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Home My WebLink About182-018 a22_pop_12-3-02, txt. subject: Returning PBU Wells 05-08 and A-22 to production oate: Thu, 50ec 2002 13:21:08 -0600 From: "NSU, ADW Well Integrity Engineer" <NSUADWWel 1 Integ ri tyEngi nee r~BP. corn> To: Tom_Maunder~admi n. state, ak. us, Bob_F1 eckenstei n~admi n. state, us, ,,] i m_Regg~admi n. state, ak. us cc' NSU, ADW well Operations Supervisor" <NSUADWWel 10perati onsSupervi sor@BP, corn>, "Rossberg, R Steven" <RossbeRS~BP. com> Gentlemen, The following "A" category well has been returned to production: DS 05-08 (on line 12/04/02 ~ 11:00). Attached please find the test records that demonstrate the two competent barriers required to produce this well. In addition, well A-22 was returned to production 12/03/02 at 13:00. with its recent workover, A-22 is no longer designated as a category "A" well. During the workover, the new tubing string was tested to 3500 psi and the inner annulus was tested to 3000 psi. Both tests passed. Dave Reem for Joe Anders 659-5102 Mobil: 943-1154 Pager: 659-5100, x1154 Name: 05-08 MIT 09-19-02.xls 05-08 MIT 09-19-02.xls Type: Microsoft Excel worksheet (appl i cati on/vnd, ms-excel ) Encoding: base64 Name: 05-08 TIFL 11-16-02.xls 05-08 TIFL 11-16-02,xl s Type: Microsoft Excel worksheet (appl i cati on/vnd, ms-excel ) Encoding: base64 Name: BP well 05-08 MIT 11-24-02.xl s BP well 05-08 MIT 11-24-02.xl s Type: Microsoft Excel worksheet (appl i cati on/vnd, ms-excel ) Encoding: base64 Page 1 ALASKA OIL AND GAS CONSERVATION COMMISSION su m' 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 76.7' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2298' NSL, 1704' WEL, SEC. 35, T11N, R13E, UM A-22 At top of productive interval 9. Permit Number / Approval No. 182-018 302-289 3425' SNL, 4208; WEL, SEC. 02, T10N, R13E, UM 10. APl Number At effective depth 50- 029-20712-00 3516' SNL, 4261' WEL, SEC. 02, T10N, R13E,UM 11. Field and Pool At total depth Prudhoe Bay Field / Prudhoe Bay 3835' SNL, 4445' WEL, SEC. 02, T10N, R13E, UM Pool 12. Present well condition summary Total depth: measured 12316 feet Plugs (measured) true vertical 9598 feet Effective depth: measured 11601 feet Junk (measured) Top of sand at 11601', IBP at 11670 true vertical 8985 feet Casing Length Size Cemented M D TVD Structural Conductor 110' 20" X 30" 8 CU yds concrete, Top Job: 140 cu ft PF 'C' 110' 110' Surface 2705' 13-3/8" 3720 cuft Permafrost II 2705' 2689' Intermediate 11401' 9-5/8" 1633 cu ft Class 'G', 130 cu ft PF 'C' 11401' 8819' Production Remedial Cmt: 870 cuft PF 'E' & 84 cu ft PF 'C' Liner 1430' 7" 432 cu ft Class 'G' 10886' - 12316' 8411' - 9598' Liner Tieback 10870' 7" N/A 10897' 8419' Perforation depth: measured Open: Sag River: 11414'- 11434'; Ivishak: 11531'- 11601', 11608'- 11617', 11623'- 11662' Sqzd: 11444' - 11446' true vertical Open: Sag River: 8830' - 8846'; Ivishak: 