressure at 0 psi. Confirm no possitive pressure on needle valve. Pull lubricator. UD BPV and R/D DSM tools and equipment. 1.50 PULL P DECOMP PJSM with SWS slickline crew and rig crew on R/U SWS equipment. Bring tools to rig floor and R/U SWS with full pressure control, lubricator extension, pump in sub, wireline BOPE, lubricator, and packoff. 1.00 PULL P DECOMP R/U SWS with GR running tool and Weatherford equalizer/ pulling tool. RIH and tag WRP at 1304'. Equalize pressure around WRP and shear off. POOH w/ pulling tool. R/U SWS with GS running tool and Weatherford equalizer/ pulling tool. RIH and tag WRP at 1304'. Latch to WRP and jar loose. Allow WRP elements to relax and POOH with WRP. UD WRP. One slip die from the WRP came up missing from WRP. Die dimensions- 4-1/4" x 1-1/2" x 1/2". 2.50 PULL P DECOMP PJSM with SWS, CH2MHILL, and rig crew. Cover upcoming circulation and procedures. R/U to reverse circulate so that returns could be routed through choke without R/D previously tested BOPE choke line. ~ieverse circulate at 8 bpm with 760 psi. Pumped 135 bbls to catch returns. Pumped a total of 870 Printed: 1{24/2008 2:44:50 PM BP EXPLORATION Page 5 of 28 Operations Summary Report Legal Well Name: 14-29 Common Well Name: 14-29 Spud Date: 2/10/1982 Event Name: WORKOVER Start: 12/20/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations - - L _ ~ ~ _ ~ -- _ _ - - _- _ __ _ ~ 12/26/2007 21:30 - 00:00 2.50 PULL P DECOMP bbls and lost 404 bbls to the well at a dynamic ratg of 200 bph. Good clean returns came to surface. 12!27!2007 00:00 - 00:30 0.50 PULL P DECOMP Monitor well. Well on vac. 00:30 - 02:30 2.00 PULL P DECOMP R/D SWS. While R/D, attempt to keep hole full by filling 02:30 - 03:00 03:00 - 04:00 0.50 1.00 PULL PULL P P DECOMP DECOMP to kee hole full. R/D SWS lubricator and R/U flow line. P/U landing joint and M/U Baker 5-1/2" spear. RIH to 23'. Engage tubing below hanger. BOLDS. Attempt to pull tubing hanger free of tubing spool. P/U to 215,000 Ibs and slack off. ,Worked several cycles. Verify lock down screw are out. Wrap wellhead with herculite and apply steam. Pump down tubing to fill well and help hydraulic hanger free. P/U to 250,000 Ibs and slack off. Work several cycles., Well took 175 bbls to fill. Tubin han er worked free just as fluid returned to surface. Up Wt to pull hanger from spool- 165,000Ibs; String Up Wt- 145,000 Ibs. Pull hanger to floor. 04:00 - 04:30 0.50 PULL P DECOMP UD tubing hanger. R!U Camco Spooler and Doyon tubing handling equipment. M/U 8rd X/O to Floor Valve. 04:30 - 06:30 2.00 PULL P DECOMP Circulate around high visc sweep down tubing at 10 bpm with 950 psi. Circ -1000 bbls without seeing sweep come back. Sweep was strung out and not noticable. Approximately first 40 bbls of circulation very dirty fluid. 06:30 - 07:00 0.50 PULL P DECOMP Flow Check Well and Monitor Static Fluid Loss ~ 40 bph. 07:00 - 11:00 4.00 PULL P DECOMP POOH and UD 5-1/2" 17# L-80 IPC 8rd Tbg w/ 1/4" Dual Incapsulated Control Line. Pulled first 44 Joints and only able to recover -150' of Control Line on Spooler. Control Line very brittle and coming apart. Recovered pieces attached to Control Line Clamps ranging from 1' to 20'. Able to POOH and UD to Joint #44 Started seeing significant over pull with 20 ft of joint above rotary table. Pulled up to 25,000 Ibs over string weight and stopped. Could move down hole with no resistance but greater than 25,000 Ibs over pull required to PUH. Drained Stack and could see significant amount of control line down hole. 11:00 - 11:30 0.50 PULL P DECOMP Discuss situtation with Willingham and others in town. Decided on pumping at high rate and try and lift out control line pieces. R1U Circulating Head On Tubing. 11:30 - 12:00 0.50 PULL P DECOMP Start off Pumping at -6 bpm and 450 psi then began to pressure up, saw -1000 psi pump pressure before shutting down pump. Bring Pumps back online and steadly ramped up from 4 bpm to 12 bpm in increments. Pump pressure stayed lower. At 8 bpm Pump Pressure = 450 psi. At 12 bpm Pump Pressure 900 psi. No Control Line seen over shakers. 12:00 - 12:30 0.50 PULL P DECOMP Found Leak from Riser Boot after -2 mins of Circulating at 12 bpm. 1/2 bbls Sw leaked onto secondary containment in cellar. Notifications were made to Willingham, BP HSE Adviser, Doyon DRLG Safety Adviser, and 5700 spill response. Cause of leak was due to riser being pushed up when circ at high rate from "birds nest" of control line. Riser pushed up -12 inches. 12:30 - 14:00 1.50 PULL P DECOMP Stack Drained and Flow Riser reseated in correct position and Air Boot Checked for inflation. Removed -20 Ibs of Control Line pieces from Flow Riser. When Stack was drained found Printed: 1/24/2008 2:44:50 PM BP EXPLORATION Operations Summary Report Page 6 of 28 Legal Well Name: 14-29 .Common Well Name: 14-29 Spud Date: 2/10/1982 Event Name: WORKOVER Start: 12/20/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 16 Rig Number: Date From - To Hours Task I Code I NPT I, Phase Description of Operations 12/27/2007 12:30 - 14:00 1.50 PULL P DECOMP that "birds nest" of control line moved up hole and now at base of Flow Riser. R/D Clrc Head and Found that Tbg able to 14:00 - 15:30 1.50 PULL P DECOMP POOH and UD 5-1/2" Tbg. "Birds Nest" of Control Line still visable but able to pull tbg with no over pull. Each Control Line Clamp had small piece of Control Line with it. Length range from 1 ft to 20 ft. Line was unable to be spooled, pieces were bagged in oily waste bags. Continue to POOH and UD 54 full Joints of Tbg and SSSV. No over pull seen when pulling SSSV through mess of control line in flow riser. All 5 Stainless Steel Bands and 27 Control Line Clamps recovered. Tbg pulled to this point looked good externally, some paraffin covering tubing and very small amount of external scale. Inside of tbg pitted with corrosion. A significant amount of Inner Plastic Coating missing. Pin Ends showed significant corrosion, cracks, and pitting. An estimate 400 ft out of 2163 ft of control line recovered to this point, 200 ft on spooler and another -200 ft in pieces. 15:30 - 22:30 7.00 PULL P DECOMP Continue to POOH and UD 5-1/2" Tbg. The interal corrosion and ittin ro ressivel of worse. Joint 95 was the first joint with holes corroded completely through. Most ioints from 145 to 166 had holes com letel throu h. All of the pin ends from 145 were severely corroded. Pitting of the inner plastic coating was very severe. Most ioints from 1-145 had only small amounts of external corrosion with only small amounts of scale Total recovery- 5 stainless steel band, 27 control line clamps, 1 SSSV, 3 GLM assemblies, 166 full joints of tbg, and 25.12' cut off joint for a total length of 6817.76'. Jet cut looked clean and flared out to 6-1/4" OD. Control line birds nest stayed in BOP stack and did not interfere the rest of the trip. 22:30 - 00:00 1.50 PULL P DECOMP Clear and clean rig floor. R/D Doyon tbg handling equipment. Fluid losses at 20 bph. 12/28/2007 00:00 - 02:00 2.00 FISH P DECOMP M/U Baker crankshaft rope spear. Work through BOP stack several times to fish control line. Control line birds nest took up to 2000 Ibs of weight while working through BOPE. Some success, but most of the control line seems too brittle to be fished with spear. Continue working on 2 joints of drill pipe to 60' and until spear came back empty. Recovered -40' of control line in pieces from 1 to 5' long. Fluid losses at 16 bph. 02:00 - 03:00 1.00 FISH P DECOMP P/U and RIH with 15 joints of 4" HT-38 drill pipe to insure there was enough room to P/U and RIH with RCJB and drill collars. Ran crankshaft spear on drill pipe. 03:00 - 03:30 0.50 FISH P DECOMP POOH and stand back 5 stands of 4" HT-38 drill pipe in derrick. Fluid losses are slowing down to <10 bph. 03:30 - 04:00 0.50 FISH P DECOMP Function BOPE watching and cleaning pieces of control line on rams. P/U BOP circulating tool and clean out BOP stack. Fluid losses are 0 b h. 04:00 - 04:30 0.50 FISH P DECOMP P/U landing joint and set wear ring. 04:30 - 05:00 0.50 FISH P DECOMP P/U BOPE cleaning sub and RIH. Circulate BOPE clean. UD cleaning sub. 05:00 - 07:00 2.00 FISH P DECOMP M/U BHA #4; 8-1/2" RCJB Shoe, Bushing, Wash Pipe Printed: 1/24/2008 2:44:50 PM BP EXPLORATION Page 7 of 28 Operations Summary Report Legal Well Name: 14-29 Common Well Name: 14-29 Spud Date: 2/10/1982 Event Name: WORKOVER Start: 12/20/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 16 Rig Number: Date From - To Hours ~ Task Code I NPT I Phase Description of Operations 12/28/2007 05:00 - 07:00 2.00 FISH P DECOMP Extension, Wash Pipe Extension, Bushing, Bit Sub, Bumper Sub, Oil Jar, Pump Out Sub, XO, (9)- 6-1/4" DC's, XO. Total Length = 324.33 ft 07:00 - 08:30 1.50 FISH P DECOMP RIH with RCJB BHA w/ 4" HT38 DP, P/U DP from Pipe Shed 1x1. Tap Up on something at 949'. Stack 10,000 Ibs on Fish - 08:30 - 09:00 0.50 FISH P DECOMP P/U 25' Off Top of Fish and Take Inital Parameters; P/U Wt = 70,000 Ibs, S/O Wt = 75,000 Ibs, Rot Wt = 74,000 Ibs. Free Torque = 1,000 ft-Ibs at 20 rpms, Pump Rate w/ Ball On Seat for RCJB = 1050 psi at 6.0 bpm. S/O and Tag Top of Fish w/ RCJB and Pumps on at 6.0 bpm, set down 5,000 lbs. P/U and Check for Over Pull -None. S/O again and set down 10,000 Ibs. P/U and Check for Wt - No Over Pull. S/O with 2,000 lbs and make few Slow Rotation, Stop Rotation, P/U and Check for Wt - No Over Pull. Repeat Process at 5,000 Ibs and 10,000 Ibs. No Over Pull Seen. Do Not Want to Rotate on Fish too much - A big ball of control line will be easier fished with Crank Spear. Circ Bottoms Up, saw small pieces of control line covering at shakers. 09:00 - 10:00 10:00 - 11:00 1.00 1.00 FISH FISH P P DECOMP DECOMP POOH, Stand Back DP and DC's. B/O and Clean Out RCJB. Found -1 gallon of hand size _ feces of control line alon with several feces of oil bare feces of sin le control line. M/U RCJB and UD in Pipe Shed. 11:00 - 11:30 0.50 FISH P DECOMP M/U Crank Spear BHA. Total Length = 318.33 ft 11:30 - 12:30 1.00 FISH P DECOMP RIH with Crank Spear BHA on DP from Derrick. 12:30 - 13:00 0.50 FISH P DECOMP Initial Parameters; P/U Wt = 70,000 Ibs SJO Wt = 73,000 Ibs. Continue to S/O and Tap somethina hiah at -933'. Move through it and continue down. Tag top of Fish at 949' S/O with 5,0001bs down and P/U -slight over pull seen but dropped off quickly. S/O with rotation, 2 rpm's at 1,000 ft-Ibs free torque. Set down 10,000 Ibs. stop Rotation and P/U, a clear 5 000 Ibs over ull coming up. Repeat process once more with same 5,000 Ibs. Hole still static -not taking fluid. 13:00 - 14:00 1.00 FISH P DECOMP POOH and Stand Back DP and DC's. 14:00 - 14:30 0.50 FISH P DECOMP Inspect Crank Spear BHA. Recovered only 6 pieces of 3"-8" 14:30 - 15:30 1.00 FISH P DECOMP RIH w/ Crank Spear BHA again with DP from Derrick. 15:30 - 16:30 1.00 FISH P DECOMP Make Up Top Drive. Take Parameters. Up Wt = 70,000 Ibs S/O Wt = 73,000 Ibs Rot Wt = 73,000 Ibs. Free Torq = 1,000 ft-Ibs at 2 rpm's. Tag Fish at 949 ft with 8,000 Ibs down. Fish let loose and well went on Vac. Fill Hole through DP and Hole Fill at 10.0 bbls per min. Lost -30 bbls to hole. After gaining returns to surface circulate another 150 bbls at 4.5 bpm with 60 psi. 16:30 - 17:30 1.00 FISH P DECOMP Continue RIH picking up 4" HT-38 drill pipe from the pipe shed to 1979' where debris was tagged. Push debris to 2103' with 10,000 Ibs WOB. 17:30 - 18:30 1.00 FISH P DECOMP M/U top drive and at 4 bpm with 110 psi. Consult with town engineer and decide to POOH for RCJB. 18:30 - 19:30 1.00 FISH P DECOMP POOH standing back 4" HT-38 drill pipe in derrick. 19:30 - 20:30 1.00 FISH P DECOMP POOH, stand back 3 stands of 6-1/8" drill collars in derrick. Printed: 1/24/2008 2:44:50 PM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: 14-29 14-29 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: NPT ~I Phase I' 12/20/2007 Page 8 of 28 Spud Date: 2/10/1982 End: Rig Name: Date 'I From - To I Hours I Task Code 12/28!2007 19:30 - 20:30 20:30 - 21:00 i 21:00 - 21:30 -~ -- 1.00 FISH P 0.50 FISH P 0.50 FISH P 21:30 - 22:30 1.00 FISH P 22:30 - 23:00 0.50 FISH P 23:00 - 00:00 1.00 FISH P 12/29/2007 00:00 - 03:30 3.50 FISH P 03:30 - 04:00 0.50 FISH P 04:00 - 05:30 1.50 FISH P 05:30 - 08:00 2.50 FISH P 08:00 - 09:00 1.00 FISH P 09:00 - 11:30 11:30 - 14:00 2.50 FISH P 2.50 FISH P 14:00 - 15:00 1.001 FISH I P Description of Operations DECOMP VD crankshaft rope spear. No control line recovered. DECOMP Clear and clean rig floor. DECOMP P/U RCJB with extensions (BHA #7). BHA consisted of 8-1/2" saw tooth shoe, bushing, extensions, bushing, RCJB, bit sub, bumper sub, jars, pump out sub, x/o, and 3 stands of 6-1/8" drill collars from derrick. Total length of BHA #7- 329.20' DECOMP RIH with RCJB on 4" HT-38 drill pipe from derrick to 2039'. DECOMP M/U to top drive. Establish parameters of Up Wt- 86,000 Ibs; Down Wt- 90,000 Ibs; Rot Wt- 90,000 Ibs at 20 RPM with 1000 ft-Ibs free torque; Pump Pressure 800 psi at 5 bpm. RIH to 2130' without tagging junk. B/D top drive. DECOMP Continue RIH picking up 4" HT-38 drill pipe from pipe shed. DECOMP Continue RIH with 4" HT-38 drill pipe picked up from the pipe shed. Ran a total of 204 joints and tag ed iunk at 6781'. Lost 52 bbls durin the tri in the hole. DECOMP M/U to top drive and establish parameters of Up Wt- 153,000 Ibs; Dw Wt- 153,000 Ibs; Rot Wt- 155,000 Ibs at 10 rpm with 1500 ft-Ibs free torque; Pump Pressure- 1350 psi at 6 bpm. Wash from 6781 to 6787' with 2000 to 5000 Ibs WOB. No overpull while making connection. P/U joint 205 where bottom was slightly more solid. Increase to 20 rpm with 2000 ft-Ibs torque and 5000 Ibs WOB. Junk would drill off steadily to 6793'. Picked up off bottom with slight overpull. S/O with 5,000 Ibs WOB without making any more hole. Picked off bottom 3 more time with same results without any overpull. Pump pressure came up to 1380 psi and RCJB would no longer drill off. Made 12'. DECOMP CBU at 8 bpm with 2380 psi. Losses are 0. Bottoms up DECOMP Blow down top drive and POOH standing back 4" HT-38 drill pipe in derrick. DECOMP Stand Back Drill Collars. Brake Down BHA and Clean Out Reverse Basket. Recovered -2.5 gallons of rubber pieces off control line and a soft ball size wad of control line. M/U BHA to run again. DECOMP RIH with same RCJB BHA on DP from Derrick. DECOMP M/U TD and Establish Parameters. P/U Wt = 152,000 Ibs S/O Wt = 152,000 Ibs Rot Wt = 152,000 Ibs. 1500 Ibs Free Torque at 20 rpm's. Establish Pump Rate at 8.5 bpm and 2600 psi. S/O and Ta to of Fish at 6792'. Pump 20 bbl High Visc Sweep and Chase Out of the Hole at 8.5 bpm. Sweep brought, back a ood amount of rubber. Attempt to Wash Down with no luck. P!U and Establish Rotation at 100 rpm's. Mi11 through Fish /Junk with 3-7K WOB. Initially torque very jumpy 3-10K ft-Ibs, after going through 4' torque smoothed out. Milled off smoothly with 4-6K ft-Ibs torque and 7K WOB. Milled a total of 9' to 6802', Torque Jumped dramaticly and Stalled. P/U and saw significant over pull. Worked Pipe Several time and broke free with ullin 85,000 Ibs over. Continue to PUH 15' with 25,000 Ibs over. DECOMP Clrc around 20 bbl high visc sweep at 8.5 bpm and 2650 psi. Printed: 1/24/2008 2:44:50 PM BP EXPLORATION Operations Summary Report Legal Well Name: 14-29 Common Well Name: 14-29 Event Name: WORKOVER Contractor Name: DOYON DRILLI NG INC Rig Name: DOYON 16 Date I, From - To I Hours Task Code _ _ 12/29/2007 14:00 - 15:00 _ - 1.00 FISH - P 15:00 - 17:30 2.50 FISH P 17:30 - 18:30 1.00 FISH P 18:30 - 19:30 1.00 FISH P 19:30 - 20:30 1.00 FISH P 20:30 - 23:00 23:00 - 00:00 12/30/2007 00:00 - 03:00 03:00 - 04:00 2.501 FISH I P Page 9 of 28 Spud Date: 2/10/1982 Start: 12/20/2007 End: Rig Release: Rig Number: NPT Phase I' Description of Operations DECOMP Nothing noticable back with sweep. DECOMP B(O Top Drive and Blow Down. VD one Single. POOH to Stand Back DP. Stuck at 60ft off bottom. Work pipe Up and Down several times. Set Jars off at 100,000 Ibs over 4 times and straight pulls to 150,000 over. Pipe free after 6 lar hits. Continue to POOH, still seeing - 5,000 Ibs over pull while POOH standing back 4" HT-38 drill pipe in derrick. DECOMP POOH with BHA #8 (RCJB). Stand back 3 stands in drill collars. RCJB recovery- 1/2 gallon rubber control line encapsulation and 1 piece 1.5' control line. DECOMP Call town and talk over options and plan forward. Decision made to P/U crankshaft rope spear and RIH. Glear and clean rig floor. DECOMP Break down BHA #8. P/U BHA #9 (crankshaft rope spear) consisting of rope spear, x/o, pump out sub, bumper sub, jars, x/o, 3 stands of drill collars from derrick, and x/o to drill pipe. Total length of BHA #9- 318.33' DECOMP RIH with BHA #9 on 4" HT-38 drill pipe from derrick to 6777'. 1.00 FISH P DECOMP Establish parameters of Up Wt- 155,000 Ibs; Dw Wt- 154,000 Ibs; Rot Wt- 156,000 Ibs at 10 rpm with 1500 ft-Ibs torque; Pump Rate- 5 bpm with 350 psi. RIH and tag junk at 6806'. Worked through junk after 7 attempts and 5000 to 10,000 Ibs WOB. Worked spear to 6816'. Pull on fish with 10,000 Ibs overpull. Fish came free and returns were lost. Up Wt at 155,000 Ibs. Fluid losses at 50 bph while pumping at 5 bpm with 300 psi. Monitor well, static loses at 12 bph. 3.00 FISH P DECOMP POOH standing back 4" HT-38 drill pipe in derrick. 1.00 FISH P DECOMP POOH with BHA #9. Stand back 3 stands of drill collars in derrick. No recovery in crankshaft rope spear. Bottom 7 bark on rope spear were bent over damaged up to the bend in the 04:00 - 05:00 1.00 FISH P DECOMP P/U new Baker straight shaft rope spear. M/U BHA #10 consisting of a straight shaft rope spear, 2 x/o, bumper sub, jars, x/o, 3 stands of 6-118" drill collars from derrick, and x/o to drill pipe. Total length of BHA #10- 312.12' 05:00 - 07:30 2.50 FISH P DECOMP RIH with BHA #10 on 4" HT-38 drill pipe from derrick. 07:30 - 08:00 0.50 FISH P DECOMP Establish Parameters; P/U Wt = 154,000 Ibs, S/O Wt = 152,000 Ibs, Rot Wt = 154,000 Ibs. 1,500 ft-Ibs torque at 10 rpm's. Tag Fish at 6811'. P/U and Establish Rotation at 10 rpm's and Tag Fish again -same. Unable to get deeper. 08:00 - 10:30 2.50 FISH P DECOMP POOH standing back 4" HT-38 drill pipe in derrick. 10:30 - 11:00 0.50 FISH P DECOMP POOH standing back 3 stands of 6-1/8" drill collars in derrick. POOH with straight rope spear with no recovery. UD jar assembly. 11:00 - 12:00 1.00 FISH P DECOMP Clear and clean rig floor. Gather up Baker washpipe BHA assembly. 12:00 - 13:30 1.50 FISH P DECOMP P/U BHA #11 (washpipe and inside mill) consisting of burn shoe, washpipe, junk mill, x/o subs, triple connection drive sub, double pin sub, (4) 7" boot baskets, bit sub, bumper sub, jars, pump out sub, x/o, 3 stands of 6-1/8" drill collars from derrick, and x/o to drill pipe. Printed: 1/24/2008 2:44:50 PM BP EXPLORATION Operations Summary Report Legal Well Name: 14-29 Common Well Name: 14-29 Event Name: WORKOVER Start: 12/20/2007 (Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 16 Rig Number: Date I From - To I Hours I Task I Code I NPT I Phase Page 10 of 28 Spud Date: 2/10/1982 End: Description of Operations 12/30/2007 12:00 - 13:30 1.50 FISH P DECOMP Total length of BHA #11- 360.38' 13:30 - 14:00 0.50 FISH P DECOMP Service rig. 14:00 - 17:00 3.00 FISH P DECOMP RIH with 4" HT-38 drill pipe from derrick to 6723'. 17:00 - 18:00 1.00 FISH P DECOMP Slip and cut 80' of drill line. 18:00 - 20:30 2.50 FISH P DECOMP Establish parameters of Up Wt- 158,000 Ibs; Down Wt- 155,000 Ibs; Rotating Wt- 155,000 Ibs at 60 rpm with 3,000 ft-Ibs free torque; Pump Rate- 8.5 bpm with 1070 psi. RIH and to to of tubin stub at 6805'. Work washpipe over tubing smoothly without any WOB. Tag top of tubing stub with inside junk mill at 6830' (spacing out top of tubing stub at 6805') and worked to 6835'. Worked junk mill into tubing at 60 rpm. Torque increased up to 4,000 ft-Ibs, and up to 5000 Ibs WOB was needed to work through tubing. Several attempts were made with same results. S/O up to 10,000 Ibs on tubing stub. Measurements were confirmed and a high viscosity sweep was pumped. fluid loss at 28 boh while oumoina. 20:30 - 21:30 1.00 FISH P DECOMP Continue pumping high viscosity sweep at 13 bpm with 2640 psi. No recovery was noticed at the shakers. 21:30 - 00:00 2.50 FISH P DECOMP POOH standing 4" HT-38 drill pipe in derrick. 12/3112007 00:00 - 00:30 0.50 FISH P DECOMP POOH standing back 3 stand of drill collars in derrick. UD jar assembly. UD washpipe and junk mill. Inside mill was wore on outside, but face was in new condition. No Go sub showed ware where it was turning on top of TBG. Iy,Q rP .ovP / in hnnt baskets. ost 48 bbls while tri in 00:30 - 01:30 1.00 FISH P DECOMP Clear and clean rig floor. Gather ITCO spear assembly. 01:30 - 02:00 0.50 FISH P DECOMP M/U BHA #12 (Itco spear Assembly) consisting of full mule shoe, ITCO spear with 4.80 Grapple, bumper sub, jars, pump out sub, x/o sub, 3 stands of drill collars from derrick, x/o sub, acceleratorjar, and x/o back to drill pipe. Total length of BHA #12- 326.96' 02:00 - 04:00 2.00 FISH P DECOMP RIH with 4" HT-38 drill i e from derrick to 6785'. 04:00 - 05:00 1.00 FISH P DECOMP Establish parameters of Up Wt- 155,000 Ibs; Down Wt- 154,000Ibs; Pump rate- 6 bpm with 640 psi. RIH to top of tubing stub at 6805'. Saw no indications of working into tubing. ITCO spear no goed out at 6812'. S/O 5000 Ibs on tubing stub. P/U only slight overpull of 2000 Ibs. Worked down. Down weight seemed to pick up 1000 lbs. S/O 5000 Ibs on tubing stub. P/U with same results. Made several attempts with up to 10,000 and 15,000 Ibs stacked on tubing stub. All with same results. No noticeable pump pressure change. 05:00 - 06:00 1.00 FISH P DECOMP Drop ball and open circ sub. CBU at 8 bpm with 720 psi. Nothing on returns. 06:00 - 08:30 2.50 FISH P DECOMP B/O and Blow Down Top Drive. POOH and Stand Back DP. 08:30 - 09:00 0.50 FISH P DECOMP Stand Back DC's and UD BHA, confirm fish to surface. 09:00 - 09:30 0.50 FISH P DECOMP PJSM -Discuss how to UD tbg and punching holes if necessary for dealing with trapped pressure. Unknown if tbg maybe plugged. 09:30 - 10:30 1.00 FISH P DECOMP B/O and UD Fish. Recovered remaining 14.49' of cut joint (jt #167) of 5-1/2" 17" L-80 tbg and joints #168-171. All joints in very poor condition. Multiple holes in tbg, all had one to one and a half inch splits near the pin end that were several feet long. Pin ends threads in bad condition, cracked and corroded away. Joint #171 was threads only on bottom, looks as if it Printed: 1/24/2008 2:44:50 PM BP EXPLORATION Operations Summary Report Legal Well Name: 14-29 Common Well Name: 14-29 Event Name: WORKOVER Start: 12/20/2007 Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 16 Rig Number: Date ~I From - To Hours i Task Code NPT Phase ~ _ _. -- 12/31/2007 09:30 - 10:30 ~ 1.00 FISH ~P DECOMP~ 10:30 - 11:00 0.50 FISH P DECOMP 11:00 - 12:00 12:00 - 13:00 1.00 FISH P DECOMP 1.00 FISH P DECOMP 13:00 - 15:00 15:00 - 15:30 15:30 - 16:30 16:30 - 18:30 18:30 - 19:00 19:00 - 19:30 19:30 - 20:00 2.00 FISH P DECOMP 0.50 FISH P DECOMP 1.001 FISH I P I I DECOMP 2.001 FISH I P I I DECOMP 0.50 FISH P DECOMP 0.50 FISH P DECOMP 0.501 FISH I P I I DECOMP Page 11 of 28 Spud Date: 2/10/1982 End: Description of Operations pulled out of collar. Attempt to B/O Spear from cut joint. Consult Town on findings and next run. Clear Floor of tools and ready for next run. Wait on new spear M/U BHA #13 (Itco spear Assembly), ITCO spear with bullnose and 4.80 Grapple, bumper sub, jars, pump out sub, x/o sub, 3 stands of drill collars from derrick, x/o sub, accelerator jar, and x/o back to drill pipe. Total length of BHA #13 = 323.62' RIH with Spear on 4" DP from Derrick. M/U Top Drive. Establish Parameters; P/U Wt = 155,000 Ibs S/O Wt = 154,000 Ibs, 5 bpm at 520 psi. RIH and tag top of fish at 6979'. Continue to S/O w/ 2-3k Ibs watching Spear engage fish, pump pressure did not increase. P/U on fish, broke over at 20,000 Ibs over pull. S/O again at same spot and P/U - No over pull seen, repeated one more time to confirm. Circulate Bottoms Up at 12 bbl /min and 2680 psi. Nothing in returns. Monitor Well. B/O and Blow Down Top Drive. POOH and stand back HT-38 DP. POOH and stand back DC's and VD BHA, confirm fish. PJSM -Discuss how to UD tbg and punching holes if necessary for dealing with trapped pressure. Unknown if tbg maybe plugged. R/U Iron Roughneck with tubing punch. B/O and VD Fish. Recovered tubing joints 172, 173 and one piece of control line (1.5') in a slit of joint #172. All joints in very poor condition with one 2' vertical split through the body of joint 172, 6" from thread of the pin end. The box on joint 172 was damaged with corrosion also. The pin end on joint 173 was severely corroded with at least 30% of the threads gone. Total 20:00 - 20:30 0.50 FISH P DECOMP Clear rig floor. R/U to RIH. 20:30 - 21:00 0.50 FISH P DECOMP M/U BHA #14 (Itco spear Assembly), ITCO spear with bullnose and 4.80 Grapple, bumper sub, jars, pump out sub, x/o sub, 3 stands of drill collars from derrick, x/o sub, accelerator jar, and x/o back to drill pipe. Total length of BHA #13 = 323.62' 21:00 - 23:00 2.00 FISH P DECOMP RIH with 4" HT-38 drill i e f r i 23:00 - 23:30 0.50 FISH P DECOMP M/U Top Drive. Establish Parameters; P/U Wt = 155,000 Ibs S!O Wt = 154,000 Ibs, 5 bpm at 500 psi. RIH and tag top of fish at 7057'. Continue to S/O w/ 5k Ibs on fish, pump pressure increase to 600 psi. P/U on fish with no over pull and pump pressure returned to 500 psi. S/O again at same spot w/ 10k Ibs, pump pressure increased as before. PIU with no over pull and pump pressure returned to 500 psi. S/O again at same spot with 3K Ibs WOB, rotate 1.25 turns to left while slacking off. S/O 15k Ibs with same results. P/U with no noticeable increase in weight. S/O again with 3k Ibs WOB, rotate 1.25 turns to left while slacking off. S/O with 20K Ibs on fish. P/U with no noticable overpull or weight. 23:30 - 00:00 0.50 FISH P DECOMP Circulate Bottoms Up at 12 bbl /min and 2700 psi. Nothing in returns. Monitor Well. 1/1/2008 00:00 - 03:00 3.00 FISH P DECOMP POOH standing back 4" HT-38 drill pipe in derrick. 03:00 - 03:30 0.50 FISH P DECOMP POOH standing back drill collars in derrick. POOH with ITCO Printed: 1/24/2008 2:44:50 PM f BP EXPLORATION Operations Summary Report Legal Well Name: 14-29 ..Common Well Name: 14-29 Event Name: WORKOVER (Contractor Name: DOYON DRILLING 1NC. Rig Name: DOYON 16 Date From - To Hours Task Code 1 /1 /2008 03:00 - 03:30 0.501 FISH P 03:30 - 04:00 04:00 - 04:30 0.50 FISH P 0.50 FISH P 04:30 - 06:30 06:30 - 07:00 07:00 - 08:00 2.00 FISH P 0.50 FISH P 1.001 FISH I P Start: Rig Release: Rig Number: NPT Phase ~~ 12/20/2007 Page 12 of 28 Spud Date: 2/10/1982 End: Description of Operations DECOMP spear with_no recovery. Examination show no signs of spear getting into tubing and no fresh marks on bottom of bull nose. UD spear. DECOMP Clear rig floor. P/U overshot and grapple. DECOMP M/U BHA #15 (overshot and graple assembly) consisting of 8-1/8" overshot w/ 6.00" grapple, bumper sub, jars, pump out sub, x/o sub, 3 stands of 6-1/8" drill collars from derrick, x/o sub, accelerator jars, xlo sub to drill pipe. Total length of BHA #15= 322.70' DECOMP RIH with BHA #15 on 4" HT-38 drill pipe from derrick. DECOMP Establish Parameters; P/U Wt= 154,000 Ibs S/O Wt = 155,000 lbs Rot Wt = 155,000 Ibs at 20 rpm's and 2500 ft-Ibs free torque. Pump Rate = 4 bpm at 225 psi. Tag Upon top of Tbg Stub at 7057' continue to work down to -7058.5' to engage grapple on overshot. PUH and see wt up to 20,000 Ibs over, wt then dropped off to 6,000 Ibs over. PUH 20 ft to next tool joint. Break connection and drop Ball & Rod for Circ Sub. DECOMP M/U Connection and wait 10 mins for Ball & Rod to fall. Bring on pumps at 3 bpm and watch pressure build to 1200 psi. Circ Sub sheared open and pressure fell off to 140 psi. Bring Rate up to 12 bpm and 1830 psi. Circ Btms Up. Nothing in 08:00 - 10:30 10:30 - 11:00 11:00 - 12:00 2:00 - 13:30 2.50 0.50 1.00 .50 FISH FISH FISH ISH P P P P DECOMP DECOMP DECOMP ECOMP B/O and Blow Down Top Drive. POOH and Stand Back Drill Pipe. Stand Back DC's and UD Bumper Sub, Jars, and Overshot. Confirm Fish to Surface. Clear Rig Floor of Tools and Subs. Rig Up Handling Tools for UD Tbg. M/U XO on Safety Valve. PJSM -Handling Rotten Tbg, Slivers, Sharp Edges on Pins and Holes, Trapped Pressure, Stuck Material Inside Tbg. UD 5-1/2", 17#, L-80 8rd L-80 Tb Total of 10 Joints _ lus GLM#7; Jt #174 -183. Total = 427.5'. Tbg looks to be in better shape, holes found in about half the joints pulled, pin ends still eaten away but looking better except in the last joint pulled. Jt #183 in bad shape, along hole was found at the collar end and extended several feet down the tube body as well as several other holes found farther down the tube. The pin end was about half way gone with a large hole extending several inches above the threads. Top of Fish at 7484'. 13:30 - 14:00 0.50 FISH P DECOMP Rig Down Tbg Handling Equipment and Clear Rig Floor. 14:00 - 16:00 2.00 FISH P DECOMP Install New Grapple in Overshot. Rebuild Circ Sub. M/U BHA #15 (overshot and graple assembly) consisting of 8-1/8" overshot w/ 6.00" grapple, bumper sub, jars, pump out sub, x/o sub, 3 stands of 6-1/8" drill collars from derrick, x/o sub, accelerator jars, x/o sub to drill pipe. Total Length = 322.70' 16:00 - 19:00 3.00 FISH P DECOMP RIH w/ Overshot BHA with 4" DP from Derrick. P/U 14 Joints of DP from Pipe Shed. 19:00 - 19:30 0.50 FISH P DECOMP Establish Parameters; Up Weight=162,000#, Down Weight=160,000#, Rotating Weight=162,000#, 5 bpm, 400 psi, 20 rpm, 2,000 ft-Ibs Torque, Continue to RIH and engage Overshot at 7,484' increase in up weight of 5,000# to break over ,increase of string weight of 2-3,000#. 19:30 - 20:30 1.00 FISH P DECOMP CBU 12 BPM C~ 1990 psi, Monitor well, Pump dry- job, B/O & Printed: 1/24/2008 2:44:50 PM BP EXPLORATION Operations Summary Report Legal Well Name: 14-29 Common Well Name: 14-29 Event Name: WORKOVER Start: 12/20/2007 Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 16 Rig Number: Date I From - To I Hours i Task ~ Code j NPT ~~ -- -- -- - - 1/1/2008 19:30 - 20:30 1.00 FISH P 20:30 - 21:30 1.00 FISH P 21:30 - 00:00 2.50 FISH P 1/2/2008 00:00 - 01:00 1.00 FISH P 01:00 - 01:30 0.50 FISH P 01:30 - 02:30 { 1.001 FISH I P 02:30 - 03:00 I 0.501 FISH ~ P 03:00 - 05:00 I 2.001 FISH P 05:00 - 05:30 I 0.50 I FISH I P 05:30 - 06:30 1.00 I FISH I P 06:30 - 09:00 2.50 FISH P 09:00 - 09:30 0.50 FISH P 09:30 - 10:30 I 1.001 FISH I P 10:30 - 11:00 0.50 FISH P 11:00 - 12:30 1.50 FISH P 12:30 - 17:00 4.50 FISH P 17:00 - 17:30 0.50 FISH P 17:30 - 18:00 0.50 FISH P 18:00 - 19:30 1.50 FISH P Page 13 of 28 Spud Date: 2/10/1982 End: Phase ! Description of Operations DECOMP Blow/DN Top-dr. DECOMP Service Draworks, Top Drive, and Iron Rough Neck. DECOMP POOH f/7,484' to 3,175'. DECOMP Continued to POOH f/3,175' to 322'. DECOMP UD ACC Jar, Stand Back Drill Collars, B/O Overshot from Tubing Stub. DECOMP RIU Tubing Handling Equiipment. UD 2 jts of 5.5" Tubing, Boxes and Pins Eroded and Multiple Holes in tubing. Tubing Lenght UD=80', New Top of Fish is 7,566' DECOMP Clear and Clean Rig Floor of Tubing Handling Equipment. Re-dress Overshot Grapple, P/U Drill Collars. DECOMP RIH with Overshot grapple assembly to 7542'. Take Initial Parameters. PJU Wt= 163,000 Ibs S10 Wt = 162,000 Ibs, Rot Wt = 164,000 Ibs @ 20 rpm's and - 2500 ft Ibs torque. Pumps Established at 5 bpm and 440 psi. DECOMP Ta To of Fish at 7 62' and Engage Fish down to 7564'. P/U and see an initial 17,000 Ibs over on wt indicator before breaking over to 4-5,000 Ibs over initial string wt. DECOMP Circ Bottoms Up at 10 bpm at 1550 psi. Nothing seen in returns. B/O and Blow Down Top Drive. DECOMP POOH and Stand Back DP. Still dragging 3-4,000 Ibs over while POOH. DECOMP UD Intensifier Jar, Stand Back DC's, UD Bumper, Oil Jars, and Overshot Assembly. Confirm Fish. DECOMP UD Fish. Recovered 3 Full Joints (#186, #187, GLM#6, #188) of 5-1/2" 17# Tbg and 1 5-1/2" MMG GLM. All pieces had holes in tube bodies from inside to outside. Pin ends are severly eaten away. Jt #188 came out with double collars. To of Fish at 7720'. The fish is the top pup joint on GLM #5 14 ft long, pin threads looking up. DECOMP R/D Equipment and handling tools. Clear and Clear Floor. DECOMP Rig Up to Test BOPE. DECOMP Test BOPE to 250 psi low and 3500 psi high as oer re uirements. Each test held for 5 mins. Test was witnessed by Lou Grimaldi with AOGCC. All components passed. Kommey Test -- Initial Pressure = 3050 psi, bleed down to 1850 psi, Recovered 200 psi in 17 sec, Recovered full pressure in 1 min and 11 sec. Bottle Pressure = 5 bottles at 2050 psi. #1 Annular, #1, 12,13,14, Kill HCR, Upper IBOP #2 #9, 11, Kill Manual, Lower IBOP #3 #5, 8, 10, TIW #4 #4, 6, 7, Dart Valve #5 #2 #6 Choke HCR #7 Choke Manual #8 Lower Pipe Rams VBR's with 4" Test Joint #9 Lower Pipe Rams VBR's with 5-1/2" Test Joint #10 Blind Rams and #3 DECOMP R/D Test Equipment and B/D Surface Lines. DECOMP Pull Test Plug and Set Wear Ring. DECOMP M/U BHA #17, Overshot Grapple with 5-1/2" Grapple for grabbing tube body. Added 4' Extendsion and Re-dresses Printed: 1/24/2008 2:44:50 PM BP EXPLORATION Operations Summary Report iLegal Well Name: 14-29 Common Well Name: 14-29 Event Name: WORKOVER (Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To I Hours Task Code 1/2/2008 ~ 18:00 - 19:30 1.501 FISH I P 19:30 - 22:00 2.50 FISH P 22:00 - 23:00 1.00 FISH P 23:00 - 00:00 1.00 FISH P ,1(312008 00:00 - 00:30 0.50 FISH P 00:30 - 01:00 0.50 FISH P 01:00 - 01:30 0.50 FISH P 01:30 - 03:30 2.00 FISH P 03:30 - 04:00 0.50 FISH P 04:00 - 04:30 0.50 FISH P 04:30 - 08:00 3.50 FISH P 08:00 - 09:30 1.50 FISH P 09:30 - 10:30 1.00 FISH P 10:30 - 13:00 2.50 FISH P 13:00 - 14:00 1.00 FISH P 14:00 - 15:00 1.00 FISH P 15:00 - 20:30 5.50 FISH P 20:30 - 23:00 23:00 - 00:00 114/2008 ~ 00:00 - 02:00 02:00 - 03:00 03:00 - 06:00 06:00 - 07:00 07:00 - 08:30 2.50 FISH P 1.00 FISH P 2.00 FISH P 1.00 FISH P 3.00 FISH P 1.00 FISH P 1.50 FISH P Description of Operations DECOMP Grapple. DECOMP RIH from 325' to 7,600'. DECOMP Slip and Gut 99' of Drilling Line. DECOMP RIH f/7,600't/7,704'. DECOMP Obtain Parameters: UpWeight=165,000#, Down Weight=164,000#, Rotating Weight=167,000#, Taa too of fish at 7 711' Work down to 7,717' with pumps off. Picked up on Drill String and broke over at 205,000#, after pulling fish up hole increase of 4,000# on the Weight Indicator. DECOMP CBU at 10 BPM with 1550 psi. DECOMP Monitor, Pump 15 bbl Dry Job, DECOMP POOH Stand back Drill Collars DECOMP B/O Overshot and Lay Down GLM. Recovered GLM #5 = Length 37.12'. New top of Fish -7,750'. DECOMP Re-Dress Overshot with a 6" grapple for tubing collars and M/U BHA. DECOMP RIH with Drill Collars and Overshot assembly to 7736' DECOMP Establish Parameters; P/U Wt= 166K, S/O Wt= 164K, Rot Wt = 166K, 2500 ft-Ibs torque at 20 rpm's. Continue to S/O and Ta to of fish ~ 7750'. Engage Overshot on to fish and P/U. Work Fish from 20,000 Ibs over to 135,000 Ibs over with straight pulls with no results. Work pipe with 3 jar licks at 60,000 Ibs over and straight pulls to 85,000 Ibs over - no result, pipe still not moving. Work pipe with 3 jar licks to 85,000 Ibs over with straight pulls to 110,000 Ibs over. On third iar lick pipe popped free. PUH and see -2-3,000 Ibs over pull. DECOMP Circulate Bottoms Up at 11 bpm and 1490 psi. Monitor Well. DECOMP POOH with Overshot BHA, Standback DP. DECOMP Stand Back DC's and B/O Overshot Assembly. No Fish. Grapple Showed evidence of latching up on fish and there was one small 6" piece of control line waded up inside grapple. DECOMP Consult with town on results. Discuss different option and plan forwards. Make clean out run with 4-3/4" mill and 2-7/8" PAC and E-Line Jet Cut if successful. DECOMP Load, Strap and Tally 3-1/8" DC's and 2-7/8" PAC DP. P/U and M/U 4-3/4" Mill BHA. DECOMP RIH from 1,045' to 7,694', break circulation at the BHA, at 4 BPM with 640 psi. DECOMP Obtain Parameters: up weight=165,000#, down weight=164,000#, rotating weight=165,000#, 10 RPM with 2,000 ft-Ibs torque, 7 BPM with 1,900 psi. Continue in the hole and tagged up on tubing stub at 7,750' Tagged up twice to confirm depth, rotated at 5 rpm to roll mill into tubing continued to wash down to 7,884'. Nothing seen to this depth. DECOMP Continue to wash though Tubing from 7,884' to 8,461'. Parameters: 10 RPM, 2,000 ft-Ibs torque, 7 BPM with 2150 PSI, Confirmed tag at 8,461' DECOMP Pumped 15 bbl Hi-Vis Sweep, and CBU at 9 bpm and 2700 psi, Monitor wellbore, pumped 15 bbl dry job and B/D T/D. DEGOMP POOH from 8,461'to 1,044' at BHA DECOMP UD Int Jars. Stand Back Drill Collars. Clean Out and UD Boot Baskets. Clear Floor of Tools and Subs. DECOMP PJSM. R/U 2-7/8" Equipment. L/D 2-7/8" PAC and 3-1/8" Start: 12/20/2007 Rig Release: Rig Number: Page 14 of 28 Spud Date: 2/10/1982 End: NPT ! Phase ~_ Printed: 1/24/2008 2:44:50 PM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-29 14-29 WORKOVER DOYON DRILLING INC. DOYON 16 Date 'I From - To ! Hours Task ~ Code NPT i/4l2008 07:00 - 08:30 1.50 FISH P 08:30 - 09:00 0.50 FISH P 09:00 - 12:30 3.50 FISH P 12:30 - 13:30 1.00 FISH P 13:30 - 15:00 1.50 FISH P 15:00 - 16:30 1.50 FISH P 16:30 - 18:00 1.50 FISH P 18:00 - 19:00 1.00 FISH P 19:00 - 22:00 3.00 FISH P 22:00 - 22:30 0.50 FISH P 22:30 - 00:00 1.50 FISH P 1/5/2008 00:00 - 02;00 2.00 FISH P 02:00 - 02:30 0.50 FISH P 02:30 - 04:00 1.50 FISH P 04:00 - 05:00 1.00 FISH P 05:00 - 06:00 1.00 FISH P 06:00 - 09:00 3.001 FISH P Page 15 of 28 Spud Date: 2/10/1982 Start: 12/20/2007 End: Rig Release: Rig Number: Phase I Description of Operations - -- _ __ DECOMP DC's. DECOMP R/D Handling Tools for 2-7/8" PAC DP. DECOMP PJSM. R/D Flow Riser and Install Shooting Flange. R/U E-Line Lubricator Extension, Pump In Sub, BOP's, Lubricator, Grease Head and Pack Off. Pressure Test Equipment with Blank Weight Bar on E-Line to 3000 psi. DECOMP PJSM. L/D Wt Bar and M/U 4.15" Jet Cutter with Dual Bow Spring Centrilizers, Shock Sub, and CCL. Length from CCL to Mid Cutter = 11.9 ft. Total Tool String Length = 15.0'. Zero Tool String at Rig Floor. DECOMP RIH w/Jet Cutter to 8456'. Sit Down on something. P/U and see 150 Ibs over pull, tie into lowest GLM and correlate to Gearhart Perf and Collar Log dated 6/13/86. Had to make -12.5 ft correction. Drop back down to 8456' and P/U with out over pull. Log into position and cut 5-1/2" 17# tbg at 8442'. Positive indication that tool fired. DECOMP POOH w/ E-Line, cleanly - no hang ups. Log back through remaining Tbg and GLM's. DECOMP PJSM with Rig Crew and E-Line Crew on Rig Down. Drain and Confirm No Press on Lubricator. Pull to Surface with Tool String. Visual confirmation Jet Cutter Fired. R/D E-tine Tools and Equipment. Install Riser nipple, B/D Choke and Kill Lines. DECOMP P/U Overshot Assembly BHA Consisted of; 8.125" Overshot, Top Extendsion, Top Sub for Over shot, LBS, Jar, Pump Out Sub, XO, 9-Drill Collars,XO, Bowen Jar, XO. BHA Lenght=325.97' DECOMP RIH with Overshot Assembly f/326' to 7,736'. DECOMP M1U Top Drive at 7,736' Obtain Parameters: up weight=165,000#, down weight=164,000#, Continue to wash down to 7.750' with 5 BPM and 350 PSI. Set 10,000# down weight on tubing stub. Then Pulled off of fish to verify tag depth, Latched onto Tubing at 7,750', PUH increase on weight indicator. up weight=180,000#, 15,000# increase over string weight. DECOMP CBU at 10 BPM with 1,370 PSI. DECOMP POOH from 7,750' to 326'. DECOMP L/D Accel Jar, Stand Back Drill Collars, Release Graoole from DECOMP R/U Power Tongs, Change out Slips and Elevators, L/D 5.5" Tubing 14 jts, 4 GLMs, Cut jt on the 4th GLM Lenght of cut jt=27.10'. Tubing condition approx 50% of the joints had holes in the tube body, Pin end all had Moderate to Heavy Erosion. Box end in fair condition. 