8926' - 8985', 8991' - 8999', 9004' - 9037' Sqzd: 8854'- 8856' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13Cr80 to about 10923' Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker 'JMZX' packer at 10882'; 7" x 4-1/2" Baker 'S-3' packer at 10866'; 4-1/2" HES 'X' Nipple at 2196' D I~ r' L" ! ~ J r" ~ 13. Stimulation or cement squeeze summary See attached summary. I~ I., ~ L ! V r ~ Intervals treated (measured) oCT 2 5 2OO2 Treatment description including volumes used and final pressure Naska 0il.& Gas Cons. Commission Anchorag~ 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations ,, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ ~ Title Technical Assistant Date j ~)' ~,,~,' (~)'~ · ~ Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Well: A-22 RWO Rig Accept: 09/14/02 Field: Prudhoe Bay Unit Rig Spud: N/A APl: 50-029-20712-00 Rig Release: 10/08/02 Permit: 182-018 Drillin~l Rig: Nabors 2ES PRE-RIG WORK 08/17/02 SET 2.125" BAKER IBP MID ELEMENT @10290', FISHING NECK 1.375" JDC @10280'. IBP SERIAL NUMBER 10013840. 08/18/02 REPAIR/REPLACE BURNED TREE FROM 8/16/02 INCIDENT. PULLED OLD 4" TREE & TBG HEAD ADAPTER. INSTALL NEW SEALS ON HGR NECK, PLACE STICK PLASTIC IN TBG HGR VOID & INSTALLED 'B' CONDITION TBG HEAD ADAPTER & 2 'B' CONDITION MASTER VALVES ON WELL - TESTED TO 3500. REPLACE IA/OA VALVES ON SPOOLS - LEFT 1 'B' CONDITION VALVE ON TBG SPOOL & 1 ON THE CSG HEAD - TESTED TO 3000 PSI. 08/19~02 FREEZE PROTECT WELL TO 2500 WITH 60/40 MEOH. RDMO. EVALUATE SURFACE CASING WITH NITROGEN TEST. 08/20/02 RAN BOROSCOPE CAMERA DOWN OA X CONDUCTOR, LEAK HUNT (UNSUCCESSFUL). 08/21/02 CONTINUE BAROSCOPE CAMERA JOB, FLUSH CONDUCTOR WITH HOT SOAPY WATER. O8/22/O2 BAROSCOPE CAMERA BETWEEN OA AND CONDUCTOR. FOUND WHAT APPEARS TO BE SPLIT IN OA CASING PIPE. TOP OF FLUID IN CONDUCTOR AT 17' 7". HARD BOTTOM IN CONDUCTOR AT 20'. RAN CAMERA DOWN CONDUCTOR PIPE TO 16' 2" AND FOUND WHAT APPEARS TO BE THE TOP OF A SPLIT IN THE OA CASING. FOLLOWED THE SPLIT DOWN TO FLUID LEVEL IN CONDUCTOR PIPE. SPLIT IN PIPE APPEARED TO GET LARGER AS WE WENT DOWN. 09/06/02 RIGGED UP BOTH IMPACT AND TORQUE ELIMINATOR WRENCHES. CYCLE AND RETORQUED ALL LOCKDOWN SCREWS ON TUBING HEAD FLANGE AND CASING HEAD FLANGE. CMIT- T X IA TO 2500 PSI FAILED. (RIG PREP). 09/07/02 FUNCTION TEST TUBING AND lC HANGER LDS (PRE-RWO). CAMERON SUCCESSFULLY CYCLED ALL THE TUBING HANGER LDS EXCEPT ONE - IT'S TWISTED ONE FULL TURN, WOULD NOT BUDGE. lC HANGER LDS ALL FUNCTIONED OKAY. RECOMMEND GRINDING THE STUCK LDS NOSE OFF ONCE THE TUBING HEAD ADAPTER IS PULLED. DRIFT W/2.5" CENT TO IBP AT 10265' SLM. TURN WELL OVER TO PAD OPERATOR LEAVE SI. 09/08/02 SHOT STRING SHOT AT 10187' - 10198'. CUT TBG @ 10196' WITH 2.625" CHEM CUTTER. BP EXPLORATION Page-1 of 13 Operations Sumrna Report Legal Well Name: A-22 Common Well Name: A-22 Spud Date: 4/14/1982 Event Name: WORKOVER Start: 9/11/2002 End: 10/8/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 10/8/2002 Rig Name: NABORS Rig Number: 2ES Date From -To Hours Task Code NPT Phase Description of Operations ..... 9/10/2002 17:00 - 00:00 7.00 MOB P PRE RD on H-02. Move camp and pits to A-22. 9/11/2002 00:00 - 06:00 6.00 MOB P PRE Move rig off of H-02A well. Move down Pad, had a spill of hydraulic fluid spraying out of containment area and dripping onto gravel pad. Notify Environmental group. Cleanup all oily gravel. 06:00 - 21:00 15.00 MOB P PRE Move rig. Rig broke through A-Pad access road at 2100 hours.. 21:00 - 06:00 9.00 MOB C PRE Jackup rig, pickup plywood matting boads, begin laying composite matting boards. 9/12/2002 00:00 - 09:00 9.00 MOB C PRE Lay sand bags and crib under the tires to get rig up onto mats. Attempt to back up rig, and the road fell through under the front tires. Crib up with addidional sandbags and wood. Latch onto rig with two (2) DSN bulldozers, pull and backout free to the intersection of roads to A and-B pads. 09:00 - 12:00 3.00 MOB C PRE Move rig to the A-Pad access road at D-Pad. 12:00 - 20:00 8.00 MOB C PRE Lay Mats on access roads from D to A pad. Locate buried utilidor on D Pad. 20:00 - 20:30 0.50 MOB C PRE Move rig down access road without problems (est. 1/3 to 1/2 way). 20:30 - 00:00 3.50 MOB C PRE Haul rig mats around to the front of the rig via D-Pad and the A-Pad access road. 9/13/2002 00:00 - 00:00 24.00 MOB C PRE Continue moving Rig 2ES down the A-Pad access road. PJSM. RU discharge lines to Vac truck, RU to 13-3/8" x 20" annulus. Flush OA with 207 bbls of clean water, at 0.5-1.5 BPM. Returns clean. RD Vac trucks. RU welding equipment. PJSM. Weld cap on well, to the 30" conductor pipe. 9/14/2002 00:00 - 12:00 12.00 MOB C PRE Move rig mats and move rig forward onto A-Pad. Re-install doghouse stairs, Beaver Slide, Motor room and Pipe Shed stairs. Continue welding cover plate on Landing ring to seal annuli. LD herculite, spot sub base and pits. Trim Herculite. 12:00 - 12:30 0.50 RIGU C PRE Spot cuttings tank. Take on seawater to pits. 12:30 - 13:30 1.00 RIGU C PRE Raise and pin derrick. 13:30 - 15:00 1.50 RIGU C PRE Bridle down and pin Top Drive to the Blocks. Hang Bridle lines. 15:00 - 16:00 1.00 RIGU C PRE RU drill floor. 16:00 - 18:30 2.50 RIGU P PRE Install secondary annulus valve, hook up hoses to circulate out freeze protect. ' 18:30 - 19:30 1.00 RIGU P PRE Inspect rig, hold pre-spud mtg with crew. ~ 19:30 - 00:00 4.50 WHSUR P DECOMP Line cellar box with absorbant and Herculite. Reverse circulate 35 bbls (diesel plus methanol), from tbg at 4 BPM and 920 psi. Swap hoses and pump 50 bbl Con-Det sweep at 5 BPM and 1,380 psi. Circulate hole clean. NOTE: Rig accepted at 1200 hrs, Sep 14, 2002. Time was backed up to account for time reassembling Beaver Slide and various stairways. 