9.6' Stub of 5-1/2" down hole. Top of Fish at 8441.5'. DECOMP Clear and Clean Rig Floor, R/D Tubing handling equipment. DECOMP P/U BHA Components and M/U Double Bowl O/S Grapple BHA. Cut Lip Guide with ID Dressed to 5-1/2", Bowen 8-1/8" Overshot Bowl, Bushing ,Bowen 8-1/8" Overshot Bowl, Top Sub, for Bowen Overshot, Bowen Lub Bumper Sub, Bowen Super Hyd Jar, Pump Out Sub, XO, 9 6-1/4" DC's, XO, Bowen Int. Jar, XO. Total Length = 325.87' DECOMP RIH with Overshot Grapple BHA on 4" DP Printed: 1/24/2008 2:44:50 PM • BP EXPLORATION Operations Summary Report Legal Well Name: 14-29 ,Common Well Name: 14-29 Event Name: WORKOVER Start: 12/20/2007 'Contractor Name: DOYON DRILLING INC. Rig Release: ,Rig Name: DOYON 16 Rig Number: Date ~ From - To j Hours j Task ~ Code NPT i Phase 1/5/2008 09:00 - 10:30 - -1.50 --- ~ ~ --I - FISH I P ~ ~ DECOMP 10:30 - 12:00 I 1.501 FISH I P I I DECOMP 12:00 - 15:00 I 3.001 FISH I P I I DECOMP 15:00 - 16:00 1.001 FISH I P I I DECOMP 16:00 - 17:00 I 1.001 FISH I P I I DECOMP 17:00 - 19:00 2.001 FISH I P DECOMP 19:00 - 20:00 1.001 FISH I P DECOMP 20:00 - 22:30 2.50 FISH P DECOMP 22:30 - 23:30 1.00 FISH P DECOMP 23:30 - 00:00 0.50 FISH P DECOMP 1/6/2008 100:00 - 02:00 I 2.00 I FISH I P I I DECOMP 02:00 - 04:00 I 2.001 FISH I P I I DECOMP 04:00 - 06:30 2.50 FISH P DECOMP 06:30 - 07:00 0.50 FISH P DECOMP 07:00 - 07:30 0.50 FISH P DECOMP 07:30 - 08:00 0.50 FISH P DECOMP 08:00 - 09:00 1.00 FISH P DECOMP Page 16 of 28 Spud Date: 2/10!1982 End: Description of Operations Establish Parameters. P/U Wt = 176,000 Ibs S/O 173,000 Ibs Rot Wt = 176,000 Ibs. 30 rpm's at 2,000 ft-Ibs free torque. Pump rate = 4.25 bpm at 290 psi. Wash down to the top of fish, started taking Wt at 8436' and continue to wash down to 8442'. Pump Pressure up to 500 psi at 4.25 bpm. Pull back up dragging 15-25K -possible junk along side. Kick up pump rate to 7 bpm and 750 psi. Washed free.Rotate Down Again. No pressure increase. P/U and pulled 50,000 Ibs over, worked back down to 8445'. Did not see pump pressure increase or increase in torque. Repeat several times but did not see over pull again. Possible fish or junk inside the overshot. Circ Bottoms Up at 11 bpm and 1850 psi. Seeina good volume of black rubber over shakers. Launch Sweep and Circulate around at 11 bpm and 1850 psi. Rubber cleaned up before sweep came back. Nothing noticable with sweep. POOH and Stand Back Drill Pipe. Initially dragging 15-20k Ibs over coming out of hole. Work pipe a few times and wait dropped off. Stand Back Drill Collars. Confirm Fish in Overshot. Retrieved 6.3' long piece of tubing. Bottom was pulled apart ,tubing in bad shape. Consult Town and Make Up Plan Forward. B/O Overshot BHA. Load New Wash Over BHA pieces into pipe shed. P/U and break down previous BHA components, P/U and assemble BHA. Clear the floor of unneeded Baker tools. M/U BHA #23, BHA consists of: Shoe, wash pipe extendsion, junk mill, 3-XOs,Triple connect, XO, 2-junk baskets, bit sub, LBS, super hyd jar, pump out sub, xo, Bowen jar, xo. BHA lenght=343.74' Continue to RIH with 4" drill pipe f/343' to 8416'. Slip and Cut 95' of drilling line. P/U two singles from pipe shed, M/U T/D at 8,446' to obtain parameters: up weight=176,000# ,down weight=175,000#, rotating weight=176,000#, 40 rpm w/ 2-3,000 ft-Ibs of torque, 5 bpm wJ270 psi. Continue to R1H and tagged fish at 8,448'. Top of fish at 8,448' Parameters: up weight=174,000#, down wieght=175,000#, rotating weight=176,000# at 40 RPM with 2,500 ft-Ibs torque, 4 BPM with 280 PSI, washed down to 8,451' torque increase to 6,000 ft-Ibs torque, picked up on drill string and Hung Up, work pipe free by going down and increasing pumps to 7 BPM w1910 PSI, and working pipe up and down with rotation, pumped 20 Hi-Vis sweep and allowed it to clear BHA, went back to bottom and continued to mill to 8.453' with 5-12,000# WOM, 80 RPM, 2-5,000ft-Ibs of torque, Sweep brought back some Control line plastic coating and fine metal millings. Unable to mill past this depth Pumped 20 BBL Hi-Vis Sweep, Displaced the Wellbore to Clean Sea Water. POOH from 8,453', Stand Back DP in Derrick. Service and Repair Hoses to Spinners on Iron Roughneck. Stand Back DC's in Derrick Repair Sheared Bolt on Clamping Dles for Iron Rough Neck. POOH and L/D BHA. Found 4-3/4" Inner Mill was missing, Printed: 1!24(2008 2:44:50 PM C BP EXPLORATION Page 17 of 28 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: i Date i 1 Name: 1 ell Name: 1 e: Name: .I From - To i ' 4-29 4-29 WORKO DOYON DOYON ~ Hours ~I - VER DRILLIN 16 ~ Task - INC , ~ Code II . PT II Start Rig Rig Phase ', -1 Spud Date: 2/10/1982 : 12120/2007 End: Release: Number: I Description of Operations -----. _ 11 008 08:00 - 09:00 -___ 1.00 - __ FISH ___ P DECOMP Threads on sub above in great shape, mill backed off. No wear j marks indicating tagged up again on top of mill. Believe mill to j be inside 5-1/2" Tbg. There was also clear indication that top of tubing stub was bottomed out on 6-1/4" XO at the top of the ~ Wash Pipe. Able to get all they way down. Top of Tbg Stub ~ Still at 8445'. Both boot baskets were full, baskets contained ~~ -2 gallons of metal control line pieces _ 1-3" inches long. 09:00 - 10:00 1.00 FISH P DECOMP Clean and Clear Rig Floor, Mobilize pieces for new BHA. Contact Dave Reem and Report last run, discuss plans. Wait on parts for BHA to fish mill. 10:00 - 12:00 2.00 FISH P DECOMP M/U BHA with 4-3/4" Overshot for fishing mill with Guide Shoe, XO bushing, Short Gatch Overshot, XO, Shear Pin Guide, 2-jts 2 7/8" PAC Pipe,XO, XO, Bowen LBS, Bowen Super Hyd Jar, Pump Out Sub, XO, Bowen Int Jar, XO, BHA Lenght-391.90'. 12:00 - 14:30 2.50 FISH P DECOMP RIH w/4"drill pipe to 8,371' 14:30 - 15:30 1.00 FISH P DECOMP M/U to Top Drive at 8,371'and obtain parameters: up weight=176,000#, down weight=172,000#, pump rate 4 BPM with 370 psi,Continue to wash down to 8,445' to the shear pins set at 10,000#, verify the short catch entering the tubing stub three times by increase in pump presure. Washed down to 8,454' to top of fish, P/U off fish and slacked off back on it with 40 r m latched onto fish. 15:30 - 16:00 0.50 FISH P DECOMP Monitor well, B/D Top Drive. 16:00 - 16:30 0.50 FISH P DECOMP POOH wl BHA #24 from 8,454 to 6,755'. 16:30 - 17:30 1.00 FISH P DECOMP Rig Service. 17:30 - 18:30 1.00 FISH P DECOMP Chain Oiler not working properly, removed chain oiler form draworks to inspect and repair, changed out oil filter and repaired oiler pump. 18:30 - 21:30 3.00 FISH P DECOMP Continue POOH from 6,755' to 391' at BHA. 21:30 - 23:00 1.50 FISH P DECOMP VD Jar, Stand Back Drill Collars, l1D Baker Tools, Recovered Junk Mill. 23:00 - 00:00 1.00 FISH P DECOMP Clear and Clean Rig Floor, P/U next BHA Tools. 1/7/2008 00:00 - 01:00 1.00 FISH P DECOMP M/U Spear Assembly, BHA Consists of: Spear Mule Shoe, Bowen Spear, 2-Spear Ext, Bowen LBS,Bowen Super Hyd Jar, Pump out sub, XO, 9-Drill Collars, XO, Bowen Int Jar, XO. BHA Lenght=337.94' 01:00 - 03:00 2.00 FISH P DECOMP RIH to 8,438', obtain parameters: up weight=180,000#, down weight=173,000#, 4 BPM with 380 psi. 03:00 - 04:00 1.00 FISH P DECOMP Washed down and to ed at 8 445'. Continued to wash down and No-Go out at 8,456' pump pressure increase to 1,200 psi. Jar up 4 times with max overpull of 170,000# overstring weight, Jarred free. Washed down to Bing at 8,444'. 04:00 - 05:30 1.50 FISH P DECOMP CBU at 7 BPM with 1,040 psi, monitor wellbore, pump 15 BBL dry job, B/D T/D. 05:30 - 08:00 2.50 FISH P DECOMP POOH with Spear Assembly and Fish from 8,444'. 08:00 - 09:00 1.00 FISH P DECOMP UD Accel Jar, Stand Back Drill Collars, B/O and L/D Seal Assembly, Recoverd 3.70' Tubing Stub, 5' Pup Jt, 13.30' of seal assembly,. Total lenght of fish recovered=22'. 09:00 - 09:30 0.50 FISH P DECOMP Clear and Clean Rig Floor. 09:30 - 10:30 1.00 FISH P DECOMP M!U Type D Spear Assembly to retreive PBR, BHA Consists of: Bull Plug, 7" Type B Spear, Stop Sub, xo, Bowen LBS, Bowen Super Hyd Jar, Pump Out Sub, xo, 9-6.125" Drill Collars, xo, Bowen INT Jar,xo .BHA Lenght=328.71'. RIH with Printed: 1/24/2008 2:44:50 PM • • BP EXPLORATION Page 18 of 28 Operations Summary Report Legal Well Name: 1 4-29 Common W ell Name: 1 4-29 Event Nam e: WORKO VER Contractor Name: DOYON DRILLIN G INC . Rig Name: DOYON 16 Date ~ From - To i Hours i Task II Code ~ NPT ----- ~ ---1 ----- I I -__ 1!7/2008 09:30 - 10:30 1.00 FISH P 10:30 - 13:00 2.50 FISH P 13:00 - 14:00 1.00 FISH P 14:00 - 15:00 1.00 FISH P 15:00 - 15:30 0.50 FISH P 15:30 - 16:00 0.50 FISH P 16:00 - 18:00 2.00 FISH P 18:00 - 19:00 1.00 FISH P 19:00 - 20:00 1.00 FISH P 20:00 - 20:30 0.50 FISH P 20:30 - 22:30 2.00 FISH P 22:30 - 00:00 1.50 FISH P 1!8!2008 00:00 - 12:00 12.00 FISH P 12:00 - 18:00 6.00 FISH P 18:00 - 18:30 0.50 FISH P 18:30 - 19:00 0.50 FISH P Spud Date: 2/10/1982 Start: 12/20/2007 End: Rig Release: Rig Number: Phase ! Description of Operations DECOMP Drill Collars to 328' DECOMP H with 4" drill i e to 8 433'. DECOMP M/U T/D @ 8,433' and obtain drilling parameters: up weight=176,000#, down weight= 175,000#, rotating weight=176,000#, 40 RPM with 3,000 ft-Ibs of torque. Washed down into PBR with 3 bpm and 150 psi, as type D spear entered PBR pump pressure increased to 260 psi, continued washing down and No Go out at 8.459' pump pressure increased to 850 psi at No Go. P/U out of PBR and Pumped 20 bbl Hi-Vis sweep. Washed down into PBR as sweep was at Type D Spear and No Go out on PBR. Latched into PBR P/U 15,000 over string weight, Started rotating to the right after 15 turns began to increase overpull to maintain 15,000# over pull. After approx 20 turns weight dropped off 15,000#, Pulled up hole 25'. Attempted to relatch K anchor to confirm retreival of PBR, stacked out 9' high of original Latch depth. DECOMP CBU at 7 BPM. Sweep brought back some control line rubber. DECOMP Washed down to confirm we still had fish after circulation. Tagged up at same depth 8,451' DECOMP Pumped 15 BBL dry job, monitor well, B/D Top Drive, Wellbore static. DECOMP POOH from 8,451' to BHA at 328'. DECOMP UD Int Jar, stand back drill collars, Pull Fish to rig floor, R/U Tubing Punch due to trapped pressure in PBR. Lenght of PBR 14' K-Anchor and seal assy 1.20'. The bore of the PBR was com letel full of Paraffin ,Tar and control line. DECOMP Clear and Clean the rig floor. P/U Fishing tools to rig floor. DECOMP M/U Packer milling assembly, BHA consists of: Packer Mill, 4-Junk Baskets, Bit Sub, Bowen LBS, Bowen Hyd jar, Pump Out Sub, XO, 9- 6.125" Drill Collars, XO, Bowen INT Jar, XO. BHA Lenght=340.61 DECOMP Continue to RIH w/ Packer Millin Assembl on 4" Drill Pi e DECOMP M/U T/D and obtain parameters: up weight=178,000#, down weight=174,000#, rotating weight=180,000#, 80 RPM, 3,000 ft-Ibs of torque, on bottom torque=5-6,000 ft-Ibs of torque, WOM 5-10,000#, 8 BPM with880 psi,, tagged up at 8,467' washed and rotated to 8,472' on fill. DECOMP Continue to Mill f/8,472' to 8,473', weight on Mill 15-20,000#, 4 BPM with 400 PSI, 80 RPM, 5-7,000 ft-Ibs of torque on Bottom, 2,500 ft-Ibs off Bottom, Pumping Hi-Vis Sweep for as needed. Pumped three 20 BBL Hi-Vis Sweeps Approx 1/2 gal of Fine metal cuttings recovered on third sweep. DECOMP Continue to mill and varying the procedure from milling dry to milling while circulating up to 11-BPM and 1200-psi and also use rapid weight transfer from 0-Ibs to as much as 40,000-Ibs. Make no ro ress from 8 471' D-16 MD between 1200-hrs to 1600-hrs. Discuss with RWO engineer and decide to POOH and examine Packer Mill. P/U on bit and pump at 11-BPM and 1190-psi, then slowly set down and see no change in pump pressure. Pump dryjob and prepare to POOH and S/B DP in Derrick. DECOMP POOH from 8,471' to 8,318'. DECOMP RIG Service. Printed: 1/24/2008 2:44:50 PM • • BP EXPLORATION Page 19 of 28 ~ Operations Summary Report Legal Well Name: 14-29 Common Well Name: 14-29 Spud Date: 2/10/1982 Event Name: WORKOVER Start: 12/20/2007 End: Contractor Name: DOYON DRILLI NG INC. Rig Release: Rig Name: DOYON 16 Rig Number: Date II From - To ~ Hours I Task II Code I NPT I Phase ~,' Description of Operations I ~ L I 1/8/2008 19:00 - 21:30 2.50 FISH P DECOMP POOH from 8,318' to BHA at 340'. 21:30 - 22:30 1.00 FISH P DECOMP UD Int Jar, Stand back Drill Collars, Clean out Junk Baskets,Recovered 1.5 Gals of metal shavings weighing 8 Ibs from the upper junk basket, that was 19' above Packer Mill, Left the BULLNOSE in the we{I. length 1.86'. 22:30 - 23:00 0.50 FISH P DECOMP Clear and Clean Rig Floor, P/U Tools for Next BHA. 23:00 - 00:00 1.00 FISH P DECOMP M/U Burn Shoe Assembly, BHA Consists of: Wash Over Shoe, TSWP Extendsion, Triple Connect ,Double Pin Sub, 4-Junk Baskets, Bit Sub, LBS, Hyd Jar, Pump Out Sub, XO, 9 - 6.125" Drill Collars,XO, Int Jar, XO. BHA Lengtht=351.53'. 1(9(2008 00:00 - 00:30 0.50 FISH P DECOMP RIH with 8.5" Burn Over Assembly and Drill Collars to 351'. 00:30 - 03:00 2.50 FISH P DECOMP RIH From 351' to 8,400' with 4" drill pipe. 03:00 - 04:00 1.00 FISH P DECOMP Slip and Cut 94' Drilling Line. 04:00 - 07:00 3.00 FISH P DECOMP Continue to RIH to 8,420', Obtain Parameters: up weight= 183,000#, down weight=175,000#, Rotating weight=180,000#, 4,000 ft-Ibs of torque at 50 RPM, pump rate at 3.5 BPM, 130 PSI, RiH and Tagged at 8,471. Milled to 8,472'. P/U off bottom and pump 20-Bbl Hi-Vis sweep, 10-BPM at 1,400-psi. Get 2-gals of metal cuttings from milling ops and from the sweep. Call RWO engineer to inform him that a BOPE test is scheduled for today. Decide to POH 3-stands and RIH with RTTS packer and Sub-Surface Control Valve to prepare for BOPE test. John Cris , AOGCC, waived State's ri ht to witness the tests. 07:00 - 07:30 0.50 FISH P DECOMP POH and S/B 3-stands of DP. 07:30 - 08:30 1.00 FISH P DECOMP Grease Choke/Kill manifold, service rig and perform Derrick inspection while waiting for Halliburton RTTS/SSCV. 08:30 - 09:30 1.00 FISH P DECOMP P/U and M/U RTTS/SSCV and RIH to 103', center of RTTS element, and set. Unlatch runninh/pulling tool and POH. Close the Blind Rams and test the RTTS to 900-psi and record on chart for 5-mins--rock solid test. 09:30 - 10:00 0.50 FISH P DECOMP P/U Wear Ring run/pull tool, RIH and pull Wear Ring. 10:00 - 10:30 0.50 FISH P DECOMP Rig up to test BOPE. 10:30 - 14:30 4.00 FISH P DECOMP Test BOPE to 250-psi low and 3,500-psi high with 4-1/2" test 14:30 - 15:00 0.50 FISH P DECOMP 15:00 - 15:30 0.50 FISH P DECOMP 15:30 - 16:30 1.00 FISH P DECOMP 16:30 - 00:00 7.50 FISH P DECOMP R/D BOPE test equipment. Pull test plug with run/pull tool and L/D same. P/U and RIH and set Wear Ring. RIH with RTTS/SSCV run/pull tool on 1-stand of DP, engage, open valve, and release RTTS. POH and UD the RTTS/SSCV assembly. Continue to RIH with the Burn-Over BHA; obtain parameters: Up wt 182K-Ibs, Dn wt 175K-Ibs, Rot wt 172K-Ibs ~ 50-RPM and 4K Ib-ft free torque, 4-BPM ~ 220-psi. Stop rotating and continue in and tag at 8,472'. Start burning over packer with 10-12K WOB, 5-6K Ib-ft torque at 60-RPM, circulating 4-BPM at 220-psi. Hi-Vis sweep pumped as needed. Changed Parameters as needed to burn over packer F/8472' to 8473' noticed 200 psi pump increase__@_ 8472.5'then lost all returns @8473' P/U off BTM and established loss rate. Pumps on =360 BPH loss. Pumps off =300 BPH Ioss.Resume pumping keeping hole full at 6 BPM Q 545 psi & push packer to 8479' and resume milling, and push to final depth of 8,482'. Printed: 1/24/2008 2:44:50 PM • • BP EXPLORATION Page 20 of 28 ~, Operations Summary Report Legal Well Name: 14-29 Common Well Name: 14-29 Spud Date: 2/10/1982 Event Name: WORKOVER Start: 12!20!2007 End: Contractor Name: DOYON DRILLI NG INC. Rig Release: Rig Name: DOYON 16 Rig Number: Date II From - To ~ Hours Ii Task II Code j NPT ~ Phase ~ Description of Operations - -- ~ ---'L - I - L - --- ---- ---- _ __- _- - - - 1/10/2008 00:00 - 01:00 1.00 FISH P DECOMP Obtain static loss rate @ 219-BPH. Batch mix 100-Bbls fresh water weighted up to 8.4-ppg ,while waiting on trucks, off loaded trucks to pits taking on 8.5-ppg sea water to pits. 01:00 - 01:30 0.50 FISH P DEGOMP POH from 8482' filling the wellbore with double displacement + 30-BPH. Pipe came wet at 7190'. 01:30 - 02:30 1.00 FISH P DECOMP Drill pipe came wet after pulling 13-stds. R/U head pin and pumped drill pipe volume at 6-BPM C~ 450-psi. Returns observed after 20-Bbls pumped. Observe static loss rate C~ 81 02:30 - 05:30 3.00 FISH P DECOMP Losses decreased but we are able to keep the wellbore full at 81 bph. Continue to POOH from 7,190'. Cleanout and UD Junk Baskets; get 3-gallons or - 30-Ibs of steel cuttings and other debris. Clear and clean Rig Floor. 05:30 - 06:30 1.00 FISH P DECOMP P/U and M/U short catch Overshot and Washpipe extension. 06:30 - 10:00 3.50 FISH P DECOMP RIH Overshot BHA on DCs and DP from Derrick.To -8400' obtain parameters, up weight=185 K, Down weight=172 K, 4 BPM @ 400 psi 10:00 - 10:30 0.50 FISH P DECOMP Taa Packer ~ 8482' engaged fish with 150 psi pump pressure increase, set down 10 K, P/U and jar free C~? 275 K 10:30 - 14:00 3.50 FISH P DECOMP POH WIBHA #29 F/8482' T/331' encounter some drag first 6 stands C~ 5-10 K. Well taking 240 BPH. 14:00 - 15:30 1.50 FISH P DECOMP UD int Jars, Stand back Drill Collers, UD fishing tools, Service boot bskt, ~iecovered Packer & 7" tbg Tail. Total length =11', Recovered "Mill nose" that was lost from BHA #28, Recovered 11.4' of slick line tools, Punched 7" tbg tail 4 times to release potential trapped pressure. 15:30 - 16:00 0.50 FISH P DECOMP Clear & clean rig floor of BHA tools. Fill well through kill line 16:00 - 16:30 0.50 FISH P DECOMP Wait on Schlumberger slick line unit. Held PJSM and N/U shooting flange to BOPE. 16:30 - 21:00 4.50 FISH P DECOMP Con't wait on Schlumberger slick line unit. 21:00 - 00:00 3.00 FISH P DECOMP PJSM, PU wire line tools & equip to floor. R/U schlumberger, Tested pressure control equipment to 2,600 psi. 1/11/2008 00:00 - 01:30 1.50 FISH P DECOMP PJSM, Continued to R/U schlumberger, Lubricator, WIL BOPE and tested pressure control equipment to 2,500 psi. While filling the BOPs and Lubricator with sea water to test Surface Epuipment a leak was noticed on the shooting flange. Less then 1-gal was leaked into secondary containment. Sea water was cleaned up and Flange was tightened properly. 01:30 - 02:30 1.00 FISH P DECOMP RIH with SWS slick line with 4.5" LIB and 2 centralizers to 8.422'. Tagged up and unable to go deeper. Slick Line Crew 02:30 - 03:00 03:00 - 04:00 0.50 1.00 FISH FISH P P DECOMP DECOMP POOH with LIB from 8,422'. Wire line run #1 with 4.5" lead impression block, WLM= 8422', Partial im ression Looks like 4-1/2" tb in u . Install a 6.1" LIB for run # 2 to comfirm. 04:00 - 05:00 1,00 FISH P DECOMP RIH with 6.1" LIB and 1 centralizer to allow to run on Low Side of the well bore to confirm previous findings and depth. 05:00 - 05:30 0.50 FISH P DECOMP POOH from 8 499' corrected de th. The 6.1" LIB had same im ression of a 4-112" tubing joint. 05:30 - 06:30 1.00 FISH P DECOMP RID Schlumberger equipment and set it aside to keep the slickline unit on standby. 06;30 - 07:30 1.00 FISH P DECOMP N/D the Shooting Flange and NIU Riser and air boots. Printed: 1/2412008 2:44:50 PM • • BP EXPLORATION Page 21 of 28 Operations Summary Report Legal Well Name: 14-29 Common Well Name: 14-29 Spud Date: 2/10/1982 Event Name: WORKOVER Start: 12/20/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 16 Rig Number: Date II From - To ~I Hours ~~ Task I Code NPT ~I Phase 1!1112008 07:30 - 10:30 I 3.00 I FISH ~P I I DECOMP 10:30 - 12:00 I 1.50 I FISH I P 12:00 - 14:00 I 2.001 FISH I P 14:00 - 15:30 I 1.501 FISH I P 15:30 - 18:00 I 2.501 FISH P 18:00 - 18:30 I 0.501 FISH P 18:30 - 19:00 I 0.501 FISH I P 19:00 - 20:00 1.00 FISH P 20:00 - 21:30 1.50 FISH P 21:30 - 23:00 1.50 FISH P 23:00 - 23:30 0.50 FISH P 23:30 - 00:00 0.50 FISH P DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Description of Operations Discuss options with ADW Engineering; decide to RIH with 5-3/4" OD Overshot and 5-3/4" OD Cut-Lip Guide dressed inside to 4-1/2" ID with carbide. Had made up the 8-1/8" Overshot, then broke out the components and UD same. UD the 6-1/4" DCs through the Pipe Shed while waiting on the 5-3/4" OD Cut Lip Guide. P/U, rabbit, and tally 9-joints of 4" Spiral DCs. RIH 5-3/4" OD Cut Lip BHA: 5-3/4" x 4-1/2" ID Cut-Lip Guide, 5-3/4" Bushing, 5-3/4" Extension, Bushing, Bumper Sub, Jars, Pump-Out Sub, and RIH on 9-ea 4-3/4" Drill Collars from Pipe Shed. Continue to RIH with Cut-Lip BHA on DP from Derrick. 22-stands RIH at 1240-hours. 57-stds ~ 1330-hrs. P/U single joint, get parameters: Up wt 170K, Dn wt 162K, Rot wt 165K, Torque 4K, 4-BPM, 40-psi. Stop rotating, slowly RIH and taa at 8,493'. See increase in pump pressure to 80-psi, but this may have been fluid fill in the DP. Set down 5K, P/U 10' and start rotating at 20-RPM, slowly lower and tag at 8,493'. Gain 1-foot of depth and see torque sporadically jump to 7-8K i Ib-ft. Stop rotating and slowly let out torque, about 2-rotations. ~ Pump pressure slowly climbed to 140-psi at 4-BPM. Stop pump I and POH 10'. S/O and stack out with 5-6K at 8,494', and repeat for same results. P/U 10', start rotating at 20-RPM, pump at i 4-BPM, 180-psi. Slowly RIH and tag at 8,494', set down 5-6K I and watch torque sporadically reach 8K Ib-ft for 8-10 i revolutions. Stop rotating and POH. See weight gain to 185K, then releases to 170K. Stop rotating, slow pump rate to 2-BPM, 40-psi, RIH and tag 8,494', set down 6-7K. P/U 10', start rotating at 20-RPM, RIH and tag at 8,494', set down 6-7K and watch torque sporadically gain to 8K Ib-ft and fall back to 4-5K Ib-ft. Stop rotating and release torque, about 2-rotations. Slowly P/U and see weight climb to 175K. Stop and observe for ~ 2-minutes, then continue to P/U and see 185K when it releases and falls back to 170K. Decide to POH to check for fish. i Discuss options with ADW Engineer. ~ POH and S/B DP and DCs in Derrick. 65-stands POH at 1700-hours. No fish. The Cut-Lip tooth was bent in toward the ID of the guide. It was likely rolling against the collapsed top of the 4-1/2" tubing. ~ Call ADW Engineer and discuss options. Agree to use Baker's 8-1/2" OD Overshot with internal taper to 4-1/2" ID. Release Schlumberger crew. ~ Load out Schlumberger equipment from Pipe Shed and I Beavalator. I M/U BHA (8 1/2" OD Overshot w/Dress off shoe) to 314'. RIH on DP from Derrick from 314' to 8746', i P/U single joint, get parameters: Up wt 174K, Dn wt 162K, Rot ~ wt 165K, Torque 4-5K, 4 BPM ~ 30 psi, Tag fish ~ 8493' , PU and rotate at 40 RPM and Dressed Tubing Stub to 8,504' Stacked 20,000# down weight to engage grapy e. UD Single, B/D Top Drive and line up on kill line to fill Wellbore DECOMP-~ POOH with Dress off shoe and overshot, 8,504' to 8,103'. Printed: 1/24/2008 2:44:50 PM • • BP EXPLORATION Page 22 of 28 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date i From - To 1/12/2008 100:00 - 03:30 03:30 - 04:00 04:00 - 06:30 1!1312008 14-29 14-29 Spud Date: 2/10/1982 WORKOVER Start: 12/20/2007 End: DOYON DRILLI NG INC. Rig Release: DOYON 16 Rig Number: ~ I Hours I Task I ~ ~ I ~ Code I NPT i Phase ~ Description of Operations 3.50 FISH P DECOMP POOH from 8,103' with Dress Off Shoe and Overshot assembly, filling hole at 100-BPH. 0.50 FISH P DECOMP Stand back Drill collars and PU one joint of DP to work fishing tools. 2.50 FISH P DECOMP Held PJSM with crew and Baker fisherman. Set twisted joint of 4-1/2" tubing in mouse hole and cut with bandsaw. Recovered one joint and -3' of the next joint that had been forced up into the collar. The end that was trapped inside the tapered overshot fell out from the overshot after three heavy hits with a sledge hammer applied to the overshot body. There was no indication of slickline tools trapped within the fish. 06:30 - 07:00 0.50 FISH P DECOMP Called ADW Engineer to discuss options and decide to R/U SWS slickline unit to RIH with LIBs to determine top of the liner and the identity of the top of the fish. 07:00 - 08:00 1.00 FISH P DECOMP N/D Drilling Riser and air boots. 08:00 - 09:00 1.00 FISH P DECOMP Wait on SWS slickline unit. Perform rig maintenance work orders. 09:00 - 13:30 4.50 FISH P DECOMP Spot SWS wireline van and R/U SWS equipment with full pressure control. 13:30 - 14:00 0.50 FISH P DECOMP Pressure test shooting flange and Schlumberger equipment to 2,500-psi. 14:00 - 14:30 0.50 FISH P DECOMP RIH at 120-FPM with 6.1" LIB. Slow down at 8,400' and make . li ht to at 8,533'. P/U and rapidly RIH to take impression..The 7" Liner to is at 8,534' from original runnin tally. 14:30 - 15:00 0.50 FISH P DECOMP POH with LIB. 15:00 - 15:30 0.50 FISH P DECOMP Remove LIB from lubricator and find small smile from what appears to be the match to the bottom of the fish that was pulled from the well at 0630-hours. There were also three small marks on the bottom side of LIB that were 1/8" wide and 1/4" to 1/2" in length. They may have come from something parked on top of the liner top. 15:30 - 16:00 0.50 FISH P DECOMP Call ADW engineer and discuss LIB. Decide to run a PDS caliper memory logging tool. Decide to make a 5.93" gage ring /junk basket run while waiting the PDS caliper tool. 16:00 - 17:00 1.00 FISH P DECOMP RIH with 5.93" gage ring !junk basket to 8,530'. See no 17:00 - i7:30 0.50 FISH P DECOMP POH with gage ring /junk basket and remove from lubricator. Fin nothin in the'unk basket. 17:30 - 22:00 4.50 FISH P DECOMP Wait on PDS Caliper tool. 22:00 - 23:00 1,00 FISH DECOMP PJSM, MU PDS caliper tools 23:00 - 00:00 1,00 FISH P DECOMP MU and Run PDS caliper log. Log up from/ 8533' to 8500' 00:00 - 02:30 2.50 FISH P DECOMP Continue to run PDS caliper loa from 8500' to 2600' @ 50 FPM tag ~ 8535' WLM, Start logging up at 8530' WLM 02:30 - 03:00 0.50 FISH P DECOMP R/D PDS Caliber tool and down load log. 03:00 - 03:30 0.50 FISH P DECOMP PJSM. RD SWS E-Line tools and equipment. 03:30 - 05:00 1.50 FISH P DECOMP N/D shooting flange and N/U drilling riser and flow nipple. 05:00 - 07:00 2.00 FISH P DECOMP M/U Fishing BHA, 8 1/2" reverse circulating junk basket shoe, 2-ea 8-i/8" washpipe extensions and RevlCirc junk basket asst'. 07:00 - 10:30 3.50 FISH P DECOMP RIH on DCs and DP from Derrick to find top of 7" Liner at +/- 8,535'. 3-stands 4-314" DCs and 44-stands of DP RIH at 0900-hours. 10:30 - 11:00 0.50 FISH P DECOMP P/U two singles, M/U to Top Drive, get parameters: 6.5-BPM at Printed: 1/24/2008 2:44:50 PM • BP EXPLORATION Page 23 of 28 Operations Summary Report Legal Well Name: 14-29 Common Well Name: 14-29 Event Name: WORKOVER Start: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 16 Rig Number: 12/20/2007 Spud Date: 2/10/1982 End: I Date I From - To j Hours ~ Task ~ Code ~ NPT j Phase Description of Operations 1!13!2008 10:30 - 11:00 0.50 FISH P DECOMP 660-psi. Pump 45-Bbls, B/O Top Drive, drop circulating sub ball. P/U stand #86 and M/U to string and to Top Drive. Chase ball and see pump pressure build to 1,750-psi when the ball hit the seat in the RCJB. 11:00 - 11:30 0.50 FISH P DECOMP RIH with last stand (#86) and get parameters: Up wt 173K, Dn wt 164K, Rot wt 170K ~ 20-RPM and 4K Ib-ft torque. Stop rotating, increase pump rate to 8-BPM ~ 2,630-psi and slowly RIH, see tag~ at 8,531'. P/U 8' and rotate string 20-RPM at 4K Ib-ft. Slowly RIH and tag at 8,531'. See torque increase to 8K Ib-ft then fall back to 4K Ib-ft; torque fluctuates from 4K to 6K Ib-ft for several revolutions then stabilizes at 4K Ib-ft with 4-5K Ibs WOB. Made 1' within the first minute. Stop rotating, P/U -6' and slowly RIH. See a quick tag at 8,527', continue in to 8,532' and stop with 5K-Ibs WOB. P/U -6', start rotating at 20-RPM and slowly RIH, do not see anything until tag at 8,532'. Circulating pressure did not change during these operations. 11:30 - 12:00 0.50 FISH P DECOMP Circulate 120-Bbls down through RCJB. B/O Top Drive and prepare to POH. 12:00 - 14;30 2.50 FISH P DECOMP POH and S/B DP and DCs in derrick. 60-stands POH at 1315-hours. Find a 3'-long section of twisted 4-1/2" tubing jammed into the teeth of the Washover Shoe. Discussed findings with ADW engineer and decided to RBIH with the same BHA. 14:30 - 15:00 0.50 FISH P DECOMP Clean out Junk Baskets, inspect BHA components, and prepare to re-run the BHA, Find ~1-1l2 Ibs of control line debris in the Junk Baskets. 15:00 - 15:30 0.50 FISH P DECOMP RIH with same BHA: 8-1/2" RCJB Shoe, 2-ea 8-1/8" Washpipe Extensions, RCJB, Boot Baskets, Bumper Sub, Jars, and Pump-Out Sub. 15:30 - 16:00 0.50 FISH P DECOMP Disconnect Kelly line and re-tighten to keep it from impacting windwalls due to stiffness caused by extreme cold weather. 16:00 - 18:30 2.50 FISH P DECOMP Continue RIH with BHA to 8499' 18:30 - 19:30 1.00 FISH P DECOMP Slip and Gut 95' of drilling line and service top drive. 19:30 - 20:00 0.50 FISH P DECOMP P!U two joints of DP and get parameters: Up wt 174K, Dn wt 164K, Rot wt 170K ~ 20-RPM and 3K Ib-ft torque. Continue to Slowly RIH tagged fish at 8,533', P/U 10' engaged pumps at 8 bpm with 2,600 psi, engage rotary at 20-RPM and continue to RIH slowly washing to bottom. Final depth was 8,539'. 20:00 - 20:30 0.50 FISH P DECOMP CBU establish circulatin loss rate of 168 b h. 20:30 - 21:00 0.50 FISH P DECOMP B/D top drive, line up on kill line and fill wellbore with 100-BPH. 21:00 - 23:30 2.50 FISH P DECOMP P/U one joint of DP, POH from 8539' and stand back DP and DC in the derrick. 23:30 - 00:00 0.50 FISH P DECOMP B/O and UD fishing tools. Clean out junk basket and recovered 1 gallon (5 Ibs) metal cuttings, scale and cement.The large piece of cement was (2" x 3" by 718" thick). LNo fish recovered. 1/14(2008 00:00 - 01:00 i.00 FISH P DECOMP PJSM and clear and clean rig floor of fishing tools. 01:00 - 02:00 1.00 FISH P DECOMP M/U SHA 6" X 4-3/d" wash over shoe, 2-joints wash pipe, boot baskets, bit sub, Jars, Pump out sub, xo, 9 DC= 379'. 02:00 - 05:00 3.00 FISH P DECOMP ith DP and DC from derrick to -8 483'. 05:00 - 06:30 1.50 FISH P DECOMP P/U i-joint of DP and M/U top drive, get parameters: Up wt 174K, Dn wt 160K, Rt wt 170K, 40 Rpm ~ 4-5 K torque. Stop rotating with 8-BPM at 390-PSI, RIH and observe -10-20-PSI pressure increase and a decrease in string wt. at 8,538'. P/U Printed: 1!24!2008 2:44:50 PM Start: Rig Release: Rig Number: Phase BP EXPLORATION Operations Summary Report Legal Well Name: 14-29 Common Well Name: 14-29 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date li From - To I Hours ~~, Task i Code it NPT Ali 1(14/2008 105:00 - 06:30 ~ 1.50 FISH I P 06:30 - 10:00 10:00 - 12:00 12:00 - 14:30 14:30 - 15:30 15:30 - 16:00 16:00 - 18:30 18:30 - 19:30 19:30 - 20:00 20:00 - 20:30 20:30 - 22:30 22:30 - 00:00 3.50 FISH P 2.00 FISH P 2.501 FISH I P 1.00 I FISH I P 0.501 FISH I P 2.50 FISH P 1.00 FISH P 0.50 FISH P 0.50 FISH P 2.00 FISH P 1.50 FISH P • 12/20/2007 Page 24 of 28 Spud Date: 2/10/1982 End: Description of Operations DECOMP and start wash over, 40-RPM C~1 5K torque, 3-BPM at 100-PSI to 8,543'. Stop rotating, P/U, then RBIH to tag at 8,541' with pressure increase to 130-psi. P/U 2-3', release torque, continue to P/U and see weight increase to 200K when it suddenly releases to 174K. Start rotating at 20-RPM, RIH and put 2-3-K on bit with 3-4K Ib-ft torque. Increase RPM to 50-RPM, then 60-RPM and see no change in torque. Increase WOB to -5K-Ibs and see no increase in torque. Stop rotation and let out torque. P/U 15' and increase pump rate to 6-BPM to see the pressure increase to 440-psi from an earlier 8-BPM pressure of 390-psi. Slowly RIH and tag at -8,541'. Decide to POH to look at BHA. DECOMP POH and S/B DP and DCs in Derrick. DECOMP Break out and L/D Overshot with two sections of Slickline Tool One of the Tool Strings has a rope socket on top with a 3-5/8" centralizer immediately below. Its total length is 8.4' long, The other Tool String has a rope socket on top, but does not have a centralizer below it. The body OD at the opposite end is 2-118" and has an overall length of 6'. Discuss with ADW engineer and decide to RIH with a 4-3/4" ID x 6" OD shoe and a "Dimpled" sub with 2-joints of washpipe. DECOMP RIH BHA: 4-3/4" x 6" Washover Shoe, W/P extension with triangular dimples, 2-joints 5-3/4" Washpipe, 2-ea Boot Baskets, Bumper Sub and hydraulic jars. RIH on DCs and DP from Derrick. DECOMP P/U stand #86 and slowly RIH to tag at 8,543'. P/U to get parameters: Up wt 170K, Dn wt 163K, 40-RPM, 5K Ib-ft torque, 3-BPM at 190-psi, work down to 8,547'. P/U single to continue RIH with same parameters, see an obstruction at 8,543', but quickly goes through to 8,547'. StaI1 out on torque limit of 7K Ib-ft after ~10-minutes. Release torque and P/U to 200K-Ibs and released back to 170K, .Repeat twice with same results and also see rattling motion from string as it torques up and falls off 2-3 times each revolution of the string; make additional 2' to 8,549'. At 1525-hours see the pressure drop to 70-psi at 3-BPM and the string torqued-out. Stop rotating and release torque, P/U and do not see the increase to 200K-Ibs while POH. Start rotating at 50-RPM to RBIH but can only get to 8,548', but do not stall out on torque with 7K-Ibs WOB. Decide to POH. DECOMP Pull 1 stand, rack it back, B/D Top Drive, line up on Kill Line to fill the wellbore at 100 bph. DECOMP POH from 8543', some drag observed coming off bottom. DECOMP Lay out 1-joint DP, stand back DC, L/D 1-joint wash pipe and shoe. No fish recovered. DECOMP Clean and clear floor and wait on Bakerfishing tools. DECOMP M/U 6" X 4.5" Washover shoe, 2-joints wash pipe, 2 boot baskets, Jars, pump out sub, 9 DC. TBHA=379.90'. DECOMP RIH with wash over assembly to 8,540'. DECOMP M/U top drive at 8,540' and obtain parameters: Up wt 170,000-Ibs, Dn wt 163,000-Ibs, Rot wt 170,000-Ibs, 50-RPM, 5,000-Ib-ft torque, pump rate 3-BPM, with 110-psi. Continue to Printed: 1/24/2008 2:44:50 PM Start: 12/20/2007 Rig Release: Rig Number: BP EXPLORATION Operations Summary Report Legal Well Name: 14-29 Common Well Name: 14-29 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To II Hours '~ Task ~ Code ~ NPT I --~-----r ~ _ __1----! 1/14/2008 122:30 - 00:00 I 1.50 ~ FISH ~P Phase • Page 25 of 28 ~ Spud Date: 2/10/1982 End: Description of Operations DECOMP RIH and to u at 8,542'. P!U off bottom and engage rotary at 60-RPM. Continue to wash to bottom, begin to mill at 8,549' with 5,000-Ibs WOM and 5-8,000-Ib-ft torque. Mill to 8,550', drill string torqued up and stalled rotary., P/U drill string showing . 30.000-Ibs over string weight. 1/15/2008 00:00 - 01:00 1.00 FISH P DECOMP Continue to mill fish from 8,542' to 8,547' after P/U at tour change. Milled to a depth of 8,550' with 60-RPM, 5-8,000-Ib-ft torque, 3-BPM with 200-psi, WOM 5-7,000-Ibs. Assembly stalled and had to pick up 5 times. The jar went off with the last P/U. Unable to reach 8,550' again. Tagging up at 8,548', worked pipe and parameters and unable to mill past this depth. 