9/15/2002 00:00 - 01:30 1.50 WHSUR P DECOMP Continue sweeping the hole from 10,196', with 140 deg seawater at 5 BPM and 1,280 psi. Pressure built to 920 psi on the outer annulus. Bled down to zero, gas, water, and Arctic Pack in returns. 01:30 - 02:00 0.50 WHSUR P DECOMP Set TWC and test from below to 2,000 psi. Outer annulus increased from 0-600 psi. Bleed off pressure with gas, water :and Arctic Pack returns. Blow down circulating lines. Printed: 10/14/2002 9:45:41 AM BP EXPLORATION Page 2 of 13 Operations Summary Report Legal Well Name: A-22 ~Common Well Name: A-22 Spud Date: 4/14/1982 'Event Name: WORKOVER Start: 9/11/2002 End: 10/8/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 10/8/2002 Rig Name: NABORS Rig Number: 2ES Date From- To Hours Task Code NPT Phase Description of Operations 9/15/2002 02:00 - 04:00 2.00 WHSUR = DECOMP PJSM. ND tree. Verify hanger threads are 4-1/2" BTC. Clean out old plastic packing material from top of hanger. Grind off the nose of one lock down screw. Pack LDS with plastic packing. 04:00- 06:00 2.00 WHSUR = DECOMP PJSM. NU BOPE. 06:00 - 12:00 6.00 WHSUR = DECOMP Test BOPE 250 / 3,500 psi for 5/5 min: Top Pipe Ram w/ 3-1/2" x 6" Variable Rams, Blind Ram, Mud Cross, Lower Pipe Rams w/2-7/8" x 5" Variable Rams, Lower Mud Cross. Tested Blind Rams, Choke Manifold, HCR, Kill and Choke lines, IBOP. Test of Annular preventer failed. Testing witnessed by John Crisp of the AOGCC. 12:00 - 17:00 5.00 WHSUR P DECOMP Change out Annular preventer. 17:00 - 18:00 1.00 WHSUR P DECOMP Test Annular preventer, outside Mud Cross, dart valve to 250 / 3,500 psi for 5/5 mi. - okay. Testing witnessed by John Crisp of the AOGCC. 18:00 - 21:30 3.50 PULL P DECOMP RU lubricator and made multiple attempts to pull TWC. LD lubricator, PU one joint of 5" DP, RIH and wash top of TWC. Recovered a small amout of plastic sealant used on the wellhead. POH, LD 5" DP, PU lubricator and retrieve TWC. 21:30 - 22:00 0.50 PULL P DECOMP Screw into and pull hanger to floor with UWT= 100K. (estimated, hanging, bouyed string wt. = 85K) 22:00 ~ 23:00 1.00 PULL P DECOMP RU Control line spooling equipment, and casing equipment. Wrap in plastic, mark and, LD Tbg hanger gently. 23:00 - 00:00 1.00 PULL P DECOMP POOH laying down 3-1/2" tbg. 9/16/2002 00:00 - 03:00 3.00 PULL P DECOMP Pull 65 joints of 3-1/2", 9.3 lb/fi, L-80, AB-M EUE tbg, SSSV, and dual encapsulated control lines. 03:00 - 04:00 1.00 PULL P DECOMP Sweep hole at 13 BPM and 730 psi.. (Approx. 50% of the encapsulation for the control lines was off, or breaking off when it was being pulled). RD control line spooling unt. 04:00 - 04:30 0.50 PULL P DECOMP Service Top Drive. 04:30 - 13:30 9.00 PULL P DECOMP Continue POOH, laying down 3-1/2" tbg. Recovered 316 joints plus 6.47' cutoff. (cut was clean). LD 5 five GLMs. 13:30 - 14:30 1.00 PULL P DECOMP LD csg handling tools. Clear and clean rig floor. 14:30 - 16:00 1.50 WHSUR P DECOMP PU one joint of 5" DP and test Upper and Lower Pipe Rams, plus Annular Preventer, to 250 / 3,500 psi, for 5/5 minutes. 16:00 - 17:00 1.00 DUMRN P INTERV PU 9-5/8" Pack-off running tool. RIH and verify casing hanger is a mandrel type of hanger. Install Wear Ring. 17:00 - 17:30 0.50 WHSUR P INTERV Hook up hoses from annulus valve to the cuttings tank. 17:30 - 18:00 0.50 ZONISO P INTERV PU mechanical set Retrievable Bridge Plug (Max OD = 8.25"). 18:00 - 19:00 1.00 ZONISO P INTERV RIH and tag up on obstruction in casing at 46' below Rig Floor. (-19' GL). PU, unseat RBP, RIH and tag up at 46'. POOH, LD RBP. 19:00 - 19:30 0.50 ZONISO P INTERV PU 8-1/2" tri-cone bit (while waiting on swages), RIH and tag up on obstruction at 46'. 19:30 - 22:30 3.00 CLEAN P INTERV PU 8.0" swage and two 6-1/4" DC. RIH and Tag up on obstruction at 47'. Swage through tight area between 47' - 53'. LD 8.0" swage and PU 8.375" swage. RIH and attempt to swage past 47' - NO-GO. 22:30 - 00:00 1.50 CLEAN P INTERV PU 6x6-3/4" DC, 8.25" swage, bumper-sub, plus 2x 8" DC above the swage. 9/17/2002 00:00 - 00:30 0.50 CLEAN P INTERV Continue to PU 6 x 6-3/4" DC, 8.25" swedge, bumper-sub, plus 2 x 8" DC above the swedge. 00:30 - 01:00 0.50 CLEAN P INTERV RIH, tag up at 47', swedge 9-5/8" csg to 8.25" from 47' - 54'. Printed: 10/14/2002 9:45:41 AM BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: A-22 Common Well Name: A-22 Spud Date: 4/14/1982 Event Name: WORKOVER Start: 9/11/2002 End: 10/8/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 10/8/2002 ~Rig Name: NABORS Rig Number: 2ES Date From -To Hours Task Code NPT Phase Description of Operations 9/17/2002 00:30 - 01:00 0.50 CLEAN P INTERV DWT= 50K (including blocks). 01:00 - 02:00 1.00 CLEAN ~ INTERV LD 8.25" swedge, PU 8.375" swedge. Worked thru constricted area from 47' - 54' - okay. Continue to work tight area, could not pass thru again. LD 8.375" and PU 8.25" swage again. 02:00 - 02:30 0.50 CLEAN ~ INTERV Swedge 47' - 54' with 8.25" swedge. Made 3 successful ~asses. 02:30 - 03:00 0.50 CLEAN ~ INTERV Circulate 100 deg seawater around @ 13 BPM / 270 psi 03:00 - 03:30 0.50 CLEAN = INTERV LD 8.25" swedge. PU 8.375" swedge and work 47' to 54' area. Made 5 passes. !03:30 - 04:00 0.50 CLEAN = INTERV LD 8.375" swedge and PU 8.50". '04:00 - 04:30 0.50 CLEAN = INTERV Work 8.50" swedge 47'-50'. Could not go past 50'. ,04:30 - 05:00 0.50 CLEAN = INTERV Circulate 104 deg heated seawater @ 13 BPM / 250 psi 05:00 - 06:00 1.00 CLEAN = INTERV LD 8.50" swedge, MU 8.375" swedge. Work thru tight area 47' to 54'. 06:00 - 07:00 1.00 CLEAN = INTERV LD 8.375" swedge & PU 8.50" Work 47'-50'. Could not go past 50'. 07:00 - 08:00 1.00 CLEAN P INTERV LD 8.50" swedge. PU 8.375" swedge and work 47' to 54' area. 15k down drag, 20k overpull. 08:00 - 10:30 2.50 CLEAN P INTERV Circulate 108 deg seawater around @ 13 BPM / 260 psi. I Service Top Drive, adjust brakes 10:30 - 11:00 0.50 CLEAN P INTERV Work 8.375" swedge thru 47' to 54' area. 15k down drag, 20k overpull. 