01:00 - 04:00 3.00 FISH P DECOMP B/D top drive and POOH from 8,548'. 04:00 - 05:30 1.50 FISH P DECOMP Stand back Drill Collars, Clean Junk Baskets, find approx 1 cup-full of Cement and UD Shoe. No recovery in Shoe or Wash i e. Found internal wear pattern 5.3' up from bottom of 05:30 - 06:30 1.00 FISH P DECOMP 06:30 - 07:30 1.00 FISH P DECOMP 07:30 - 10:00 2.50 FISH P DECOMP 10:00 - 11:00 1.00 FISH P DECOMP 11:00 - 15:00 4.00 FISH P DECOMP Clear and Clean Rig Floor. Have welder shorten the Baker Cut-Lip guide. P/U and M/U 5-718" Bowen overshot with 4-112" Basket Grapple and modified Cut-Lip guide and RIH on DCs to 352'. RIH BHA on DP from Derrick. P/U two singles and get parameters: Up wt 170K, Dn wt 163K, 5-BPM, 240-psi. Slowly RIH and tag soft at 8,543' which is the top of the 7" Llner.. P/U, start rotating 20-RPM and set torque limit at 6K-Ib-ft. Stop rotating and slowly RIH, slipping easily through the Liner Top and stack out 5K-Ibs at 8.548'. P/U 10' and see that pump pressure climbed to 440-psi with returns at the surface after 96-Bbls pumped. Slowly RIH and set down 15K-Ibs and pipe drops 1' foot deeper to 8,549', continue to 20K WOB. P/U and RIH to stack out 15K-Ibs and pipe drops another foot to 8,550'. Stack out to 20K with no further movement. P/U 10' and slowly RIH and see pipe drop about 4-6" with 15K-Ibs WOB, continue to 20K-Ibs with no further movement. Repeat same process one more time with no movement. Decide to POOH. POOH and S/B DP and DCs in Derrick. Find 3' of twisted 4-1/2" 15:00 - 15:30 0.50 FISH P DECOMP B/O and UD the BHA. Call ADW Engineer and he will be sending a revised completion program for a GLM completion that requires an 8-1/2" Bit with 9-5/8" Scraper run and Casing pressure test prior to RIH with the completion. 15:30 - 16:30 1.00 CLEAN P DECOMP M/U Casing cleanout BHA: 8-1/2" Rock Bit, 9-5/8" Casing Scraper, 2-ea Boot Baskets, Lubricated Bumper Sub, Hydraulic Jars, and Drill Collars. Total Length of BHA #39- 316.16' 16:30 - 18:30 2.00 CLEAN P DECOMP RIH with BHA #39 on 4" HT-38 drill pipe from derrick to 8500'. 18:30 - 19:00 0.50 CLEAN P DECOMP Establish parameters of Up Wt- 170,000 Ibs; Down Wt- 162,000 lbs. Continue RIH and softl to to of li P/U off liner top to 8541'. 19:00 - 19:30 0.50 CLEAN P DECOMP Circulate we at 8 pm with 1090 psi. Pumped 60 bbls to fill hole. Pumped a total of 105 bbls to bring any debris around and above boot baskets. 19:30 - 20:30 1.00 CLEAN P DECOMP Slip and cut 101' of drill line. Printed: 1/24/2008 2:44:50 PM • • BP EXPLORATION Page 26 of 28 Operations Summary Report Legal Well Name: 14-29 Common Well Name: 14-29 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 16 Date From - To j Hours Task Code 1/15/2008 20:30 - 23:00 ~ 2.50~CLEAN ~ P 23:00 - 00:00 I 1.00 I GLEAN I P 1/16/2008 00:00 - 01:00 01:00 - 03:00 03:00 - 04:00 04:00 - 09:00 09:00 - 10:00 10:00 - 10:30 10:30 - i 1:30 11:30 - 12:30 12:30 - 14:30 14:30 - 17:30 17:30 - 19:00 19:00 - 20:00 20:00 - 21:30 21:30 - 22:00 22:00 - 00:00 1.00 CLEAN P 2.00 CLEAN P 1.00 CLEAN P 5.00 CLEAN P 1.00 CLEAN P Spud Date: 2/10/1982 Start: 12/2012007 End: Rig Release: Rig Number: NPT Phase I Description of Operations DECOMP POOH with bit and scraper. Stand back 4" HT-38 drill pipe in derrick. DECOMP POOH with BHA #39. Stand back drill collars and UD bit, scrapers, boot baskets, bumper sub, and jars. Cleaned out boot baskets.. No recovery in boot baskets. DECOMP Pull wear ring from wellhead. P/U Cameron tools and equipment for pulling 9-518" packoffs. DECOMP M/U Vetco/Grey pulling tool. RIH and engage packoff. One of the pulling tool lugs sheared off while making up to packoff. POOH with pulling tool. P/U new Vetco/Gray pulling tool. RIH and engage 9-5/8" packoff. Attempt to work packoff free with 10,000 Ibs overpull. Pulling tool lug sheared off pulling tool. DECOMP POOH and R/D Vetco/Gray pulling tool and equipment, Diagnose problem with pulling tool lugs. Cameron to take pulling tool to Baker Machine Shop and have lug repressed into pulling tool and weld a bead around lug to hold into place. Clear and clean rig floor. DECOMP P(U HES 9-5/8" RBP and RIH on 3 stands of driN collars and 4" HT-38 drill pipe from derrick. 55-stands RIH at 0700-hrs; 65-stds ~ 0725-hrs. Set RBP at 8,450', and unsting. Fill wellbore to prepare for casing test. DECOMP R/U to pressure test 9-518" casing to 3,500-psi for 30 charted 0.50 1.00 .00 CLEAN CLEAN LEAN P P P DECOMP DECOMP ECOMP POH 5-stands of DP abd SIB in Derrick. P/U storm Packer and RIH. Top rubber seal on the assembly rolled off against the wear ring while RIH. POH and reseat the seal and RIH using tugger to centralize the string. Continue RIH and set 3-stands below the Rig Floor. POH and S/B 3-stands of DP. Pressure test storm packer to 2,500-psi for 30 charted minutes. Good test. 2.00 BOPSU P DECOMP Pull wear ring. N/D BOP to prepare to remove and replace the Vetco-Gray 9-5/8" packoffs. 3.00 BOPSU P DECOMP Inspect upper Vetco-Gray 9-5/8" packoff. Upper packoff "J-Slots" damaged beyond use. R/U dog collar clamp on upper packoff and work free of casing spool with hydraulic Aorta power. M/U and engage Vetco-Gray pulling tool into lower packoff. M/U to landing joint. Lower packoff pulled free with 1000 Ibs overpull. Start loading and tallying 4-112" Vam-Top tubing in Pipe Shed. 1.50 BOPSU P DECOMP Clean up hanger mandrel and casing spool for installation of new 9-5l8" Gray Gen II packoff. Install new lower packoff. RILDS. Install upper packoff. 1.00 BOPSU P DECOMP N/U tubing spool and torque to specs. RILDS for upper packoff. 1.50 BOPSU P DECOMP R/U Cameron test equipment and test new 9-5/8" primary and secondary packoffs to 5000 psi. Hold test for 30 minutes, good test. Test witnessed by Cameron Wellhead Tech and BPX WSL. R/D Cameron testing equipment. 0.50 BOPSU P DECOMP R/U rig tools and equipment to test BOPE. 2.00 BOPSU P DECOMP Test BOPE to 250 si low ressure and 35 pressure. Each test was held for 5 minutes. AOGCC witness of test was waived by AOGCC inspector Lou Grimaldi. Test Printed: 1/24/2008 2:44:50 PM • BP EXPLORATION Page 27 of 28 Operations Summary Report ,Legal Well Name: 14-29 Common Well Name: 14-29 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date ~~ From - To I Hours i Task Code I NPT ___ -1----~ ~---i 1/16/2008 22:00 - 00:00 ~ 2.00 BOPSU ~ 1/17/2008 100:00 - 02:00 I 2.001 BOPSURP 02:00 - 02:30 0.50 BOPSU P 02:30 - 03:30 1.00 BOPSU P 03:30 - 04:30 1.00 BOPSU P 04:30 - 06:00 06:00 - 14:30 14:30 - 15:00 15:00 - 16:30 16:30 - 20:00 20:00 - 00:00 1!18!2008 00:00 - 07:30 07:30 - 08:30 08:30 - 10:00 10:00 - 13:00 13:00 - 16:00 Spud Date: 2/10/1982 Start: 12/20f2007 End: Rig Release: Rig Number: Phase ; Description of Operations DECOMP was witnessed by Doyon Toolpusher and BPX WSL. Test 1-Annular Preventer, Manual Choke, Manual Kill, Upper IBOP Test 2- HCR Kill, HCR Choke, Lower IBOP Test 3- Choke Valve 1, 12, 13, 14, and Dart Valve Test 4- Choke Valve 9, 11, and TIW Valve Test 5- Choke Valve 5, 8, and 10 Test 6- Choke Valve 4, 6, and 7 DECOMP Continue testing BOPE to 250 psi low pressure and 3500 psi high pressure. Each test was held for 5 minutes. AOGCC witness of test was waived by AOGCC inspector Lou Grimaldi. Test was witnessed by Doyon toolpusher and BPX WSL. DECOMP R/D BOP testing equipment and set wear ring. DECOMP RIH with 3 stands of 4" HT-38 drill pipe from derrick. Engage storm packer and unseat. POOH and UD storm packer. DECOMP RIH with 4" HT-38 drill pipe from derrick to 8450'. Establish circulation at 4 BPM with 260 psi. Engage HES RBP. Open circulating ports and monitor well on a suck. Establish circulation at 4.5 BPM at 380 psi to keep hole full. Establish loss rate of 270 BPH. Continue circulating for 30 minutes. Finish loading and tallying 4-112" Vam-Top tubing in Pipe Shed. 1.50 BOPSU P DECOMP Reset HES RBP and close circulating ports. CBU above RBP at 8 BPM with 1070 psi. 8.50 BOPSU P DECOMP PJSM. POH and L/D DP, DCs, and RBP. Keep hole fill at 100-BPH. 1300-hrs, 75-joints of DP, 9-jts DCs, and RBP remaining to be POH. 0.50 BUNCO RUNCMP Pull Wear Ring. 1.50 BUNCO RUNCMP R/U Doyon Casing equipment to RIH with new 4-112", 12.6#, 13Cr80, Vam Top completion. 3.50 BUNCO RUNCMP Strap completion jewelry, clean threads to be Bakerloked, check and position jewelry, count and flag tubing for jewelry placement. 4.00 BUNCO RUNCMP PIU and RIH with 4-1/2", 12.6#, Cr-80, Vam Top tubing. Jet Lube Seal Guard use on connections for pipe dope. All connections below Baker S-3 packer were cleaned and Bakerloked. Connections made up to 4440 ft-Ibs. 7.50 BUNCO RUNCMP P/U and RIH with 4-1/2", 12.6#, Cr-80, Vam Top tubing. Jet Lube Seal Guard use on connections for pipe dope. All connections below Baker S-3 packer were cleaned and Bakerloked. Connections made up to 4440 ft-Ibs. 1.00 BUNCO RUNCMP P/U M/U two XOs and two HT38 DP pups and torque up to 22K-Ib-ft for landing joint. P/U Hanger and M/U to landing joint. PIU weight = 141,000-Ibs; S/O weight = 133,000-Ibs. 1.50 BUNCO RUNCMP Land Hanger. RILDS. Test packoff seals to 5,000-psi for 5-minutes, good test. 3.00 BUNCO RUNCMP Reverse circulate 150-Bbls 120-F seawater followed by 450-Bbls corrosion-inhibited seawater, all at 4.5-BPM, 30-psi. 3.00 BUNCO RUNCMP Break off circulating line from Floor valve and drop ball and roc to set acker. Pressure u on tubin to 3 600- si and hold for 30 charted minutes. Bleed tubin to 1,500- si. Fill annulus to test casino. Took 35-Bbls of fluid to fill annulus, which puts flui~ Printed: 1/24/2008 2:44:50 PM • BP EXPLORATION Page 28 of 28 Operations Summary Report Legal Well Name: 14-29 Common Well Name: 14-29 Spud Date: 2/10/1982 Event Name: WORKOVER Start: 12/20/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 16 Rig Number: Date i From - To ~~ Hours ~ Task II Code I NPT I Phase it Description of Operations --- ---- ~'---- ~---- - L L 1/18/2008 13:00 - 16:00 3.00 BUNCO RUNCMP 30 charted minutes. Bleed tubing and DCR-M valve shears at 1,300-psi. Insure communication by reverse circ through valve 3-BPM at 280-psi; circulate long way 3-BPM at 190-psi. 16:00 - 16:30 0.50 BUNCO RUNCMP B/O and UD drilling pups and two XOs. 16:30 - 18:00 1.50 BOPSU P RUNCMP Install TWC. R/U and test TWC from below to 1000 psi. Hold test for 5 minutes, good test. Attempt to test TWC from above to 3500 psi. TWC would not test from above.,; 18:00 - 20:00 2.00 BOPSU N WAIT RUNCMP Send for DSM lubricator and new TWC. 20:00 - 21:00 1.00 BOPSU N SFAL RUNCMP Gather DSM lubricator and equipment. R/U lubricator and test to 500 psi, good test. Pull TWC and install new TWC. 21:00 - 22:00 1.00 BOPSU N SFAL RUNCMP R/U and test TWC from below to 1000 psi for 5 minutes,. good test. Test TWC from above to 3500 psi from above for 5 22:00 - 00:00 2.00 BOPSU P RUNCMP Suck out lines and BOP stack. N/D BOPE. 1!19/2008 00:00 - 00:30 0.50 BOPSU P RUNCMP N/D BOPE. Remove riser. Finish cleaning pits for rig move. 00:30 - 01:30 1.00 WHSUR P RUNCMP Clean hanger area in tubing spool as per Cameron Wellhead Tech. Set adapter flange and N/U. 01:30 - 02:00 0.50 WHSUR P RUNCMP Test adapter fange to 5000-psi. Hold test for 30 minutes. Test witnessed by Cameron Wellhead Tech and BPXA WSL. 02:00 - 04:00 2.00 WHSUR P RUNCMP PJSM. P/U and set production tree on adapter flange. N/U tree. 04:00 - 06:30 2.50 WHSUR P RUNCMP R/U and test tree to 5000-Ibs. Hold and record test for 30 minutes. 06:30 - 07:30 1.00 WHSUR P RUNCMP P/U DSM lubricator and R/U to Tree. Test Lubricator to 500-psi, pull TWC. R/D lubricator. 07:30 - 10:00 2.50 WHSUR P RUNCMP PJSM. R/U Lil Red to pump diesel freeze protect fluid. Test Lil Red's line to 3,500-psi. Reverse circulate 150-Bbls diesel, 3-BPM at 375-psi initially and at 575-psi final pressure. 10:00 - 12:00 2.00 WHSUR P RUNCMP R/D Lil Red and line up circulating manifold valves to U-tube the diesel into the tubing. 12:00 - 13:00 1.00 WHSUR P RUNCMP P/U BPV and Cameron Tech installs in hanger. Test to 1000-psi, charted for 10-minutes. 13:00 - 14:00 1.00 R1GD P POST Bleed down all lines, suck back diesel freeze protect fluid from Tree. Secure Tree and Cellar and prepare to RDMO. 14:00 - 16:30 2.50 RIGD P POST P/U bridles and R/D Rig Floor. R/D Cellar and raise windwalls. Release rig at 15:00 hrs. Printed: 1124/2008 2:44:50 PM TREE = GRAY GEN 2 WELLHEAD= GRAY ACTUATOR= AXELSON KB. ELEV = 71' BF. ELEV = KOP = 6000' Max Angle = 28 @ 6800' Datum MD = 9086' Datum TVD = 8800' SS DRLG DRAFT 13-3/8" CSG, 72#, L-80, ID = 12.347" I-j 2600' Minimum {D = 3.687" @ 8584' 4-1/2" CAM DB-6 LAND NIPPLE 4-1(2" 7bg; 12.6#, 13Cr80, VamTop. 3.958" iD 842T .0152-Bpf TOP OF 7" LNR 9-5/8" CSG, 47#, L-80, ID = 8.681" SS3y' PERFORATION SUMMARY REF LOG: BHCS ON 02/28(82 A NGLE AT TOP PERF: 18 @ 8898' Note: Refer to Production DB for historical pert data 512E SPF INTERVAL Opn/Sqz DATE 3-318" 4 8898 - 8914 O 06/09!92 3-3/8" 4 8934 - 8954 O 06/09/92 3-3/8" 4 9084 - 9120 O 08/29!91 3-118" 4 9123 - 9130 O 12/25/82 3-1/8" 4 9135 - 9155 O 12!25/82 3-318" 4 9160 - 9188 O 06/13/86 3-1/8" 4 9265 - 9267 S 12!25(82 PBTD 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" f 9520' I SAFETY NOTES: CAUTION: CORRODE TAILPIPE, THREE TOOLSTRINGS & FAlLm IBP ARE LODGE iN 14 ~~ ~ LNR BELOW 8550' POST*1/2008 RWO. * 4-1 i2" CHROM E TBG' HES 4-112" X-Nipple, 3.813" Pkg Bore GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3258 3257 1 MMG DOME RK 16 01!31108 4 5298 5296 3 MMG 50 RK 20 01/31/08 3 6754 6706 27 MMG DMY RK 0 01/18/08 2 7833 7684 21 MMG DMY RK 0 01(18/08 1 8198 8027 18 MMG DMY RK 0 01/18/08 $278' HES 4-112" X-Nipple, 3.813" Pkg Bore 8309` 9-5/8" x 4-1/2" Baker S3 Packer $27$' HES 4-112" X-Nipple, 3.813" Pkg Bore $415` HES 4-1l2" XN-Nipple, 3.813" PKg with RHGM Rug $42T 4-1(2" WLEG, ID= 3.958" 8550' -Top of 4-102" Fish wl 2-SIL Tooi Strings ~8594' 4-112" CAM DB-6 LAND NIP; ID = 3.687" ~8605 4-1;2" BKR SHEAROUT SUB, ID = ? ~8606` 4-112" TUBING TAIL, ID = 3.958" A 3rd S/L Tool String is lodged inside or below the tubing tail BKR IBP SET (05118/04) 9250' I--i~ RETAINER (sEr 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 03/03/82 ORIGINAL COMPLETION 01/19/08 (TLH CORRECT~NS 05/10/82 LAST WORKOVER 01!21108 JDM(fLH SAFETY NOTE ADDED 01/08/02 RN/TP CORRECTIONS 01/31/08 DAVlPJC GLV C/O 10(20(06 RLIWPAG CORRECT~NS -MULTI 2004 10124/07 RRD/PJC JET CUT @ 6818' 01/19/08 D16 RWO PRUDHOE BAY UNfT WELL: 14-29 PERMIT No: 1811680 API No: 50-029-20680-00 5EC 9, T10N, R14E, 4886.58' FEL & 2384.18' FNL BP Exp{oration (Alaska) PBU 14-29 RWO ~ ~ Page 1 of 1 Maunder, Thomaa E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, January 31, 2008 4:23 PM To: Chan, Paui (PRA) Cc: Reem, David C; Hubble, Terrie L Subject: RE: PBU 14-29 RWO Paul, et al, A 404 is the correct form since the hybrid completion was not accomplished. Call or message with any questions. Tom Maunder, PE AOGCC From: Chan, Pauf (PRA} [mailto:Paul.Chan@bp.com) Sent: Thursday, January 31, 2008 4:21 PM To: Maunder, Thomas E (DOA) Cc: Reem, David C; Hubble, Terrie L Subject: PBU 14-29 RWO Tom PBU 14-29 Workover PTD 181-168 Due to lack of progress fishing the tailpipe and the three s{ickline fish within the tailpipe, BP made the decision to stop fishing operations and to complete the well as a gas Nfted oil well. The Sundry Application approved by the AOGCC was to Workover the well and to then complete the well as a hybrid Ivishak producer/ Sag River injector. The approved Sundry required a 10-407 fiorm to be submitted upon completion of the well. As the well was not completed as a hybrid Ivishak producer/ Sag River injector but just as a Ivishak producer, could BP submit a 10- 404 in liu of the 10-407? Sincerely Paul Chan Workover Engineer BP Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) 2/20/2008 • SARAH PALIN GOVERN OR ALASSA OII/ A1~TD (iA;S 333 W. 7th AVENUE, SUITE 100 C011T5FiRQATIOI~T CO1rII-IIS5IOrT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader ~~~~~ N0~ ~ ~ 2007 BP Exploration Alaska Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 14-29 Sundry Number: 307-338 Dear Mr. Reem: 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 ~c~ day of November, 2007 Encl. Sincerely, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM SIGN ,~ ~~~ ~ ~ ~~~~ APPLICATION FOR SUNDRY APPROV skafltl & ~Ga~s Cans. Cnmmis$~o-~ 20 AAC 25.280 Snchnr'n• 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ®Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other Convert to Dual Strin Producer / In'. 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 181-168 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20680-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: N/A PBU 14-29 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): , ADL 028312 y 71' Prudhoe Bay Field / Prudhoe Bay Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9560 - 9324 - 9250 9027 8628 Unknown Depth Casin Len th Size MD TVD Burst Colla se Structural C nd r 7 ' 2 76' 76' 1490 470 Surface 2600' 13-3/8" 2600' 2600' 4930 2670 Intermediate 8857' 9-5/8" 8857' 8653' 6870 4760 Production Liner 1026' 7" 8534' - 9560' 8347' - 9324' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8898' - 9188' 8692' - 8968' 5-1/2", 17# x 4-1/2", 12.6# L-80 8595' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'SAB' packer Packers and SSSV MD (ft): 8488' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ®Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: November 21, 2007 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ®WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed Na avid Reem Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date // / D~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity 'BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~ other: 3 5~ >~S\ trt ~~ Mvv.~~Q ~t~ . ~`10.\ rO.MS 11~~ ~ ~l ~~-~-OZ' ~~~ `E ~"l,~a ~ Qcov~~c rc VS~T 1o Q-\~c~Coh ~ ~ vJ~@~ o~r~~ S ~ Subsequent Form Required: ~{(~`~ APPROVED BY A roved B : MMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 ~ ^ t Submit In Duplicate S ~~: ~~(iY . ZOD7 • by GP I 14-29 Rig Workover Objective: The objective of the RWO is to run a completion that will enable Zone 4 production to continue in the updip area of DS14 while allowing a slip stream of Ivishak water to be injected into the Sag River formation with an ESP to increase recovery in offset producers. Scope of Work: Pull 5-'/2° completion, mill and retrieve Baker SAB packer, fish IBP and slickline tool strings, drill out cement retainer at 9250" MD, cleanout well to 9400' MD, isolate perforations at 9265' - 9267' MD, run 3 packer completion with ESP on 4-'/z° 13Cr-80 tubing. MASP: 2370 psi Well Type: Ivishak Producer and Sag River Injector Estimated Start Date: November 21, 2007 Pre-riq prep work: S 1 Drift thru 5-'/z" tubin for tubin cut. F 2 MIT-OA to 2000 si. No CMIT re uired. E 3 Jet cut the 5-%2" L-80 tubing at 6821' MD, in the middle of the first full joint 100' above the roblem area at 6921' MD. Reference tubin tall dated 05/10/82. F 4 Circulate well with kill wei ht fluid and diesel thru the cut. W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. S 6 Set WRP at -1400' MD. Adjust set depth as necessary to obtain a pressure test. Pressure test to 1500 si. Perform this step 'ust rior to ri arrival. O 6 Set a BPV in the tubin han er. O 7 Remove the wellhouse & flow line. Level the pad as needed for the ri . Proposed Procedure ~ ~~~~ W ~,~ ~~ ~~ ~ ~ 1. MIRU workover rig. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Retrieve 5-%2" tubing string down to the packer. 3. Mill and retrieve Baker SAB packer at 8488' MD. 4. Fish SL tool strings. Fish IBP. 5. Mill up cement retainer at 9250' MD. 6. cleanout well to 9400' MD. 7. Isolate perforations from 9265' - 9267' MD with either a cemented scab liner or patch. 8. Run RST-sigma log to determine if any additional Ivishak zones need to be perforated. Run USIT log from 9320' PBTD to 8534' MD. Re-perforate Sag River from 8898' - 8914' MD. Add Ivishak perfs if needed. Depths to be determined from RST log. 9. Set 7" RBP at 9050' MD. POOH. 10. Run STP-RST borax log from 9050' to 8534' MD. 11. RIH and unset 7" RBP. POOH to 8700' MD and set RBP. Test casing to 3500 psi. 12. Run 4-'/2° kill string to 8400' MD. 13. Set BPV. ND BOPE. NU and test tree. RDMO workover rig. • • 14. MIRU completion rig. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater. 15. Pull and lay down 4-%2" kill string. 16. Run and set 7" Baker GT dual packer (at -9050' MD) and 9-5/8" Baker Twinseal packer (at 8450' MD) on drillpipe. Packers will be logged into place. 17. Run Baker PBR seal, gauge carrier, "upside" down ESP with shroud, and 9-5/8" Baker GT dual packer at 8250' MD on 4-%2° 13Cr80 tubing. Space out Baker PBR seal into 9-5/8" Baker Twinseal packer at 8450' MD. 18. Displace the IA to packer fluid and set the packer. 19. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 20. Set BPV. ND BOPE. NU and test tree. RDMO. Distance from 14-29 Sag Injection to Nearby Sag Penetrations Nearby Sag Wells - distance to 14-29 ~~~ `4 -12 1337' 14-13 3290' 14-16A 3553' 14-35 2442' 14-43 4335' 14-24 3624' 14-05A 1946' 14-05 1710' 14-18 4133' 14-36 2790' 14-39 3882' 14-11 A 3439' 14-11 2072' 14-27 2931' 14-28 2014' 14-30 3709' 14-26 3667' 13-23A 3002' 14-14 4880' 14-02C 2027' 14-07 3745' 14-34 .5289' 4-~4 ,~ TREE = GRAY GEN 2 WELLHEAD= GRAY ACTUATOR = AXELSON KB. ELEV = 71' BF. EL KOP= Max A Datum Datum C DATE REV BY COMMENTS DATE REV BY COMMENT'S 03/03/82 ORIGINAL COMPLETION 10/20/06 RLM/PAG CORRECTIONS -MULTI 2004 05/10/82 LAST WORKOVER 11/17/06 KSB/PAG GLV GO (11/11/08) 01!08/02 RN/TP CORRECTIONS 02/07/07 JMCrTLH GLV CORRECTION (ADD 10th) 11/29/03 JLJlfT.P GLV GO 04/07/04 JLJ/KAK GLV GO 04/01/05 DAV/TLH TOOLSTRBJG FISH (03/19/05) PRUDHOE BAY UNIT WELL: 14-29 PERMIT No: 1811680 AR No: 50-029-20680-00 SEC 9, T10N, R14E, 4886.58' FEL & 2384.18' FNL BP Exploration (Alaska) 14-29 Proposed Comp'fetion GRAY GEN 2 TREE _ WELLHEAD = GRAY { ACTUATOR= AXELSON KB. ELEV = 71' BF. ELEV = KOP = 6000' Max Angle = 28 @ 6800' Datum MD = 9086' Datum TV D = 8800' SS 13-318" CSG, 72#, L-80, ~ = 12.347" Minimum ID = 3.687" @ 8584' 4-1/2" CAM DB-6 LAND NIPPLE JET CUT (10/24/07) 681 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ~ = 4.892" I-i 8498' TOP OF 7" LNR 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" 8596' 8857' PERFORATION SUMMARY REF LOG: BRCS ON 02/28/82 A NGLE AT TOP PERF: 18 @ 8898' Note: Refer to Roduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 4 8898 - 8914 C 06/09/92 3-3/8" 4 8934 - 8954 C 06109/92 3-3/8" 4 9084 - 9120 C 08!29/91 3-118" 4 9123 - 9130 C 12!25/82 3-118" 4 9135 - 9155 C 12/25/82 3-318" 4 9160 - 9188 C 06/13/86 3-118" 4 9265 - 9267 S 12/25/82 PBTD 9520' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9560' 14-29 SAFETY NOTES: 5-112" CAM BAL-O SSSV NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2927 2927 1 MMG DMY 0 11 /11 /06 2 4820 4819 2 MMG DOME RK 16 11/29/03 3 6101 6094 14 MMG DMY RK 0 4 7121 7033 26 MMG DOME RK 16 11/29/03 5 7663 7526 22 MMG DMY RK 0 6 7741 7599 22 MMG DMY RK 0 7 8054 7891 20 MMG DMY RK 0 ""8 8116 7950 19 MMG DMY RK 0 9 8364 8186 18 MMG SO RK 24 11/29/03 10 8442 8260 18 MMG E-DMY RKP 0 '"'CORRECTED GLM - ST#8 @ 8116' ORIGINALLY NOT LIST 8466' S-1/2" BKR PBR ASSY, ID = ? $4$$' 9-518" X 5-1/2" BKR SAB PKR, ID = ? 8498' I-~ 5-1 /2" X 4-1 /2" XO, ID = 3.958" 8584' -14-112" CAM DB-6 LAND NIP, ID = 3.687" 8595' 4-1 /2" BKR SHEAROUT SUB, ID = ? 8596' 4-1/2" TUBING TAIL, ID = 3.958" 8582' ELMD TT LOGGED 06/13/86, ~~~ I---I SL TOOLSTRINGS & IBP LOST IN HOLE 03/19/05 8628' ELM BKR IBP SET (05118/04) DATE REV BY COMMB~fT'S DATE REV BY COMMENTS 03/03/82 ORIGINAL COMPLETION 10/20!06 RLM/PAG CORRECTIONS -MULTI 2004 05/10/82 LAST WORKOVER 11/17106 KSB/PAG GLV GO (11111(06) 01/08/02 RN/TP CORRECTIONS 02/07/07 JMCITLH GLV CORRECTION (ADD 10th) 11/29!03 JLJ/TLP GLV GO 10/24/07 RRD/PJC JET CUT @ 6818' 04/07/04 JLJlKAK GLV GO 04/01/05 DAVITCH TOOLSTRIVG FISH (03!19105) I CMT RETA~IER (SET 12!25182) I PRUDHOE SAY UNff WELL: 14-29 PERMff No: 1811680 API No: 50-029-20680-00 SEC 9, T10N, R14E, 4886.58' FEL 8 2384.18' FNL BP Exploration (Alaska) • • Sag River Injector Downhole Oil/Water Separation -Gravity Tubing Conveyed ESP Max Open Hole ~ Dog Leg = 5°/ 100ft 2900 ft and Max Hole Angle = 40 ° ESP Wire Packer Hole Size for Pump is 4" ID 7" Liner ~ u u ~~na 1 W H c7 a` ~ 1 ~ Motor 9-5/8" Casing 4-1/2" Tubing Production provides motor cooling Press = Temp = a =_ Seals •1500BWPD' ~ ` • @ 6000 psi ~ • Blast Joints by Water J. Brady/LJL 1 /6/2006 _ _ - _ _ -_ - Kingak -_-_- -- - Shale ----- ~mp = ~ u~. m - - - - - - --- -- -- -- -- --- - _ ~ ` 10100' md, 8800' tvd _ -_ . ~ Sag River ~ ~ ' . ' - _ , _ - - °-. ~ - :, _ _ _-_-_ Shale -_-_-_ • 8940' tvd ' • ' . ' ~one'4 ~ ' • • • o a m # . . . • ' .Producing Zone' . ' . ; c ~ • 4000 BFPD ~ 92-98% WC , ,°, ~ • FBHP = 1500-1800 psi . T o Aes Temp x'220 °F' ' c Screen ~` Dip Tube TREE = GRAY GEN 2 WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 71' BF. ELEV. - KOP = 6000' Max Angle = 28 @ 6800' Datum MD = 9086' Datum TV D = 8800' SS 13-3/8" CSG, 72#> L-80, ID = 12.347" ~ 26pp' Minimum ID = 3.687" @ 8584' 4-1/2" CAM DB-6 LAND NIPPLE JET CUT (10/24/07) 6$18' ~ 14-29 ~, 5-1i2" CAM BAL-O SSSV NIP, ~ = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2927 2927 1 MMG DMY 0 11/11/06 2 4820 4819 2 MMG DOME RK 16 11/29/03 3 6101 6094 14 MMG DMY RK 0 4 7121 7033 26 MMG DOME RK 16 11 /29/03 5 7663 7526 22 MMG DMY RK 0 6 7741 7599 22 MMG DMY RK 0 7 8054 7891 20 MMG DMY RK 0 '*8 8116 7950 19 MMG DMY RK 0 9 8364 8186 18 MMG SO RK 24 11 /29/03 10 8442 8260 18 MMG EDMY RKP 0 ""CORRECTm GLM - ST#8 C~ 8176' ORIGINALLY NOT L15T $466' 5-1/2" BKR PBR ASSY, ID = ? $488' 9-5/8" X 5-1 /2" BKR SA B PKR, ID = ? ~ 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~ ~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9-5/8" CSG, 47#, L-80, ID = 8.681" H 8857' PERFORATION SUMMARY REF LOG: BRCS ON 02/28/82 ANGLE AT TOP PERF: 18 @ 8898' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8898 - 8914 C 06/09/92 3-3/8" 4 8934 - 8954 C 06/09/92 3-3/8" 4 9084 - 9120 C 08/29/91 3-1/8" 4 9123 - 9130 C 12/25/82 3-1/8" 4 9135 - 9155 C 12/25/82 3-3/8" 4 9160 - 9188 C 06/13/86 3-1/8" 4 9265 - 9267 S 12/25/82 ~PBTD ~ 95Z0' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9560' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/03/82 ORIGINAL COMPLETION 10/20/06 RLM/PAG CORRECTIONS -MULTI 2004 05/10/82 LAST WORKOVBt 11/17/06 KSB/PAG GLV GO (11/11/06) 01/08/02 RN/TP CORRECTIONS 02/07/07 JMGTLH GLV CORRECTION (ADD 10th) 11/29/03 JW/TLP GLV GO 10/24/07 RRD/PJC JET CIJT @ 6818' 04/07/04 JLJ/KAK GLV GO 04/01/05 DAV/TLH TOOLSTRING FISH (03/19/05) ~CMT RETAINER (SET 12/25/82) ~ PRUDHOE BAY UNIT WELL: 14-29 PERMfT No: 1811680 API No: 50-029-20680-00 SEC 9, T10N, R14E, 4886.58' FEL & 2384.18' FNL BP 6cploration (Alaska) TOP OF 7" LNR H 8534' 5-1/2" X 4-1/2" XO,ID = 3.958" i $5$4~~- (4-1/2" CAM DB-6 LAND NIP, ID = 3.687" 8595' 4-1/2" BKR SHEAROUT SUB, ID = ? 8596' 4-1/2" TUBING TAIL, ID = 3.958" 8582' ELMD TT LOGGED 06/13/86 ?~? H SL TOOLSTRINGS 8~ IBP LOST IN HOLE 03/19/05 ~ 8628' ELM H BKR IBP SET (05/18/04) TREE = GRAY GEN 2 WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 71' BF. El KOP= Max P Datun Datum C 1 ~9 Proposed Com~etion DATE REV BY COMMENTS DATE REV BY COMMENTS 03/03/82 ORIGINAL COMPLETION 10/20/06 RLM/PAG CORRECTIONS -MULTI 2004 05/70/82 LAST WORKOVER 11/17/06 KSB/PAG GLV GO (11/11/06) 01/08/02 RN/TP CORRECTIONS 02/07/07 JMGTLH GLV CORRECTION (ADD 10th) 11/29/03 JLJ/TLP GLV GO 04/07/04 JLJ/KAK GLV GO 04/01/05 DAV/TLH TOOLSTRING FISH (03/19/05) PRUDHOE BAY UNfi' WELL: 14-29 PERMff No: 1811680 API No: 50-029-20680-00 SEC 9, T10N, R14E, 4886.58' FEL & 2384.18' FNL BP Exploration (Alaska) FW: 14-29 BOPS configurat' for the completion Page 1 of 2 Maunder, Thomas E (DOA) From: Reem, David C [ReemDC@BP.com} Sent: Wednesday, November 14, 2007 2:28 PM To: Maunder, Thomas E (DOA) Cc: Chan, Paul (PRA) Subject: RE: 14-29 (181-168) BOPS configuration for the completion Tom, the plan would be to have a 4-1/2" safety joint available with a TIW valve to stab as required to lower across the stack and shut the well in should a well control situation arise during this short pahse of the completion operation. DCR From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Tuesday, November 13, 2007 1:42 PM To: Reem, David C; Chan, Paul (PRA) Subject: RE: 14-29 (181-168} BOPE configuration for the completion Dave and Paul, A good meeting was held with Jerry and Trina this morning. With regard to your no dual ram request, what is the contingency plan that would be employed if a well control situation were to arise while running the dual string? Thanks in advance. Tom Maunder, PE AOGCC Prom: Maunder, Thomas E (DOA) Sent: Friday, November 09, 2007 3:22 PM To: 'Reem, David C'; 'Chan, Paut (PRA)' Subject: RE: 14-29 BOPE configuration for the completion Dave and Paul, I suspect we will talk further next week on the plan. A meeting is tentatively set with Jerry and Katrina early next week. Regards, Tom Maunder, PE AOGCC Prom: Reem, David C [mailto:ReemDC@BP.com] Sent: Friday, November 09, 2007 1:32 PM To: Maunder, Thomas E (DOA) Subject: FW: 14-29 BOPE configuration for the completion Tom, please see Paul Chan's request below. Happy to discuss at your leisure. Thanks Dave Reem From: Chan, Paul (PRA) Sent: Thursday, November 08, 2007 3:45 PM 11/14/2007 FW: I4-29 BOFE configura~for the completion ~ Page 2 of 2 To: Reec-t, David C Subject: 14-29 BOPS cor-figuration for the completion Dave I forgot to request permission from the state to NOT put in dual rams for the short section of dual strings we will be running from 8450 - 9200' A14D, 'Chew two packer will be run and set on dritlpipe, There are no 4-1/2" x 2- 3/8" duat ram blocks that t know of. Can you c~fl Tom and ask to insert the correct verbiage to forgo the dual ram? Thanks Paul Chan workover Engineer BP Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax 11/14!2007 • Maunders Thomas E (DOA) From: Cooper, Katrina N [Katrina.Cooper@bp.eom] Sent: Thursday, November 08, 2007 3:42 PM To: Williamson, Mary J (DOA); Maunder, Thomas E (DOA) Cc: Reem, David C; Brady, Jerry L; Chan, Paul (PRA) Subject: RE: DS 14-29 (181-168) Workover Plan Jane and Tom, Fage 1 ofd ~~ Jerry and 1 will come over to the AOGCC at 9:00 AM on Tuesday Nov 13. We'll bring a couple of diagrams and see if we can answer your questions. Trine Trine Cooper, PE East Waterflaod Subsurface Team Leader (and DS 14 engineer) Work: 907-564-4212 Home: 907-279-2667 Celt: 907-230-4212 E-mail: cooperkn~bp.com F :Williamson, Mary J (DOA) [mailto:jane.wiNiamson@aiaska.gov] Sent: nesday, November 07, 2007 4:31 PM To: Brady, rry L; Cooper, Katrina N Cc: Reem, Da C; Maunder, Thomas E (DOA) Subject: RE: DS 9 (181-168) Workover Plan Actually, if one of you (or yo drill-site engineer) could come by and give Tom an a an overview, it would probably save time and bunche f e-mails. Thanks From: Maunder, Thomas E (DOA) Sent: Wednesday, November 07, 2007 4:18 P To: Williamson, Mary J (DOA) Subject: FW: DS 14-29 (181-158) Workover Plan FYI From: Reem, David C [mailto: mDC@BP.com] Sent: Wednesday, Nove r 07, 2007 4:15 PM To: Cooper, Katrina rally, Jerry L Cc: Maunder, Th as E (DOA) Subject: FW• S 14-29 (181-158) Workover Plan Folk an you guys take a stab at answering Tom Maunder's questions #1-2 on the 14-29 project? P Chan is 0 of town or else I'd pass this request on to him. 11/8/2007 • Maunder, Thomas E (DOA) From: Williamson, Mary J (DOA) Sent: Wednesday, November 07, 2007 4:31 PM To: jerry.brady@bp.com; katrina.cooper@bp.com Cc: reemdc@bp.com; Maunder, Thomas E (DOA) Subject: RE: DS 14-29 (181-168) Workover Plan • Page 1 of~~ ~~ Actually, if one of you (or your drill-site engineer) could come by and give Tom and me an overview, it would probably save time and bunches of e-mails. Thanks From: Maunder, Thomas E (DOA) Sent: Wednesday, November 07, 2007 4:18 PM To: Williamson, Mary J (DOA) Subject: FW: DS 14-29 (181-168) Workover Plan FYI From: Reem, David C [mailto:ReemDG@BP.com] Sent: Wednesday, November 07, 2007 4:16 PM To: Cooper, Katrina N; Brady, Jerry t Cc: Maunder, Thomas E (DOA) Subject: FW: DS 14-29 (181-168) Workover Plan Folks, can you guys take a stab at answering Tom Maunder's questions #1-2 on the 14-29 project? Paul Chan is out of town or else I'd pass this request on to him. Tom, the "problem area" refers to corroded /damaged tubing that recently ate up the 4th slickline toolstring in this well. You can run tools past/thru this damaged pipe but the slickline gets snipped off at the rope-socket as the tools are pulled. This damaged tubing is likely a very wide gap in the low side of the hole that is completely corroded away. As such, we anticipate extensive fishing operations to get this old pipe out of the well. DCR From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, November 07, 2007 3:46 PM To: Reem, David C Cc: Williamson, Mary) (DOA); Arthur C Sa[tmarsh Subject: DS 14-29 (181-168) Workover Plan Dave, Following up on our conversation yesterday, we are requesting some further information. 1. Mechanically I need further detail on the proposed completion. [t is unclear exactly where fluids are produced or injected. 2. The reservoir engineer should contact Jane Williamson (793-1226} to further explain the reservoir aspects of this proposal. 3. In the pre-rig section mention is made of a "problem area at 6921' and". Could you or Paul provide additional information on the "problem"? Thanks in advance. CaR or message with any questions. Tom Maunder, PE 11 /8/2007 • • by c~,~. 14-29 Rig Workover Objective: The objective of the RWO is to run a completion that will enable Zone 4 production to continue in the updip area of DS14 while allowing a slip stream of Ivishak water to be injected into the Sag River formation with an ESP to increase recovery in offset producers. Scope of Work: Pull 5-'/z" completion, mill and retrieve Baker SAB packer, fish IBP and slickline tool strings, drill out cement retainer at 9250" MD, cleanout well to 9400' MD, isolate perforations at 9265' - 9267' MD, run 3 packer completion with ESP on 4-'/z" 13Cr-80 tubing. MASP: 2370 psi Well Type: Ivishak Producer and Sag River Injector Estimated Start Date: November 21, 2007 Pre-ria prep work: S 1 Drift thru 5?/z" tubin for tubin cut. F 2 MIT-OA to 2000 si. No CMIT re uired. E 3 Jet cut the 5-'h" L-80 tubing at 6821' MD, in the middle of the first full joint 100' above the roblem area at 6921' MD. Reference tubin tall dated 05/10/82. F 4 Circulate well with kill wei ht fluid and diesel thru the cut. W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. S 6 Set WRP at 1400' MD. Adjust set depth as necessary to obtain a pressure test. Pressure test to 1500 si. Perform this ste 'ust rior to ri arrival. O 6 Set a BPV in the tubin han er. O 7 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU workover rig. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Retrieve 5-'h" tubing string down to the packer. 3. Mill and retrieve Baker SAB packer at 8488' MD. 4. Fish SL tool strings. Fish IBP. 5. Mill up cement retainer at 9250' MD. 6. cleanout well to 9400' MD. 7. Isolate perforations from 9265' - 9267' MD with either a cemented scab liner or patch. 8. Run RST-sigma log to determine if any additional Ivishak zones need to be perforated. Run USIT log from 9320' PBTD to 8534' MD. Re-perforate Sag River from 8898' - 8914' MD. Add Ivishak perfs if needed. Depths to be determined from RST log. 9. Set 7" RBP at 9050' MD. POOH. 10. Run STP-RST borax log from 9050' to 8534' MD. 11. RIH and unset 7" RBP. POOH to 8700' MD and set RBP. Test casing to 3500 psi. 12. Run 4-'/z" kill string to 8400' MD. 13. Set BPV. ND BOPE. NU and test tree. RDMO workover rig. • • 14. MIRU completion rig. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater. 15. Pull and lay down 4-~/z" kill string.. 16. Run and set 7" Baker GT dual packer (at 9050' MD) and 9-5/8" Baker Twinseal packer (at --8450' MD} on drillpipe. Packers will be fogged into place. 17. Run Baker PBR seal, gauge carrier, "upside" down ESP with shroud, and 9-5/8" Baker GT dual packer at 8250' MD on 4-'/z" 13Cr80 tubing. Space out Baker PBR seal into 9-5/8" Baker Twinseal packer at 8450' MD. 18. Displace the IA to packer fluid and set the packer. 19. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 20. Set BPV. ND BOPE. NU and test tree. RDMO. Prudhoe Bay DS-14, Well 29 Gas Venting Information ¢~i~i!~~ii~~!~~ii:~::::i::i~::~::~~!~.:..ii~~ii~i~i~i~i~i~i~i~i::~i~i~i::~i~i~!~ii::~i~i~i~::~...:..::-~i~}~::~[~!iii!~J~ii~!~ii~i~i~i~iii~::~i~i~ii~!i!~i~ .~..~i~}.~.i~::~::::::::::::.:-:-:.:s::.-...-....--:.:.:.:.:-:.:......-.---.->-....:-.-?-:-:-:~---------~--.-------.-.-.-.-.-.×.-.-...-.-.-...-. ........ ':'" "i~it:':':"- ........ '""' ":"~'"-'"' ":':'-":'-":':':~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: To: Wendy_Mahan~admin. state.ak.us /~£,~, ,,.. ,o, ee ~'~ Wendy, This note is to provide the written report on the 14-29 venting incident of Jun~ 10, 1999 as required by 20ACC 25.205 (b). Time of Incident: June 10, 1999 5:45pm Location Where Incident Took Place: Prudhoe Bay Arco Drillsite 14 Volumes of Crude Oil & Natural Gas Lost: <40 bbls oil; estimated 674 mscf gas Cause of Loss: External corrosion failure on well 14-29 flowline between wellhead and mani fold building. Actions Taken and Planned to Prevent Further Loss: The well was isolated at the wing valve and surface safety valve. A formal investigation team has been formed to review this incident to assist in the prevention of this type of loss in the future. Specific actions will result from this investigation. If further information is necessary, please contact us at 659-5566. Paul Andrews EOC Supervisor I of 1 6/14/99 1:11 PM MEMORANDUM TO: State of Alaska Ali~ska Oil and Gas Conservation Commission Robert Christenson,~ DATE: June 12, 1999 Chairman THRU: BlairWondzell, ~ FILE NO: P. I. Supervisor FROM: Lou Grimald~ SUBJECT: Petroleum Inspector GG9JFLGF.DOC Parted Flow-line inspection Arco well #14-29 Prudhoe Bay Field Saturday, June 12, 1999; I made a site inspection of the parted Flow-line on Arco's well #14-29 in the Flow Station #3 area of the Prudhoe Bay Field. I met with George Williamson (Flow 3 supervisor) and Tom Manson (Arco Environmental) on the access road to Drillsite 14. We discussed the situation at present and proceeded to the site of the parted Flow-line. The Flow-line on the wellhead end was parted and split from what appeared to be caused by external corrosion on the bottom side of the pipe. Looking inside the split portion I could not see any evidence of internal corrosion. I asked George if the SVS system was in-service at the time of the break and he assured me that it was. The Flow- line had folded over on itself effectively pinching off the flow which most probably held enough back pressure on the line to keep the LPS from tripping. There was a good amount of collateral damage to the Flowlines (both Crude and Artificial lift) evident along with the V.S.M. that supported them. These lines although damaged, did not appear to be parted or leaking. These lines will be fully inspected and repaired as needed. I asked George for a preliminary report that I could include with my report, which he provided me and is included. I asked to be provided with information as it becomes available. ., SUMMARY: I made a preliminary investigation of the parted Flow-line on Arco's well #14-29 in the Prudhoe Bay Field. Attachments: 14-29 Flow-line. JPG, 14-29 Flow-line 2.JPG Arco preliminary accident assessment. cc; George Williams (Arco Flow Station 3 supervisor.) CONFIDENTIAL 0Un-13-99 10:19A CTD P.Oi Well 14.29 Flowline Failure On 6110/99 around 5:45PM well 14-29 flowline failed sending oil, water and gas across the Drill Sile I¢ pad. The failure was observed by the on site operator, reported immediately and emergency crews responded. The site was secured, the incident evaluated and approximately 50 minutes later thc source was shut in. The associated spill was about 30 bbis of oil and 120 bbls of water contained on ~.he gravel pad. In addition, less than ! bbl of oil and I bbl of water spread in a fine mist very lighlly over approximately 30 acres off pad. No wildlife was affected. Absorbent boom was strategically placed in ponds, lakes and a nearby river as a precautionary measure to assure containment. The affected gravel is being recovered and will be propedy disposed. For the affected off pad areas, sheen on ponds or free standing water will be removed using absorbent pads and the vegetation will be monitored for natural recovery. Final clean up plans will be coordinaled with thc appropriate agencies. Well 14-29 was shut-in m 12:42 PM for a production proration. The proration was anticipated to be of short duration (less than 24 hours). All well safety systems on 14-29 were active (n~t defeated) at the time of failure. The flowline fully ruptured and separated into two }[ne sections. The sectkm attached to manifold building was immediately depressured. Fluids continued to discharge from the section et' line altached to the wellhead. The rapid energy release caused this section of flewline to fold back on itself partially restricting fluid flow. This restriction kept back-pressure on the parted section of flowline and the wellhead safety systems did not activate. Emergency response personnel isolated the flowline by opening the emergency dump valve outside thc wellhouse. Subsequently, they closed the wing valve for redundant isolalion. Due to hazard{~t~s conditions surrounding the wellhouse, personnel could not immediately access the emergency dump valve, Fluids were flowing from. the ruptured line in the direction of the wellhouse, After emergency response personnel arrived with proper protective equipment and rescue back-up, the On- Scene-Commander approved the isolation plan. An Incident Investigation Team has been formed to study thc root-cause of failure and any corrective actions, STATE OF ALASKA -ALASKA OIL AND GAS CONSERVATION COMMISSI '~ 6. Datum of elavation (DF or KB feet): 71' RKB ~'~ 1. Operations performed: REPORT OF SUNDRY WELL OPERATIONS 2. Name cf Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchora~le, AK 99510-0360 4. Location of well at surface: 2225' FNL, 847' FEL, Sec 9, T10N, R14E, UM. At top of productive interval: 2439' FNL, 234' FWL, Sec 10, T10N, R14E, UM. At effective depth: 2416' FNL, 322' FWL, Sec 10, T10N, R14E, UM. At total depth: 2387' FNL,392' FEL, Sec 10, T10N, R14E, UM. 7. Unit or Property: Prudhoe Bay Unit 8. Well number: 14-29 9. Permit number/approval number: 83-168 10. APl number: 50-029-20680 11. Field/Pool: Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: Operation Shutdown_ Stimulate_.~ Pull tubing _ Alter casing _ 5. Type of Well: Development _X Exploratonj _ Stratagrapic _ Service _ measured 9560 feet Plugs (measured) true vertical 9324 feet Effective Depth: measured true vertical 9179 feet Junk (measured) 8959 feet ORIGIN PBTD Tagged @ 9179' MD (7/9/98). Cemented Measured depth True vertical depth 76' 2600' 8653' 9324' Casing Length Size Conductor 76' 20" Surface 2529' 13-3/8" Production 8786' 9-5/8" Liner 1026' 7" 400 Sx Permafrost II 76' 2000 Sx AS III & 2600' 400 Sx AS I 500 Sx Class G 8857' 350 Sx Class G 9560' Perforation Depth measured 8898 - 8914'; 8934 - 8954'; 9084 - 9120'; 9123- 9130'; 9135 - 9155'; 9160 - 9188' true vertical 8693 - 9708'; 8795- 8815'; 8869- 8903'; 8906- 8912'; 8917- 8936'; 8941 - 8968' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8498' MD; 4-1/2", 12.6#, L-80, PCT @ 8596' MD Packers and SSSV (type and measured depth) Baker SAB Packer @ 8488' MD; 5-1/2" Camco BaI-O SSSV @ 2192' MD see attached Representitive Daily Average Production or In!ection Data 13. Stimulation or cement squeeze summary Intervals treated (measured) Intervals treated (measured) OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 1285 13581 3806 - 481 Suspended _ Service _ 14. SUBMIT IN DUPLICATE Pdor to well operation Subsequent to operation 1377 14431 4247 15. Attachments 116. Status of well classification as: I Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil _X Gas _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~~ ~/1' ~ Title: Engineering Supervisor Form 10-404'~v 06/15/88 14-29 DESCRIPTION OF WORK COMPLETED HCL ACID STIMULATION TREATMENT OF ZONE 4 3/19/98: RIH & tagged PBTD at 9181' MD. 5/26/98: A CTU HCI Acid Stimulation Treatment was performed as follows: MIRU CTU & PT equipment. RIH w/CT loading the wellbore w/Crude. Tagged bottom, then PU and reciprocated an Acid Stimulation Treatment to remove CaCO3 Scale Damage, across the open Zone 4 perforations at: 9084- 9120' MD (Z4) 9123 - 9130' MD (Z4) 9135- 9155' MD (Z4) 9160- 9188' MD (Z4) Ref. Log: BHCS 2/28/82. Pumped: a) 55 bbls 75% Diesel/20% Xylene/5% Musol @ 2.5 bpm, followed by b) 240 bbls 12% HCI w/10% Xylene @ 1.2 - 2.3 bpm, followed by c) 60 bbls 2% KCI Water Overflush w/Citric Acid & Musol, followed by d) Shutdown. POOH w/CT. RD. 7/9~98: RIH & tagged top of fill at 9179' MD. Placed the well on production & obtained a valid production welltest. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATrN: Sherrie NO. 9628 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 8/9/95 Field: Prudhoe Bay ~ Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 6-7 ~ ~ O ~ I PROD PRORLE 950724 I 1 D.S. 12-30 ~ ~ I ~'~ PRE, URE BUILD UP 950721 I 1 D.S. 14-29 '~1 j ~ ~ PRODPRORLE 950721 I 1 D.S. 15-14 ~l '1~ ~ ~RFRE~RD 950721 I 1 D.S. 15-24 E I I ~ LEAKD~ECTION 950721 I 1 D.S. 15-36 ~ ~ 7~ ~RFRE~RD' 950724 I 1 D.S. 18-2A ~ ~ ~ ~ ~ PROD PRORLE ... 950716 I 1 D.S. 15-25~ ~-~O 95261 DUAL BURSTTDT-P ~ ~ ~ 950725 1 D.S. 11-3A ~.~ 95260 CNTD[~ ~q/ 950718 1 D.S. 15-1 ~Z.O~ 95262 DUAL BURST TDT-P ~ ~ 950726 I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Drill Site: 14 Well: 29 K-VAL%~ DESIGN. Sat Jan 22 18:11:49 1994 COMMENTS: ti' Du~ ~ET PRE.~URE: 345 PS~ @ 6u DEG : ' Si FTP @ CLOSE (PS,'IG): 330 PSiG ~' T/his will require the well be choked back to keep · zrom dumping. To aid in dumping,~ if ok, Open up the drain system. CC: ENGINEERING FiLE / COORDINATOR PRB 24 (WITH ATTACHMENTS) J.C. SMART / M.G. SNOEM~kKE PRB 20 (WITHOUT ATTACHMENTS) Jmmes Fausett / Scott~Piggott PRB 13 (COVER ONLY) Rydeii Reints ATO 15 (WITHOUT ATTAC~.~NTS) STATE OF ALASKA (COVER ONLY) DESIGNED BY: Drill Site: 14 Well: 29 CK LGR FTP OIL %~TR 82 83 82 82 82 82 82 82 82 81 81 WELL TEST DATA Sat Jan 22 18:11:50 1994 GOR GLR LiQ P~ PI SEPARATOR DATE SEL TF~ PRES 0 318 3225 55.8 4375 1931 7306 0 0.00 171 218 01/20/94 0 340 3118 57.8 4167 I755 7401 1407 3.32 171 220 0i/~02/94 Y 0 331 3135 57.1 4649 1993 7310 0 0'00 170 230 12/15'/93 0 327 3i64 57.5 4757 2019 7454 0 329 3100 57.3 4654 1983 7274 0 332 3130 57.2 4658 i989 7329 0 332 3194 57.5 4677 1985 7524 0 331 3325 57.2 4496 1923 7771 0 334 ~ 3Z,6 57.0 4490 1926 7634 0 333 3421 55.6 4245 1882 7714 0 326 3388 56.0 4293 1887 7706 0 0.00 169 226 12/01/93 0 0.00 172 233 11/19/93 0 0.00 169 236 11/10/93 0 0.00 170 235 10/30/93 0 0.00 170 227 09/29/93 0 0.00 170 232 09/29/93 0 0.00 170 228 09/09/93 0 0.00 170 217 08/30/93 Drill Site: 14 Well: K-VALVE DESIGN Sun Apr 18 15:16:23 1993 DOME SET PRESSURE: FTP @ CLOSE (PSIG): K-VALVE CLASS (A, B, C.): 285 PSI¢ @ 60 DEE F 145 PSI= C COMMENTS: Well moved into LP CL on 4/15/93. Redesign assumes an increase in watercut and ~OR. Will need to .be pulled to test. CC: EN~INEERIN= FILE / COORDIN~R~J~ PRB24 (WITH ATTACHMENTS.) J.C. SMART / M.=. SHOEMAKE PRE 20 (WITHOUT ATTACHMENTS) J.E. FAUSETT / C.W. SHUMWAY PRB 13 (COVER ONLY.) J.L. Bacak ATO 1578 (WITHOUT ATTACHMENTS.) STATE OF ALASKA (.COVER ONLY) DESIGNED BY: R. T. Burno ARCO ~1~: Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 9-18-92 REFERENCE: ARCO CASED HOLE FINALS 14-18 14-29 6-4-92 5-8-92 5-29-92 6-12-92 7-2-92 6-9-92 6-9-92 4-18-92 7-3-92 Run 1j, 5" Run 1, 5" R.n 1, 5" Run 1, 5" R-n 1, 5" Run 1, 5" Run 1, 5" R.n 1, 5" Run 1, 5" Peri Record Peri Record Peri Record Peri Record Peri Record Peri Record Peri Record Peri Record Peri Record # ~-I,IPS PB WEI~ FILES R&D # BPX # STATE OF ALASKA TEXACO Please sign and return.~at~/~l co__of data. I;UECEIVED AT0-1529 ~s~ 9220~ ~ -- ~ 0il & 6as Cons. C0mmissi0~ ~chorage e ~~ON ~ EX~NSION E~~~TION ~ E~ON ~~ON ~ MO~ STATE OF ALASKA REPORT SUNDRY 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X _ Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2225' FNL, 847' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 2439' FNL, 234' FWL, Sec. 10, T10N, R14E, UM At effective depth 2416' FNL, 322' FWL, Sec. 10, T1 ON. R14E, UM At total depth 2387' FNL, 392' FWL, Sec. 10, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service JUL 1 0 Alaska 0il & Gas Cons. Anchore. ge 6. Datum of elevation(DF or KB) 71' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-29 9. Permit number/approval number 81-168 10. APl number 50 - 029-20680 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth' measured true vertical 9560 feet Plugs(measured) 9324 feet Effect ive depth: measured 9246 feet true vertical 9023 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 76' 20" 400 sx Permafrost II 76' 76' Surface 2529' 13-3/8" 2000 sx AS III & 400 sx ASI 2600' 2600' Production 8786' 9-5/8" 500 sx CI "G" 8857' 8653' Liner 1026' 7" 350 sx CI "G" 9560' 9324' Perforation depth: measured 8898-8914'; 8934-8954'; 9084-9120'; 9123-9130'; 9135-9155'; 9160-9188' true vertical 8693-8708'; 8795-8815'; 8869-8903'; 8906-8912'; 8917-8936' 8941-8968' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC tubing @ 8498' MD; 4-1/2", 12.6#, L-80 PC tubing @ 8596' MD Packers and SSSV (type and measured depth) 5-1/2" Camco Bal-0 SSSV @ 2192' MD; Baker SAB Packer @ 8488' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 3819 - 10201 2669 1111 3777 J' 10424 2794 1074 Tubing Pressure 893 897 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as' Oil ~ Gas , Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~' ~~.~ Title Senior Engineer Form 10-404 Rev 06/15/88 JLB c: SW Date SUBMIT IN DUPLICATE '% SUMMARY OF WELL OPERATIONS ARCO Alaska, Inc. perforated DS 14-29 at selected intervals in the Sag River and Shublik formations of the Prudhoe Bay Unit on 6/9/92 (8898-8914'MD, 8934-8954'MD Ref Log: BHCS 2/28/82). Produced fluids were in the wellbore at the time of perforating. A short summary of the work is given below. - Began perforating operation on 6/9/62. - RU perforating unit and pressure tested equipment to 3000 psi. - RIH w/ gun #1, tied-in, and shot #1: 8934-8954'MD @ 4 spf. - POOH. All shots fired. - RIH w/ gun #2, tied-in, and shot #2: 8898-8914'MD @ 4 spf. - POOH. All shots fired. - Secured well. RD. RECEIVED J U L 1 0 199 - Alaska Oil & Gas Cons. Comm'tss'tor~ Anchorage JLB 6/25/92 Drill Site: 14 Well: 29 K-VALVE DESIGN Sun Jan 19 09:46:21 1992 DOME SET PRESSURE: 635 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 750 PSIG K-VALVE CLASS (A,B,C): A COMMENTS: Redesigned K-Valve following wellwork. Test valve in LP system. CC: C.P. FARMER / W.D. COOPER~ J.C. SMART / M.G. SHOEMAKE J.E. FAUSETT / C.W. SHUMWAY ENGINEERING WELL FILE PRB 24 PRB 20 PRB 13 DESIGNED BY: Kara 1578 Printing contents of current screen - wait for message to Clear RECEIVED. FEB 1992 Alaska 0il & Gas Cons. Commission Anchorage Drill Site: 14 Well: 29 Thu Oct 17 08:51:50 1991 K-VALVE DESIGN SSSV DEPTH (MEAS): 2192 FTP @ CLOSE (PSIG): 800 PRESS ADJUSTMENT: 200 TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: SEP COML CK LGR FTP OIL %WTR GOR GLR LIQ PWF PI TEMPPRES DATE SEL 64 0 1025 6418 19.1 3043 2459 7942 2357 6.12 167 0 10/12/91 Y CONDITIONS AT CLOSURE: 64 0 800 7393 19.1 3043 2459 9149 2169 6.12 167 0 WELL TEST @CLOSE TEMPERATURE @ SSSV: 192 197 PRESSURE @ SSSV: 1321 1120 DOME SET PRESSURE: 680 PRIOR DESIGNS: DATE: 04/08/91 o /o1/81 os/ol/es SET PRESSURE: 180 FTP @ CLOSURE: 185 0 -i- 0 0 0 TEMP: LINEAR NA NA ESC=EXIT; Fl=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SFS=RESTORE WELL TEST; CF9=CYCLE DATA; Printing contents of current screen - wait for message to clear Drill Site: 14 Well: 29 Thu Oct 17 08:52:57 1991 SENSITIVITY TABLE P.I. 6.12 6.12 6.12 6.12 %WTR 19 . 0 30 . 0 19 . 0 30 . 0 GOR 3043 3043 5000 5000 LGR 0 0 0 0 FTP I 800 1120 1112 1180 1160 FTP 2 700 1037 1025 1111 1086 FTP 3 100 743 704 912 861 ENTER VALUES FOR PRODUCTIVITY INDEX, WATER CUT, GAS-OIL RATIO, LIFT GAS RATE, AND FLOWING TUBING PRESSURE 1, 2, or 3. PRESSURES AT THE SSSV WILL BE CALCULATED FOR EACH GROUP OF ITEMS ENTERED. ESC=EXIT; FI=HELP; F2=WELL TESTS; F3=DESIGN; F4=DISTRIBUTION LIST; F6=CHECKLIST; F10=ACCEPT; ~Printing contents of current screen - wait for message to clear Drill,'Site: 14 Well: 29 K-VALVE DESIGN ThU Oct 17 08:58:12 1991 DOME SET PRESSURE: 680 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 800 PSIG K-VALVE CLASS (A, B 'C ): A COMMENTS.' New design due to increasing GOR, post frac. Well is planned to be operated at 900 ftp. CC: C.P. FARMER / W.D. COOPERv' .K.M. KENNEDY / L.D. LASH RalPh / BraSsfield PRB 15 ENGINEERING WELL FILE PRB 24 PRB. 20 STATE OF ALASKA (COVER) DESIGNED BY: Matt Maguire Printing contents of current screen - wait for message to clear STATE OF ALASKA ALASK/'~tLAND GAS CONSERVATION C )MISSION REPORT OF SUNDRY WELL OPI:RATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging -~. Pull tubing ~ Alter casing Repair well --.. 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic X Perforate X Other 6. Datum of elevation(DF or KB) 71' RKB 7. Unit or Property Prudhoe Bay Unit 4. Location of well at surface 2225' FNL, 847' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 2439' FNL, 234' FWL, Sec. 10, T10N, R14E, UM At effective depth 2416' FNL, 322' FWL, Sec. 10, T10N/R14E, UM At total depth 2387' FNL, 392' FWL, Sec. 10, T1 ON, R14E, UM 8. Well number 14-29 9. Permit number/approval number 81-168 10. APl number 50 - 029-20680 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9560 feet Plugs(measured) 9324 feet Effective depth: measured 9246 feet true vertical 9023 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 76' 20" 400 sx Permafrost II 76' 76' Surface 2529' 13-3/8" 2000 sx AS III & 400 sx ASI 2600' 2600' Production 8786' 9-5/8" 500 sx CI "G" 8857' 8653' Liner 1026' 7" 350 sx CI "G" 9560' 9324' Perforation depth: measured 8907-8909'; 9084-9120'; 9123-9130'; 9135-9155'; 9160-9188' true vertical 8701-8703' 8869-8903'; 8906-8912'; 8917-8936' 8941-8968' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC tubing @ 8498' MD; 4-1/2", 12.6#, L-80, PC tubing @ 8596' MD Packers and SSSV (type and measured depth) 5-1/2" Camco Bal-0 SSSV @ 2192' MD; Baker SAB Packer @ 8488' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. 0c-r 1 4 1991 ,q~.~kn 0il & Gas Cons. Gomt~ss~t~--' Representative Daily Averao_ e Production or Iniecti0n Data ~3ttot'agtl OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1276 3932 2288 - 238 Subsequent to operation 7114,- ..... 21358 1383 938 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 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. Signed .... -_-- Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 762/5 DRR c: SW, JWP DS 14-29 DESCRIPTION OF WORK COMPLETED PERFORATING & FRACTURE TREATMENT OF SAG/Z4 8/29/91: Added perforations: 8907 - 8909' MD (Sag) Ref. Log: BHCS 2/28/82. Reperforated: 9084 - 9120' MD (Z4) Ref. Log: BHCS 2/28/82. 9/4/91: MIRU & PT equipment to 4000 psi. RIH w/CT & pumped 23.5 bbls of sand slurry containing 3,000 lbs of 20/40 mesh & 300 lbs of 100 mesh sand, to isolate perfs at: 9123 - 9130' MD (Z4) 9135- 9155' MD (Z4) 9160- 9188' MD (Z4) 9/6/91: RIH & tagged top of sand plug at 9129' MD. 9/8/91: Made several runs w/dump bailer to place additional sand to fully isolate the lower perforation intervals (listed above). A final tag indicated the top of sand at 9114' MD. 9/9/91: MIRU & PT equipment to 9000 psi. Pumped a Hydraulic Fracture Treatment using 12/18 mesh intermediate strength proppant, through the upper perforation intervals located above the sand plug, at: 8907 - 8909' MD (Sag) Ref. Log: BHCS 2/28/82. 9084 - 9120' MD (Z4: Bottom 6 feet sand covered). / Pumped: a) 250 bbls Uncrosslinked Pre-Pad, @ 45 bpm, followed by b) Shutdown. ISIP @ 1898. Resumed pumping: c) 100 bbls 40# Crosslinked Gelled Pad w/5% Diesel, @ 45 bpm, followed by d) 100 bbls I ppg Linear Gel, followed by e) 300 bbls Flush, followed by f) Shutdown. ISIP @ 1963. Resumed g) h) i) J) Placed a pumping: 300 bbls Crosslinked Pad, @ 45 bpm, followed by 229 bbls Crosslinked Slurry @ 1-10 ppg proppant concentrations, followed F! 204 bbls Flush, followed by R E CF-! V Shutdown. 9/14/91 Performed a sand plug/proppant fill cleanout. £D total of.~_lb~ of proppant into the formation. Rigged down. 0c'r '~ 4 ~91 - 9/15t91' Alaska 0il & Gas Cons. C0mm[ss~0a Tagged bottom at 9075' MD. N~ch0rage Placed well on production & obtained a valid welltest. Another proppant fill cleanout is being considered, and flow rates are still increasing with step ups from restricted choke settings. ARCO ALASKA, INC. F'.O. BOX i00S60 ANCHORAGE, ALASKA 995t DATE: 9-t 3-9t REFERENCE' ARCO CASED HOLE FINALS 3-4' 8-25-9t TUBING CUTTER 3-3 t" 9- t -9 t F'ERF RECORD 4- t 5J 8-28-9 t COLLAR t3-4- 7-25-9t F'ROD F'ROFILE J ~-34~ 8-29-9 ~ COLLAR-F'ERF ~ 4-6~ 7-27-9J GA~' LIFT J4-7~ 9-2-9J F'ERF RECORD ~ 4-~ 8' 8-3~ -9~ COLLAR-F'ERF ~4-2~ 8-29-9~ F'ERF RECORD ~8-~6- 8-3J-9~' F'ERF RECORD RUN t, RUN i, RUN i, RUN t, RUN t, RUN t, RUN 1, RUN t, RUN t, RUN 1, RUN t, RUN ~, RUN t, .RUN i, 1 5' 5' 5" 5' , 5' 5' 5' 2'&5' 5' 5' 5' PLEASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIVED BY' ~__.~ HAVE A NICE DAY!' ,$ONYA WALLACE AT0-1529 RECEIPT OF DATA. APPROVED TRAN~'$ 9 t ATLAS $CH ATLAS $CH SCH $CH CAMCO CAMCO ATLAS' CAMCO ~'CH ATLAS SCH $CH DISTRIBUTION $ CENTRAL FILES $ CHEVRON D & M $ EXTENSION EXPLORATION · ~ EXXON MARATHON .~. . · ~ MOBZ'i~'. .- PHILLIF'$ F'B WELL FILES R & D BF'X STATE OF ALASKA TEXACO RECEIVED Drill Site: 14 Well: 29 K-VALVE DESIGN DOM.E SET PRESSURE: 175 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 157 PSIG K-VALVE CLASS (A,B,C): C COMMENTS: BENCH TEST CC: C.P. FARMER / W.D. COOPER ENGINEERING WELL FILE PRB 24 PRB 20 PRB 13 M.O. JOHNSON ATO 1552 STATE OF ALASKA (COVER) DESIGNED BY: AWB Printing contents of current screen - wait for message to clear Drill Site: 14'~eli: 29 Thu Jun 27 19:39:14 1991 ~ K-VALVE DESIGN SSSV DEPTH" FTP @ CLOSE (PSIG')~':~ ...... i57 P~SS ~JUST~NT: 74. T~ COLLATION: LINE~ N~E: LINE~ CO~ USES SEP TE~, PI PROF USES BH T~ ~D ~LL PI CONDITIONS OF WELL TEST: SEP COML CK LGR FTP OIL %WTR GOR GLR LIQ PWF PI TEMP PRES DATE SEL 86 2826:~ 226 1514 65.0 1230 1083 4328 1166 1.68 165 0 06/23/91 Y CONDITIONS AT CLOSURE: 86 2826 157 1595 65.0 1230 1050 4558 1032 1.68 165 0 WELL TEST @CLOSE TEMPERATURE @ SSSV: 1'80 180 PRESSURE @ SSSV: 380 306 DOME SET PRESSURE: 175 PRIOR DESIQNS: DATE'.: 0 4 / 0.8 / 91 SET PRESSURE: 180 FTP @ CLOSURE: 185 TEMP: LINEAR 01/01/81 0 0 NA 01/01/81 0 0 NA ESC=EXIT; Fl=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SENSITIVITY TABLE; F10=ACCEPT; SFS=RESTORE WELL TEST; CF9=CYCLE DATA; Printing contents of current screen - wait for message to clear Drill Site: 14 Well: 29 Thu Mar 21 15:03:24 1991 K-VALVE DESIGN DOME SET PRESSURE: 180 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 185 PSIG K-VALVE CLASS (A,B,C): C CC: C.P. FARMER ~- PRE 24 K.M. KENNEDY ! W.S. WILDER PRE 20 J.P. WINTERS / C.W. SHUMWAY PRB 13 ENGINEERING WELL FILE M.O. JOHNSON ATO 1552 STATE OF ALASKA (COVER) DESIGNED BY: KARA Printing contents of current screen - wait for message to clear FCEIVED APR 7 199i Alaska Oil & ~a.~ ~.o~$. (JO~missior,~ ARCO ALA,?KA., iNC.~ P~O. BOX ~ 0,:..';,360 ANCHORAGF, ALASKA DATE' '?-i'?-gG REFEF;'.Ei'.iCE' AF;.:CO CA::~..'ED HOLE FINALS TEMF' F'F;:ODUCT i ON F'ROF.I: LiE F" ]2 "1" $ F'RODUCT ti: ON F'ROF I 1..E C;.R INJECTIOiq F'i:;:CIF I LE :i: iq J ::-' C T I 0 iq P R ('i F' I I.. INJECTION F:'ROF ]:L.E iNJECTION F.'ROF1LE F'I;..'ODUCT I ON F:'ROF I I-E F' R 0 D U C'. T I 0 N r-;' R C.I F' I L ff 'i'EMP F'ERF BREAK-t)ONN 2URVE:Y PRODUC;'t-'F_ ON PROF.' I I_E F'RODLICT ION P'ROF I I_E: LEAK DE't-ECT l:ON RUN i ,' !Rt. JN i, F,..' U N i , RUN 1, RtjN i, RUN i , F;.: L.tN i , RUN i, R UN i , RUN i , R U i'.! i , RUN i , RtJN i, RUN i , RUN t , PI_EAZE' SIGN AND RETURN THE ATTACI-iED HAVE: A NICE DAY! .'~'AL.I..Y HOFF'ECK ER A T 0- i '3 '2 9 COPY A3: RE:CE:'IF'T OF DATA. ! JUL t~ u .E~'i:"ROVED ~ Alaska 0ii & u,:,,o -,- · 'AncbomcJa DISTRIBUTION ~ CEN 'I'RAL FILES · "-..- CHEVRON ...-"- EXTENSION EXi:-LDRA1 ION · "- EXXON ir H~RATHON ~ MOBIL "' P H I I_ L I P ::'7 PB WELL. F'ILEZ R & O ~' BF'X -Il" '"' STAi'E 01"' AI_A'~KA,~ I'EXACO l:..' ti ...- £~.' il ...:. rA'n ~.:,' Ii ....' I::,' I ,...' 57." 2"&5" L; A t'l L.' U C A ',"i C 0 C A i'i C !'-J C: A i"i C C) C A f'i C O C A t'i C 0 CAf,iCO C.': A i~ C 0 (]AH(]:(] C A M C 0 CAMCO C A M C C A M C O PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite-Well: 14-29 Comments: Routine redesign following well work. Category C Date: 7/11/90 Previous K-valve Settings: Production Data: ROR= 1675 CFR = Swing Well (very high or Iow GOR) .............. Design Parameters: Design parameters are based on (Mark one of these) XXX Set Pressure, psig Date 185 4/4/9O 205 8/25/89 255 6/1 6/89 BOPD @ 90 deg. choke BOPD @ deg. choke No Choke Priority Well ..................... Actual Well Test ..... Date of Test ...................... Flowing Press. Survey ...... Date of Survey ...... Theoretical Rates used with Hydraulics Program If hydraulics program was used of the parameters, mark which program... Oil Rate 1490 BOPD Watercut 61 percent Formation GOR 1600 scf/stbo Gas Lift Gas Rate 2000 mscfpd Total GLR 1136 scf/stbl Flowing Tbg. Pressure 240 psig Flow. Wellhead Temp. 160 deg. F to get some xxx PH2 PH3 PRUDHYD Other Temp. @ SSSV ............. 175 deg. F Pressure@ SSSV ....... 385 psig Pressure Adjustmen 75 psig Calculated Dome Set Pressure = 178.4 psig @ 60 deg. F IActual Dome Set Press. 1 8 0 FTP at K-valve Closure = 1 75 psig @ 60 deg. F psig ~ surface cc: Ferguson / Farmer3 Wilder / Kennedy (2 copies) State of Alaska cc: D.S. Engnr. J. Michels D.S. Supvsr. J. Winters/C. Shumway Prepared by J. Scheidt RECEIVED Alaska 0il & Gas ~u,~. Anchorage '~"~ WT44,14-29., i2 07-tI-~) 0726 ~LL DATE TiME 040KE NO. COMP POS AYG SEP T~MP 14-29 06-08 02(~ 85 160 ' i4-29 05-20 0851 85 t61 !4-29 04-17 ! '.:-'36 79.. :o.."' '" i4-29 013-3! 0756 90 i65 i~-29 03-07 0452 ')0 i59 14-2'? 02-26 !636 '.?0 i5') 14-29 02-(~4 i~14~ 89 i57 14-29 01-i3 22i6 89 157 14-29 01-13 0i3! 89 156 14-'?~. ,, ,~<,-o4~ ..... i55! ~9 i59 14-29 i!-02 !83! 89 159 14-29 i0-!6 0204 90 164 ~;£LL ENTRY ¢40. NO. i4-29 12 1! t0 9 7 6 5. 4 3 2 t DATE WELL TEST REPORT $$ TESTED RATES' A~ AVG TOTAL LIFT FTP SEP OIL WTR GAS GAS TEST PRES STBD BPD MSCFD ~SCFD FORM ", GOR WTR SCF/B TOTAL TEST GLR LENGTH Sp~- ..r/~ ~OU~S 03-07-90 12-24-89 09-12-8~ 07-09-89 06-25-89 05-I5-89 04-0i-89 03-03-89 1 i-i2-88 ,,~,. 2.7 252 220 1472 2:303 413, i3 i'.;'52 6i i6(~4 ~":' 24! 203 1647 98- 5i39 2775 6 i435 2945 8.0 259 214 !702 2700 5420+ 2')98 6! 14'23+ 1231 7.5 254' 220 i837 2')08+ 52i7+ 2798 6! 13i7 1099 8.0 244 .,..,,':",,:',' .,.~,,.,,'~'='"' 2434 471q6+ ...... 21:<~li 59 1i98+ i!70 7,3 301 2¢~:.'....,",...,:.A,~..,,., ......,o..,'"~;':' 4862+ 2743 ,':',0i272+ i i66 6, 0 3":0 2i0 '"'"" ','ZlY "'"" . . ii75 3,9 "' ~cO., 2721.i 57 ' '~l,: ,. . i i{.~£ .;, i :-- ,..~,y':'~'~ 220 i672 2375 4A15. 3081 59 9i7 1i40 g.<'>. . 376 230 175') 2147 5i04 35<17 55 908 1307 8.0 · :";'"216 i722 2383 4659+ 2971 58 9:90+ t!35 8. i ~.[.. ..... 400 2i2 '.-'62! 29,96. 4665 '12°8... ,..-, ou'"' 849 116i ,J2.0., 326 z23 i762 '-,5'"~ .... :" ::<, 899 ' ,....,... ~,.:.¢,...,..,- 278i .:.. . t0i.'..:; 8, 0 WELL SHAKE-OUT DATA =~=r~,~ LOC: SAMPLE PERCENT r:~c~:T..~2S r,n*¢~ Ti~E ~ATER :~OL:DS ~ILLiC~ ENTERED BY TAKEN FRO~ 0400 62,00 ~-r '-.~,,',' 2i30 58.00 0.0 PRODUCTION 1500 60.00 0,00 PRODL(:TiON 2300 ...,. ~, oo., .¢RODUCTiON 0ii0 6.0 PRODL~3TiON 2000 5.0 PRODUCTION 0400 70.00 0.00 17.0 0200 70.00 0.~ 4.0 PRODUCTION i400 64.00 0.00 PRODUCTION 2i00 66.00 0.00 PRODtJCTION '2'330 53.(×! 0.(~ 6.0 PRODUCTION 2200 60.(t0 0.00 PRODUCTION SEPARATOR HEADER HEADER HEADER SEPARATOR SEPARATOR SEPARATOR SEPARATC~ HEA£ER HEA£~R HEADER HEADER ..... E×PECTED---- FORM T T A ¢ ORIFC OIL GOR STBD SCF/B WTR T P L S iNChES i674 1424 61NR~ G 3.50 i694 1423 ~i E R ~ B 3.50 1641 1t98 59ER YS 4.50 i640 1i99 60E ~ ~G 3.50 1748 981 58ER N¢i 4.00 i724 980 58E R N G 3.25 i700 ~ t;:~ N i699 980 58 N R N $ 4.00 ~7 980 ~AN R N $ 4.00 i679 820 61E i657 817 ~! NRNG "2.75 !674 8i~ 61E SS_SV ¢ I MEMORAhu of Alaska ALASKA OI AND GAS CONSERVATION COMMISSION TO: Lonnie C. Sm.~//' Commissioner/&~/ DATE: FILE NO: May 23, 1990 JT.HH.523.2 THRU: TELEPHONE NO: SUBJECT: Bench Test K Valves AAI PBU DS12-1,3,5,11, 17 &26 Prudhoe Oil Pool FROM: Harold R. Hawkins Petroleum Inspector ~unday May 20,~ !990- I witnessed "K" valves being tested. K 03 A SET TO CLOSE AT 300 PSI TO BE SET IN WELL AAI PBU DS 12-1 K 16 A " 200 " 12-3 K 13 A " 150 " 12-5 K 21 A " 100 " 12-11 K 04 A " 305 " 12-17 K 07 A " 210 " 12-26 In summary, I witnessed the bench testing of 2 K-valves for opening. All K valves were satisfactorily tested by Jeff Nolen, Safety Valve Technician. At tachment 02-00lA (Rev. 6,'89) 20/11/MEMO1.PM3 PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite-Well' 14-29 Date: 4/4/90 Comments: The need for this redesign is a side effect of clearing the debris from the choke and reducing the FTP to its current level. Previous K-valve Settings: Production Data' ROR = 1850 BOPD · · CFR = BOPD Swing Well (very high or Iow GOR) ..............No Design Parameters: Design parameters are based on (Mark one of these) XXX Set Pressure, psig Date 205 8/25/89 255 6/16/89 335 5/25/89 @ 90 deg. choke @ deg. choke Choke Priority Well ..................... No Actual Well Test ..... Date of Test ...................... Flowing Press. Survey ...... Date of Survey ...... Theoretical Rates used with Hydraulics Program If hydraulics program was used of the parameters, mark which program... Oil Rate 1850 BOPD Watercut 61 percent Formation GOR 1300 scf/stbo Gas Lift Gas Rate 2800 mscfpd Total GLR 1090 scf/stbl Flowing Tbg. Pressure 240 psig Flow. Wellhead Temp. 165 deg. F Temp. @ SSSV ............. Pressure @ SSSV ....... Pressure Adjustmen to get some xxx PH2 PH3 PRUDHYD Other 180 deg. F 400 psig 75 psig Calculated Dome Set Pressure = 186.7 psig @ 60 deg. F IActual Dome Set Press. 1 8 5 FTP at K-valve Closure = 1 70 psig @ 60 deg. F psig @ surface / cc: Ferguson / Farmer ~- Wilder / Kennedy (2 copies) State of Alaska cc: D.$. Engnr. J. Michels D.S. Supvsr. J. Winters/C. Shumway Prepared by J. Scheidt ! 1. Type of Request: STATE OF ALASKA ALASKA AND GAS CONSERVATION C( '¥11SSION ri APPLICA ,ION FOR SUNDRY APPROVAT..$ 2. Name of Operator ARCO Alaska, Inc. Abandon Suspend Operation shutdown ...... Alter casing Repair well Plugging Change approved program ...... Pull tubing Variance 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development X Exploratory ...... Stratigraphic . Service 4. Location of well at surface 2225' FNL, 847' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 2439' FNL, 234' FWL, Sec. 10, T10N, R14E, UM At effective depth 2416' FNL, 322' FWL, Sec. 10, T10N, R14E, UM At total depth 2387' FNL, 392' FWL, Sec. 10, T10N, R14E, UM 9560 feet Plugs(measured) 9324 feet 12. Present well condition summary Total depth: measured true vertical Re-enter suspended well Time extension Stimulate Perforate X Other .... 6. Datum of elevation(DF or KB) 71' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-29 9. Permit number 81-168 10. APl number 50 - 029-20680 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 9246 feet true vertical 9023 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 76' 20" 400 sx Permafrost II 76' 76' Surface 2529' 13-3/8" 2000 sx AS III & 400 sx ASI 2600' 2600' Production 8786' 9-5/8" 500 sx CI 'G' 8857' 8653' £E VED Perforation depth: measured 9084-9120'; 9123-9130'; 9135-9155'; 9160-9188'; NOV 2 true vertical 8869-8903'; 8906-8912'; 8917-8936'; 8941-8968' ~ , ~ ~nch0rag~ Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC tubing @ 8498 'MD; 4-1/2", 12.6#, L-80, PC tubing @ 8596' MD Packers and SSSV (type and measured depth) 5-1/2" Camco BaI-O SSSV @ 2192' MD; Baker SAB Packer @ 8488' MD 13. Attachments Description summary of proposal ... x Detailed operations program . BOP sketch x 14. Estimated date for commencing operation December 1989 16. If proposal was verbally approved 15. Status of well classification as: Oil x Gas Suspended__ Name of approver Date approved Service 17. I hereby,e~rtify that the foregoing is true and correct to the best of my knowledge. Signed ,~),'~~~//~~__~_.,v.x-~ __ Title Operations Engineering Manager Date FOR COMMISSION H~E ONLY Conditions of approval: Notify Commission so representative may witness [Approval No. Plug integrity BOP Test Location clearance ....... Mechanical Integrity Test Subsequent form required 10-' ...... Z~ ' Approve(:i CoPY ORIGINAL SIGNED BY Returned ,'~ ~ Approved by order of the Commissioner LONNtE C. SMITH ComTh'~sioner Date // -,~ "'~"~' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE PROPOSED PERFORATING DS 14-29 ARCO Alaska proposes to add perforations in the DS 14-29 producer in the Sag River formation of the Prudhoe Bay Unit. All wire line work will be done through 5000 PSI. working pressure BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The purpose of the proposed perforating will be to provide effective drainage of the Sag River reserves. Ref: BHCS 2/28/82 Proposed Perforation Interval: 8898-8918' MD RECEIVED NOV 2 1. 19~,'? A~chora~ 3 i 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF bi ! REL ! NE BOP EGu ! ,PHENT PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite-Well: 14-29 Date: 8/25/89 Previous Comments: The current K-Valve design is restricting 300-400 BOPD of production. This new K-valve design should work under normal gaslifted conditions without restricting this well's production. Because the calculated pressure at this weirs SSSV is approximately the same whether the well is flowing with or without lift gas, this K-Valve design should work in either case. CURRENT LOW CMLN PRESS CAUSING THIS WELL'S K-VALVE TO DUMP EARL~ K-valve Settings: · Set Pressure, psig Date 255 6/16/89 335 5/25/89 385 5~8/89 Production Data: ROR = 850 CFR = Swing Well (very high or Iow GOR) ........... BOPD @ 90 deg. choke BOPD @ dog. choke No Choke Priority Well .................. Design Parameters: Design parameters are based on (Mark one of these) Oil Rate Watercut Formation GOR Gas Lift Gas Rate Total GLR Flowing Tbg. Pressure Flow. Wellhead Temp. XXX 1318 66 1190 3802 979 332 162 Actual Well Test ..... Date of Test ...................... Flowing Press. Survey ...... Date of Survey ...... Theoretical Rates used with Hydraulics Program If hydraulics program was used to get some of the parameters, mark which program... percent scf/stbo mscfl~l scf/stbl deg. F XXX XXX Temp.@ SSSV .............177 Pressure @ SSSV ....... 500 Pressure Adjustment 150 PH2 PH3 F)RUDHYD Other deg. F psig psig Calculated Dome Set Pressure - 204.0 psig @ 60 deg.F .. -IActual Dome Set Press. IFTP at K-valve Closure 205 175 Dsla @.60 deg. F psig ~_ surface I cc: Sennett/Farmer W.der/~ Kennedy (2 c~a~ias). Stateof ~ cc: D.S. Engnr. K. R. Ferguson, ATO 1554 D.S. Supvsr. J. Winters/C. Shumway #13 Prepared by: R. E. Krause Ancho~aqe PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite-Well: 1 4-29 Date: 5/25/89 Comments: Because of a change in K-valve design philosophy, this design used a well test with no gaslift gas. A pressure adiustment was added to minimize the amount the well must be CHOKED BACK under normal gasli.ft producing conditions. Previous K-valve Settings: Set Pressure~ psi.cl Date 385 5/8/89 226 8/12/88 225 7/29/88 Production Data: ROR = 2200 BOPD @ 9 0 deg. choke CFR = - BOPD @ - deg. choke Swing Well (very high or Iow GOR) ........... No Choke Priority Well .................. Design Parameters: Design parameters are based on (Mark one of these) XXX Oil Rate Watercut Formation GOR Gas Lift Gas Rate Total GLR Flowing Tbg. Pressure Flow. Wellhead Temp. Actual Well Test ..... Date of Test ...................... Flowing Press. Survey ...... Date of Survey ...... Theoretical Rates used with Hydraulics Program If hydraulics program was used to get some of the parameters, mark which program... 566 BOPD 6 5 percent 4 39 scf/stbo 0 mscfpd 206 scf/stbl 231 psig 142 deg. F XX PH2 PH3 PRUDHYD Other Temp. @ SSSV ............. 1 63 deg. F Pressure @ SSSV ....... 61 2 psig Pressure Adjustment 7 5 psig Calculated Dome Set Pressure = 335.0 psig @ 60 deg.F I Actual Dome Set Press. 3 3 5 psig @.60 deg. F FTP at K-valve Clesure 3 4 0 psig @_ surface Comments: FTP at k-valve closure is based on well flowinq at recommended gaslift injection rate of 2250 M$CFPD. cc: Sennett / Vacant '~' t Wilder / Kennedy (2 copies) State of Alaska cc: D.S. Engnr. K. Ferguson ATO 1554 / D.S. Supvsr. Shumway/ Winters PRB #15 Prepared by: K. Lofgren Gas Cons. commission Anchorage ARCO ALASKA, INC. F'.O, BOX i00360 ANCHORAGE, ALASKA DATE: 3-2-89 REFERENCE: ARCO CASED HOLE FINALS 3-t2 2-2~-89 PRODUCTION PACKER 4-2 2-tG-89 PRODUCTION PROFILE 4-i2 2-ii-89 PRODUCTION PROFILE it-2 2-3-89 INJECTION PROFILE ii-3 2-i-89 PRODUCTION PROFILE tt-3 ~-'~-n~~ . ~- TEMP SURVEY ii-4 ~ ~ 89 PRODUCTION PROFILE ti-5 2-6-89 PRODUCTION PROFILE ii-? 2-3-89 INJECTION PROFILE ti-J2 2-3-89 TEMP SURVEY it-iS 2-2-89 TEMF' SURVEY i 2-3i 2-t ?-89 CBT i2-3i 2-i7-89 CET t4-i8 2 ~-89 CNL-GAMMA i4-i9 ~-~-~~ _~ CNL-GAMMA i4-28 2~5-89 TEMP t4-29 ~o-°~-~Q~ __ CNL-GAMMA t4-33 2-22-89 CNL-GAMMA i5-~ i-23-87 PRODUCTION PROFILE t 8-4 2-t 2-89 PRODUCTION PROFILE i8-i7 2-i3-89 F'RODUCTION PROFILE -, . ~ · - . . · ,. PLEASE SIGN AND RETURN THE ATTACHED COPY RUN t, 5' RUN t, 5' RUN i, 5' RUN t, 5' RUN t, 5' RUN t, 2'&5' RUN i, 5" RUN t, 5' RUN RUN t, 2' RUN t, 2' RUN RUN i, RUN RUN t, 5" RUN t, RUN t, 5" RUN RUN i, RUN RUN t, AS RECEIPT OF DATA. 'RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 TRAN$ ~Ggj~9 APPROVED ~ .... DISTRIBUTION ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO $CH $CH ATLAS ATLAS CAMCO ATLAS ATLAS CAMCO CAMCO CAMCO CENTRAL FILES, CHEVRON D &M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS PB WELL FILES R&D SAPC STATE OF ALASKA TEXACO ARCO ALASKA, I F'. O. BOX ANCHORAGE, ALASKA 995 DATE: REFERENCE: ARCO MAGNEI'IC TAPES W/[..ISI']~NG 4-t8 2-22-89 CH: CN/M$ (4 PA$£) JOB:~J'?29 t4--~9 2-22-89 CH: CN/M$ (2; F'A$$) JOB~J'Z2;O 4-29 2-22-89 CH: CN/MS (J PAS'S) JOB:IJ'?[5I 4-~ 2-22.-89 CH: CN/M$ (i~ F'AS~') JOB~J;7~12 ATLAS ATLAS ATLAS Al°LAS PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF I)ATA. RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 DI~'I'RIBUI'ION CENTRAL FILE£ (CH) CHEVRON D&M I'AMMA$ BROWN (OH) EXXON MARATHON MOBIL PHILLIPS F'B WELL F'ILE&' SAF'C &'l'Al'E OF ALASKA TEXACO ARCF! ALA,~'KA. ]'NC,. F-', Iq,. BFIY, i ('.~6(.) ~ At'JC, HFII:;:AI";F..: AI...A..t31(,.A 99.r...:;t (., ,I DATE' RF. CFERF~P.,E- ARCO PRES',.~IIRE DATA t4-6 ti-t-87 t4-6 t?-~-R7 ,i4-24 ti-tS-R7 t4-3t BHP-~TATTC GRAI)TFNT RHP-FI..flWTN(; (;RADTFNT BHP-$TAI'IC ~RADIENT RHF'-~TATTC ~RADIENT BHP-~TATIC ~RADTENT F'I. EA.%E ,.~TGN AND RETURN THF' ATTACHED COPY A,%' RECFIF'T OF DATA.. HAVF A NI'F:F.' DA ATO- t 529 TRANY ~8807t ~ AF'F'ROVED DI2TRTRI,ITTON OTT~ nTTY' nTT~ nTT~ CE. N1 R. Ai... FII...E,~ CHEVRON ,. D & M · ! . F. XTEN,.S'I ON EXF L. ORATION ,.'" EXXON MARATHON ~ MOBIl_ ARCO AI.a~l<a, Inc. I::'.r). Box t(')0360 99.5.~ ~ () DATE: Apri L 2:3, t98'7 I~[F'~t;,ElVC£: /;/~CO Press'qre Da tm 4-33 .4.-. t () ...- 8 '? ~'t;.at: ic (:~racl ien't 14-2~' 4-9-87 Sfai-iC Gradienk rtl c o ?t"~ I::' .. i) A t' E · I) ~.:.:, (:: (.:-:, m b e r i ~ 'i ? 8 6 ii.'(:: h F:' I. (.x,a :!~: (~, :~: i g )'~ a ~'~(:I )" (e .i- u.r ~'~ 't' h E, a .I- 't' a (:: h r' ~~ (:: o . . . ,:¢~., I:> ';.,' a :iF )" 6?(:: (-:~, J p .I. o '[: (:I a 't' a ,. L.' J ......... LJ :.., . ARCO ALa~.km, lng._ - F'.O. Box 100360 Anchorage, Alaska 995t.8 DATE' August t, t986 REFERENCE' ARCO Ca:ed HoLe F inmL 4-~b ~'~6- J q'-°6 ~ 6-2'J.' -86 ~J4-i5 6-i2-86 ~"~ t 4-22 6-i 4-86 4-,~, 6-1,, ~6 6-!8 6-i 8-86 Col [ar Perforating log Coll. ar F'erforating Icg CoLLar Pe;-forating Log CoLLar F'erforating log CoLlar F'erforating Icg Cr-,Llar/depth de¢ermi',;ation ~'..' U. i"i I ":'" ..j. F:un i '-';" RUl] i ='-" ,q'un I ~'" : _:. Pun I ~" · ~ ~:. _. bear -. bear Gear Gear Gear Gear se si gn and ' ~-n_~..~, ~,i.~ed cop~~ F' I em ired Rece HAVE A N ~I,C.E-~C, Ay !AlasKa O~I & Gas Cons. commissioti Anchor~9~ Linda Hulce ATO-i~°m_,.., receipt of data. DISTRIBUTION -'- ~' ' F' le~, ~ ,_.el]f.l-.~ I . '"' L-.:" ...... .,~- ]], & M · " E×i'~,n$ i on Ex p ,',. c,r ~ ± i c,r, ~' Ex xon Marathon - Mob; t Phi {.lip: PB ,U, eLL Fi Le: :'7oh i o State of A:.a-sl<a Texaco ARCO Alaska, Inc. ~ Prudhoe Bay L,,{~ineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 11, 1986 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re' DS 14-15 DS 14-29 DS 14-22 Permit No. 81-84 Permit No. 81-168 Permit No. 82-75 Enclosed are the Completion Reports and Subsequent Sundries for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/SAD:sd Enclosure CC' Standard Alaska Production Company File: PI(DS 14-15)W1-3 PI(DS 14-29)W1-3 PI(DS 14-22)W1-3 RECEIVED Gas Cons, Comrnissbn Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA (. ~AND GAS CONSERVATION CO,, '~IlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~, GAS[] . SUSPENDED lq ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. ' '~.81-168 3. Address 8. APl Number P.O.. Box 100360, Anchorage, Alaska 99510 '.. 50- 029-20680 4. Location of well at surface 9. Unit or Lease Name 2225' FNL, 847' FEL, Sec. 94, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2439' FNL, 234' FWL~ Sec. 10, T10N, R14E, UM 14-29 At Total Depth 11. Field and Pool 2387' FNL, 392' FWL, Sec. 10, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF~ etc.) II 6. Lease Designation and Serial No. Prudhoe Bay 0il Pool 71' RKB ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 02/10/82 02/27/82 05/12/82I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSY set 12a. Thickness of Permafrost 9560'MD, 9324'TVD 9219'MD, 8997'TVD YES [7~ NO [] 2192 feet MD 1900' (Approx.) 22. Type Electric or Other Logs Run CBL/CNL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf, 76' 30" 400 s× Pe.~m~frn.~e 11 13-3/8" 72.0# L-80 Surf. 2600' 17~" 2000 sx AS 111 & 400 sx kS 1 9-5/8" 47.0~A L-80& Surf, 8857' 12~" 500 sx C1~.~.~ P. S00-95 7" 29;04A L-80 8534' 9560' 8%" 350 sx Class G 24. Perforations open to Production (MD+TVD of ToP a~nd Bottom and 25. ' TUBING ~I~ECORD" ' interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9084' - 9120'MD 5~" 8595' ~'~' 9123' - 9130'MD 9135' - 9155 'MD 26. ACID, FRACTUREi CEMENT SQUEEZE, ETC. 9160' - 9188'MD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8869' - 8965'TVD 9265' - 92~7' 9~ ~ P.l~_~.~ Ref: BHCS 2/28/82 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 12/27/82I Flowin~ Date of Test Hours Tested PRODUCTION FOR Gl L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I 6/18/86 4.6 TEST PERIOD I~ 422 661 515 Rq Flow Tubing Casing Pressure CALCULATED=lk OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 275 N/A 24-HOUR RATE =~ 2213 3436 2676 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, · MEAS. DEPTH TRUE VERT. DEPTH.. GOR, and-time.of each phase.,'-; Top Sadler0chtt.. :f}?.:.::;8993' . 8782' N/A -' : ,:' ':: ''j..'' ':' · "~; :; c:; ' ~'' ' ' . O/W Contact ':', i.,:<'--'?:.::9280~' 9055' . ' :-!':'~;': .: ..... ". , ' -' , "'" ' '-"::' ' '" ...... · .:, , -:. -. ,:. ; .. Base Sadlerochit' ', Not'Reached '~ ."' ": .. , . . .. ,.. . .. · :, .. ~:' . · ." . . .· , · ~ -, ., .,~.,',, c:~':~ ~,~ ,..," ,'.~'.,.'- ' i' ' ~ .. ".~" , -' . .. · . .. 31. LIST OF ATTACHMENTS .. , ,.,. .,,..,. ~, ~ ; ':, . ~, . ~ * '',. 32. I hereby certify' that the foregoing is true and cgrrect to t~e best of my' knowledge . Signed _ ' " Title_ Re§;[onal' Engineer Date . ,., 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 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 .comp.!.eted for separate production from more than one interval (multiple co .m,.pletion), 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 cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA ALAS~. ")OIL AND GAS CONSERVATION COMr~ "~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. A~d({~¥ Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 2225' FNL, 847' FEL, Sec. 9, TION, R14E, UM At top of productive interval 2439' FNL, 234' FWL, Sec. 10, TION, R14E, UM At effective depth 2418' FNL, 297' FWL, Sec. At total depth 2387' FNL~ 392' FWL~ Sec. 11. Present well condition summary Total depth: measured true vertical 10, TION, R14E, UM 10~ TION~ R14E~ UM 5. Datum elevation (DF or KB) 71' RKB Feet 6. Unit or P,~ope~',ty na~e vruanoe ~ay Unit 7. Well number DS 14-29 8. Approval number 81-168 9. APl number 50-- 029-20680 10. Pool 9560 feet Plugs (measured) 9324 feet Effective depth: measured 9219 feet Junk (measured) true vertical 8997 feet Casing Length Size Cemented Measured depth Structural Conductor 20" 400 sx Surf Surface 13-3/8" 2400 SX Surf Intermediate Production 9-5/8" 500 SX Surf Liner 7" 350 SX 8534' - 9560' Perforation depth: measured Prudhoe Bay Oil Pool 9084'-9120', 9123'-9130', 9135'-9155', 9160'-9188'MD true vertical 8869' -8965' Tubing (size, grade and measured depth) 5½",L-80 @ 8596' Packers and SSSV (type and measured depth) Baker @ 8499' 12. Stimulation or cement squeeze summary Not Appl i cable Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation True Vertical depth Surf Surf Surf 8347 ' OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2315 1572 3889 -- 280 2213 3436 2676 -- 275 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge Title Form 10-404 Rev. 124-85 Date ¢/:¢J~ Submit in Duplicate Gas Cons. Anchorage Representative Daily Average Production or Injection Data RECEIVED Begin perforating operation on 6/13/86. RU perforating unit and pressure tested equipment. RIH w/ gun #lA, shot interval 9178 - 9188'MD, (4 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. RIH w/gun #lB, shot interval 9160 - 9178'MD (4 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. Secured well. RD. Ref: BHCS 2/28/82 RECEIVED ARCO ALaska, Inc P.O. Box i Anchorage, Alaska DATc ' May .=","~, t oc.-,' ..... FbRENCE :..-, .... -:.-., ? ~,5-b 4-21 - F'-.'6 .,:.,.i. a+ - -- -- ... _ , i C ~'"..'S~ .*.'_~'-'.-i: ~:"z'-":'5 4-i 6 86 ~"* G d i e'n+.. - ..., a ':.' ic '"'-- 3-._'3, t " 4-6-86 ;'74:a't ic L-;rad ie'n~ --~-' '" '-' 4-9-86 -.-' 4. '- ~ 3;-33 4-2i-86 £~at i c - ~'-' ~ 4 .'~-'--' 4- ~ 6 :.-:ia ± ~ c -~a-iA 4 "~ "'"" ."::+a* r-,-, ~ - ~ 7-i 3 "'~-":'-"'-'" ' , , - ' -? .-: uA Si'a+ '~'o_? 4-2,5-86 £+a'l: ;c Grad ie'n,'f "~9-6 4 ""= "6 .-.:a: c bra -.-:_:--o v4. *, -"'I i -~ ~') 5_.::,_o~. £;, 4- C.:.ra,~. - --t ! -i 3 5-5-86 $'~a '~ i c L;r.=,d i e'n!- "~'i4-i i 4-9-86 2*,.a+. ic Grad i e'r,:.'t ~-i4-29 ~_~..-,._o,: Fir, wing C.-rad ienl ~i6-4 4-'~ 6-F:A~ _ _ 2,4:'. a*: ir.. ',_-.-;-.ad i .-o"n*, · ' ' ~-i6-1.3 4-26-8,6 2.:"ta'!' ~c ,.~, ad i e'.,'~ -" 1 7-5 4-.2-z- ° ~'._, ::,_, 2±a*: ~:a file 0 Ca ff,,c o C a ~'~'~ c o Ca .,'ac o Ca ~'~'~ c o Ca f,,'~ c o Camco Camco C@ file 0 C .a In ,.-_ o C:-3 mC 0 C:.-~ alt_ o Ca mc o C8 ~'~iE 0 :rm.~ Car ATO-! 5.-29 Gas C0~a. ~ ............ ---~ Z 2TF.: 2 ?UT: ON C:h err c:r:. E::: -'t;. e,:'.~. :: .:.~ Exz, ~o'~-~'. i c.,-.r, ~ ~ Ex xo'r; ~ STATE OF ALASKA ALASI i'~IL AND GAS CONSERVATION COMk "~'ION APPLICATION FOR SUNDRY APPROVALS feet/ 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] StimUlate ~ Pull tubing [] Amend order ~ Perforate [] Other 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 2225' FNL, 847' FEL, Sec. 9, T10N, R14E, UM 5. Datum elevation (DF or KB) 71' RKB 6. Unit or Property name Prudhoe Ba~v Unit 7. Well number DS 14-29 At top of productive interval 2439' FNL, 234' FWL, Sec. At effective depth 2416' FNL, 322' FWL, Sec. At total depth 2387' FNL, 392' FWL, Sec. 10, TION, R14E, UM 10, TION, R14E, UM 10, TION, R14E, UM 8. Permit number 81-168 9. APl number 50- 029-20680 10. Pool Prudhoe Bay 0il Pool 11. Present well condition summary Total depth: measured true vertical 9560 feet 9324 feet Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length measured 9084' true vertical 8869' 9246 feet 9023 feet Size 20" 13-3/8" 9-5/8" 7" - 9120' - 8936' Tubing (size, grade and measured depth) 5'~" L-80 8596' Packers and SSSV (type and measured depth) Baker @ 8499'HD Plugs (measured) 9250 feet Junk (measured) Cemented Measured depth True Vertical depth 400 SX Permafrost II 2000SX ASIII & 400SX ASI Surf Surf 500 SX Class G Surf 350 SX Class G 8534 8347 ,9123' - 9130' , 9135' - 9155' RECEIVED MAY 2 7 1986 Alask8 Oil & Gas Cons. i;~,,mi~ion ~-qchorage 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation May 1986 14. If proposal was verbally approved Name of approver Date approved SignedI/~//~t,~[,,/.,~r'~/yl///~ __...- Title Operations Engineering ManagerDate Commission Use Only Conditions 'of approval Approved by Notify commission so representative may witness ~ Plug integrity ~ BOP Test ~ Location clearance ~:~-;:- i::' ~ '~-: ~' '~; '; <'' ':::~,:"', Commissioner by order of the commission Date~'---~--~4 Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Alaska, Inc. proposes to perforate DS 14-29 at selected intervals within the Sadlerochit Sand of Prudhoe Bay Unit. Upon perforating, the well will be flowed for clean-up. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-uP operation. Ref' BHCS 2/28/82 Proposed Perforation Intervals' 9160' - 9188'MD II ' 1I i I I! 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF H I REL I NE BOP EQU I PNENT i · ARC() Ala:'ka, Inc · P.O, BOX t00360 AnCho'rage~ Ala~ DATE' March 27, ~986 REFERENCE' ARCO Ca.sed HoLe Final. ~ DS ~J DS "~ DS 'J DS ,~J DS '-~ DS t 4-t t 0-24-- '=' 6 J. C N L F;,' u n t . t 4-t t0-24-.-85 Ep i Log Run t 5" 'i 4-7 2-3-85 C'.ET Rub ~ 5' ~4-~ ~2-.26-85 Diff Temp · Run ~4-.~5 ~2-23-85 Diff Temp Run ~ 5:' ~ 4-24 ~ ~ -9-85 Ep i Log Run ~ /~ ~-9-85 . CNL ~,~. ~ Run ~ 5' ~4-28 ~2-2~-85 Diff Temp ' Run ~ 5' ~ 4 - 29 ~~. ''~ - ,. '~ TM~. -. ~q., ~ D i f f l'e m p R u n ~ 5 ' DS ~ 5-7 2-,.0-86 Sp inner Run ~ 5' ... ;, :,_.o,.. Sr..' inne'~ .... Teml:., F,'un i '=.:' DS '16-'~ * E ~ i 6-3 S 6-8/=. SP i'oi'ier-]"efftl~ Rurl D£' 'i 6--~ 3 ') ~ 9-86 ~" ,...-' ,.> p i n n e r - b F;.'. R u n '~ .,. · -- " :~ VPl ~, i g., ~R Run i '-"'" DS i A-~ ~- i,.~ '~ 28-85.. ~.,Ct. !.../ , _ / DS i6--~6 2 .... ~9--.86 Water Injection Run DS i6-~9 ~-~--F',6 ACBL./VDL/Sig/C,I;: Run ~ 5" r) '-.': i z _. o .- ': ' ~' /" G R R u i .. ~ .., ~.0 i ...... ,..:. 86 ACBL/VDL./,,, ig n DA DA Sc: h DA DA I)A I) A I) A I) A C a fil C 0 C a Iff c: c) C a m c o C a m c o · DA fi)+. i.s I>A DA F'l. ea:-;e ,-.:igrl arid r'e'['urn 'l:he a'f:'~'mched copy as r'eceip'~' of d@-.t:a, Received By ..... R.. [ D HAVE A NICE DAY! Iff,la Cai- Lin 011 & Gas Cone. Gommlmdon A.c~omge fRANS ~:86215 DISTRIBUTION Central Fi Les Chevron D & M Extension ExpLora'~ion Ex XOl'l Mara ~hon Mob i L Phi LLip$ F'B WeLL Fi Les R & D Soh i o S~a~e of ALaska Texaco ARCO Alaska, In( /r Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Date: February 18, 1985 Reference: ARCO CH Final /9-16 Injection Profile Survey 1-12-85 Run 1 5" GO j13-21 Injection Profile Survey 1-14-85 Run 1 5" GO ,~15-7 Gamma Ray Log ./15-8 Gamma Ray Log /15-9 Gamma Ray Log ~/~15-16 Collar Log 15-20 Ga~a Ray Log · ,~14-29 Spinner /14-30 Spinner 1-27-85 Run 1 5" Camco 1-28-85 Run 1 5" Camco 2-4-85 Run 1 5" Camco 1-10-85 Run 1 5" GO 1-25-85 Run 2 5" Camco 2-2-85 Run 1 5" Camco 1-30-85 Run 2 5" Camco / Pl~~ease sign and return the attached copy as receipt of data, Received by Pam Lambert ATO 1429C Trans f~)~ .'~;~ska ~ii .~ ~,',s Co,qs. Co~mission Chevron D&M Expl. Services Ext. Exploration Exxon Marathon Mobil Mobil E & P Phillips PB Well Files R & D Sohio State of Alaska Texaco ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 9, 1983 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 14-6 DS 14-9B DS 14-11 DS 14-26 DS 14-29 Permit No. 78-65 Permit No. 82-34 Permit No. 80-131 Permit No. 81-110 Permit No. 81-168 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/TKKW/lmi Enclosures cc: Sohio Petroleum Co. RECEIVED ARCO Alaska, Inc. ) Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer May 25, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: D.S. 2-20 Permit No. 82-29 D.S. 2-24 Permit No. 82-71 D.S. 2-25 Permit No. 82-96 D.S. 14-6 Permit No. 78-65 it No. 82-34 ~~,¥~ermit No 80-131 D.S. 14-22 Permit No. 82-75 D.S. 14-26 Permit No. 81-110 D.S. 14-28. Permit No. 82-12 D.S.~ Permit No. 81-168 Enclosed are Completion Reports for work done on the above- mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/cl Enclosures cc: Sohio Petroleum Co. ARCO Aleska, Inc 1~ a .~ub,.)d~l~y o; Atl.ntlcfllchHeldCor*~pan¥ Gas Cons. Commission Anchoragb STATE OF ALASKA ALASKA ]~L AND GAS CONSERVATION C'; '~tMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well , OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] : ~. Name of ~)perator 7. Permit Number ARCO Alaska, ];nc. 81-168 -3. Address 8. APl Number P.O. ....... Box 360, Anchorage, AK 99510 s0- 029-20680 .... 4. Location of well at surface 9. Unit or Lease Name 2225' 'FNL, 847' FEL, Sec. 9, TION, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2439' FNL, 234' FWL, Sec. 10, TION, R14E, UM 14-29 At Total Depth 1 1. Field and Pool 2387' FN~..~q?' FWL, Set. ln. TIFiN. R14E= IIM Prudhoe Bay Field 5. Elevation in fee't'(i~d'icate KB, DF, etc.) -I 6: Lease De;ignation and Serial No. 71' RKBI ADL 28312 Prudhoe'Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offsh.ore 116. No. of Completions 02/10/82 02/27/82 05/12/82 I N/A feet MSLI 1 17. Total Depth(MD,TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 9560'MD, 9324'TVD 9546'MD, 9286'TV[; vis~5~ NoEl 2192 / feetMa 1900'(approx.) 22. Type Electric or.Other Logs Run CBL/CNL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASlNGSIZ'E WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 2n" 91.5# H'40 Surf 76' 30" 400sx Permafrost I.I 13-3/8" 72.0# L-80 Surf 2600' ]7-1/2" 2000sx AS III & 400 sx AS I 9-5/R" 47.0# L-80 Surf 8857' ~ ]2-1/4" 500sx Cl~ass G $00_95 ,, 7" 29.0# L-80 8534' 9560' 8-1/2" 350sx Class G ..... :;. TUBING RECORD 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5-1 / 2" 8595' 8466' 9084' -9120' MD 9123' -9130' MD 2'~'. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,,, . . 9135 ' -9155' MD . ~ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8869'-8936'TVD :9265'-9267' 200 sx Class G ..... Ref: BHCS 2-28-82 · ~ 27. PRODUCTION TEST Date First Production i Method of Operation (Flowing, gas lift; etc.) 12-27-82I F1 owing ..... Date of Test Hours Tested PRiDDUCTION FOR.OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE iGAS-OILRATIO 3-22-83 6.1 ZFE-ST PERIOD I~ 60 'I 602 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) P,r~ss-711 24,HOUR RATE I~ ' 4461;-: 2687 0 27.0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED , JUN 1 3 !983 ~ Oil & Gas Cons. Co~~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME . Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH ' TRUE VERT. DEPTH GOR, and time of each phase. . : Top .Sa[JlerOchit "8993' 8782' N/A O/W Contact .,... 9280: · 9055, Base Sadlerochit~ Not Reach.~d.i. · ~ . . . · . . · : 31. LIST OF ATTACHMENTS " 32. I' hereby 'certify that the foregoing is true and correct to the best of my knowledge .. Signed Titlel~nqnn~l Fnn Date ; 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 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 f.o.r 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 sta~e cement- ing and the location of the cementing tool. Item 27: Method' of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no' Cores taken, indicate "none". Fnrm 10-407 ARCO Alaska, Inc. Post Gffice b~~60 Anchorage. AlasKa 99510 Teteohone ~lO7 2.77 June 10, 1983 .... Reference: Arco Pressure Data D.S. 1-13J 5-30-83 Static Survey Camco D.S. 1-18~ 5-30-83 Static Survey Camco D.S. 6-18/ .5-11-83 Static Survey Camco D.S. 6-2~r 5-1-83 Static Survey DA D.S. 7-2' 4-9-83 Pressure Build-up Camco 4-9-83 Pressure Build-up Data Sheet D.S. 12-11/ 5-30-83 Static Survey Camco D.S. 14-29-it'' 4-2-83 Pressure Build-up Camco 4-2-83 Pressure Build-up Data Sheet D.S. 14-30/ 4-1-83 Pressure Build-up Camco 4-1-83 ' Pressure Build-up Data Sheet D.S. 17-5 f 5-19-83 Static Survey Camco D.S. 17-9/ 5-18-83 Static Survey GO Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. ~ 381 DISTRIBUTION NORTH GEOLOGY l-.. ':- ].'. DRILLING -_ >SOHIO. MARATHON CHEVRON .-..D .& M. -'- -'.:,k~ "'~'-,-~ - - DALLAS CAROL[NE SM[TH ARCO Alaska, Inc( Post Office Bo,, 360 Anchorage. Alaska 99510 Telephone 907 277 5637 April 14, Reference: 1983 Arco Cased Hole Finals D.S. 2-11/ 12-27-82 C.A.T. D.S. 13-7 3-20-83 Spinner Log D.S. 13-17~ 2-17-83 EPL 2-19-83 EPL D.S. 14-9B~ 3-31-83 Spinner D.S. 14-18~/ 3-30-83 Spinner ./ D.S. 1:4'~','29 [;~ ? Spinner Run 1 5" DA 5" Camco Run 1 5" Sch Run 2 5" Sch 5" Camco 5" Camco 5" Camco D.S. 18-1~' 2-16-83 CPL/Volan w/Listing ~ 5" Sch D.S. 18-3/ 3-28-83 CPL/Producibility w/Listing Sch '2-16-83 CPL/Volan w/Listing 5" Sch D.S. i8-6~/ 2-16'83 CPL/Volan w/Listing 5" Sch D.S. 18-7~ //2-17-83 CPL/Volan w/Listing 5" Sch D.S. 18-1~ ~-25-83 CPL/Pr0duCibility w/Listing Sch /P1 ~2-16-83 CPL/Volan w/Listing 5" Sch ease sign 'and re.turn the attached, copy as receipt of data. Kelly McFarland AFA-4 03 Trans. # 273 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS .,..-/ ~ ~'" ARCO AlaSka, In.~ Prudhoe I[, -'ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 7, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porc~ine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: D.S. 14-6 D.S. 14-9B D.S. 14-11 D.S. 14-26 D.S. 14-29 D.S. 14,30 Permit No. 78-65 Permit No. 82-34 Permit No. 80-131 Permit No. 81-110 Permit No. 81-168 Permit No. 81'166 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells.. Very truly yours, D. F. Scheve DFS/TKKW/kn Attachments cc: Sohio Petroleum ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfieldCompany STATE OF ALASKA ALASKA ~"~L AND GAS CONSERVATION Ct.~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. NameofOperator 7. PermitNo. ARCO Alaska, Inc. 81-168 3. Address 8. APINumber P.O. Box 360, Anchorage, Alaska 99510 50- 029-20680 4. LocationofWell 2225'FNL, 847'FEL, Sec 9, TION, R14E, UM (surf) .2439'FNL, 234'FWL, Sec 10, T10N~ R14E, UM (top producing interval) 2387'FNL, 392'FWL, Sec 10, T10N~ R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 71' I ADL 28312 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 11. FieldandPool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and givepertinentdates, includingestimateddateofstartingany proposedwork, forAbandonmentsee20AAC25.105-170). Began perforating operation 12/25/82. RU perforating unit, pressure tested surface equipment. RIH with gun #1 shot 9136'-9156' MD 4spf (20' ref CBL 3/11/82) flow well to tank for clean up. POH all shots fired RIH with gun #2. Shot 9124'-9131' MD and 9111'-9121' MD 4spf (7' and 10' ref CBL 3/11/82) Flow well to common line for clean up. POH all shots fired. RIH with gun #3. Shot 9085'-9111' MD 4spf (20' .ref CBL 3/11/82). Flow well to common line for clean up. POH, all shots fired. Run static pressure survey. Secured well 12/29/82. RECEIVED F E B - g I983 Alaska Oil & Gas Cons, Co.,'nmissior, Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ........ _ _ Title Regional Operations Engineer The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Posl ~l!~ce E~ox 360 Anchorage, Alaska 99510 Telephone 00-"77 $~37 February 3, 1983 Reference: D.S. 7-11 Arco Pressure Data 12-1-82 12-1-82 Pressure Build-up Camco Pressure Build-up Survey Report D.S. 12-3 /1-12-83 1-12-83 Pressure Build-up Otis Pressure Build-up Survey Report D.S. 14-3~"1.2-10-82 Pressure Build-up Camco 12-9/12-82 Pressure Build-up Survey Report D.S. 14-17 f 11-12-82 Static Survey Camco D.S. 14-26~1-1-83 Static Survey Camco D.S. 14-29 12-27-82 Static Survey 12-27-82 Static Pressure Survey Data Camco D.S. 14-30~12-28-82 Static Bottom Hole Pressure Survey 12-28-82 Static Pressure Survey Data DA D.S. 15-11/12-30-82 12-30-82 · Pressure Build-up Camco Pre~sure Build-up Survey Report Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. $ DISTRIBUTION ll~ORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON ARCO Alaska. Inc. is a Sul~sldiary of AtlanticRichfieldComDan: EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS ARCO Alaska, Inc. Post Office )360 Anchorage, Alaska 9'9510 Telephone 907 277 5637 November 10, 1982 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3,001 Porcupine Drive 'Anchorage, Alaska 99501 Re- D.S. 14-26 Permit No. 81-110 D.S. 14-28 Permit No. 82-12 D.S. 14-29~Permit No. 81-168 D.S. 14-30 Permit No. 81-166 Dear Mr. Chatterton' Attached are "Notice of Intention" the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/TKKW/lmi Attachments cc' Sohio Petroleum Sundry Notices work proposed on RECEIVED NOV ! 51982 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc, is a subsidiary of AtlanlicRichlieldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-168 3. Address 8. APl Number P,O. Box 360 Anchorage, AK 99510 50-029-20680' 4. Location of Well 2225'FNL, 847'FEL, Sec 9, T10N, 2439'FNL, 234'FWL, Sec 10, T10N, (top producing interval) 2387'FNL, 392'FWL, Sec 10, T10N, 5. Elevation in feet (indicate KB, DF, etc.) RKB 71 ' 12. R14E, UM (surf) R14E, UM R14E, UM (TD) I 6 . Lease DeSignation and Serial No. ADL 2 8312 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 14-29 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note:Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to the flow station for clean-up and production. Should additional drawdown be necessary to unload the wells, it may be flowed to a tank for initial clean-up. The perforated intervals will be given in the subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intarvals: 9084' - 9120' MD 9123' - 9130' MD 9135' - 9155' MD Ref: BHCS 2/28/82 on Form No.f~--L~ Date~:l NOV 1 51982 Alaska 0il & Gas Cons. Commission Anchorage 14. I herebypeirtify that the fgcjegoiog is true and correct to the best of my knowledge. Date Conditions of Approval, if any: ORIG~N~LL SIGNED BY LONNIE C. SMITH Approved by COMMISSIONER Approved Copy Returned the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~ Post Office b~.~!360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 2, 1982 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- DS 14-29, Revised Well Completion Report Dear Mr. Chatterton' Enclosed is a revised completion report for DS 14-29. Original- ly, operations were suspended without completing the well due to a questionable CBL. Information concerning the subsequent completion of this well (tubing depth, packer setting and SSSV depths) is now included on the enclosed report. Sincerely, P. A. VanDusen Regional Drilling Engineer PAV/JG:llm Enclosure GRU1/L38 RECEIVED J U £ i 2 982 A~aska Oil & (~as Cons. Cornrn,~ssion Anchorage ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA · ALASKA AND GAS CONSERVATION C ~MISSION 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 ARCO Alaska, Inc. 81-168 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20680 4. Location of well at surface 9. Unit or Lease Name 2225' FNL, 847' FEL, Sec. 9, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2439' FNL, 234' FWL, Sec. 10, T10N, R14E, UM 14-29 At Total Depth 11. Field and Pool 2387' FNL, 392' FWL, Sec. 10, TION, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oi 1 Pool 71' RKB ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 02/10/82 02/27/82 05/1 2/82I N/A feet MS LI 1 17. Total DeptI~(MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionalSurvey i 20. Depth where SSSV set I 21.Thickness of Permafrost 9560'MD, 9324'TVD 9546'MD, 9286'TVD YES rx-t NO [] 2192 feet MD 1900' (approximate) 22. Type Electric or Other Logs Run CBL/CNL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 76' 30" 400sx Permafrost II 13-3/8" 72.0# L-80 Surf 2600' 17-1/2" 2000sx AS Ill & 400 sx AS I 9-5/8" 47.0# L-80 Surf 8857' 12-1/4" 500sx Class G 500-95 ,~,~'"'0 a"W. ,~1 ~,,id~'//~:/W- ~A~, ~,~-~,,~. 7" 29.0# L-80 8534' 9560' 8-1/2" 350sx t..laSg G 24. Perforations open to Production {MD+TVD of Top and Bottom.and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A 5-1/2" 8595 ' 8466 ' 26. ACID, FRACTURE, CEMENT SQUEE,ZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9265'-9267' 200 sx Class G 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ 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. N/A JUL 1 2 i982 Alaska 0il & Gas Cons. CommiSsion Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ NAME Include interval tested, pressure data, all fluids recovered and gravity, · MEAS. DEPTH TRUE VERT. DEPTH GOR, and time.of each phase. . · ' Top Sadleroch~t 8993~ 8782~ N/A . . 0/W Contact 9280' 9055' - Base Sadleroch'i~:. NoI: Eeached · .. · . · · .. . · . · · · ., · 31:. LIST OF ATTACHMENTS .... . 32. I hereby certify that the foregoing is true and correct to the best of m¥ knowledge , 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 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· h-om 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' I~dicate 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 cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10407 ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 9, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 14-29 Dear Mr. Chatterton' Enclosed is our subsequent report 14-29. If you have any questions, please Sincerely, M. A. Major Area Drilling Engineer MAM/JG: 1 lm Enclosure GRU1/L15 of the call me completion at 263-4965. of well JUN 1 lgB2 Oil & Gas Cons. Commission ~ch0rage ARCO Alaska, inc. is a subsidiary of AtlanticRichfieldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLA3 OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-168 3. Address 8. APl Number ~P, 0. Box 360, Anchorage, Alaska 99510 50-029-20680 4. Location of Well 2224' SNL, 847' WEL, Sec. 9, TION, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 12. I 6 . Lease Designation and Serial No. ADL 2~3 ~12_ 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 14-29 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Commence operations at 1600 hfs, 05/08/82. ND tree, NU BOPE. Test to 5000 psi - ok. R1H w±th 3-1/2" drill pipe, tagged bottom at 9531' and circulated 1/2 bbl of cement/scale fi11, POOH w/drill pipe. RIH with 4" perforating gun, perforated the 7" liner at 9265'-67' with 4 spfi, POOH with perforating gun. Performed cement squeeze job, pumping 10 bbls fresh water and 41 bbls cement, R1H with 6" bit, tagging cement at 9238', Drilled out 19' cement to retainer at 9257', POH. Run 5-1/2" 171t completion string with gas l±ft mandrels at 2914', 4807', 6088', 7108', 7650', 7728', 8041', 8117', 8351' and- 8/430'. Install packoff and tested to 5000 psi, NU gray tree and tesf. ed to 5000 psi. Set Baker poe~.r and test to 2000 psi. R1H wi~.h E line, to determine PBTD to 9546'. POOH with E line. Prepare tree and released rig at 1200 hfs, 05/12/82. 14. I hereby certify that the for,,egoing is true and correct to the best of my knowledge. Signed Title Area Drilling Engineer The space below for Commission use JUN 1 1 1982 Alaska Oil & Gas Cons. Commission Anchorage Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 GRU7/A1 1 Rev. 7-1 ~30 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate N 17 ~¢. t4~~ ~o 'T' to 1,4, RI4.~ Cl. lq. I"-' 4~' ~d X' G'r ~'1'o~'. ~1 I=~'T; · -I0° 14' 09.4188" I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS-BUILT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT, AS OF: x, = G,'7 ~, ~,7..?..4'f LAT. = 70% 14' IZ..tS~ol" t,..~r-T. , 14~,0 3~' .~4..85o" r..~.~.~. 'lScsx. ~-~-V.-- 4ZS--~ AR.CTO Oil and Gas Company .- IDATE, J DRAWING No.: ALASKA DISTRICT-PRUDHOE BAY '~' IZ/~/,~/ 4.13~-Z, Alaska, Inc. Post Office Box 360 Anchorage, Al"-,~a 99510 Telephone 90 I7 5637 May 20, ~ 1982 Reference: ARCO CASED HOLE DATA D.S..14-29 3/12/82 C.A.T. Subsurface Casing Field Interpretation Report & Subsurface Casing Inspection Report Summary Please sign and return the attached copy as receipt of data. ~ry F. Kellis North Engineering Transmittal # 177 DISTRIBUTION '.:~TEi~GEOLOGY R&D MARATHON MOBIL D&M GEOLOGY 1 1982 Alaska 0il & Gas Cons. Commission Anchorage AT. ® · · (Corrosion AnalYsis-Tubulars) cUSTOMERARC0 ALASKA, INC. LEASE/WELLNO. D. S. 14-29 FIELD PRUDHOE BAY WORK ORDER NO. 32080 CUSTOMER ORDER NO. COUNTY NORTH SLOPE DATE 3-12-82 STATE ALASKA CASING O.D. 9 · 6 WEIGHT(S) 47 # NOMINAL WALL THICKNESS GRADE 1'~-80 TOTAL FOOTAGE INSPECTED 6400 FT. FROM 8400 TO 2000 DEPTH SUBSUI::F:ACE CASING RELD INTERPRETATION REPORT . Joint Class COmment . Joint Class Joint Class Comment Joint Class No. 2 3j 4 No. 2 3 4 Comment . No. I2 F3 4 No, '2 3 I4 · ,, , , I I 51 ,~ : 101 151 · : , ,,, 2 52 102 152 3 ~ 53 103 153 , , , , , 4 {.54 104 164 5 , , 55 I 105 155 6 ~ ' 56 106' 156 , : , , '"7 ~Z ' . .... 57 107 . .- 157 8 [ 58 108 158 9 59 109 ~ 159 . . 10 60 11.0 ~. 160 ,, 11 ~ 61 111· 161 · . 12 62 112 162 r -. 13 63' 113 [ , ' ,' 163 14 X q,,,, 64 114' , 1'64 15 Ii 65 115 165 , - 16 ~ 66 116 166 17 67 "~"" 117 "' 167 , , 18 68 '~ 118 168 . , 19' ]; 69 119 169 . , 20 , 70 120 170 21 71 121 171 22 72 122 172 ,, i 23 73 123 173 . , 24 ~ ; 74 124 174 25 ~ 75 125 175 , 26 76 126 176 27 77 127 177 , 28 78 128 178 , 29 79 129 179 30 80 ~30 }[ 180 31 81 131 ' 181 , , , 32 82 132 182 , '33 83 133 183 3~1 .... 84 134 184 37 , 87 137 187 '~e ~. 13~ 180 40 "[- ' 90 ~ 140 190 41 01 141 101 i i ii 42 92 142 43 93 143 193 , ,, , 44 ' 94 144 , 194 46 ' 96 146 196 47 97 . 147 197 48 ' 98 148 198 ~ . . ii I DA-1368-A (10/80) C;A.T' LO ' (CorrosiOn Analysis TubUlars) CUSTOMER ARCO ALASKA, INC. DATE 3-12-82 WELL D.S. 14-29 SERVICE ORDER NO. 32080 FIELD PRUDHOE BAY 'COUNTY N. SLOPE STATE ALASKA CASING S~ZE 9.6 WEIGHT)S) 47~; GRADE L-80 NOMINAL WALL THICKNESS ' TOTAL FOOTAGE INSPECTED 6400 FT. FROM 8400' M'~D'. TO 2000' M.D DEPTH ~UB~URFACE CASING INSPECTION REPORT SLJM~ 1.38 LENGTHS WERE" FOUND TO SHOW NO EVIDENCE OF CORROSION EXCEEDING PERCENT OF THE NOMINAL BODY WALL. I1 LENGTHS WERE FOUND TO SHOW EVIDENCE OF CORROSION EXCEEDING' PERCENT BUT LESS THAN 41 PERCENT OF THE NOMINAL BODY WALL. . , LENGTHS WERE FOUND TO SHOW EVIDENCE OF CORROSION EXCEEDING PERCENT BUT'LESS THAN 61 PERCENT OF THE' NOMINAL BODY WALL. LENGTHS WERE FOUND TO' SHOW EVIDENCE OF CORROSION EXCEEDING PERCENT OF THE NOMINAL BODY WALL. TOTAL LENGTHS - TOTAL FOOTAGE -~- 2O CLASS 1 20 CLASS 2 40 CLASS 3 60' CLASS 4 REFERENCE FOR FOOTAGE MEASURE LENGTHS ARE NUMBERED FROM TOP DOWN COMMENTS ! SERVICED BY DA-1363-B (10/80) Post Office Box 360 Anchorage, A"'"~o .92510 Teler~hone 90, I7 5637 April 29, 1982 Reference: ARCO CASED HOLE FINALS D'.S.14-9B~/4/10/82 D.S.2-20 ¢ 4/12/82 D.S. 13-17 ~4/7/82 D.S.13-17~ 4/13/82 D.S.2-20¢ 4/19/82 D.S.7-11u/' 3/31/82 DS..15-3 ~ 4/2/82 D.S.15-3 / 4/2/82 D.S. 7-14 ~ .... 4/1/82 D.S.14-28~ 3/28/82 D.S. 17-10¢/ 3/15/82 ~~ 3/1i/82 D.S. 13-23A v/3/17/82 3/1i/.82 D.S.ll-2¢/ 4/10/82 D S 2-13'~4/i9/82 CNL' Run 1 2" & 5" ACBL/VDL/GR Run'l 5" ACBL/VDL/GR Run 1 5" CNL Run 1 5" CNL Run 1 5" CNL Run 1 5" ACBL/VDL/GR Run 2 5" CNL Run 1 5" CNL Run 1 5" CNL Run 1 5" Perf Record Run 1 5" Pipe Analysis Log Run 1 5" CNL Run 2 5" CNL Run 1 5" CBL/VD Tun 1 5" Collar & Perf Log Run 5 5" Collar & Perf Log Run 1 5" ~e sign and return the attached copy as receipt of data. Mary Kellis NCrlth Engineering TransmitO~-I # 134 DISTRIBUTION R&D MARATHON D&M GEOLOGY ~,, ~.-- - .,i. ii, ARCO Alaska, Inc. "~ Post Office Box360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 3, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUB3ECT: Sundry Notice for DS 1Lt-29 Dear Mr. Chatterton: Enclosed is our Sundry Notice off intent to complete DS 14-29 with 5-1/2" plastic-coated tubing. Since we estimate starting this proposed work on May 7,'1982, your earliest approval will be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM:OG/hrl Enclosures GRU4/B12 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ,1;,i'M ALASKAC AND GAS CONSERVATION CO ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, ]:nc. 81-168 3. Address 8. APl Number P, 0, Box 360, Anchorage, AK 99.510 50-029-20680 4. Location of Well Surface: 2224'S and 847'W of NE cr See. 9, TION, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) ~,0' Pad 70' RKB I 6 . Lease Designation and Serial No. ADL 28312 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 14-29 11. Field and Pool Prudhoe Bay Field Prudhoe 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes completing this well with 5-1/2" plastic-coated tubing. Before the compIetion string is run, the 7" iiner wiii be squeeze cemented. Cement bond iogs indicated poor bonding on the Iiner. The compietion string wiii incIude gas iift mandreis and provisions for a subsurface safety vaIve. A 13-5/8", 5000 psi, RSRRA BOP stack will be used on work performed by the workover ring: The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. Estimated start date': May 7, 1982 RECEIVED MAY 0 1982 Subsequent Work Be:ported on Form No./~ Dated ~._/~_.J~.~ Alaska Oil & Gas Cons. Comm/ssion Anchorage 14. I hereby certify that_the foregoing is true and c,orrect to the best of my knowledge. Signed ~~1~'~'~~"~ Title Area Drilling Engineer The space below for Commission use Conditions of Approval, if any: Approved by lt¥ [~F!E C. SglTil Form 10403 Approved Copy Returned By OrOer of COMMISSIONER the Commission Submit "Intentions" in Triplicate Rev. 7-1-80 GRU4/A24 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. April 30, 1982 Mr...C.V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001Rorcupine Drive Anchorage, Alaska ~9501 Subjec~: State Reports Dea~ Mr. ChaLterton: Enclosed are Well CompleLion ReporLs for Lhe following drill siLes: 11-6 11-7 15-2 1A-15 (Revised) Also enclosed are monthly reports for March on [hese drill sites: 2-19 15-4 2-20 Eileen #1 13-17 West Sak 24 13-23A 1A-16A (Sidetrack) 14-9B IE-9 14-28 Oliktok Pt. #1 14-30 West Sak 25 15-3 We are also including plug and abandonmen( subsequent sundry reports on Eileen #1 and 1A-16. The reports on Eileen #1, Oliktok PL. #1, and the two West Sak Wells are of a'conFidential naLure. We would appreciate it if you could store informa[ion concerning these wells in a secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG:pb eno. GRU4/B4 ~ , ' ~ STATE OF ALASKA ,,, .... ~ ALASKA .[..~J~AND GAS CONSERVATION C~,..~ISSlON WELL COM.PLETION OR RECOMPLETION R'EPORT AND LoG' 1. Status of .Well Classification of Service Well ' OIL [] GAS [] SUSPENDED [] ., ABANDONED.[] SERVICE [] ' , , 2. Name of Operator 7. Permit Number ARCO A1 aska, :Inc. 81-168 3. Address 8. APl Number P. 0, Box 360, Anchorage, AK 99510 50-029-20680 4. Location of well at surface .. 9. Unit or Lease Name 2225' FNL, 847' FEL, Sec. 9, TION, R14E, UM LOCATIONS: Prudhoe Bay Unit At Top Producing Interval' VERIFIED ! 10. Well Number 2439' FNL, 234' FWL, Sec. 10, TiON, R14E, UM sur{..~ 14-29 At Total Depth B.H.~ 11. Field and Pool 2387' FNL, 392' FWL, Sec. 10, TiON, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i ] P0ol 71' RKBIADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 02/10/82 02/27/82 ' 03/13/82IN/A feetMSLI 1 17. TotaIDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 9560'MD, 9324'TVD 9520'MD, 9286'TVD YES~ NO[--] feetMD 1900' (approximate) 22. Type Electric or Other Logs Run CBL/CNL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD .CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 76' '~ 30" 400sx Permafrost II 13-3/8" 72.0# L-80 Surf 2600' 17-1/2" _~O00sx AS III & 400 sx AS I 9-5/8"~ 47.0# L-80 Surf 8857.' .1.2'1/4" 500sx.Class G .. ' S00-95 7" 29,0# L-80 8534' 9560' 8-1/2" 3505x Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD , . .., interval, size and number) . SIZE DEPTH SET (MD) PACKER SET (MD) , N/A. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. N/A..~ . . DEPTH INTERVAL (MD.) AMOUNT & KIND OF MATERIAL usED N/A. ' .... , .... 27. pRODUCTION TEST ' ' Date;?irs{ Pr.0duction · Method o.f Operation (Flowing, gas li~t, etc.) N/A. ' N/A. ' ' .. ' Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO .. TEST PERIOD Flow. TUbing Casing Pressure CALCULATED.1~ el-L-BBL.. GAS-MCF WATER-BBL OIL GRAVITY-APl (c0rr) 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. · APR o 1982 '*-'J22k;:). 0;1 & G2:] Cons. Form 10-407 GRU3/B23/24/25 Submit in dUplicate Rev, 7-1-80 CONTINUED ON REVERSE SIDE · ~ NAME '. Include interval tested, pressure data, all fluids recovered . . ;" ., MEAS.. DEPTH ..., TRUE. VERT. DEI~T,H. 'GOR, and time Of each .phase. To~ '$adlerochit 8993' ~' 8782'" ~' " O/ . Contact ' 9280' 9055" .. . .... · · · " N/A'. · .. ., · . .. . . · . . . . . ·· ~ . . . . ? .. . . . . 31. LIST OF ATTACHMENTS . Drilling H~story, Cyro Mult~shot (2 cop~es)~ ':"'~ . 32.. I hereby certify that.the foregoing is true and correct to the best of my knowledge " Signed ' Title Area Drlg Engr Da,e 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 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 th.is well is completed for ~parate 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 cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". · . DS 14-29 Drilling History NU 20" Hydril & diverter. Spudded well ~ 2230 hrs, 02/10/82. Drld 17-1/2" hole to 2630' Ran 62 jts 13-3/8" 72#/ft, L-80, BTC casing w/shoe ~ 2600'. Cmtd 13-3/8" csg w/2000 sx AS III & 400 sx AS I. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BORE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 8906'. Ran 220 its 9-5/8" 47#/ft, L-80 & S00-95, BTC csg w/shoe ~ 8857'. Cmtd 9-5/8" csg w/500 sx Class G cmt. Instld 9-5/8" paekoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 9560'. Ran DIL/SR/BHCS/GR & FDC/CNL/GR/Cal. Arctic packed 9-5/8" x 13-3/8" annulus. Ran 26 its 7" 29#/ft, L-80 csg f/8534' -9560'. Cmtd 7" lnr w/350 sx Class G. Drld cmt to 9520' RBTD. Tstd lnr lap to 3000 psi - ok. Displaced oep well to NaC1. Rev cite diesel^in hole. Set tbg hgr & BRV. ND BORE. (There is no tbg below hgt.) NU tree & tstd to 5000 psi - ok. Secured well & releas- ed rig ~ 1200 hfs, 03/03/82. Gyro, multishot survey ran 03/13/82. Note: Well was suspended without completing due to questionable CBL. 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'. ..... · ......... . ............. ......... :: -. . ........... . .. - .... :-:::.-:"::7.:v v'.:v'. ......... :.:L :.:::'-: :"-',::': "::' '~CO ____ _~S~ ---_~N~. -- "-'"": ........... ':":~:: .... .' :' .... -' ' ' COMPANY -.. ., -.. .... .- --. . '., .-- . . ' ..,, '. - .- -. . - '.-..-. : ..... ~ ................. .. :: -.*- :.. ' '"' '.' ' .' ' ' ' "._..:':..': .... .-:: .:'.'. ':~.': v ', .' " '- t....._...~.t:-" .'-'----t.-'.:-..: ..' t.---: DS 14, Well N~ber: 29 ' ' . ......... . --. - . -. · . .. . ~fikk~M[ ..... . _~ - . .. ._ .... Prudhoe Bay, North Slope, Alaska _ LOCATI ON _ -.. --- _-.. - ..-. _ . . . . ~: '.... '- - --- .. · - . __. ~-' ~ :i: . . .... . .... ' ....... ~ . . - -. - ~-. _ -.. - ................. a '.-: ...... - ._. -.. ~" :"'-':"-':: '--' ..... ':::: JoB '~IUMB'ER-~..?.~:.~:i!!ili:i...'-':!i::ii!i~:i:: TYPE OI~' SURVEY::'i!-:-!-'.::-7-L-~f::--.~:t:tS::':::-)~-.:!!-.:i-.:L:';'i'!!'~..'~(-DATE '":_~/i-:.:':.:~":.. ...... -:'- .: ' ,: :: -.: -: ' : ' -': - ' ' ' ." -: '"i.'..":--.'.:.'. ~'- ' '" :- " ...... ":' :"::::'::'-~::::--: ::':" -':""-:?-"-':::-"-" .......... ............. . ........ . ...... .:- -.:. ...... ' " ........ :.':::L :2 .'. '_'.'.": -' _ . -.'.-.'.' ' - ............................................... - A0282D0268 ..'-' .:" ':'-:-:: _' .-:-:::.-' Direc~i0~'al Singl.~.~..:.~.-'_~::[:~:-~::.-'"':iii_~ ~::!:' '27:Feb-8 2.''::-.~- ': ' ':'....''- . .... . ..: : . :...: -: : - : :: . _ . ' . ·:'2:",':: ... '7...:_".'. ...... ':: - ':"' :: ...... " ' ' . .-.. 'F: .''::' . ........ _. .-'-.-.. :'::~:-...-;i.:~iil/._?-:iC(:~:)::}i.i!'i':-:i:S.::::ii:ii:.j::::::it-;:' ':· i:-'i-:-::-?.:::...:.:.:!-".'..-.'.:-:.!'.' ~:.:~-::":::-::-'-'.·!'·:'--:" --::::AFR::-.~-~-:-~:'.982:-:::"-:'--::-'.-·-~-':'-.'~:: :.::-'-:-:'-'"-' · .,-..::':-'....:'.:~::~::::::-:,:.:£.'.-...'...:~:':'//:::,. ........ ..':: .. :..:..:.:.~ ..... '~ ..:::...7..:.::..:.`:.....!:.!:.::`.::f:..:::.:...:.~L:.::....~...-...::..`..:.::t:.::.:...::::.i.:::::L. ~ '"' '.:.:.-'_-'~f--.:::' .. ::-'~" - '-:--.-: "':-:(ii:i-..,-.i:::.:-_.--..-:~i.:i'.~ 7/i:'~::' ~ :::::~'.:---':-:':77':--?~'-::: ' : --.'.7"'-."-.'":?: . : ::-!:(~(~:~:~-:~2~i:i~0~:i~[~ ::-.-"' . V'-:. '. : .. : . . ...... . ..... ' .............. "'-"---'-'- ..... '-":"-"-':"::'-: .... ::--: :-:-:::-"'. '---:'::-:----': ......... - . -' -':-.':~?::?!:-': ::~?i?::'-::':"-'::::"'-'--:' ::' ' ....... -':'""'::::~::::'--:":-::':.: ..::~.!~:.::....::!:.!:..:.-..~..:.:...:F...!!.::.!::..:.:::..-:.:.:..~.!:.:.:.!!:.....-....:.:..`..7-......v:``:::F ::.,.:.-.-::::_:.-_::-. ...... F_::.-.:.:.:.:-:.:.:.--_-.._:::-::-. SURVEY BY i i:.-'-.'-:-:-.-.--,--. ........ :.---: ':'-..,.-:-:,:'.:/::~:.?'.'-:..::i-: ::".':..'.L:.::-":,::.::':.::'::"i'.- OFFICE .: .... .:. v-.-.-: ::::-_: .... :::. :::::: ::-::::-.-_:-,'.-:-- -'_ .- ....... --.-. '..--. ' 'v::' :: - :~'--'.,:.,- - v,'.v::-.-,v.-.:_::-:-.:vv .-::~.:_.-:.::_j.~-:-.:~ -'..- .:. '-. .... ','''.- 2~': ........ ..:JJ2.2.:'. '''.:' 2 .... T':.': ..J.'.'.'. ..:i:_'.'-'.'2.'..'2.'J::".::;'.'.L...~:::::o":.'::.'::o.'..." 2'.':::- . ............. ..................................... . .. . :-:: --' .... - ......... ::-" '. '::"':.-:' D T,e~e~e '- ' "::' ':'- ..... A~aska . . --:. P. O. Box 4-1970/Anchorage, Alaska $9509/(90?) 349-4617 5~rch 1, 1982 A~RCO ALASKA, INC. P.O. Box 360 ~mchorage, Alaska 99510 Well Number: DS. 14-29 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Directional Single Shot Date: 27-Feb-82 '' Method of Computation: Minimum Curvature o Surveyor: D LeJuene Job Number: A0282D0268 Attn: Bob Hines Dear Mr. Hines, We are enclosing the original and one Copy of the Directional Single Shot Survey run on the above mentioned well. To date, the following distribution has been accomplished: A. 0 copy(ies) telecopied to E/W North Slope office for delivery to Arco field.representives. B. 1 copy(les) delivered to drilling for in-house distribution. C. .3 copies for E/W permanent well files. We wish-to take this opportunity to thank you for calling on our services ~nd we trust that we may continue to serve your needs in the future. Si.n.c?rely, ' Sn---'YA~ TALWAR ' ' District Operations Manager ST/bb cc: file ~nclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ARO0 ALA,.qKA, .~NC, ' DS'14,' ;IELL NO; 27 DSS dOB NO; A0~8,=])0268 F'RUDHOE BAY, NORTFI SLOPE, Al. ASEA. DSS~ 0-8846 HD, DRIL[.ERI D I..EJ()F::NF~ DECLINATION: 30 ~/2 DEG,' EAST UERTICAL SECTION CAI CIJI ATED."ZN F'I ~NE~'OF~F' 'OF'O~ !?~~ ~?~>?~'~ ..... APE I'f ~()IANfY COMPANY RECORD OF SITRVEY .'~' ~'~ ...................... ~ ................ , ........... ; ........................................................................................................................................................................................ ~__~,~ ...................... .............. ~,: : , ~_~. ........... ., .... -. MINIMUM CHRVAT[JRE METHOD . . .... ~,: :.. :;,.: :[. -;.:'/. :.~'~'.. ~, .- , . ·. · ~:,......: ~ ~ ~ :.. rjS 14, WELL NO; 29 ][;SS " :'RUDHOE-BAYS-NORTH-S['~OF'Ei ...... AL.'ASKA- JOB NO; AO282D0268 · .!ii! ;! COHF'UTAT]ON PAGE '!-TIHE:''i!~'; DAT~ , . : TRUE ,i ,' tEASURE',D-DF~IF'T.----DRI FT ...... COURSE VERI'.I. CAI.:-- VERI"I CAL--'SUBSEA .... R'"E'-C-T--A-N-8-U-L--A-R-----'C-L-.-O-S DEPTH..' .ANGLE DIRECTION [.ENGTH DEPTH SECTION TVD C 0 0 R D I N A~T E 8 DISTANCE FEET.~mI) M ri M FEFil' FEET FEET F'EET FEET ' .. ,'i FEET .......... . .... _,..,...._.,.. .... -- ........ o. _..,. ................................... ... . : . . . 0.00 0.00 -71.00 0.00 4547.00 0.00 4476.00 0.00 ",~046'~-9..- ............ ~.'44 ....4975'~-92 .......... 7~-49'-S 5642,34 6.55 5571.~4 ~1.68 S · .,776,15 9,91 .,~70~-'. '1~., ~8,55 S .6 0 S 49 0 E 123. 5898.75 19.06 58~7.75~ 4~,.,,9~ S O, O0 O, 0 0 0 0 O. , 4547,,." 0 ~ 0 0 0 4547, .... 504'7~----1--45"-$'"'~'t---0-W ......... 500~ 5643, 3 15 S 25 30 W 596. 5777, ~ 15 S 25 0 E 1~4. IJ'-R- E D I R E: C T I 0 N 0~00 0 0 0,00 0 0 ]0,47 W ~.~6 S 1~ 17 W 1'0.50 W : :'39o95 S 15 14 W DOQEE~ SEVERI' .'DG/IO0~ 0.00 0.00 0,35 0,27 2.07 5900o. ,:,. 4.17:W 46,12 S 5 11 W E 94, 599,1. o94 31,23 5920,94 52,78 S -";" 5.94 E'":::'.,53oll S 6 25 E ...~55 "E ............ 9~' 6083i'54 ................ 47'i'1'7 ..... 6012¥54 ............ 58v95--S- -20~6-E~62~50~S--19---24 E '3"i16 E 241. 6317.58 10,1.14 6246.58 69.56 S 76.80'E-i ',103o62 S 47 50 E 2.50 E 221; 6527,74 ,1164.43 6456.74 78.57 S 144.48 E :".164,46 S 6,1. 28 E ,1.39 ..................... 5994, i' 9 0 S 60 30 ~-6087-1":--1-t--'0-S~73 .... 0 6328, 16 ~0 S 83 30 6549.. 19 30 S 81 30 6757, 24 0 S 78 30 E 7332o., 22 45 S 79 30.E .... 753&r'--21-15_S...79_30. E 8169. 16 0 S 79 30 E 8846. 17 0 N 84 30 E 9500° 14 30 N 75 30 E 33,.. i8037,47 7J:6.,,46~I7966,47 ,.186,47~.~,S i7.18~,07,E 741,89 ~ ~5 ~ 677'~';~'.'~-;8,~86'92 "', 885,5i~'~-9'~"86fiSl~2%~:~/Jg,.3~?~;97~8w- ~O~(.4~,:;'E ';' "928,9J S 77 57 E 0.69 "'~ ........ ~"~'": ...... "'"'"' "~ ..... '" ' ~"./.;-~"':.'~'~ ~t~'""~-., 654, 9316,41. 10~ 75 9245~,/411¥)lAtl~S,4.,.t32N'S 1082,91 E :'.1095.31 S 81 22 E '0,53 FINAL CLOSURE - DIRECTION; S 81 [lEGS 22 MINS 19 SECS E DISI'ANCE; ~1095, ~,1 FEET ' ' t.. ,.~,.~ ' -. ~ ;' ,.I :~,~i ' ' ~'~ .... t~.:~. ;. ',5 i:.',:~.:,;k'.' ~ ~: ~. :,', ;'t, ·, }j. . ' ,.>:;~; ].Nt'¢-'-~'.t. :: .:;;;~, ~; - DRIFT CHART'S REL.ATED DATA FILE · , , qRCO ALASKA, INC, ,.iS 14, WELL NO: 29 DSS , ,JoB NO: AO,-.8~.K O,: 68 " ~ ~ I P RUBHO E-'BA Y'T-'NO R TH-'~L:'OF'E"'i ...... AI/~SKA .............. : ........................................................................... ~URVEY-F,TL-E-~-NUMBER---267 ............................ BOTTOM HOLE ASSEMBL'Y VALUES IJSED FOR DEF'TH ARE MD DEPTH DESCRIF'TION 110, O0 F'ENDUL.LIM ASSHEI. B.Y,.,~,, ,s,~.,·,.,~. ' 2630. O0 PACKED HOLE/ANGLE: BUILD ASSEMBt~Y:~~~)~ .-': 8906,00 F'ACKED HOLE ASSEHBI..Y , ......................................................................................................................... PRILLING DAYS UAI.UES IJSED FOR DEF'TH ARE DAY DEPTH 1 t. 2630,00 ..... ~'2'-~-- 26~0~'00 .............................. 3 " 3061.00 4 5693.00 6 ~ 6100.00 7 6378.00 ~ 8 ....... 7026,'00 ............................ 9 ' 7656,00 10 ,' 8542.00 i-1 8906-~00 ............................... t0 ~O~.~ /'t / ..~'_:* //.i'( )1 A/J~: (;(, .)/;dt :~l/~Jy' ~ ...... I)EF'TH ...................... NEIBt.IT ..... ~'I'OTO0 ......... 6~'~ O0 ............. 2630,00 65,00 5&9~, O0 ' O, O0 --6159~'00 ......................... 65~00 .......................................................................... 6787,00 85,00 7606,00 · 65,00 ~8906'~'00 50,00 - REVOLUTIONS F'I:'R-'HINUTE' ........................................ ~ ' ,-'--. :".,':'.',:...i :~..i. . · , ' ' VALUES "' ~ ' ' _'~ ~. ' .......................... ~,,~ ~,~f~ .,~ ~ ,,~.:~ % .. 110, O0 140 O0 A t.-~: lift_ I.AN[~ COMI.~WY S ...... ] ' . 2630, O0 140,0.0 . ~15~,00 140,00 ' :~.; ' .... 6787,00 140,00 --7~06'~00 1 O0; O0 8~0~00 120,00 .¢',., & 9,7& 1,~ DEPTH DRILLWlTH WEigHT. b PUMP_ 3 ~ 0 Bit type 0~~~_ & Knozz~ size J~ Hours on Bit - Dc . .. 1,50 - ',5 ~c Z .9'6 31,oq Purpose of Assy.D:;// . : : ' : _ . :~ 3., ._..-'..' . .'Y . . . ' - ~URVEYS FOR THIS ASSY. DRILLWITH ~,~,~,~ ~¢~./~~- " Bit typ~a ~ & Knozzle size Hours on Bit - ItO0 Purpose of Assy.~,,~7,~ SURVEYS FOR THIS ASSY ' '":- ' ' -'---':-"h"'--- '~ .'~ '"<" ...... ~.~-~ · -~ '--" -'" ' '- .., 'T ~ - ~..,;.':~.~ . .... ~ . ~;~ .._ __ DRILLWITH WEIGHT. ~ RPM _ _~ '~ · Bit type ~ ~_D~ '~'~' & Knozzle Size ~~y) Hours on Bit- ~'3 F 22',1o ~7 ~.~z.z ~ D£ )~-z~ SURVEYS FOR THIS ASSY. DRILLWITH /,- Bit type ~ ~.¢ & Knozzle Size Hours on Bit- 22'// -. -. i Purpose of Assy. /-J~/d ~ . _ . . .:. - . .,: .... ~ - . . . SURVEYS FOR THIS':'ASSY. . 2 .75 36 DRILLW1TH WEIGHT_ ~ ~ Bi~ tyue~ Hours on Bit - · · ~ D.(., 3/,oF. Purpose o-f' Ass_y...29¢~,~7/¢ ~ -._, . · ' :--;. y'. ,"~' ..... .ii.?:- .. - . SUR,%TEYS FOR THIS ASSY. D RILL V,,'ITHi RPM /t? 0 & Knozzt~: Siz Hours on Bit- 3'9'7 ~7,7 7 3 ,?7 Purpose. of As. sy.~ .. SURVEYS i~OR THIS ASSY. ..-.. ~...z::..-._ . : .: ..' ~:-~-. -- : . .'-;' . · .... ~.:7%::-~ . .... .'' -.,.. ;---: . - _ . -. DRILLWITH WEI~HY PUMP Bit typ~ & Knozzle Size Hcu-ss cn Bit - !i RRCO LRSKR, MELEE · ":'i FINRLi Eastman / ~-~ Whipstock l)~ A PETROLANE CC~PANY REPORT of SUB-SURFACE DIRECTIONA L, SURVEY ARCO ALASKA, INC. COMPANY DS 14, Well Number: 29 WELLNAME Prudhoe Bay, North Slope, A~a. sk.a LOCATION JOB NUMBER A0382G0416 TYPE OF SURVEY Gyro Multi Shot ~ka 0;1 & "' '- ua~ Cons. SURVEY BY B Jahn OFFICE Alaska DATE 13-Mar-82 OI,~M I)-302 R2 Eastman Whipstock A PETROLANE COMPANY P. O. Box 4-1970/Anchorage, Alaska 99509/(90?) 349-4617 March 25, 1982 ARCO ALASKA, INC. P.O. Box 360 Anchorage, Alaska 99503 Well Number: 14-29 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: .Gyro Multi Shot Date: 13-Mar-82 Method of Computation: Radius of Curvature Surveyor: B Jahn Job Number: A0382G0416 Attn: Bob Hines Dear Mr. Hines, We are enclosing the original and sixteen copies of the Gyro Multi Shot Survey run on the above mentioned well'. , To date, the following distribution has been accomplished: A, 1 copy telecopied to E/W North Slope office for delivery to ARCO fiel~ 'representives. B. 16 copies delivered to drilling for in-house distribution. C. 3 copies for E/W permanent well file. We wish to take this opportunity to thank you for calling on our services and we trust that we may continue to serve your needs in the future. Sincerely, District Operations Manager ST/bb cc: file enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ARCO AI_AS~A, INC~ ~' '° ~ ~ ..... DS ..... 1~4, WELL~--NOI~29~'GMS ................................................... ~tOB--NO~---A0382G041~6 ............ PRUDHOE BAY, NORTH SLOPE, ALASKA GMS~ 0-?~00 MD, SURVEYOR, B, ,~AHN, DATE RUN; ]~-MAR-82 FORESIGHTI N 7 16 W VERTICAL SECT ION CAI.CULATE~D~t~N PL RECORD OF SURVEY RADIUS (}F' CURVATURE HETHOD ~ DS 14, WELL NO: 259 GHS.' JOB PRUDHOE"BAY, NCIRTH SI. OPE, ALASKA TRUE HEASURED'" DRIFT DRIFT COURSE '-VERTICAIZ- VERTI'CAI~ ....... SUBSEA .... R 'E" C' T' "A-'N'-G'-U '15 -'"A'---R ...................... C'-L--'O'-"S"-U-R-"E ............................... DOGL'EG'--i DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE IIIRECTION SEVERITY FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/IOOFT . . O, 0 0 0 0 O, 0,00 0,00 -7].,00 0,00 0,00 0,00 0 0 0,00 100. 0 0 0 0 100. 200. '0 0 ' ' ' 0 '0 ........ l'"O0'i .......... 200',-00 ...................... 0 ;"00 ...... 1'259'~'00 ....... 0 300. 0 30 S 41 30 W ]00, 300.00 -0.09 229,00 0,33 S 0,259 W 0.44 S 41 30 W 0,50 400, 0 0 0 0 100, 400.00 -0,18 329,00 0,65 S 0,58 W 0,87 S 41 30 W 0,50 500. 0 15 S 46 0 E 100, 500.00 0,03 429,00 600, 0 15 N 76 0 W 100, 600,00 0.03 529,00 700." 0 30 S 86 O- E .... ].00~ ..... ~99~-99 ........... ~0~-12 .... 628~'99 800. 0 15 S 0 0 E 100, 799.99 0,45 728.99 900, 0 45 S 54 30 E 100, 899,99 '1,15 828,99 0.80 S 0,42 W 0,91 S 27 41W 0 ].,09 S 0,58 W ~,2~ 0.65---S ............... O~-5~-W ................... 0'~-8~ .....S-"~38 ........ 2"-W .......0-~-75 .... 1,059 S 0,10 W 1,09 S 5 25 W 0,54 ].83 S 0,28 E 1,86 S 8 44 E 0.64 1000 I 0 S 53 0 E 100, .......... 999 98..? ~.,. ,.,67 9~8.98 -~ 74 S 105] E 3,13 S 28 56 E 0,25 1100 I 3;0 S 59 0 E ]00* 1'1099 3;.96 S ~,32 E 5,16 S 40 0 E 0.52 1300. 0 45 N 68 0 E ]00':~'.:~12~9 ~ 6.73 :;1~8.~D°~ 3 27-::S · · 88 E 6.7~ S 60 56 E 0.~1 1400. 0 15 N 72 30 E 100'":'~::~'1399.93 2;97: S .' ~'~'?:~.~:;'. 70 E 7.33 S 66 5 E 0.50 I 0 S 16 30 E 100. ]479.92 8.28 1428.92 ~.43 S 7.57 E 8.31 S 65 0 45 S 25 0 E 100. ]599.91 ?.45 1528.9J 4.86 S 8.]1 E 9.45 S 5~ 4 E 0.28 I 15 S 29 O'W "1-00-~ 1699~89 10,23 ]628.89 6.54 S ..... 8'~'05"-'E ............... 10"~"3'7 ...... S'"50-"'54 E i 15 S 2 0 E 100. 1799.87 10.83 1728.87 8.6~ S 7.55 E ]1.47 S 41 9 E 0~67 0 45 S 14 0 E 100. 18~9.85 11.87 ]828.85 ~0.36 S 7.79 E 12.96 S I 15 S 4S 0 W 100. 1997.84 12.32 1928.84 ~1~98 S 7.37 E 14.0& S 1500. 1600. 1700. 1800. 1900. 2000. 2100. -2200. 2300. 2400. 2500. 2600. 2700, 2800. 2900. · . i 45 S 18 0 W 100. ;2099.80 12.28 2028.80 0 45 S 10-'30'E ...... [00'-~ .... 21-99,78 ............. 1'3"23 .... 21-28,78 0 30 S 80 0 E 100. 2299.77 J4.21 2228.77 0 45 S 15 0 W !00. 2399,76 ]5,07 2328.76 1 30 S 21 0 E ]00, 2499.74 16.1] 2428,74 1 0 S 15 0 E 100. 25959,72 ]7.72 ~..~.8,72 14.22 S 6.05 E 15.45 S 23 3 E 0.81 ]6.37S ........ 5'~-9'~'-"~ .................. 1-?-v4't .......... S ...... 1'9-"5'~-"-E ............. 1',1'5' 17.09 S 6,64 E 18,34 S 21 13 E 0,74 ]7,9] S 7,16 E ~9.29 S 21 47 E 0,94 19.84 S 7,26 E 21,13 S 20 6 E 1.00 1,91 S 7.93 E 23.30 S 19 54 E O.~ 0 45 S 20' O--E-100. '2699,7] 18"~84 '2628.7] ' 23.37"S .......... 8'~-3'9"-~E ............. 24"e'8~ .......... S ...... 1-9-4'5"'-E ........... 0,26 0 15 S 50 0 W 100, 2799 70 19 05 9798 70 24 16 S 8,18 E ~" . · .... . .~,,51 S 18 42 E 0,70 I 30 S 7 0 W 100, 2899.69 19.07 2828.69 25.47 S 7.47 E 26,54 S 16 20 E ],33 14, WELL NO: 29 GMS"' " JOB NO: A0382~0416 TIME ' D~TE ['RUDHOE-BAY, NORTH'SLOPE~ ..... AI.ASKA lo.0~.0! ~o MAR 8~ TRUE :~EASURE[~--DRIDT ............ DR']'FT .......... COURSE-'~-VERT-ICA[:--VERTICAI.' SUBSEA-~'R"'E'"-'C~-T-A--N-'G-U--C-'-~A--R ........... C-~-b-O-S--U-R--E .................. DOObE6-7 DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/IOOFT 3000. 1 15 S ~ 0 W ]00. 2999.66 20.07 2928.66 27.86 S 7.26 E 28.79 S 14 36 E 0.27 3100. 0 45 S 18 0 E 100. ~099.65 21,12 ~028.65 29.58 S 7.49 E 30051 3300. 1 15 $ 18 0 E ]00. 3299.62 23.62 3228.62 32.93 S 8.46 E 34,00 S 14 25 E 0.26 3400. 0 45 S 23 0 E 100. 3399.60 24.96 3328.60' 34.56 S 9.07 E 35.73 S 14 42 E 0.51 3500. 0 45 S 20 0 E JO0. 3499.59 25.98 3428.59 35.78 $ 9.55 E 37.03 S 14 57 E 0 3600. 0 45 $ 4 ~0 W 100. 3599.58 26.77 3528.58 37.07 S 9.73 E 38.32 S 14 42 E 3800 0 30 $ 28 0 W 100 3799 ,8 27 O1 3728 58 38.49 S 9 20 E 39 57 S 13 27 E 0 25 3900. 2 0 S 39 0 W 100, 3899.55 26.86 3828.55 40.31 S 8.00 E 41.09 S 11 14 E 1.51 4000. 2 J5 S 28 0 W 4100, 2 45 S 38 0 W 4200, 2 .30--~S----37 ...... O--W 4300, 2 45 S 28 0 W 4400. 4500. 4600. 4700. 4800. 4900. 2 0S3530W 2 OS 5 OW 215S 4 OE 100,~.3999.48 26.61 10 :~42~9, 18 25.49' 100. 4499.03 100o 4598.96 2 15 S 8- O-E .... 1'00-, · 46'98,88 2 15 S 3 0 E 100, 4798.80 2 30 S 1 0 W 100. 4898oY2 3928,48 43,39 $ 5,96 E 4028:~:::39:::: :::, 47,05 $ ' ;'~, 58 E 7.70 4527.96 6~,00 S 5.07 W 43,80 S 7 49 E 0,48 47.18 S 4 21 E 0.66 50,-.6? ....... S 0..-54---E ...... 0,25 54.57 S I 45 W 0.48 58.19 S 3 47 W 0,81 61.51 S 4 42 W 1,05 65.20 S 4 28 W 0.42 29.98 4627,88 -'6'8~9-~--S ................. 4'~---66--W .......... 69,06 S 39.°4~ ~ 4727.80 72.81S 4.28 W 72,94- S 3 34,35 4827.72 76.95 S 4.21W 77,07 S , . , , ,5 81,31S 4,21W 81 42 S 2 58 W 0 O? 5000 2 30 S 1 0 E 100 4998 62 36 ~0 4927,62 . . 5100. 2 45 S 7 30 E 100, 5098.52 39 05 5027 ~'~ ~ · ,,,,. 85,88 S 3.87 W 85.97 S ~ 35 W 0.3? 5200, 2 45S 4 ..... O-E ........J-O0~ ......... 51-'98~,'40 41,83 5J. 27.40 90-~-6'5'"-$ ............... 3-~"39-"W ................ 90',72"S 2 9'W ......... 0o~17 ............ . 5300, 3 ]5 S 5 0 W ]00. 5298.27 5400. 3 30 S 14 0 W 100. 5398.09 5500. 3 30 S 13 0 W 100. 5497,91 5600. 3 45 $ 14 30 W 100. 5597,7] 5700, 4 0 S ~"'"30-W '100, ~ 5697~48 5800, 5 0 S 36 0 E 100, 5797,J7 5900. 7 45 S 63 0 E 100. 5896.54 44.37 5227.27 95.88 S 3,44 W 95.94 S 2 3 W 0,69 46.39 5327.09 101,68 S 4.41 W 10],78 S 2 29 W 0.59 48°09 5426.91 107.62 $ 5.83 W 107.78 S 3 6 W 0.06 49 81 ,.,)~6,7] 113.76 S 7.33 W ]14000 S 3 41 W 0 ~7 52,19 5626,'48 .... 120~-4'2'-S ........................ 8'~-39-'W .......... 120,72 S 359"W 57.71 5726,17 J27081 $ 6,24 W 127,~6 S 2 48 W 3,18 68 51 ._o,~,54 134,95 S 2,13 E lg4,97 S 0 54 E 4,00 DS 14, WELL NO; 29 GMS-' .' .JOB NO~' AO38200416 TIME .' DATE F'RUDHOE BAY, NORTH SLOPE, ALASKA 1~,0~",0] ~.~-HAR-8~~ ......... '-' TRUE !MEASURE[;-'DRIFT ....... DRIFT ..........COURSE""VERTICAIL"'"VERTICAIL ..... SUBSEA ...... R'"'E"-C'"'T'-~"--'-N"""G'-'U"-E-'-~-"R .................. C--'[ ..... O--S"-U-R'--E .................. DOGE'EG-- DEPTH ANGLE DIRECTION I.ENGTH DEPTH SECTION TVO C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY' FEET [, M D M FEET FEET FEET FEET FEET FEET D M DG/100FT 6000. 10 45 S 75 ~0 E 100, .~.~,5~ 2~ 84.36 ~,9~4,~ ~ 23 140,64 S 17,13 E 141,67 S 6 57 E ~,59 6100. 13 3'0 S 83 0 E 100, 6092.99 ~04.22 6021,99 ]44,55 S 37,75 E 149,40 S 14 ~8 E 5,16 '6200,' 1615 S'89 O'-'E ........... ]O0-Y ...... ~'I8~-~3 .............1-27,36 ...... 6I'18~'6-3 .........I4~'~-'34---S .................... 6'3~-3~---"E ............ I5~'Y'46 ........... S-23"-24'"E ....... 3,'1'5 ..... 6300, 18 0 S 87 ~0 E 100, 6285.19 153.39 6214,19 ].47,24 S 92,77 E 174,03 S 32 13 E 1,80 6400, 19 45 S 86 0 E 100, 6379,81 ]82.38 6308,81 ]49.07 S 125,07 E 194,59 S 40 0 E 1,82 6500, 20 45 S 83 0 E ].00, 6473,63 213.97 6402,63 ]52,39 S 159,51 E ~0~ ,61 S 46 19 E i ~4 6600. 23 15 S 82 0 E 100, 6566.34 248,67 6495.34 157,28 S 196,65 E 251,81 S 51 21E 8700, 26 0 S 81 O'E ..... 100-~ .....6657~-'2~ ...... 287,'54 '-6'586'~'23 ..........]'6'3'~44-'-S ........... 2'3'7388-'E ............... 2'88-~0 .......... S'-55"-'~'0'E '2,78--' 6800. 27 45 S 80 0 E 100, 6746,4~ 329,99 6675,43 170,90 S 282,44 E 330,12 S 58 49 E 1,81 6900. 27 15 S 81 30 E 100, 6835,13 373028 6764.]3 178,32 S ~28,01E ~73,35 S 61 28 E 0,85 7000. 26 45 S 81 30 E 100., ........ 6924.~3::.:..::::741o.64 68.~3,~3 185,03 S 372,91E 416,29 S 63 37 E 0,50 7200, 26 0 S 8? ~0' E 10 · ~2 o31 ~ 500-i'"82 ....... S"'66'48 E 0,22 7300, 25 0 S 83 30 E 1001~:~:~1:7193,96 537:*'1:4~i:::i: .... ~1122~'~:~ .: ~0~,56~ 04 E 542,29 S 68 4 E 7400 24 SO S 84 30 E ]00~:-ii!i!!!~284,77 ~ ~:~: :"': ::'~:::: . .~7.,,8I Z213,:~77.' 68 E 582,66 S 69 ]2 E 0.65 7500. 23 30 S 8..5 0 E 100. 7376,13 612,86 585+].8 E 621,94 S 70 12 E 1~02 7600~ 22 45 S 83 30 E 100, 7468,09 648.78 7397,09 214,59 S 624.25 E 660,11 S 71 2 E 0°95 7700. 22 0 S 84 O'E 100, 7560~06 683'73 7489'~56 218'i"74 .....S ........... 6'62~"]:'0'"'E .......... 69'7'"i29 .... S 71 43 E 0'77 7800. 21 30 S 84 0 E 100. 7653,44 717.69 7582.44 -~72,61S 698°95 E 733,54 S 72 20 E 0.~.~0 7900. 20 45 S 84 30 E 100. 7746,72 750.65 7675~72 226.22 S 7~4.81 E 768,84 S 72 53 E O~~ 8000 00 0 S 84 0 E 100. 7840,46 782 49 7769 46 229,71S 769.4~ E 803.01 S 73 23 E 0~77 8100. 1~ 0 S 85 ~0 E 100. 7934,73 8]2.90 7863.7~ 232,76 S 802,69 E 835076 S 73 50 E 1~12 8200+ 1R 0 S'85 0 E' '100-, ....... 8029-'~-56 .............. 841,70 79o8,.6 .~So,~9 $ 8~4~i--E ......... 866'~'88 .......S 7'4 15 E 1.01 8300. 18 0 S 86 0 E ]00, 8]24,66 869,68 8053,66 237,82 S 865.]] E 897,21 S 74 38 E 0,3~ 8400 18 15 S 87 30 E 100, 8219 70 897.~ . · · .6 8148 70 239,58 S 896,17 E 927,64 S 75 2 E 0.5~ 8500~ t8 15 N 89 30 E 100, 83]4.67 925°05 8243,67 240.13 S 927,48 E 958.06 S 75 29 E 0.94 8600. 18 15 N 85 0 E 100. 8409+64 951.50 8338,64 238.62 S 958.75 E 988,00 S 76 I E 1~41 8700. 19 0 N 81 30'E 100, '8504'~-40- --977.22 843~'40 .......... 2'34-~87---S ........... 990~"46-"'E ........... 1'0~7"'~'93 ..... S"76"40'E 1,35 8800+ 18 45 N 79 0 E 100. 8599+03 1002 23 8528 03 229 39 S ]0~.34 E 1047.76 S 77 21 E 0.85 8900. 18 15 N 74 0 E 100. 8693.86 1025039 8622.86 221.99 S ].053019 E ]076,33 S 78 6 E 1.66 DS 14, WELL NO; 29 GMS' " ~'RUDHOE"-'BAY,"' NORTH SLOPE, AI.-ASKA JOB NO~ A0382~04]~ TRUE ~E-ASURE'D""DRI'FT .......... DRI'FT .........COURSE"--'VERT'ICAI.'-VERTICAI;- SUBSEA ........... R--'-E---C--~--A--N'--G-'-IJ-L--A-'---R .............. C'--L-'O--S--U-'R'--E DEPTH ANGLE DIRECTION I.ENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY. FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/IOOFT ' 9000, 18 30 N 73 0 E JO0, 8788,76 1047,25 8717,76 213,04 S 1083,41 E 1104,16 S 78 53 E 0,40 9100· 18 0 N 72 0 E 100 888~ 73 1068 .7 88]2 73 203,62 S 1113,28 E 1].31 75 S 79 38 E 0,59 ...... 9200~ ........ 1'7"-45-N'-~2'--~0'-~ ....... 1'00'~ ....... 8978~90 1089~36 8907~90 ............. 1-'94'"~-26-~ ..... 1'~A'2'~5~ .....E ........ t']'58~"9'1 ....... S'"'80-'2'1 ...... E 9300° 17 15 N 73 0 E ]00· 9074,27 1109·93 9003~27 185,34 S 1171·23 E 1185·80 S 81 9400° 16 0 N 72 0 E 100, 9170·09 J129·40 9099·09 176,74 S JJ.~8,52 E 12~1·48 S 81 ~7 E 1o28 9500· 15 30 N 70 0 E 100· 9266·33 1147o35 9195o33 167o90 S 1224o18 E 1.235,64 ?ROJECT'ED""TO 'TD 9560· 15 30 N 70 0 E 60· 9324,15 1157,74 9253·15 162,42 S 1239,25 E 1249,84 S 82 32 E 0,00 FINAl. CLOSURE - DIRECTION .......................... 84 FEET .............. ARCO ALAS~{A, INC. ° .~ - IlS 14" 'WE'LL NO~ 2S~'~'GMS JOB'-NO F'RUDHOE BAY, NORTH SLOPE, ALASEA GMS, 0-~5O0 MD, ~URVEYOR, B. JAHN, DATE RUN; ........... GTRO l'--3'~'~-K ~'~-ME R~-: 1572'~--~ 4---DEG '"--A-/U; ..... 258 FORESIGHT~ N 7 1~ W 14, WELL NO~ 29 GMS" ' :'RUDHOE'-BAY* NORTH"SLOPE, ...... ALASKA TTME ,' D~TE NAME DEPTH DEF'TH DIFF DEPTH C 0 0 R D I N A T E S DISTANCE DIRECTION THICKNESS FEET FEET FEET FEET FEET FEET D M TOF' OF SADLEROCHIT 8993.00 8782.2.2 220.9 871~.22 213.66 S 1081.30 E 1102.20 S 78 49 E i OIL/WATER CONTACT 9280.00 9055.20 224.8 8984.20 ~87o13 S 1165.4~ E 1180.41 S 80 53 E TD 9560.00 9324.15 235.8 9253.15 162.42 S 1239.25 E 1249.84 S 82 32 E ~ ...... =--.~-~--r F-,. ~ ..... ,--r--t-w .... , ~ ....... ~-"-> .... , ..... ~-"~W-~"- '~'"~-?-i ........ P-r-f"- .'~ ~: ............... ~ ~E~.L-:-~"-"~-'-~-*-L4t, ~ ~ ........ ~"-~ ~ ,z-'+"-~-i .-~--~..~, ~ i ''-~ ...... ~' :~ ..... '. ~ : .;" . , , : ' ' ~ ~ 4 ' J ~ .~ ~ ~ , ~ .... . ..... ......... ;---~---~ .... ~.-.~.4-, ........ ~__i._p_; ...... +-4-4-..4- -~----~--.-i---i ..... ~----;.--~----;-- - i ....... i-...i ........ ~-. ..... I-"-?-x .....----.r'~T-'; ......-.----=T'TT .... Fff"'T-~ ..... V-r"T-';_,. ........ ~;-i'-q ........ i'-T"~'-T ...... ~-~ .-.~-- 'f ......... * "+-"~-?'?-'i ........ r"~ ..... ~-'1"H-1 .... -??-T"q .......... t"'?-'* ......... I- 't-''-e''i ....... t .......... ....................... t ..... m~-wL ..... ~--t+ .... +-t.4--~- -~-¢-~ ..... ¢~4-~ -.4-..~.---~ ........ ,..-; ..... .......... ~-,_~-.~ .... ~l ,-.~-.~-~..,--~,.-~-~-.~--= -.~-.~,--¥ .......... ,--.~-- '--'l''~ i - . ~ t ~ '~-~-= -:--~ ~ t - t ~ ~ ; ............... t * ] ~ i j ...... ;-~..,~-. i.-- t - i ~ ~"~'--} ..... ~ ....... 4.--! ] ~ ~'-- '-~ ...... 4-~I [ ~ Lira--* ~T '- ~ ........ ~--~ ' i ! ~i ,-~-'~'~ --¢'--~ ...... ............. ;....,..-~ ~ ........ ~--4-..-~ ..... t...-~.-.-~...4 ................. ~..-~ ....... '. ......... ~ ....... ; ...... ~ -4. ;..4. ~.--~-. ' ~ ; : ' t I i '!It I ~--'' '''' ' ' ~ ....' ~1~ ~--' ' ' ' ':-'-~ ........ ~ ........... ~""~ ...... ?-~-I ........ T?'~'"~ ..... ~-f-r-?-ff-.4 T-r=.+--'i.-~ ..... ~....f_L_ ............ ;..-.-;.-i .... ~-~-~- .~-.~-~ ..... ~.~. M-4-.G~-;-.~+~.- ~---~ ....... ~ .... .............. ~-.-~ .~-~ ~-,~ ...~-, ....... ~- l~....~-+ ..~ ......... ~+..- l.-.~..4 ............. ~-.. ~ ....... I ...................... ~ ............. ~ ..... ,..,.-$...,..-L..L ~"-+"'t .......... ~'"'~ .......... l-..~ ....... ~ ...... ......... ~_,, =~ :..__~' ~_~ ~ _L.~_LL.. , , i_~_~_., , , , _L: .L.L~. , . ~--'..-.~ ............. ~ . L, ............. ........... ~ ...... : '-~ -L~4- ~.~ -~-~M-~--LG ...... ~.~ i : ..... ;.~ .', i ~ '. L i ~ { ~ i i ~ ! .. ~l~l! ~ --~-.~"; :_~ ..... ;_._; ....... L_:~_~_:._.~L __;_~_~ ....... ~_. j__N_z..S.~i. ,.,,~-~ ' ~ .................... t .......................................................................t ) ............. ~. ~ .....................................................~2 ;"~] ............. : ....................... , ...... j .... i ....................................................... ~ .... ~ .... : ............. ~ ............. ~ ............ _ ........ ~ ..................... ,-,. ............. =~ -~ ..... : ......... ~ ............ J'.,-~ --~ .... , , ,, · , ' : i : ' : .... , "j ......... ~ ...... ~ .... !'-;--~'": ................ U'-~'--'~ ..... := .................... ~ .......... J. '-- i;-, Li.i--;TLT:22[iii/2E;2CiiZiiiS'2~E~2Zi_'i]i'iZ_.~',., - ·.', ....... = ~-~...t-':': ................. '.--:-----.:--~-~.__ ...... ~ ...... ~ . - - I ~6t t ~ ~ .................. --; .... : ...... ._ ...... ~: ........................... I I ~ ............................... ~ ........................................ T .... . . ~.. ~_~ ~. ..... ;...i ........ +_L~) .......... ~.-~4.-;-~--¥-~--L~.-~ .... t :' ..... ~ ~ ; ...... '. ~ ~_~._.., .~._~.~ .... ~.~ l.-~..~-~-..~-i-f-..i.~-~ ..... ,... ; ~ : . t. -. J. ,--; .- : ;-~ t-; ;-+i ...... :--.~.--~4.-1..?-~-.+--;;;.'-;~;:/-U}- I .... t:'; :' :t ~-'~t'--~'¢ f"~ .... x'--t _ s~ .0- E ' 'I Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator, Well Name and Number Reports and Materials to be received by: ~--'1~ Date Required Date Received Remarks · Ccmpletion Report Yes Wel 1. History ' Yes "~ -- ~0 --g ~2. ~.. ~":'~ , , Core Chips //~ ~_~ Core Desjcription /f/~ /~' ~,~.. _ .,Registered. Survey Plat ~ ~-~. ~ //' ~ '~ ~} , 0 ~/ . · Inclination Survey Directional Survey I ~ ~ 4 Drill Stm Test Re. ms ~ ~~ .... . , , , Pr~u~ion T~t Re.rte ~ ~~ Digitiz~ ~ta , . ~ ~ Telephone 907 277 5637 May 17, 1982 Reference: ARCO CASED HOLE FINAL LOGS D S.2-214~/5/1/82 D!S.12-1 ,4/29/82 D S.13-18~/~ 4/30/82 D.S.14-9B~"3/8/82 D.S.14-9B~ 4/21/82 D.S.14-28~~ 22/82 3/12/82 S.15-3 3/23/82 D.S.15-4~' 4/22/82 ACBL/VDL/GR Run 1 5" PLS Run 1 5" ACBL/VDL/GR Run 1 5" CoA.T. Log Run 1 5" Gamma Ray Neutron Run 1 5" CB~/VDL Run 1 5" C.A.T. Log Run 1 5" CBL/VD Run 1 5" ACBL/VDL/GR Run 1 5" D.S 15-14~- 12/25/81 Collar for Gyro Correlation Run 1 2"/5" D.S~15-14 12/25/81 CNL/GR Run 1 2"/5" D.S.16-14// 3/18/82 Perf Record W/CCL Run 1 5"/2" D.S.17-10j' 4/7/82 PLS Run 1 5" D.S.14=30 .... 5/8/82 Collar Log Run 1 5" D.S.14-5 ¢~' 5/8&9/82 Collar LOg for Tattle Tale thru Tubing Vented Bridge Plug Run 1 ~~' 5/8/82 Collar & Perf Log Run 2 5" D.S.lv8~ 4/24/82 Diff Temp Log Run 1 5" sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal f! 170 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON 63IEVRON .. EX~O~ D&M GEOLOGY 0il & Gas Cons. Commission ARCO Alaska, Inc. Post Office E' ~60 Anchorage, /-,. ~/ka 99510 Telephone 907 277 5637 April 28, 1982 Reference: ARCO MAGNETIC TAPES & LISTINGS ]~.s.2-19 ~'" 3/24/82 D, $,7-12 ~'~1 / 11/81 D' Si 13-20~7/82 .D.S 15-3 /82 D.S 1-17 ~ 2/26/82 D.S.i-10 z ~/18/80 D.S.14-28~ 3/28/82 D. S. 7-14~/82 D.S 12-1~ 2/23/82 D.S 7-11' 3/31/82 Tape# ECC 1232 Open Hole Tape# ECC 884 DDNLL Tape# ECC 1255 CN Tape# ECC 878 DDNLL Tape# ECC 1225 CN Tape# ECC 1266 CN Tape# ECC 876 DDNLL Tape# ECC'733 DDNLL Tape# ECC 1262 CN Tape# ECC 1265 CN Tape# ECC 1231 CN Tape# ECC 1264 CN Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 131 DISTRIBUTION NORTH GEOLOGY ~ R&D MOBIL DRILLING GETTY D&M GEOLOGY MARATHON CHEVRON ARCO Alaska, Inc, is a Su~,~;~ary of A',lanllcR~chhelaCompan¥ 0ii & Gas Cons. Anchorage ARCO Alaska, Inc. Post Office Bo×_350 Anchorage. ~ )a 9S510 Teleohone 907 z77 5637 March 30, 1982 Reference: ARCO DIRECTIONAL SURVEY DATA D.S.15-3 3/9/82 to 3/21/82 ~¢S';~4-29,73/13/82 D.S.13-6 3/2/82 D.S.11-7 2/27/82 D.S.16-1 3/6/82 Single-Sho t Gyro scopic Gyro scopic Gyroscopic Gyroscopic Job No. 0382-021 Job No. A0382G0416 Multi-Shot Job No. A0382G0404 " Job No. A0382G0407 " Job No. A0382G0408 " Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 75 DISTRIBUTION NORTH.GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Al,~s~a. i:3c. is a $'ac',,:J,-~r¥ of AHantlcR~chhe~CCo;*npan¥ ARCO Alaska, Inc. Post Office B Anchorage, A",.~..Ra 99510 Telephono 907 277 5637 March 29, 1982 Reference: ARCO DIRECTIONAL SURVEY DATA' D.S.i4-i3 3/3/82- D.S.i3-9 3/i/82 ~-"~,D.;S',i'4-29~' 2/27/82 Gyroscopic Multi-Shot Gyroscopic Multi-Shot Single-Shot Jon No. AO382G0405 Job No. AO382G0406 Job No. AO282D0268 Please sign and return the attached copy. as receipt of data. Mary F. Kellis North Engineering Transmittal #70 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA ARCO AlaSka, inc. Post Office Box,~360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 22, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive .Anchorage, AK 99501 SUBJECT' State Reports Dear Sir' Enclosed are Well Completion Reports for the following drill sites' 13-20 15-1 ' 1A-14 lA-15 WS 23 Also enclosed are monthly reports for February on these drill sites' 11-7 13-23A 14-29 14-30 15-2 Eileen No. 1 Oliktok Pt. No. Copies of the DS 13-20 gyroscopic survey were sent to you under separate cover. Si nc ere 1 y,/I P. A. Van Dusen District Drilling Engineer PAY' JG/hrl Enclosures GRU2/B14 ARCO Alaska. Inc ~s m .Subs~ci~a,¥ of ~,~h~nlicRicllfJehJCo,npany DS 14-29 Drilling Hi story NU 20" Hydril & diverter. Spudded well @ 2230 hrs, 02/10/82. Drld 17-1/2" hole to 2630' Ran 62 jts 13-3/8" 72#/ft, L-80, BTC casing w/shoe @ 2600' Cmtd 13-3/8" csg w/2000 sx AS III & 400 sx AS I. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 8906'. Run DIL/SP/GR from 8016' Ran 220 its 9-5/8" 47#/ft, L-80 & S00-95, BTC csg w/shoe @ 8857'. Cmtd 9-5/8" csg w/500 sx Class G cmt. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to~T2'~"5 Ppg E'M~- ok. Drld 8-1/2" hole to 9560'. Ran DIL/SP/BHCS/GR & FDC/CNL/GR/Cal. Arctic packed 9-5/8" x 13-3/8" annulus as of 02/28/82. JG:hrl 03/18/82 GRU2/A4 ~ STATE OF ALASKA :', ' '~' ' ALASKA )LAND GAS CONSERVATION C~ ~iMISSION , MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~ Workover Operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 81-168 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 5o-029-20680 , 4. Location of Well at surface 2225' FNL, 847' FEL, Sec. 9, TiON, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 71' RKBI ADL 28312 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 14-29 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay Oil Pool For the Month of February ,19.82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2230 hrs, 02/10/82. Ran & cemented 13-3/8" casing w/shoe @ 2600'. Ran & cemented 9-5/8" casing w/shoe @ 8857'. Drilled 8-1/2" hole to 9560' as of 02/28/82. (See Drilling Hi story) 13. Casing or liner run and quantities of cement, results of pressur9 tests 20" Conductor, 91.5#/ft, H-40 to 76'. Cmt w/400 sx Permafrost II. 13-3/8", 72#, L-80, BTC casing to 2600'. Cmt w/2000 sx AS III & 400 sx AS I. 9-5/8", 47#, L-80 & S00-95, BTC casing to 8857'. Cmt w/500 sx Class G cmt. (See Drilling Hi story) 14. Coring resume and brief description N/A. 15. Logs run and depth where run Ran DIL/SP/GR from 8016'. D IL/SP/BHCS/GR FDC/CNL/GR/Cal 16. DST data, perforating data, shows of H2S, miscellaneous data N/A. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,ONED ~ ~ T,TLE Area Drilling Engineer DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 1§th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 &~{~t 1~1~ ARCO Alaska, Inc. Post Office ) 350 Anchorage, A,'aska 99510 Telephone 907 277 5637 March 24, 1982 Reference: ARCO OPEN HOLE FINAL LOGS D.S.14-29 2/29/82 D.S.14-29 2/29/82 D.S.14-29 2/28/82 D.S.14-29 Comp Densi/Neutron Log Comp Densilog BHC Acoustilog Run 1 2" & 5" Run i 2"& 5" Run 1 2" & 5" 2/23/82 & 2/28/82 DIYL D. S. 14-29 2/28/82 Pro'lo§ _5" Run l&2 2" & 5" Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 60 DISTRIBUTION NORTH GEOLOGY EXXON . , '-' R&D MOBIL PHILLIPS D&M SOHIO GEOLOGY ~THON STATE OF A~S~ CHE~ON Oil & Gas Cons. ARCO Alaska, Inc. Post Office ~'~-- 360 Anchorage. ~-,,~Ska 99510 Telephone 907 277 5637 March 24, 1982 Reference: ARCO CASED HOLE FINAL LOGS 2/29/82 D.S.11-7 2/26/82 D.S.12-14 2/23/82 D.S.11-7 2/.19/82 D.S.13-20 2/17/82 D.S.15-1 2/17/82 CNL Run 1 2"-& 5" CNL Run i 5"' CNL Run 1 2"/5" ACBL/VDL/GR Run 1 5" ' CNL Run 1 2"/5" CNL Run 1 2"/5" ~P~ease sign and return the attached copy as receipt of data. Mary F. Kel~is North Enginaer-~ng . ~ · Transmittal # 59 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA ARCO Ata$~.~l. ,nc. is a ';~JG.~u~ry ct A;13nt~cRichfle!,~.C.o;'npan¥ N~sks 0it & Gas Cons. Commission Anchorage ALASKA L AND GAS CONSERVATION C~. MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] 1. OTHERY~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-168 3. Address 8. APl Numbeb29_20680 P.O. Box 360, Anchorage, Alaska 99510 50- 4. Location of Well 9. Unit or Lease Name Prudhoe Bay Unit 2224'SNL, 847' WEL, Sec. 9 TION, R 14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 71 RKB I 6' Lease Designati~nDaL~d ~§r~aJ~ ~o. 12. 10. Well Number 14-29 11. Field and Pool Prudhoe Bay Unit Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair'Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other )~ Pulling Tubing [] · (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Several casing 'inspection logs will be required on subject well. The logs will require upwards of i rig day and a full 9-5/8" casing bore for well entry. Considering the anticipated logging time and the bore requirements ARCO Alaska, INC. proposes the following' Subsequent to running and cleaning out 7" liner the well will be displaced to NaC1 brine. Lay down drill pipe leaving a +1000' diesel cap on the well. Land tbg hanger and back pressure valve. ND BO~E and NU 13-5/8" single gate with blinds, boss flange and master valve to insure logging 'is done safely. The rig will then be released to DS 14-28. A wellhead schematic is attached for your informat'ion. NOTE' This procedure has been discussed with Blair Wondzell,AOGC, by Mark 4ajor, Area Drilling Engineer, on 3/1/82. The master valve will be removed for ogging operations. RECEIVED MAR 0 1 1982 Alaska Oil & Gas Cons. Commission 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Anch0rage Signed - Title Area Drilling EngineerDate 3///S~ The space below for Commission use Conditions of Approval, if any: Approved by Form 10-403 Returned By Order of COMMISSION[R the Commission Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate RECEIVED MAR 0,'l 1982 Alaska Oil & GasCons. Commission Anchorage .. ALASKA OIL AND GAS CONSERVATION COMMISSION Chat Chat~~ Chairman ~/~-~ THRU: Lonnie C. Smith Commissioner Ben LeNorman Petroleum Inspector February 17, 1982 Witness BOPE Test on ARCO's DS 14-29 Sec. 9, T10N, R14E, UM Prudhoe Say~ Un.it wednes~day, F~br~a~ !0 - i departed my home at 7:15 a.m. for a '7:'45 a.m, showuP and 8..45 a.m. departure via Alaska Airlines flight #55 for Deadhorse arriving at 10:35 a.m. Weather: -6°F, light snow, light wind. ThursdaY,_ February 1.~ - BOPE tests on ARCO's DS 13-23A began at 10:00 p.m.... Friday,_F~br~ua~ !_2 - . . . and were completed at 2:00 a.m., the subject of a separate report. Saturday, February 13 - BOPE tests on ARCO's DS 14-29 began at '~"~3~ ~m'"'""~nd Wer~completed at 11:45 a.m. BOPE inspection report is attached' BOPE tests on Sohio's were A-20 completed, the subject of a separate report. S~nday,_~ February 14 - i departed Deadhorse via Alaska Airlines flight #66 at 11,10 a.m. arriving in Anchorage at 12:50 p.m. and at my home at 1:20 p.m. In summary, I witnessed a successful BOPE test on ARCO's DS 14-29. ~ATE OF ALASKA ALASKA OIL & AS CONSERVATION CQMMISSION B .O.P.E. Inspection Report ~nspector ! Representative Dperator. · · Jell .. D $ /~'- 2~ ~cation: Sec ~ T/D~R/~Z°'~I~//;] ?ril ling ~n~a~or ~~ ~ Rig location, General"'' {ell Sign ~eneral Housekee~, ing ~.eserve pit' ~ig 3OPE Stack %nnular Preventer Pipe Rams ~lind Rams ~oke Line Valves__ -. Test Pressure ACCL%~UIATOR SYSTEM Ful 1 Charge Pres sure ~ ~(p · psig Pressure After Closure /'.~ 4-- psig Pump incr. clos. pres. 200 psig. Full Charge Pressure Attained: N2 ~/~D ~_ -%~o o -~/O~ j%/J~) psig Controls: Master Remote 6D/~ Blinds switch cover~=~_C Kelly and Floo'r Safety Valves i.C.R. Valve <ill Line Valves Upper Kelly Lo~r Kelly. Ball Type. Inside BOP. Test Pressure Test Pressure-- Test Pressure Test Pressure .~heck Valve ?est Results: Failures ~ ' Choke Manifold No, Valves,__ No. flanges_ Adj ustab le Chokes Hydrauically operated choke ,., Test Time'-T/,%J hrs. Test Pressure__~-~dP~.,-~ ~,epair or Replacement. of failed eqUipment to .be made within,, days and lnspector/Ccmmission office notified. {emarks: min/J- sec. min,~o sec. Distribution prig. - AO&GEC uc -Operator rc - Supervisor Inspector ARCO Alaska, Inc. Post Office Boy ~0 Anchorage, AI~~99510 Telephone 907 277 5637 January 25, 1982 Mr. Lonnie Smith State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- Sundry Notices Dear Sir: Enclosed pleaSe find the Sundry Notice of Intent to plug and abandon the following wells: Put River #1, BP 19-10-15, BP 31-10-16, and BP 18-~10-15/. Also included are ~Subsequent Sundry Notic~ done o~..15-10 and a change of the target location f~S 14-2.9. ~ A mu~ti.-'sh'Ot, survey for West Sak #18 is included as requested by Elaine 'Johnson. Sincerely, Mark A. Major Area Drilling Engineer Enclosures MAM/C~' ss RECEIVED JAN? 5 1.82 Alaska 0il & Gas Cons. Commissior~ Anchorage ARCO Alaska, Inc. is a Subs,diary o! AtlenticRichfioldCompany ~)L STATE OF ALASKA ALASKA AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-168 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 50-029-20680 4. Location of Well 2224' SNL 847' WEL Sec 9 T10N 5. Elevation in feet (indicate KB, DF, etc.) 71' RKB 12. R14E, UM 6. Lease Designation and Serial No. ADL 28312 9. Unit or Lease Name ' Prudhoe Bay Unit 10. Well Number 14-29 11. Fieldand Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. has changed the target' location for the drilling on subject well. The target, initially shown to be: 2250 NSL 44 GWL Sec 10 T10N R14E, UM has been changed to: 2550 NSL 44 EWL Sec 10 T10N R14E, UM Any question regarding this change should be directed to Mr. John Rall, 263-4963. 14. I hereb~ certify that the ¢ore.q~ng is true'rind correct t.o S igne~~~,~. The space below for Commission use the best of my knowledge. Title Selrl_ior Drilling Engineer Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate November 10, 1981 Mr. Po Ao VanDusen DiStriCt Drilling Engineer ARCO Alaska, Inc. P. O, Box 360 Anchorage, Alaska 99510 Re~ Prudhoe Bay Unit DS 14-29 'ARCO Alaska, Inc. Permit NO. 81-168 Sur. Loco~ apx. 2224~SNL, 847~WEL, Sec Hottomhole Loc. s 2446.~NSL, 184tEWL, Sec 10, T10N, R14E, OM. Des r Mr o VanDusen ~ Enclosed-is the approved application for permit to drill the above referenced well. We!l samples and a mud log are not required. A continuous .directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. ,' Many rivers in Alaska and their drainage systems have been classified as important for the spawning or ,migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Admidistrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinatorts office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen prUdhoe Bay Onit DS 14-29 -2- November 10, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the Commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, ~. ~amil ton Alas~ Oil & ~as co~er~ xo Enclosure cc.= Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. ARCO Alaska, Inc. ~ Post Office B,..]360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 3, 1981 Mr. Hoyl e Hami 1 ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 14-29 Dear Sir- Enclosed please find: 1. The application for permit to Drill DS 14-29. 2. The $100.00 application fee. 3. The horizontal/vertical wellbore crossections. 4. The critical data points. 5. Surface and Sub-surface proximity map. Please note that an as-built drawing of the conductor location has not been included. As soon as this information becomes available it will be sent to you. Sincerely, P. A. VanDusen District Drilling Engineer PAV: 1 tc Attachments ARCO Alaska, Inc, is a subsidiary of AtlanticRichfieldCompany RECEIVEI) NOV 0 6 198t Naska Oil & Gas Cons. Commission knch0rag~ j,~_ STATE OF ALASKA ALASKA AND GAS CONSERVATION CO,'i,-)vIISSION PERMIT TO DRILL 20 AAC 25.005 (AF la. Type of work. DRILL ~] REDRILL [] DEEPEN [] 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface )rox) 2224'SNL, 847'WEL, Sec. 9, TION, R14E, UM At top of proposed producing interval 2250'NSL, 44'EWL, Sec. IO, TION, R14E, UM At total depth 2446'NSL, 184'EWL, Sec. lO, TION, R14E, UM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. 71 'RKB I ADL 28312 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number Fed Ins Co. 8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line Appx 6 miles NW of Deadt~se 1320 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 9689'MD 9490'TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures L KICK OFF POINT 5500 feet. MAXIMUM HOLE ANGLE 1 9 oI (see 20 AAC 25.035 (c) (2) 11. Field and pool Prudhoe '.Bay F i el d Prudhoe Bay 0il e Pool Amount $500,000 15. Distance to nearest drilling or.completed well 2640 feet 18. Approximate spud date 2/10/82 +- ~800 psig@, . Surface +_ 4600 psig@ 9490 ft. TD (TVD) 21' SIZE Hole 32" 120" 17~" / 13-3/8 12¼"I 9-5/8 7" Casing Weight Grade 94# 72# 47# 29# L-80 Proposed Casing, Liner and Cementing Program CASING AND LINER t Coupling I Length H-40 IWeldedI N-80I Butt ] .-80 & ] Butt 8860! S00-95]] Butt 11.29' SETTING DEPTH MD TOP TVD 110' 0 ~ 0 2650.'.~ 0 ~ 0 I 0 ' 0 I I -+8560' :~8400' QUANTITY OF CEMENT MD BOTTOM TVD (include stage data) 110'I. 110' IPoleset +-2650'I -+2650' 128005x A.S. I I I ,400sxAi ~8860' I -+8~07 ' icl ass:_G:,SbOsx l s t I 1300sx 2n~'"~tag~ - -+9689 ~-+.9A9~0 13OOsx Class G ' 22. Describe proposed program: -- ARCO Alaska, Inc. proposes to directionally drill this well to 9689'MD (9490'TVD) to pro- duce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8".5000 ps RSRRA BOP stack will be used. The BOP equipment will be pressure tested each week and opel ationally, tested each trip. A string of 5½" 17# L-80 tubing, packer and necessary provisi( -for subsurface safety equipment will be run. A non-freezing fluid will be left in all un- cemented annuli within the permafrost interval. Selected intervals within the Sadlerochit to be perforated and reported on a subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on all wireline work. The packer will be set abm the Sadlerochit. The downhole safety'valve will be tested and installed upon conclusion ol job. The 13-5/8" 5000 psi RSRRA BOP stack will be tested to 5000'psi. A surface diverter system will be installed and operationally tested prior to spud at least daily thereafter. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge .SIGNED. ,.~~,, '~~,~4~ TITLE Dist. Drilling Engineer DATE The 'space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log required []YES eNO F-lYES E~O Permit number ~r/_[ ~ ~ Approval date 1~_!!0/81 APPROVED BY._~ Directional Survey required I APl number [~YES []NO SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE NO--Z: 10:1981 by order of the Commission Form 10401 Submit in triplicate Rev. 7-1-80 22? i ~ 83" -"?~ ', ~. L,"'*"m .tx'. ~,, ,~ r- ,' T[EP TH_ ..... 'AT ...................... 55'00-'~ O0 ...... 0 ANGLE~.:'" ::.*,-a ::,t._,, ~-,~., ~...,.'r .:,H,::. D AT 5243,1S 1.23 r, ~F'F:T '~ l ;~ '-"-' 0 ................ :- ..... ¢~T ~bT! · O0 i0,24 .. ......... uw ¢~Ou.O0 18,9~.. 6256.86 18,72 9034.79 <:'-:;i~P, iiIONAL. F'Oi¢'4T .AT ,:}8~I tOO :':~r,[:i-T'~NAL, .,_, ,..: F'OINT, _ , A'T 8046', O0 ADDITIONAL POINT AT 87&7,00 · A~r~ T. T l ON. A L" -PO iNT ¥*.,'T ;h:~iTIE~NAL. POIHT AT , ~-,,-,,r T IONAL F'C.~. ,qT A T "t ~.. ,l. J. ...,_, ...... ~. i iONA POINT "~'"' ~' 'r 18 N A' F' 81 N .-r ., --,- 18 1.8 ?2:: ' 7544~25 ;-'.c 81.,~.. 6F ¢2 8872. oo ~.'"'1 ~'~'~ "'-' 8771.36 ToP 92 9034.79 ~~ _~. TO ~ i iiii I I II I i i ,,~ , I " ~'--~, ~-- 9'10 , %1 WELL- Y 5,937,892.53 \ ~ \ \[ ' LAT 70 14 '09.423" \ ~~\ LONG = 148°34'52.674'' ~\\ WELL · Y 5,938,009.29 \ .. \ ~\~ X 675;677.83 \ ~ ®\ :--i\ LAT 70°14'10.578'' \ ~4®\ . ~\ w~, ~ I \\1 I ~' I. AT 'LONG 148°34'54.123'' WELL 30 X ~ 675,622. 54 ,_~E.C.,T~ON 9,T~Ot,,I, KI4~U.M. ~'~ · ~:~ LAT = 70°14'12.887'' NOT TO LONG = 148°34'54.848" --_~ OF AL.,, ~I~_~T~ _e .eeete ce_TM i?lI · ._ ~.,,<~"..-" I-..~,S¥ ,~ I HEREBY CERTIFY THAT ! AM .;~!49th Jpllil[ ~* ~. PROPERLY REGISTERED AND ~,~.~,.,..,.,,~..,~,_...?.,~:,~ LICENSED TO PRACTICE LAND ~.~..~ su,vsv,.e ,. ms s~^~s o~~ ~,_~/ sAiY A. cms~Aw : ~ ALASKA AND THAT THIS PLAT -~:~:.;._ ......, ...'.~ffREPRESE.TS ^N A.~BU,LT SURVEY '~,~'.. .,' ~.~ MADE BY M~ AND THAT ALL -'~~ ~ DIMENSIONS AND OTHER DETAILS , '~%~;~,'~ .... · ARE COI~.RECT- AS OF: IO/Xe/.$! I I I II AtlanticRichfieldCompany <l~ DATE:' DRAWING NORTH AMERICAN PRODUCING DIVISION ALASKA DISTRICT-- PRUDHOE BAY .... , ::RRCO R[LRSKRJ :INC~.' .. "DS 14, I, jELL NO S'.' 30, :L:)9, PROPOSED '4123 .............. :".: :':. :"/.::I:'.-:":-.::[:: :::::::::::::::::::::::::::: :::..::i.::::.'i'"::::".:: :1' :": ::, :::.;: .,':. t ............. ..:.,. - :,..:.-.:-. .... ' ', 500 - I 4510 I 458~ L_ 12. 13. 14. 15. 16. Check anC fill accsmulator reservoir to proper level with nycr.'uli~. fluid. Assure that accumulator pressure is 3COO psi witn 1503 pst d¢:.:nscre~m of the regulator. Observe time, then close all units simultan- eously and record the time ant pressure re- maining after all units are closed with charging pump off. Record on IADC re~ort. (The acceptable lo~er limit is 45 seconds closing :ime and 1200 psi remaining pressure.) 13-5/8" ~CP Stack Test Fill BOP stack and manifold with a non- freezing liquid. Check that all hold down screws are fully re- tracted. Predetermine depth plug will seat & mar~ running joint. Run te.~ plug on drill pipe and seat in wellhead. Run in lock down screws in head. · Close annular preventer and chokes and bypass valves on manifold. In each of the following tests, first hold ~- - '- 250 psi low pressure test for a minimum of 3 minutes, then test at the high pressure. Increasep~essure to 3000 psi aAd hold for a min~:,~m-.of 3~minutes. Blee~ pressure to zero. Open annular preventer and close top set of pipe · rams. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. ClOse valves directly upstream of chokes & open chokes. Increase press, to 5000 psi & hold for at least 3 min. Bleed pressure to zero. Open top set of pipe rams then close bottom set of-pipe rams. Increase press, to 5000 psi below the bottom set of pipe rams & hold for at least 3 minutes· Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. · -.. -.. .- Bleed pressure to zero. Open'bottom set Of pipe rams. Back off running joint and pull out Of hole. Close blind-rams and test to 5000 psi for at least 3 minutes. · Bleed pressure off all equipment. Open blind rams. Make sure manifold & lines are full of non-freezing liquid and all valves are set in drilling position. Test standpipe valves to 5000 psi. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. · Check operation of De Gasser. Record test inform..ation on Blowout preventer test form. Sign and send to Drilling Super. · -. Perform complete BOPE test onc~ 'w~ek ~"'_~ functional operate BOPE daily. . . .. . · ~ RECEIVEI) NOV 0 6 1981, AI~sK~ Oil & Gas Cons. Comll~is$io~. Anchorag~ k SURF/\C~ DIVERTER SYSTEM . o . Note: Valves on ~Jverter lines open aucemaCically when the annular preventer iS closeO. ' NOV o 6 ; 1. 20" BRAOEHHEAD SPOl~a~ 0ii & GaS CONS. 2. 20" 2000 PSI DRILLIHG 3. 20" 2000 PSI Ati~IULAI3 PREVEIITER 4. 10" BUTTERFLY VALVES 5. RIG DRILLI:iG RISER 6. [0" LI::ES TO SU.MP CHECK LIST 'FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc thru 8) (4) Casg ~ //~-a~} thru 20) <:> OeE ~21 thru '24) (6) Add: le e 3. 4. 5. 6. 7. 8o. 10. 11. '12. 13. 14. 15. 16. 17. 18. 19, 20. 21. 22. 23. 24. 25. Is the permit fee attach_ed ........... ~ .......... Is well to be located in a ~~ ~i ...... i.i.ii.iiii . Is well located proper distance from property line .................. Is well located proper distance from other wells .................... YES NO Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is well bore plat included ............... Is operator the only affected party ................................. Can permit be approved before ten-day wait .......................... Does operator have a bond in force . ~ ................................ Is a conservation order,needed ..................... Is administrative approval needed Is conductor string provided Is enough cement used to circulate on conductor and surface ......... W±ll cement tie in surface and intermediate or production ............ strings .... i W±il cement cover all known productive horizons Will surface casing protect fresh water zones ................... Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed .............. Is a diverter system requ±red Are necessary diagrams of. di'rerter ~1~'1~(~ ;;u~';~l;I~[ Does BO?E ha-re suffic±ent pressure rating - Test to Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. REMARKS Additional requirements .............................................__ Additional Remarks: Geology: Engineering :. HWK ../'~ LCS' .'- mW ~ WVL~ JKT~~~RAD ~ rev: 03/10/81 'INITIAL 'GEO. UNIT { ON/OFF POOL CLASS STATUS AREA NO. :{ SHORE RECEIVED NOV 0 6 1 Oil & {Sas Cons. Conunis,sio. A~chorag~ 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 APPENDIX' .. No special'effort has been made to chronologically organize this category of information. .o PROGRAM: L!SC.~N RTVISION: 5.1 Start of execution: Mort 27 FEB 8:? 9:~7m '**** REEL HEAg~ER LIS ATLAS Ol FORMAT TAP~' 'LIS CUSTOMER mART ~*** TAPE HEADER LIS 8 '9 / 7 2 /0 2 3731 01 'THREE P,ASS CN/MS ' PILE ~ 1 PASS CN WN FN CJUN STAT : DS : nRUDHOE : N,ORT~ SL'OP~.. ~ : AL~SK~ i NC ~ORMAT mECORD (TYD=~, 64) ON- D~PT~ PER =R$'4E T,~p= "'~PTH UNiT : mT t2 CURVES : 1 !J U i T ~YTES T T ~:: ~,i ~' :~ i L E~, TEN 68 I LE S ~ £~ 68 I F- / M M CCL1 6,$ 1 VOLT CCL 6.?, I VOLT SSN 68 1 CTS C S S N ~ 8 1 C T S L S N 68 1 C T S CL SN 68 I CT S C N 6 S ! P C T CNC 6~ I PCT * DATA RECORD (TYPE~ O) 994 BYTES * DEPTH GR TTEN CCL1 CCL SSN C' Sx~ rN rNC 91o7.000 3~ 37 ,~..- 796 0.9000000 0.0600000 o 9o910~ 15 O00OO 1 305. ~ 6 141.985 19.0000 91 47 Ouu 73.73'~47 1 ¢54 713 O. 3000000 O. 0000000 1 88. 2782 1 4. 02205 31 , 06534 35. 06534 90e7.000 55.11295 O,O0000OO 0.0000000 1~ 960~8 3~ 21 037 9047.000 26.~6571 O.OOOO000 9,0000000 18.67~74 Z3.922Cl ~997. 000 4,;.:. 56145 O.O000OOO 0.0000000 21 .55919 22.63537 8947.000 192.1158 0.0300003 o.6,5052. 40.;~1313 .uOu 13g.033~ 9 000 · ,~uu g. O00000 16.eZC46 26.'?fi543 3c47.C3'~ z9 1 000000'3 9. 0030000 .3";' 703 ! ,C, 7. S ~480 1536.6 !~2.06 36.2t0 1537.5 23!.18 Z7.922 1536.0 200.76 26.630 1524.2 176,14 44.813 1516.o 149.45 30.755 1 5'Z4 . 3 121 .4'; 101.50 ";'7 28 37 60 96 61 1t 27 37 66 07 13 36 91 48 TEN CSSN 157.4848 141 .9558 93,4410~ u,3428 6. 7801 50 190.2879 -6.136295 220,9874 -13.71494 248,1596 -1 3 · :3491 4 145.9131 -16.03477 21S.c~326 lZ.19878 t 2'~ 32~' SPD LSN 21.99780 35.99640 24,56612 58.93930 24.76172 54.16451 25.34471 85.67841 24.67070 59.93651 24.99751 49.83691 25.1O791 30.56760 24,o~751 21 .43329 TOTAL j~T:~ ,:$-C~q~',S,, ~. : FILE T~AZLER **** .'; 9 91 o7. O0 TAPE ] c I:::, T d = 882~.00 FILE ?aSS FOR ONE M~T RECORD (TY?EX OEPTH PER FR~t4E TAP;, ~... OF-'PTH:_ UNIT : ,ZT 12 CURVES : NAME CODE 2 T T = N 6 ~.? 4 SPD 68 ~ CCL1 6;4 6 CCL 68 S S N .z, ,~ 9 L S N 68 ...... CLS S AM 64) PLE~ UNIT BY 1 APZ 4 1 LB 4 1 LS 4 1 F/m~ 4 1 VOLT 4 1 VOLT 4 '1 CTS 4 I CTS 1 CTS I CTS 1 PCT 4 I PCT 4 TES DATA RECORD DEPTH CCL1 CLSN 9197.000 ~ 24on7~ 9147,000 O.OOOO00O t4.07775 ~0~71003 O.O0000OO 14.1435~ 0.000003:3 ~997 nog 0.00900:33 2~. :.7~7'~ 8,947. COO O. JOOn,330 ,5.3 ? 8 ,? 4 ,? 38~7. O. :3:390 "'" ?" 1 7. 64 ,~ ,5 ~, ~ S647. i'3OO 0 nao'~ aOn 5.69 ';' :f! .53 · 7 O. 2 6 O. 2 2 O. 2 4 t 1 O. 6 (TYPS~ GR CCL C N 38.87796 0000000 ~.OOOO0 9.58221 000000'.~ 7.58235 1 .90914 0009 O0 9. 5663 2.4.4156 000900'3 '2.63 z, 59 7.52277 00 O 0 O 00 1,30125 O r} 30 <_300 n 3~':,'6 4 P ':" 627 a.51430 ._., 0 i.] b C 5.37,.z, 32 O) 994 'BYTES * TTEN S SL CNC 1329.667 t40.9859 19.0JOOO 1556.912 192,542t 31 .59235 I 55!3. 503 181,57'48 3 ,:":, 66632. 1540.78,0 236 ;'7 ~, ~ Z6 t,;, 459 1 536. 1~2,1t50 25.59125 1533.1~! 17~.8347 15 '2t. 96'~ 1'z7 27,, 51433 I ~,8!.~ . 231 t 22. 9075 O 9 '~ 7 ~ 3 ~ TEN CSSN 173.8326 140.9859 104. 4220 195.9714 9,604452 195.2330 -8.089516 217.4159 -12.19789 247.B243 -1 ~ 84 z~,35 14o.7e.~3 -1 z,. 583 ~,.8 215.,'7138 -27.44725 119 "391 SPD LSN 21 .99780 36.99631 24.02742 55.90102 23.~9762 54.25151 24.85910 $ 8 · 60870 24.52371 54.77230 24.39792 53.56703 74.48807 ~1.53601 2C.q9751 21.og160 TOTAL DATA RECORDS STARTING TAPE DEPTH FILE TRAILER = 91 97 ~' · (¢~ 0 ENOING DEPTH : 8829.00 FILE # 3 PASS 3,003 **** =ILE HE~DER **** 1924 FORMAT ONE DEP RECORD (TYPE~ 04) TH PER FRAME TAPE DEPTW UNIT : FT CURVES : NAME COD 1 GR T T E N 3 TEN 5 CCLI ,58 7 SS~ 65 ,?, C S S N 6 o LS N 68 0 C L S N 6 1! CN 2 CNC 6 E S~MP 1 1 1 1 1 1 t 1 1 1 1 t LE# UNIT apl LB LB F/MM VOLT VOLT CTS CTS CTS CTS PCT PCT ~YTES * DAT~ RECORD D=PTH CCL! CLSN O.OOOOCOC 9.2~073 '~!47.000 0.9099C30 14.. 89 .? C 0 9097.000 0 n r~ C 0 .-, 9047. 006 0.90 O 0 C 0 e I 3.141 ~'~; ? (TYP=# 4 7 C. 2 7 C. 2 O, 2 GR CCL 3.45184 5 i~ 9000030 OOO..., ,,,, ~.7~3~ 5.3S00J 000,3O00 O) 904 ~YTES * TTEN SSN CNC 126R.6 !39.9~ 1¢.000 15al .6 177.16 2c, .757 1542.3 27.303 73 6O 0 '3 5~ 63 ,53 75 48 TEN CS SN 118.0381 139.9 360 90.14735 lO4.1.397 2.753693 203.1900 -7.049162 2t8.1237 SPD LSN 20.99789 36.99631 23.51311 57.8336C 23.52120 ~1.82351 24.30052 ~3.92~12 8997. CO0 49. 3791 6 I 5 26 . 1 23 -1 6 · 54411 23 · 0c~1 71 '245 . 3741 54.61 9?0 947. 000 I 57. g2a3 I 5! 9. 469 "'O000On 9. Ou 30~"~0 ,~ .... .,~ .:, "' ..... :~ 1,91 14,~! S.442726 4,1. 24542 a5.24542 897,000 77,75656 1 514,551 I 2,90000 I 2 · OOOO0 ! 17. 0229 ~47 OOO 4'~ 45689 1~37 047 . 0090003 0 · 0090000 122. 9704 5 · 371 95 t 71 . !5! 79 75. 251 79 -le.4o868 142.2153 -15.278o6 223.3804 12.1987:5 117.7273 ?.3.g6782 55. 74011 23.99762 24.05151 24.99751 21.58559 TOTAL ~ATA RECORDS : STARTING TAPE DEPTH : FILE TRAILER 39 71 97.00 ENDING TAPE DE PTH = 8829.00 **** TAPE LiS 89172102 3731 01 TRAILER **** TOTAL RECORDS IN THIS LOGICAL TAPE : 130 **** REEL LiS 89/22/02 ATLAS 01 Tq~ILER *+** TOTAL RECORDS IN T~IS LOGICAL REEL : 131 TOTAL R=CORD~_ , ~ IN TH-S' PHYSiC.AL RE=L:, _ 1 '~1 Encl of execution: F1on Elapsed execution time = 44.00 seconds. SYSTEi, i RETURN COO= = 0 C~VE STECITICATION£ Company Well , ARCO ..ALASKA. INC, D. S. 1.4-29 FSeld PRUDHOE BAY County, State N. SLOPE , ALASKA Date_ 2-29-82 Curve Name (Abbrev.) Standard Curve Name Logs USed DIFL t! f! CFOC CILM CICD t RFOC [ Ri LM Focussed: Conductivity Medium: " Deep: " ResiStivity: Focussed N " : Med. Ind.-- RILD " : Deep " " CAL Ca 1 ip er CD/CN GR Gamma Ray CD/CN GR1 SP DEN' DENP CORR CN AC Self Potential Bulk Density Porosity form Densilog DIFL, BHC AC DIFL CDL Correction " Compensated Neutron CN Acoustic Transit Time BHC AC Scale 0-2000 .2-2000 6-16 0-100, 100-200 I! · 2-3 0-60 -.5 to .5 0-60 ...... So-!,,So .- FILE=LA1232 PROGRAM=LISTER ECC NUMBER 1222.B~ ARCO ALASKA, INC. D.S.14-29 28 CURVES : CFOC CILM CILD SP GR! TEN SPD 'RFOC RILM RILD CAL ACQ AC SSH LSN DEN CORR CH GR FROM 256~.B~ TO 96~g.B~ LEVEL SPACING 62. SAMPLES PER RECORD ARCO ALASKA, INC, D.S,. 14-29 GR I$ R~.N W'ITH CD/C.N.GRI TS RUN it,/ITH BHC AL/DIFL. DEPTH RFOC RILH RILD GR1 GR SP CAL DEN CORR AC CN DENP 8988. 8985. 8918. 8915. 8928. 8925. 8938. 8935. 8948. 8945. 8958. 8955. 8968. 8965. 9.4 9.6 12.5 117.5 94.5 26. 11.6 2,34-8.84 78.7 28.4 18,6 9.1 11.6 12.4 62.3 74,8 15. 11.1 2.62 .8,41 83.8 28.9 1.7 8.6 9.6 18.8 76.3 78.1 19. 9.9 2.5.8-8.83 82.7 29.7 8.8 15.3 14..8' 15.2 63.4 188,7 22. 9.5 2.59 8.15 73.2 23.9 3.4 26.5 22.3 19.7 95.6 68.5 42. 9.4 2.61 B.81 72.2 14.3 2.7 24.9 23,8 23.1 83.2 49.4 48. 9.5 2.56 8.82 67.8 17.8 5.6 27.7 21.5 22.6 56.2 61.1 51. 9.7 2.61 8.86 66.5 15.9 2.2 7.7 6.8 7.5 94.3 188.6 66. 9.9 2.49 8.17 69.g 26.2 9.9 '13.8 12.3 12.6 1,8'5.1 131.1 68. 18.2 2.63 8.88` 81.7 23.9 1.4 18.8 7.2 8.3 155.3 Z25.8 63. 11.1 2.39 8.29 73.9 31.7 15.9 15.2 9.6 18.8 35.8.3 286.~' 39. 9.8 2.83 8.28 72.8' 27.8-18,9 66.4 25.3 29.7 139.8 153.4 12. 9.5 2.66 8`.85 63.8 12.5 -~r.5 77.6 36.3 43.5 285.5 I78.8 5. 9,5 2.69 8.87 61.7 18.5 -2.7 84.3 56.6 48.3 79.7 81.1 1.8. 9.6 2.64 .8.11 67.8 13.3 .8.7 897.8. 31472.8 78.2 86.9 88.6 87.9 18. 9.5 2.58 .8.83 64.4 17.9 4,5 8975. 52.2 28.8 31.6 97.5 94.3 19. 9.3 2,66 8,13 59.1 13.8 -8.8 8988. 1f~88.8 69.7 69.7 113.2 112.5 28. 9.1 2.78 8.87 66.3 15.4 -2.9 8985. 8998. 8995. 9895. 9.81.8. 9815. 98.28. 9825. 9838. 9.835. 984~. 9845. 9858. 9855. 9868. 9865. 9,878. 9875. 9888. 9885. 9898. 9895. 91.88. 91.85. 9118. 9115. 912.8. 9125, 9138, 9135. 914.8. 9145. 58.8 26.4 23.4 1.86.8 112.6 46. 9.1 2,66 8,2.5 72.8 18.2 -8.7 2,8.8 7.8 7.4 144..8 188.7 48. 8.8 2,68 8.81 79.2 26.1 3.8 8 3 6.3 7.8 63.7 68.8 37. 8.8 2,51 8.86 79.7 2~8`.8 8.5 11.4 3.6 2.4 36.8 36.2 24. 8.8 2.28 8:82 81.52'?,8 22 7 13.2 18.9 14.4 29.4 26.8 18. 8.8 2.36 8.83 82.7 23.2 17.5 28.7 18.4 22~6 39.6 81.2 14. 8.8 2,25 8.84 86.6 23.8. 24.1 21.1 118.3 25.7 54.9 71.3 7. 8.9 2.25 8.84 87.4 23.3 24.4 32.8 26,8 48.9 76.2 76.8 8. 8.8 2.38-8.85 86.9 27.5 16,1 22.8 28.9 28.8 48.8 42.2 9. '8.8 2.38 .8.8`4 87.9 25.3 21.4 22.4 21.8 33.8 32.1 26.8 lB'. 8.9 2.25 8..83 98.1 24.3 24.4 24.4 21.6 31.8 24.1 26.7 18. 8.8 2.22-9..82 98.4 24.8 26.2 25.3 22.8 33.7 28.2 23.7 1.8. 6.9 2.21-.8.92 91.2 24.9 26.8 21,5 19.4 28.4 28.1 28.9 13. 8.8 2.27-8..81 89.5 24.5 22.8 22.9 19.9 28.8 25.3 23.4 13. 8.9 2.31 8.81 87.3 24.7 28.4 22.1 28.6 28.9 33.7 25.4 12. 6.9 2.29 8..88 88.1 25.1 22.1 34.2 26.4 31.6 26.8 33.5 19. 8.9 2.53 8..89 79.9 19.2 7.5 17.8 16.7 19.6 49.9 41.6 31. 9.8 2.48 8.82 75..8 18.7 15.3 18.5 28.1 26.4 33.8 28.2 13. 9..8 2.21-8.83 9.8.1 23.5 26.4 28.5 23.8 33.5 25.8 22.3 6. 9.8 2.42 8'.81 76.8 21.8 14.1 33.8 25.3 28.7 22.4 21.4 6. 8.9 2.45 8`.85 71.5 17.1 11.9 17.4 15.1 28.3 31.2 29.2 18. 9.9 2.24-8.83 92.1 27.8 25.1 21.6 28'.7 3.8.7 25.2 23.4 12, 8.9 2.24-8.81 95.1 27.1 24,9 19.7 18.1 25.2 35.9 33.8 15. 6.9 2.36 8..84 91.1 24.7 17.6 23.4 22.9 33.4 29.1 27.7 13. 8.9 2.22-8.88' 94.1 26.4 26.1 17.7 28.5 26.3 41.7 35.5 19. 6.9 2.31-8.8'8` 93.2 26.9 28.8 18.2 17.5 24.3 22.7 23.7 13. 8.9 2.29-8.83 97.7 26.9 21.7 17.9 18.6 25.5 35.3 25.1 28. 8.9 2.27 8.8`4 93.6 26.6 22.9 12.2 12.7 14.4 79.3 82.8 45. 8.9 2.53 8.12 83.1 22.7 7.5 25.6 21.5 25.8 19;3 21.5 28. 8.9 2.28 8.82 91.9 24.3 22.6 18.4 12.8 16.2 27.7 33.5 26. 9.8 2.45 8.12 86.6 27.5 11.9 15,1 11.9 14.4 31.8 22.7 29. 9.8 2.25 8.85 85.9 23.9 24.8 18,2 19.9 27.9 28.7 25.4 14. 8.9 2.33 8.84 87.9 25.1 19.7 16.8 15.5 22.6 37.8 45.2 26. 8.9 2.27 8.81 86.6 25.2 23.2 ARC~ ALASKA, INC. D.S.14-29 GR IS RUN WITH CD/CN.GR1 IS RUN WITH BHC AL/DIFL. DEPTH RFOC RILM RILD GR1 GR SP CAL DEN CORR AC CH DENP 9158,. 9155. 916.8. 9165. 917~r. 9175. 918.8. 9185. 9198'. 9195. 920.8. 92,8*5. 921.8. 9215. 922.8. 9225. 923.8. 9235. 924.8. 9245, 925.8. 9255. 926.8. 9265. 927.8. 9275. 928.8. 9285. 9298. 9295. 93*8.8. 93*85. 931.8. 9315, 932.8. 9325. 9338. 9335. 934.8. 9345. 9358. 9355. 9368. 9365. 9378, 9375. 9388. 9385. 939,8. 9395. 11.2 12.8 14.7 37.4 23.7 37. 9.0 2.61 8.12 91.2 29.2 2.5 14.6 13.~ 13.6 34.6 25.2 45. 9.0 2.43 8.12 87.1 27.7 13.2 13.7 11.4 1.8.6 33.9 21.0 47. 8.9 2.31 .8.00 83.5 24.9 2.8.7 7.4 9.6 1B*.l 57.2 54.9 42. 8.9 2.31 8.8'7 89.3 22.9 28'.4 13.6 12.3 16.8. 25.6 27.4 18, 8.8 2.26 .8..8.8 88.9 27.3 23.7 17.1 15,6 Z.8.4 23.5 21.3 14. 8.9 2.27 .8.81 86.8 24.6 22,9 12.9 11.9 16.8. 32.3 32.5 18. 9..8 2.31 8'..86 88.8 24.1 2.8.6 16.4 15.8 21.7 26.8 23.3 28.. 8.9 2.27 .8.8,2 87.5 25.6 23.1 11.8 11.5 12.2 48..9 39.7 33. 8.9 2.42 8.07 81.3 25.8 13.7 17.,8 15.8 17.1 27.1 34.5 38. 8.9 2.43 .8.81 77.3 21.4 13.4 13.4 13.8 13.9 42.1 41.9 44. 8.9 2.44 .8..87 75.3 18.6 12.8 14.1 11.3 11.3 22.1 21.9 21. 8.9 2.33 g.02 81..8 2.8..8 19.2 13.9 1.8.1 1.8.1 22.5 2.8.5 28. 8.9 2.41 .8.8'1 8.8.1 17.2 14.7 19.4 12.1 ll.Z 28..8 18.9 28. 8.9 2.39 .8.8'3 64.8 16.2 15.9 8.6 5..8 4.5 19.8 19.6 21. 8.9 2.32 .8..81 8.8.5 23.5 19.7 9.6 5.1 4.9 22.5 19..8 25. 9.B 2.35 .8..82 88.7 21.4 18.3 25.4 15.4 14.9 23.9 21.7 48. 9.8 2.48 .8.81 73.9 19.1 18.3 13.2 14.5 13.7 49.9 46.7 47. 9.1 2.55 .8..87 68.8 18.2 5.9 31.2 23.8. 23.4 24.1 22.5 14. 9.8 2.46 .8..83 65.8 12.8 11.8 39.2 21.8 24.2 21.8 2.8.8 14. 9.~ 2.49 8..88 63.2 12.8 9.5 27.7 19.6 19.3 22.2 18.5 28.. 9.8. 2.47-.8.1.8 69.1 15.3 11.2 18.3 15.1 15.6 23.3 19.9 23. 9.88* 2.32 8*.83 77.9 19.5 2.8.1 28..7 16.1 16.8 22.7 28.1 22. 9.1 Z.35 8.85 77.8 28.5 18.1 13.6 11.2 11.2 23.6 23.2 25. 9.8 2.29 .8.88 83.4 23.5 22.1 13.9 11.2 18.4 35.7 36.9 29. 9.8 2.37 .8.84 82.8 23.1 17.1 18..5 9.1 15.6 1.8'. 3 13.5 9.2 9.5 6.6 6.1 3.1 4.8. 2.2 4.1 2.5 4.3 2.5 12.7 ,4.1 3.9 3.1 4.2 2.9 7.9 4.3 11.7 4.8 3.4 2.3 3.9 2.1 3.9 2.7 3.3 I .9 2.9 2.1 12.4 5.4 5.9 5.1 5.8. 3.7 2.9 1.7 2.8 1.7 3.2 2.8.8' 4.1 2.6 8.6 25.8 25.5 25. 8.9 2.31 .8.81 8.8.5 21.8 2.8.8 9.7 22.1 21.6 24. 8.9 2.38 .8..85 72.5 28..8' 16.6 8.5 23.9 21.8 26. 8.9 2.38 8.85 73.8 18.5 16.3 6.2 28..8 19.3 27. 8.9 2.25 .8.82 71.2 19.9 24.3 3.8. 27.8 24.3 38.. 8.9 2.26 .8..84 87.2 23.6 23.9 2.1 23.8. 21.1 38. 8.9 2.38 .8.8.4 92.2 26.8' 21.2 2.4 22.2 28.1 38. 8.9 2.25 .8..83 86.6 26.8' 24.5 2.5 27,6 27.7 32. 8.9 2.3.8 ~..81 87.6 25.1 21.1 3.4 23.5 21.7 31. 9.8 2.43 .8.8'7 76.8 19.7 13.6 2.7 24.3 21.1 32. 8.9 2.42 .8.8'9 81.8 21'.8 14.8 2.9 22.5 21.8 32. 8.9 2.29 .8..82 81.5 25.9 21.6 3.7 28.,5 21.8 34. 8.9 2.35 .8.8'3 78.4 21.8 18.8, 3.5 18.6 22.8 36. 8.9 2.35 .8.87 75.2 16.5 18.8' 2.1 34.5 25.1 39. 9.8 2.28 .8..81 81.9 26.8' 22.5 2.8. 23.2 22.2 34. 8.9 2.26 8.8'2 84.7 25.3 23.7 2.7 33,7 24.5 45. 9.8 2.37 .8.8'2 78.3 26.8 16.7 1.8 21.9 23.5 32. 9.8 2.31 8..8.8 86.7 26.8 2.8.7 2.1 22.2 19.6 38. 9.8 2.33-8.8'8 88.4 25.7 19.2 4.7 18.3 17.8 31. 9.8 2.64 .8.15 78.3 18.7 0.7 4.4 58.4 84.9 64. 9.1 2.73 .8..87 75.9 22.2 -4.8 3.5 48..8 38.3 48. 9.8 2.31 .8..82 77.7 23.6 28,.5 1.6 2*8.9 2.8.7 38. 9.0 2.2.8 .8.82 88.9 26.8 27.8 1.6 26.2 22.7 3,8'. 9.8 2.27-.8..81 91.8 26.8' 23.1 1.9 34.2 38.9 33. 9.8 2.3.8-8.8.3 92.1 25,8 21.4 2.6 32.8. 38.9 34. 9.1 2.39 .8..83 85.2 23.8' 15.7 ARCO ALASKA, IHC. ' DTS,14-29 PAGE 3 GR IS RUN WITH CD/CN.GR1 IS RUN WITH BHC AL/DIFL. DEPTH RFOC RILM RILD GR1 GR SP CAL DEN CORR AC CN DENP 9488,. 4,4 948,5. 6.1 9418,, 11.4 9415. 6.9 9428. 6.5 9425. 2,8 9438. 4.1 9435. 3.4 9448. 3.7 9445. 7.3 9458. 4.6 9455. 3,4 9468,, 4.7 9465, 4.8 9478. 7.1 9475. 16,4 948~. 6.4 9485, 2.8 949~, 3.5 9495. 3.6 9580. 3.8 5.6 7.4 7.9 4.6 4,7 2.3 3.1 2.3 2.6 5,9 3.9 5.2 99.6 18,g.2 83. 9,3 2.66 8,.8,3 76.8 21.1 7.4 93.5 87.8, 78. 9.1 Z.65 8,.15 71.1 23.1 7.2 21.2 21.7 38,. 9.3 2.39 8,.8,2 69.7 28,.1 15.5 4.1 38,.7 32.1 33. 9.8 2.37 8,.8,2 73.4 22.8, 16.7 3.9 19.3 20.5 29. 8.9 2.35 8,'.8,8 74.2 28,.1 17.9 2,2 23.1 20.6 28. 8..9 2.24 8,.8,6 83.8 28.5 24,6 3.1 42.3 35.7 39. 8.9 2.31 8,.8,3 88,.5 24.4 2.2 23.3 23.8, 29. 8.9 2,24 8,.~'2 86.8' 24,9 24.6 2.5 ZZ.5 27.1 28. 8,g 2,31 8,.8,1 84,7 23.1 5.8, 23.5 23.2 35. 9.8 2,52 8,,8'1 88,.8, 22.,e' 8.2 3.8 29.8 26.2 41. 8.9 2.41 8,.8,8 81.3 28,.2 I4.7 2.3 2.2 27.8, 28.7 34, 9,1 2.56 8.02 85.3 22.2 5.6 5.1 4.6 7.5 7.9 3.6 1.9 2.8 1.9 2.8, 5.1 187.1 18'5.1 98. 9.3 2.66 8,.18 76.6 29.5 -8.8 4.9 188'8.3 189,4 92. 9.2 2.7,~ 8.28, 75.9 27.9 .-2,8 6.6 67.9 68.8 87. 8.8 2.88 8.16 78.5 24.8 -9.1 7.8 45.1 57.1 69. 8.9 2.55 8.~r8, 69,8 23.8 5.9 3.5 51,5 39.6 43, 8.6 2.32 8.82 79.4 28.7 28.2 1.8 28.8 27.6 29, 8,5 2.27 ~'.,~7 98.4 26;3 22.8 1.9 29.8 29.3 3~'. 8.5 2.34 8,.89 86.1 25.3 18.9 1.8 27.2 28.1 38,. 8,5 2.21 8,.8,1 86.6 25.8 26.8 1.9 31.8 31.8, 32. 8.5 2,28 8,.8,3 89.2 25.8' 22.7 ~;~----SCHLU~B~RGER ....... ~ LiS TAPe V~RiFIC~TiON LISTING LVP 010.H02 VERiFICATIJN LiSTi>~S PAGE ...... R~L HEADER ..... S-RVIC~. NAME D~T~ :85/1i/2~ O~IGiN : REEL NAME :302103 CSNTiNU~TZPN m :01 PREVIOUS REEL COMMENTS :LZERARY ~;~q~ TAP~ HEADER ::~:X SERVICE NAME .~'=OIT JATE :86/11/26 DRZGIN :FSI~ TAPE NAME : CONTINUATION ~ :01 PRSViOUS T~PE : COMMENTS :LZB~RY TAPE ...... FILE HEADER FILE NAME :~O~T_ S~RVIC~ NAM~ VERSION ~ : D~TE : MAXIMUM LENGTH sZL~ TYPE eREVZOUS FiLE .001 102~ ...... iNFOR~TTON RFCORDS ...... MNEM CONT2NTS UNiT TYPE CATE SIZE C09~ CN : ,~RC~ ALASKA iNC. 000 000 016 065 WN : G.S. 14-2:~ 000 000 010 065 FN : PRUDHO~ BAY 000 000 012 065 RANG: 14E 000 000 004 085 TOWN: iON 000 000 004 085 S~CT: 9 000 000 002 085 COUN: NORTH SLOP~ 000 000 012 06~ STAT: ALASKA 000 000 006 065 MNEM CONT=NTS. UNTT, TYPE, . CAT~ .~qiZ~,_ CODE PRES: E OOO 000 00i 065 ...... COMMENTS-,--,- ~;: ~:= ..:.- .................... " ....... ;;-' ;:.~ '4: ::: ............................... ' ....... " .......... :k ;:: ~:: ::~ ::: ................. "' '~'" ............... -,- ........... . .... , ............... . ?-%: .... ~..,. ~:: f.~ ~:~., ............. , ......... ~ ....... .,..,...,..,..~ .,..,..,..,. LVP OlO.H02 VERiF'~CATIgN,~ L'rSTiNG~. ,c'~GE,~ 2 .,...~,CdLUm~EmGER -,, -" .&L~SK& CCM'~UTiNG CENTER ?,.' CONP~NY = ARCO ~LASK~ WELL = FIELD = COUNTY : NORTd SLOPE STATE = ALASKA JOB NUMBER AT ACC: 72080 RUN ~GNE, DATE LDP: T HALST~AD CASING CASING TYPE FLUID = 9.625" SURF~C£ TO 8856.0 = 7.000" SURFACE T~ 9560.0 = PRO~UCEO CRUDE LVP OlO.dO2 VE~i~i,CnTIQN LiSTZN'* PAGE 3 ~;~;;= DAT~ FORMAT RECORD ~;=;:= ENTRY BLOCKS TY°E SiZE REPR CODE ENTRY 2 i 5~ 0 4 i 66 i B 4 73 60 ~ 4 55 .lin 16 i 66 i 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT afl ~P,i ~PI AP1 FiL= SiZE SPL REPR ID ORDER ~ LOG TYPE CLASS MOD NO. DEPT FT O0 OOO O0 0 0 4 GR PS1 G,~Pl O0 310 O1 0 0 4 NPHi PS1 ~U O0 890 O0 0 0 4 NRAT PS1 O0 420 Ot 0 0 4 RNRA PSI O0 000 O0 O 0 4 NCNL PS1 CPS O0 330 B1 0 0 4 FCNL PS1 CPS O0 330 30 0 0 4 GR PS2 GAPl O0 310 O1 0 0 4 NPHi PS2 PJ O0 890 O0 0 0 4 NRAT PS2 O0 420 Ol 0 0 4 RN~A PSi O0 000 O0 0 0 ~ NCNL PS2 CPS O0 330 31 0 0 4 PROCESS CODE (OCTAL) 58 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 OOOO0000000000 68 00000000000000 63 00000000000000 63 00000000000000 68 00000000000000 58 00000000000000 68 00000000000000 68 00000000000000 OlO.HO2 VE~iFiCaTICN LISTING PAGE LVP FCNL PS£ CPS O0 SR PS3 GAPl O0 NPHi PS3 PU O0 NRAT PS3 O0 RNRA PS3 O0 NCNL PS3 CPS, ,~'~ FCNL PS3 CPS O0 330 ~-20 000 330 3O O0 31 30 DEPT 9235,0000 GR RNRA 2.4375 NCNL NPHi -999.2500 NRAT FCNL -999,2500 GR RNRA -999.2500 NCNL DEPT 3200.0000 3R RNRA 2.5020 NCNL NPH$ 19.091d NRAT FCNL 824.5000 GR RNRA 2.2109 NCNL D~PT 9100.0000 GR RNRA 2.9668 NCNL NPHI 29,4434 NRAT FCNL 726,5000 GR RNRA 3.0525 NCNL D~PT 9000.0000 GR RNRA 2.2070 NCNL NPHi 19.7754 NRAT FCNL 1413.0000 GR RNRA Z.Z246 NCNL D~PT 8900.0000 GR RNRA 2.816~ NCNL NPHZ 22.9~'92 NRAT FCNL 852.5000 GR RNR~ 2.6992 NCNL DbPT 5543.0000 GR RNPA -999.2500 NCNL NPHi 53.8574 NRAT ~CNL 334.7500 GR ~NRA -999.2500 NCNL ...... FiLE TRAILER-,--,- :-IL~ NAME :EDIT .001 S~2RViCE NAME : VeRSiON ,~ : DAT~ : F, AXiMU;~ LmNSTH : 102~. 38.$750 1992.0000 -999.25OO -999.2500 42.~437 2220.0000 2.~Z58 ~7.0625 2166.0000 28.3906 2198,0000 3.0176 30,1719 2174,0000 26.609~ 3056.0000 2.4688 19.5000 328B.0000 53.0000 2258.0000 2.6621 55.0313 2225.0000 -999.2500 -999.2500 4.3594 -999.2530 -999.2500 NPHZ FCNL RNRA NPHZ FCNL NPMi FCNL RNRA NPHI FCNL NPHI FCNL RNRA NPHZ FCNL NPHi FCNL RNRA NPHI FCNL NPHi FCNL RNRA NPHi PCNL NPHi FCNL RNRA NPHZ FCN' 0 © 0 '3 0 0 18.3594 817.0000 -999.2300 -999.2500 -999.2500 18.4082 2.4383 15.8203 979.5000 29.1016 740.5000 3.2109 28.3691 709.5000 15.7227 1384,0000 2.2402 14.5508 1477.0000 22.8027 2,7715 22.0703 824.5000 -999.2500 -999.2500 4.3945 -999.2500 -999.2500 ! 68 1 NRAT GR NCNL NRAT NRAT GR NCNL NRAT NR~T uR NCNL N ~ ~,&T NRAT GR NCNL NRAT NRAT GR NCNL NRAT NRAT NCNL NRAT 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 gO000000000000 2.~750. -999.2500 -999.2500 -999.2500 2.3770 4~.7500 2202.0000 2.1992 2.9980 27.3125 233~.0000 2.9590 2.1934 27.9062 3!68.0000 2.1094 2.6543 78.5625 2364.0000 2.6133 -999.2500 39,1562 1472.0000 -999.2500 LV? OiO.M02 VERI,ZlCATiRN LiST!N~3 P~G~ 5 F.~ L P. TYPE : N~:XT,_ F!L': NAv,~E .' FiLE NAM~ :EDIT SERViC~ NAME : VBRSION ~ : D~TE : MAXIMUM LENGTH : PiLE TYPE : ~REVIOU$ FiL~ : .002 ::::;: DATA ~ORMAT ENTRY 5LOCKS R~_CORO TYPE S!Z~ 4 1 15 1 66 73 66 ~LOCKS UNIT ~PI API AOl ~ml FiLE LOG TYPE CL4SS MOD NO. ~T O0 000 O0 0 0 O0 150 O1 0 0 O0 150 O1 0 0 O0 150 O1 0 0 ~NTRY 0 10 ,IIN 0 SIZE SPL 4 1 4 i 4 I q 1 REmR PPOCESS CODE (OCTAL) 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 OEPT '9235.41~0 DEPT 9200.2300 DEPT 9100.2500 DEPT 9000.ZSO0 OEPT 8900.2300 D~PT ~843.0000 CCL -0.0049 CCL CCL -0.0122 CCL CCL -0.0806 CCL CCL -0.0562 CCL CCL -0.0~5~ CCL CCL -999.2500 CCL -999.2500 CCL -0.0195 CCL -0.3369 CCL 0.0171 CCL -0.1050 CCL 0.0830 CCL -999.2500 -0.0!71 -0.4028 0.0854 -0.0684 -999.2500 '~'~' FIL: TRAILER ...... ~ILE NAME :EDIT S~RVICE NAME : VERSION DATE : .002 LVO 010 ~i02 VERifiCaTiON LiSTi~' ,~G ~.&G= ,5 MAXIMUM L2NGTH : FiLE TYPE : NEXT FILE NAME : 1024 ...... TAPE T2AZLER ...... SERVICE N&ME :EDIT DATE :86/11/26 ORIGIN :FSIA TAPE NAME : CONTINUATIgN # :Gl N~XT TAPE NAME : COMMENTS :LIBRARY T~PE q~'4~ REEL TR&iLER ~:~ SERVICE N&M[ :EDIT D~TE :86/11/25 CRIGiN : R~E~ NBM~ :302103 CONTINUATION ~ :O1 N2XT REiL N~M~ : COMMENTS :LIBRARY TAP~ * ALASKA COMPUTING CENTER . **~************w********~***~. . ............................ * ....... SCHLUMBERGER ....... . ............................ RECE v u DEC 2;~ 1997 Alaska Oil & G~s ~s. Comn~ss~ COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D. S 14 -29 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292068000 REFERENCE NO : 97532 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/12/14 ORIGIN : FLIC REEL NAME : 97532 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, PRUDHOE BAY, DS 14-29, API #50-029-20680-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/12/14 ORIGIN : FLIC TAPE NAME : 97532 CONTINUATION # : 1 PREVIOUS TAPE : CO~EiFT : ARCO ALASKA INC, PRUDHOE BAY, DS 14-29, API #50-029-20680-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S 14-29 API NUM~ER: 500292068000 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: Il-DEC-97 JOB NUMBER: 97532 LOGGING ENGINEER: J. PAWLUK OPERATOR WITNESS: M. REYNOLDS SURFACE LOCATION SECTION: 9 TOWNSHIP: ION RANGE: 14E FNL: 2224 FSL: FEL: 847 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 71.00 DERRICK FLOOR: 70.00 GROUND LEVEL: 40.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8.500 7.000 9560.0 2NDSTRING 3RD STRING PRODUCTION STRING CURVE SHIFTDATA - ALL PASSES TO STANDARD(FIEAS~DE~) LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 28-FEB-97 LOGGING COMPANY: ATLAS BASELINE DEPTH .............. 88888.0 9164.5 9158.5 9157.0 9154.0 9152.0 9151.5 9149.5 9132.0 9126.0 9120.0 9117.0 9114.5 9104.0 9097.5 9096.0 9094.5 9090.0 9082.0 9080.5 9069.5 9068.0 9065.5 9063.5 9052.5 9048.5 9046.5 9042.5 9029.0 9025.5 9022.0 9020.0 9011.5 9011.0 9005.0 8992.5 8991.5 8979.5 8979.0 8969.5 8958.5 8958.0 8954.5 8949.0 8948.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. 88888.0 88887.5 9154.0 9151.5 9130.0 9115.0 9102.5 9096.5 9092.5 9081.0 9067.0 9065.0 9051.0 9046.0 9029.5 9021.0 9011.0 8992.0 8979.0 8969.0 8958.0 8947.5 9164.0 9158.0 9155.0 9151.5 9149.0 9130.0 9125.5 9118.0 9113.0 9102.0 9096.5 9088.5 9078.0 9067.0 9065.0 9062.0 9046.0 9039.0 9025.5 9023.0 9021.0 9011.0 9005.0 8992.0 8979.0 8968.5 8958.0 8954.0 8950.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 8945.5 8947.5 8942.0 8942.0 8941.0 8942.5 8936.0 8938.5 8933.0 8932.5 8932.0 8924.0 8923.5 8921.0 8921.0 8917.5 8917.0 8917.0 8914.5 8913.0 8906.0 8907.0 8903.0 8904.5 8899.0 8901.0 8897.0 8897.0 8896.0 8897.0 8895.0 8894.5 8894.5 8894.5 8892.0 8892.0 8888.5 8888.5 8883.0 8882.0 100.0 100.0 99.0 $ REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTG DATA AQUIREDONARCOALASKA'S WELL DS 14-19. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN PASS #1 GRCH TO THE BCS GAM~A~Y, ALSO PASS #1 NPHI TO THE BCS GA~W_ARAY, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS ArdM~ER: 1 DEPTH INCREMENT: 0.5000 FILE SUF~L~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9165.0 8878.0 CNTG 9170.0 8878.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. REFiARKS: THIS FILE CONTAINS CNTG PASS #1. PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA THERE ARE NO PASS TO ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELE~ CODE (HEX) DEPT FT 1088212 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTD PU-S 1088212 O0 000 O0 0 1 1 1 4 68 0000000000 NRATCNTD 1088212 O0 000 O0 0 1 1 1 4 68 0000000000 CRATCNTD 1088212 O0 000 O0 0 1 1 1 4 68 0000000000 NCNTCNTD CPS 1088212 O0 000 O0 0 1 1 1 4 68 0000000000 ~CNTCNTD CPS 1088212 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTD CPS 1088212 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELD CODE (HEX) ....................................................................................... CNTC CNTD CPS 1088212 O0 000 O0 0 1 1 1 4 68~ 0000000000 GRCH CNTD GAPI 1088212 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTD LB 1088212 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTD V 1088212 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1088212 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9250.000 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD -999.250 CCL. CNTD -999.250 GR.BCS DEPT. 8861.000 NPHI. CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD -999.250 CCL.CNTD -999.250 GR.BCS -999.250 -999.250 22.219 -999.250 -999.250 72.870 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .00I SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME '. EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER : 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: FILE SUPmlARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9165.0 8864.0 CNTG 9170.0 8864.0 $ CURVE SHIFT DATA - PASS TO PASS (R~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH CNTG 88888.0 88888.0 88887.0 9165.0 9164.0 9160.5 9160.0 9156.0 9155.0 9151.5 9151.5 9149.5 9148.5 9148.5 9147.5 9143.5 9143.0 9143.0 9142.0 9141.5 9140.0 9135.0 9133.5 9132.0 9130.0 9127.5 9126.5 9122.0 9119.5 9119.5 9117.5 9115.0 9113.0 9109.5 9107.5 9104.0 9102.5 9099.0 9098.0 9095.5 9096.5 9095.0 9092.5 9091.5 9089.0 9089.0 9087.0 9086.0 9083.5 9082.5 9081.0 9078.0 9076.5 9077.0 9074.0 9070.5 9069.5 9069.5 9066.5 9065.5 9065.0 9063.5 9062.0 9060.0 9058.5 9059.0 9057.0 9052.5 9051.0 9048.5 9046.0 9046.5 9046.0 9042.5 9039.5 9039.0 9038.5 9032.5 9031.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: 9026.5 9026.5 9025.5 9023.0 9022.5 9022.0 9021.0 9016.5 9016.5 9005.5 9005.0 8999.0 8999.0 8994.5 8994.5 8992.0 8992.0 8987.0 8987.0 8982.0 8981.5 8982.0 8979.0 8979.0 8973.0 8972.5 8968.0 8967.0 8967.0 8961.5 8960.5 8948.0 8947.5 8947.0 8947.0 8941.0 8942.5 8938.5 8938.0 8936.5 8938.5 8932.5 8931.5 8931.5 8931.0 8922.0 8921.5 8921.0 8921.0 8918.0 8917.0 8917.0 8914.5 8913.5 8909.5 8910.0 8908.5 8908.5 8903.5 8903.0 8901.0 8902.0 8894.5 8894.5 8893.0 8892.5 8892.5 8892.0 8882.5 8882.5 100.0 99.5 100.0 $ REd, ARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NPHI PASS #2 TO NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: TYPE REPR CODE VALUE .............................. 3 73 44 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1088212 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTD PU-S 1088212 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTD 1088212 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTD 1088212 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTD CPS 1088212 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTD CPS 1088212 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTD CPS 1088212 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTD CPS 1088212 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTD GAPI 1088212 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTD LB 1088212 O0 000 O0 0 2 i I 4 68 0000000000 CCL CNTD V 1088212 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9169.000 NPHI.CNTD 42.308 NRAT. CNTD 3.717 CRAT. CNTD NCNT. CNTD 1989.287 FCNT. CNTD 519.869 CFTC. CNTD 552.522 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD 3009.000 CCL.CNTD -0.018 DEPT. 8877.500 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD. -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD 49.726 TENS. CNTD -999.250 CCL. CNTD -999.250 3.723 1950.293 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SBRVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9165.0 8868.0 CNTG 9170.0 8868.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTG ............................ 88888.0 88888.0 88885.5 9169.0 9166.5 9166.0 9164.0 9160.5 9159.5 9156.5 9155.0 9151.5 9151.5 9134.5 9133.0 9132.0 9130.0 9126.5 9125.5 9125.0 9123 . 5 9120.0 9117.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: 10 9119.5 9119.0 9116.5 9117.0 9109.0 9107.5 9104.0 9102.0 9103.5 9102.5 9099.0 9097.0 9098.5 9098.0 9096.0 9096.5 9094.5 9092.5 9087.0 9085.0 9082.0 9081.0 9077.0 9076.0 9069.0 9067.0 9065.5 9065.0 9065.0 9064.5 9063.5 9062.0 9060.0 9058.5 9058.5 9056.5 9058.0 9055.5 9052.0 9051.0 9048.5 9046.0 9046.5 9046.0 9041.5 9039.5 9039.0 9038.5 9031.0 9031.5 9026.5 9025.5 9026.0 9026.5 9023.5 9023.0 9023.0 9022.5 9021.5 9021.0 9014.0 9013.5 9011.0 9011.0 9009.0 9009.5 9004.5 9004.5 8999.0 8999.0 8992.5 8992.0 8991.5 8992.0 8981.5 8982.0 8969.5 8968.5 8967.0 8967.0 8961.0 8960.5 8958.0 8958.0 8948.0 8947.5 8946.0 8947.5 8942.5 8942.0 8936.0 8938.5 8923.5 8923.0 8922.0 8921.5 8921.0 8921.0 8917.5 8917.0 8917.0 8914.5 8914.0 8914.0 8913.0 8908.0 8908.5 8903.0 8904.5 8902.5 8902.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: 11 8896.5 8897.0 8896.0 8897.0 8894.5 8894.5 8894.5 8890.0 8892.0 8888.5 8888.5 8886.0 8885.0 8881 . 0 8882.0 8882.0 100.0 101.0 101.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO NPHI PASS #3 TO NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NTJM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~B SAMP ELE~f CODE (HEX) ....................................................................................... DEPT FT 1088212 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTD PU-S 1088212 O0 000 O0 0 3 1 1 4 68 0000000000 NRATCNTD 1088212 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTD 1088212 O0 000 O0 0 3 1 1 4 68 0000000000 NCNTCNTD CPS 1088212 O0 000 O0 0 3 1 I 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: 12 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... FCNTCNTD CPS 1088212 CFTC CNTD CPS 1088212 CNTC CNTD CPS 1088212 GRCH CNTD GAPI 1088212 TENS CNTD LB 1088212 CCL CNTD V 1088212 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9167.500 NPHI. CNTD 41.931 NRAT. CNTD 3.891 CRAT. CNTD NCNT. CNTD 1971. 988 FCNT. CNTD 557. 947 CFTC. CNTD 561. 478 CNTC. CNTD GRCH. CNTD - 999. 250 TENS. CNTD 2977. 000 CCL. CNTD -0. 048 DEPT. 8879. 000 NPHI. CNTD 71. 514 NRAT. CNTD 6.160 CRAT. CNTD NCNT. CNTD 1256. 336 FCNT. CNTD 265. 530 CFTC. CNTD 254.243 CNTC. CNTD GRCH. CNTD 43. 934 TENS. CNTD 2912. 000 CCL. CNTD O. 414 3. 703 1923.237 5.326 1282. 954 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCRi~fS~ O. 5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: 13 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS CNTG 1, 2, 3, $ REMARKS: THIS FILE CONTAINS THE ARITH~ETIC AVERAGE OF PASSES 1,2, &3 OF THE CNTG TOOL. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP EL~ CODE (HEX) ....................................................................................... DEPT FT 1088212 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1088212 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1088212 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1088212 O0 000 O0 0 4 1 1 4 68 0000000000 NCNTCNAV CPS 1088212 O0 000 O0 0 4 1 1 4 68 0000000000 FCNTCNAV CPS 1088212 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1088212 O0 000 O0 0 4 1 1 4 68 0000000000 CNTCCNAV CPS 1088212 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTD GAPI 1088212 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTD LB 1088212 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: 14 ** DATA ** DEPT. 9169.500 NPHI.CNAV -999.250 NRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV GRCH. CNTD -999.250 TENS. CNTD 3005.000 DEPT. 8877.000 NPHI.CNAV -999.250 NRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV GRCH. CNTD -999.250 TENS. CNTD 2993.000 -999.250 CRAT. CNAV -999.250 CNTC. CNAV -999.250 CRAT. CNAV -999.250 CNTC. CNAV -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREF1ENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... CNTG 9208.0 8859.0 $ LOG HEADER DATA DATE LOGGED: 23-SEP-97 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: 15 SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 8C0- 609 1617 23-SEP-97 9183.0 9170.0 8850.0 9167.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY CNTG COMPENSATED NUETRON $ TOOL NUMBER ........... SGT-L CNT-G BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 9560.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PUMPED IN CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6400 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): TIED INTO AWS BHCS DATED 2/28/82. PUMPED 403 BBLS CRUDE AND 10 BBLSMETHANOL LOGGED ON SANDSTONE MATRIX GOCAPPEARS AT 9085' THIS FILE CONTAINS THE RAW DATA FOR PASS #1. LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: 16 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... O0 000 O0 0 $ 1 1 4 68 0000000000 DEPT FT 1088212 NPHI PS1 PU 1088212 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1088212 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1088212 O0 000 O0 0 5 1 1 4 68 0000000000 RCNTPS1 CPS 1088212 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1088212 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1088212 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1088212 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1088212 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1088212 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1088212 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: 17 DEPT. 9170. 000 NPHI.PS1 RCNT. PS1 1681. 424 RCFT. PS1 GR.PS1 68.361 TENS.PSI DEPT. 8878.000 NPHI.PS1 RCNT. PS1 1354.646 RCFT. PS1 GR.PS1 43.953 TENS.PSI 29.136 RTNR.PS1 541.803 CNTC.PS1 3005.000 CCL.PS1 61.982 RTNR.PS1 235.449 CNTC. PS1 2993.000 CCL.PS1 3.196 TNRA.PS1 1658.848 CFTC.PSi 0.007 4.786 TNRA.PS1 1236.265 CFTC. PSI 0.711 3.001 544.940 4. 803 269. 872 ** END OF DATA ** * * * * FILE TRAILER * ** * FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUF~zARY VENDOR TOOL CODE START DEPTH ........................... CNTG 9181.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): STOP DEPTH .......... 8856.0 23-SEP-97 8C0-609 1617 23-SEP-97 9183.0 9170.0 8850.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: 18 BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 9167.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAFIMA RAY CNTG COMPENSATED NUETRON $ TOOL NUMBER ........... SGT-L CNT-G BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 8.500 9560.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PUMPED IN CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6400 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: TIED INTO AWS BHCS DATED 2/28/82. PUMPED 403 BBLS CRUDE AND 10 BBLS M~THANOL LOGGED ON SANDSTONE MATRIX GOC APPEARS AT 9085' THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: 19 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1088212 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1088212 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1088212 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1088212 O0 000 O0 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 1088212 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1088212 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1088212 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1088212 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1088212 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1088212 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1088212 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9170.000 NPHI.PS2 42.308 RTNR.PS2 3.717 TNRA.PS2 RCNT. PS2 1989.287 RCFT. PS2 519.869 CNTC.PS2 1950.293 CFTC. PS2 GR.PS2 72.449 TENS.PS2 3009.000 CCL.PS2 -0.018 3.723 552.522 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: 2O **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUFk~ARY VENDOR TOOL CODE START DEPTH ........................... CNTG 9186.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH .......... 8856.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY CNTG COMPENSATED NUETRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 23 -SEP-97 8C0- 609 1617 23-SEP-97 9183.0 9170.0 8850.0 9167.0 1800.0 TOOL NUMBER ........... SGT-L CNT~G 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: 21 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 9560.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PUMPED IN CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EP I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6400 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REM3~RKS: TIED INTO AWS BHCS DATED 2/28/82. PUMPED 403 BBLS CRUDE AND 10 BBLS METHANOL LOGGED ON SANDSTONE MATRIX GOC APPEARS AT 9085' THIS FILE CONTAINS THE RAW DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: 22 TYPE REPR CODE VALUE .............................. 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 I 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELI~'I CODE (HEX) ....................................................................................... DEPT FT 1088212 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1088212 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1088212 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1088212 O0 000 O0 0 7 1 1 4 68 0000000000 RCNTPS3 CPS 1088212 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1088212 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1088212 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1088212 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1088212 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1088212 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1088212 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9170.000 NPHI.PS3 41.931 RTNR.PS3 3.891 TNRA.PS3 RCNT. PS3 1971.988 RCFT. PS3 557.947 CNTC. PS3 1923.237 CFTC. PS3 GR.PS3 72.534 TENS.PS3 2977.000 CCL.PS3 -0.048 3.703 561.478 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-DEC-1997 10:16 PAGE: 23 * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 97/12/14 ORIGIN : FLIC TAPE NAME : 97532 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, PRUDHOE BAY, DS 14-29, API #50-029-20680-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/12/14 ORIGIN : FLIC REEL NAME : 97532 CONTINUATION # : PREVIOUS REEL : COM~IENT : ARCO ALASKA INC, PRUDHOE BAY, DS 14-29, API #50-029-20680-01 * ALASKA COMPUTING CENTER * *******************~********~* * ............................ * ....... SCHLUMBERGER ....... * ............................ COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D . S . 14 -29 FIELD NAME : PRUDHOE BAY BOROUGH '. NORTH SLOPE STATE : ALASKA API NUMBER : 500292068000 REFERENCE NO : 98602 RECEIVED NOV O6 1998 A~s~a ~ ~ ~as ~ns. Comm~ A~chorage LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/11/20 ORIGIN : FLIC REEL NAME : 98602 CONTINUATION # : PREVIOUS REEL : CO~94ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 14-29, API# 50-029-20680-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/20 ORIGIN : FLIC TAPE NAME : 98602 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 14-29, API# 50-029-20680-00 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NAME: D.S. 14-29 API NUMBER: 500292068000 OPERATOR: ARCO Alaska, Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 20-NOV- 98 JOB NUMBER: 98602 LOGGING ENGINEER: C.A. Yon OPERATOR WITNESS: Worthington SURFACE LOCATION SECTION: 9 TOWNSHIP: 1 ON RANGE: 14E FNL: 2224 FSL: FEL: 847 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 71. O0 DERRICK FLOOR: 70. O0 GROUND LEVEL: 40. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) iST STRING 8. 500 7. 000 9560.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEAS~ DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: DIL LDWG CURVE CODE: GR RUN NUMBER: PASS NUFIBER : DATE LOGGED: 28-FEB-82 LOGGING COMPANY: ATLAS BASELINE DEPTH 88888.0 9149.5 9149.0 9149.0 9146.5 9145.5 9145.5 9144.5 9144.0 9144.0 9133.0 9132.5 9132.5 9120.0 9120.0 9120.0 9115.0 9114.5 9114.5 9103.5 9104.5 9104.5 9095.0 9095.0 9095.0 9082.5 9083.0 9083.0 9069.0 9069.0 9069.0 9062.5 9063.5 9063.5 9046.5 9047.5 9047.5 9024.0 9024.0 9024.0 9011.5 9011.5 9011.5 8993.0 8993.0 8993.0 8980.0 8980.5 8980.5 8970.0 8970.0 8970.0 8965.5 8966.0 8966.0 8959.0 8959.0 8959.0 8948.5 8948.5 8948.5 8941.5 8942.0 8942.0 8924.0 8924.5 8924.5 8918.0 8919.0 8919.0 8911.5 8912.0 8912.0 8893.0 8894.0 8894.0 8875.0 8876.0 8876.0 100.0 101.0 101.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. 88887.5 88887.5 REM_ARKS: CONTAINED HEREIN IS THE CNTG DATA ACQUIRED ON ARCO ALASKA, INC. WELL D.S. 14-29 ON 2-AUG-98. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CNTG PASS #1 GRCH TO THE BASELINE GAMMA~Y PROVIDED BY THE CLIENT (GR.DIL); AND CNTG PASS #1 NPHI TO GR.DIL. ALL OTHER CNTG CURVES WBRE CARRIED WITH THE NPHI SHIFT. $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: **** FILE HEADER **** FILE NAFIE : EDIT .00I SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUF~iARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9153.0 8828.0 CNTG 9164.0 8828.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTG $ REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTG PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: TYPE REPR CODE VALUE .............................. 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 1 1 1 4 68 0000000000 DEPT FT 1239882 NPHI CNTG PU-S 1239882 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1239882 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 1239882 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 1239882 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 1239882 O0 000 O0 0 1 1 1 4 68 0000000000 EAHA~ CNTG 1239882 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 1239882 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 1239882 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 1239882 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1239882 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 1239882 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 1239882 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1239882 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 1239882 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTG V 1239882 O0 000 O0 0 1 1 1 4 68 0000000000 GR DIL GAPI 1239882 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9180.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA. CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS.CNTG -999.250 CCL.CNTG GR.DIL 29.306 DEPT. 8829.000 NPHI.CNTG 58.670 ENPH. CNTG 46.546 CPHI.CNTG NRAT. CNTG 4.488 CRAT. CNTG 4.621 ENRA.CNTG 6.174 NCNT. CNTG PCNT. CNTG 311.838 CNTC. CNTG 1427.424 CFTC. CNTG 336.013 CNEC. CNTG CFEC. CNTG 441.943 GRCH. CNTG 44.102 TENS. CNTG 3088.000 CCL.CNTG -999.250 -999.250 -999.250 -999.250 51.157 1435.681 2728.562 -1.279 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: GR.DIL -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ND!~BER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUF~4~LgY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9155.0 8828.0 CNTG 9166.0 8828.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTG ............................ 88888.0 88887.0 88887.5 9159.0 9158.5 9146.5 9145.5 9132.0 9131.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: 9127.5 9127.0 9119.5 9120.0 9115.0 9114.5 9110.0 9110.0 9109.5 9109.5 9104.5 9104.5 9098.5 9099.5 9096.5 9096.5 9094.5 9095.5 9082.5 9083.0 9079.5 9080.0 9078.0 9079.0 9071.0 9071.0 9069.0 9069.0 9064.0 9064.5 9060.5 9061.5 9058.5 9060.0 9053.5 9054.5 9049.5 9049.5 9046.5 9048.0 9029.5 9030.0 9023.0 9024.5 9022.0 9022.0 9014.0 9014.5 9000.5 9000.5 8992.5 8992.5 8989.0 8989.0 8980.0 8980.5 8970.0 8970.0 8964.5 8965.0 8955.5 8955.5 8948.5 8948.5 8941.0 8941.5 8937.0 8937.0 8924.0 8924.5 8918.0 8919.0 8919.0 8909.0 8909.5 8907.0 8909.0 8903.0 8904.0 8897.0 8898.5 8895.0 8896.0 8893.0 8894.0 8892.0 8892.0 8879.5 8881.5 8870.0 8871.0 8851.0 8851.5 8848.0 8849.0 8844.0 8845.0 100.0 101.0 101.0 $ THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #2 GRCH TO PASS #1 GRCH; AND PASS #2 NPHI TO PASS #1 NPHI. ALL OTHER CNTG CURVES WERE CARRIED WITH THE LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: NPHI SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 2 1 1 4 68 0000000000 DEPT FT 1239882 NPHI CNTG PU-S 1239882 O0 000 O0 0 2 i 1 4 68 0000000000 ENPH CNTG PU-S 1239882 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 1239882 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 1239882 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 1239882 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1239882 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 1239882 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 1239882 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 1239882 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1239882 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 1239882 O0 000 O0 0 2 1 1 4 68 0000000000 CFECCNTG CPS 1239882 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 1239882 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 1239882 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 1239882 O0 000 O0 0 2 i 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: ** DATA ** DEPT. 9165.500 NPHI. CNTG 28.875 ENPH. CNTG NRAT. CNTG 3. 065 CRAT. CNTG 2. 987 ENRA. CNTG FCNT . CNTG 702.273 CNTC . CNTG 1932 . 786 CFTC. CNTG CFEC. CNTG 580.158 GRCH. CNTG - 999.250 TENS. CNTG 28.117 CPHI.CNTG 4. 464 NCNT. CNTG 679.109 CNEC . CNTG 3015. 000 CCL. CNTG 27.943 2114.243 2589.928 -0.230 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUMFiARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9155.0 8808.0 CNTG 9166.0 8808.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NI]FIBER : 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTG LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: 88888.0 9156.5 9149.0 9146.5 9142.5 9131.5 9125.5 9119.0 9114.5 9109.0 9095.0 9089.0 9085.5 9082.0 9068.5 9066.0 9060.0 9058.5 9052.5 9046.5 9029.0 9023.5 9013.5 9011.5 8992.5 8991.5 8979.5 8967.5 8958.5 8952.5 8948.0 8941.0 8940.5 8924.0 8917.5 8908.0 8903.0 8894.5 8892.5 8880.5 8880.0 8869.5 8856.5 8854.O 8847.5 100.0 $ 88888.0 88888.0 9149.0 9146.0 9142.5 9131.5 9125.0 9120.0 9114.5 9095.5 9083.0 9069.0 9060.0 9053.5 9047.5 9030.0 9024.0 8993.0 8980.5 8968.0 8958.5 8948.5 8941.5 8924.5 8919.0 8904.0 8894.0 8882.5 8858.0 8849.5 102.0 9156.5 9126.5 9110.0 9089.5 9086.5 9066.5 9061.5 9014.5 9011.5 8992.0 8953.0 8941.5 8925.0 8919.0 8909.0 8896.0 8881.5 8871.0 8855.5 101.5 THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT PASS #3 GRCH TO PASS #1 GRCH; AND PASS #3 NPHI TO PASS #1 NPHI. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: 10 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 3 1 I 4 68 0000000000 DEPT FT 1239882 NPHI CNTG PU-S 1239882 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1239882 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1239882 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 1239882 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 1239882 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1239882 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1239882 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTG CPS 1239882 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1239882 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1239882 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 1239882 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1239882 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 1239882 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1239882 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 1239882 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: 11 ** DATA ** DEPT. 9166.000 NPHI. CNTG 28.272 ENPH. CNTG 25.546 CPHI. CNTG NRA T. CNTG 3.143 CRA T. CNTG 2.954 EJFRA. CNTG 4.186 NCNT. CNTG FCNT. CNTG 762.425 CNTC. CNTG 2095.177 CFTC. CNTG 742.962 CNEC. CNTG CFEC. CNTG 645. 824 GRCH. CNTG -999. 250 TENS. CNTG 3062. 000 CCL. CNTG DEPT. 8809. 500 NPHI. CNTG 63. 932 ENPH. CNTG NRA T . CNTG 5.276 CRA T . CNTG 4.910 ENRA . CNTG FCNT. CNTG 271 . 823 CNTC. CNTG 1360. 311 CFTC. CNTG CFEC. CNTG 399.636 GRCH. CNTG -999.250 TENS. CNTG 51.622 CPHI.CNTG 6.572 N CNT. CNTG 282.938 CNEC. CNTG 2991. 000 CCL. CNTG 27. 550 2270. 479 2703. 571 -0.193 72.104 1381. 379 2626. 422 -2. 477 ** F_iVD OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, CNTG REMARKS: THE ARITHFIETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: 12 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1239882 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1239882 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1239882 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 1239882 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1239882 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 1239882 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNAV 1239882 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1239882 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1239882 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1239882 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1239882 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 1239882 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 1239882 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 1239882 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9163.500 NPHI.CNAV 26.582 NRAT. CNAV 2.969 CPHI.CNAV CRAT. CNA V 2. 861 ENPH. CNAV 32. 142 ENRA. CNAV 4. 878 NCNT. CNAV FCNT. CNAV 624. 909 CNTC. CNAV 1826. 176 CFTC. CNAV 633. 335 CNEC. CNAV CFEC. CNAV 508 . 383 GRCH. CNTG -999. 250 28.513 1881.703 2479.515 LI~ Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: 13 DEPT. 8829.000 NPHI. CNAV 59.399 NRAT. CNAV CRAT. CNAV 4.661 ENPH. CNAV 52.114 ENRA. CNAV FCNT. CNAV 315.216 CNTC. CNAV 1427.684 CFTC. CNAV CFEC.CNAV 414.984 GRCH. CNTG 44.102 4.669 CPHI.CNAV 6.601 NCNT. CNAV 331.812 CNEC. CNAV 52.756 1416.264 2733.560 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE S~Y VENDOR TOOL CODE START DEPTH ........................... CNTG 9186.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~E LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH .......... 8825.5 2-AUG-98 8C1-205 1813 2-AUG-98 9208.0 9172.0 8825.0 9172.0 1800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: 14 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY CNTG COMP. NEUTRON $ TOOL NUMBER ........... SGT-L CNT-G BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 8.500 9560.0 BOREHOLE COArDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T1E~IPERATURE (DEGF) : BOTTOM HOLE T~PERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Crude NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6400 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: This log was depth referenced to a SWS CNT-G, dated 09/23/97. Logging procedure: Sandstone Matrix Pumped 345 BBLS crude to kill well Pass #1 made w/345 BBLS away & 300 psi WHP. Pass #2 made w/366 BBLS away & 300 psi WHP. Pass #3 made w/383 BBLS away & 300 psi WHP. Pumped a total of 395 BBLS away & 5 BBLS diesel to freeze protect. THIS FILE CONTAINS THE RAWCNTG DATA FOR PASS #1. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: 15 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 1239882 O0 000 O0 0 5 I 1 4 68 0000000000 TNRA PS1 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA PS1 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC PS1 CPS 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC PS1 CPS 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PS1 CPS 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 RCEN PS1 CPS 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 RCNTPS1 CPS 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR PS1 PU 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1239882 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: 16 ** DATA ** DEPT. 9186.500 NPHI.PS1 31.419 ENPH. PS1 22.407 TNPH. PS1 TNRA.PS1 3.126 RTNR.PS1 3.200 ENRA.PS1 3.832 CFEC. PS1 CNEC. PS1 2820.326 RCEF. PS1 745.508 RCEN. PS1 2665.922 RCNT. PS1 RCFT. PS1 620.271 CNTC. PS1 1974.644 CFTC. PSi 644.793 NPOR.PS1 GR.PS1 44.308 TENS.PSI 2314.000 CCL.PS1 -0.189 DEPT. 8825.000 NPHI.PS1 50.995 ENPH. PS1 43.527 TNPH. PS1 TNRA.PS1 4.200 RTNR.PSi 4.200 ENRA.PS1 5.924 CFEC. PS1 CNEC. PS1 2775.610 RCEF. PS1 515.446 RCEN. PS1 2738.392 RCNT. PS1 RCFT. PS1 345.882 CNTC. PS1 1470.125 CFTC. PSi 347.755 NPOR.PS1 GR.PS1 46.032 TENS.PSi 3099.000 CCL.PS1 -999.250 31.251 736.033 2016.078 31.251 50.686 468.532 1643.000 45.915 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUF1BER : 2 DEPTH INCREMENT: 0.5000 FILE SUM~L~RY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... CNTG 9210.0 8826.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: 17 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 2-AUG-98 8Cl-205 1813 2 -AUG- 98 9208.0 9172.0 8825.0 9172.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTG COMP. NEUTRON $ TOOL NUMBER ........... SGT-L CNT- G BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 8.500 9560.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Crude NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6400 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: This log was depth referenced to a SWS CNT-G, LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: 18 dated 09/23/97. Logging procedure: Sandstone Matrix Pumped 345 BBLS crude to kill well Pass #1 made w/345 BBLS away & 300 psi WHP. Pass #2 made w/366 BBLS away & 300 psi WHP. Pass #3 made w/383 BBLS away & 300 psi WHP. Pumped a total of 395 BBLS away & 5 BBLS diesel to freeze protect. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1239882 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1239882 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1239882 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 1239882 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1239882 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1239882 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA PS2 1239882 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 1239882 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 1239882 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: 19 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... RCEF PS2 CPS 1239882 O0 000 O0 0 6 1 1 4 68 RCEN PS2 CPS 1239882 O0 000 O0 0 6 1 1 4 68 RCNT PS2 CPS 1239882 O0 000 O0 0 6 1 1 4 68 RCFT PS2 CPS 1239882 O0 000 O0 0 6 1 1 4 68 CNTC PS2 CPS 1239882 O0 000 O0 0 6 1 1 4 68 CFTC PS2 CPS 1239882 O0 000 O0 0 6 1 1 4 68 NPOR PS2 PU 1239882 O0 000 O0 0 6 1 1 4 68 GR PS2 GAPI 1239882 O0 000 O0 0 6 1 1 4 68 TENS PS2 LB 1239882 O0 000 O0 0 6 1 1 4 68 CCL PS2 V 1239882 O0 000 O0 0 6 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 9210.000 NPHI.PS2 24.889 ENPH. PS2 38.542 TNPH. PS2 TNRA.PS2 2.768 RTNR.PS2 2.833 ENRA. PS2 5.487 CFEC. PS2 CNEC. PS2 2769.780 RCEF. PS2 511.260 RCEN. PS2 2618.144 RCNT. PS2 RCFT. PS2 769.408 CNTC.PS2 2169.631 CFTC. PS2 799.827 NPOR. PS2 GR.PS2 28.571 TENS.PS2 2183.000 CCL.PS2 -0.212 DEPT. 8825.500 NPHI.PS2 53.225 ENPH. PS2 46.287 TNPH. PS2 TNRA.PS2 4.322 RTNR.PS2 4.371 ENRA.PS2 6.153 CFEC. PS2 CNEC.PS2 2673.605 RCEF. PS2 453.063 RCEN. PS2 2568.169 RCNT. PS2 RCFT.PS2 338.301 CNTC. PS2 1416.143 CFTC. PS2 333.485 NPOR.PS2 GR.PS2 48.551 TENS.PS2 2956.000 CCL. PS2 -999.250 25.942 504.762 2215.157 25.942 51.119 434.520 1531.697 48.015 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: 20 FILE HEADER FILE BT]MBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMFIARY VENDOR TOOL CODE START DEPTH CNTG 9192.0 $ LOG HEADER DATA STOP DEPTH .......... 8806.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 2-AUG-98 8C1-205 1813 2-AUG-98 9208.0 9172.0 8825.0 9172.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY CNTG COMP. NEUTRON $ TOOL NUMBER SGT-L CNT-G BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 8.500 9560.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Crude NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: 21 TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6400 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REd, ARKS: This log was depth referenced to a SWS CNT-G, dated 09/23/97. Logging procedure: Sandstone Matrix Pumped 345 BBLS crude to kill well Pass #I made w/345 BBLS away & 300 psi WHP. Pass #2 made w/366 BBLS away & 300 psi WHP. Pass #3 made w/383 BBLS away & 300 psi WHP. Pumped a total of 395 BBLS away & 5 BBLS diesel to freeze protect. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: 22 ** SET TYPE- CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... DEPT FT 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 ENPH PS3 PU 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS3 PU 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 ENRA PS3 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC PS3 CPS 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC PS3 CPS 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 RCEF PS3 CPS 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 RCEN PS3 CPS 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 RCNTPS3 CPS 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PS3 PU 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1239882 O0 000 O0 0 7 1 I 4 68 0000000000 TENS PS3 LB 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1239882 O0 000 O0 0 7 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 9192.000 NPHI.PS3 31.419 ~PH. PS3 34.026 TNPH. PS3 TNRA.PS3 3.126 RTNR.PS3 3.200 ENRA.PS3 5.064 CFEC. PS3 CNEC. PS3 3200.077 RCEF. PS3 640.123 RCEN. PS3 3024.883 RCNT. PS3 RCFT. PS3 640.123 CNTC. PS3 2038.871 CFTC. PS3 665.431 NPOR.PS3 GR.PS3 45.714 TENS. PS3 2282.000 CCL.PS3 -0.215 DEPT. 8805.500 NPHI.PS3 58.143 ENPH. PS3 54.069 TNPH. PS3 TNRA.PS3 4.592 RTNR.PS3 5.033 ENRA.PS3 6.755 CFEC. PS3 CNEC.PS3 2698.414 RCEF. PS3 398.418 RCEN. PS3 2507.220 RCNT. PS3 RCFT. PS3 280.598 CNTC. PS3 1394.441 CFTC. PS3 298.913 NPOR.PS3 GR.PS3 45.429 TENS.PS3 3044.000 CCL. PS3 -999.250 31.275 631.987 2081.653 31.275 65.254 399.491 1336.052 69.606 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-NOV-1998 16:37 PAGE: 23 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/11/20 ORIGIN : FLIC TAPE NAME : 98602 CONTINUATION # : 1 PREVIOUS TAPE : COMIVlENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 14-29, API# 50-029-20680-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/11/20 ORIGIN : FLIC REEL NAME : 98602 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 14-29, API# 50-029-20680-00