11:00 - 11:30 0.50, CLEAN P INTERV Inspect derrick, crown & Top Drive after jarring operations. 11:30 - 13:30 2.00 CLEAN 'P INTERV LD 8" DC's, rack back 6.25" DC's. LD swedge, clear rig floor. 13:30 - 15:00 1.50 CLEAN P INTERV Test 9 5/8" csg to 2070 psi/30 mins. Loss 45 psi. 15:00 - 17:30 2.50 FISH P INTERV PU & MU fishing BHA for IBP. 17:30 - 18:00 0.50 FISH P INTERV Circ thru BHA 0.8 BPM @ 380 psi. 18:00 - 00:00 6.00 FISH P INTERV RIH w/fishing BHA on 5" DP from pipe shed @ 7293 ft. Up wt 150k, Dn wt 135k 9/18/2002 00:00 - 02:30 2.50 FISH P INTERV RIH w/fishing BHA on 5" DP from pipe shed. Btm out on bushing on 3 1/2" tbg stump @ 10,182 ft. Up wt 200k, Dn wt 165k 02:30 - 03:00 0.50 FISH P INTERV PU to 10,177 ft. Est pump rate of 0.85 BPM w/680 psi. MU TIW valve in string. 03:00 - 04:00 1.00 FISH P INTERV Release bushing w/7 turns. Work fishing assy over 3 1/2" tbg stump & push IBP to 10,342 ft. Btm string out on 4 3~4" XO on top of 3 1/2" tbg stump @ 10,182 ft. 04:00 - 05:00 1.00 FISH P INTERV POH to 10,145 ft. Drop dart & open circ sub w/900 psi. (utilze TIW valve to drop dart in a closed system as a precaution) 05:00 - 05:30 0.50 FISH P INTERV Bullhead 90 bbls @ 3 BPM / 1800 psi to displace wellbore of formation fluids. Confirm IBP released. 05:30 - 06:15 0.75 KILL P INTERV Observe well flowing. Shut in well, monitor following pressures. SIDPP 610 psi, SICP 610 psi in 20 mins, fell to 430 psi in 15 mins. Bleed off pressure manually to 0 psi. 06:15 - 06:45 0.50 KILL P INTERV Shut in well, monitor following pressures. SIDPP 250 psi, SlCP 250 psi in 10 mins, fell to 210 psi in 10 rains. Bleed off pressure manually to 0 psi. 06:45 - 07:30 0.75 KILL P INTERV Shut in well, monitor following pressures. SIDPP 100 psi, SICP 100 psi in 5 mins, fell to 90 psi in 10 mins. Bleed off pressure manually to 0 psi. Shut in well, observe no pressure build up for 10 mins, open well observe well static for 30 mins. 07:30 - 08:30 1.00 EVAL P INTERV Circ well @ 13 BPM / 780 psi for total 200 bbls. Shut down Printed: 10/14/2002 9:45:41 AM BP EXPLORATION Page4 of 13 Operations Summary Report Legal Well Name: A-22 Common Well Name: A-22 Spud Date: 4/14/1982 Event Name: WORKOVER Start: 9/11/2002 End: 10/8/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 10/8/2002 Rig Name: NABORS Rig Number: 2ES Date From -To Hours Task Code NPT Phase Description of Operations 9/18/2002 07:30 - 08:30 1.00 EVAL 'P INTERV pumps monitor well flowing. 08:30 - 11:00 2.50 KILL P INTERV Shut in well, monitor following pressures. SIDPP 20 psi, SlCP 140 psi in 10 mins. Circ well thru 1/2" choke @ 3 BPM / 70 psi back pressure. Open choke to 100%, circ total 110 bbls w/5 bbls lost to formation. Shut in well. Observe no build up. Open well monitor for 1 hr observe gas breaking out at surface, no flow. 11:00 - 17:30 6.50 EVAL P INTERV Cir¢ well @ 2.5 BPM / 40 psi. Shut down pumps, observe well static. (lost 15 bbls) 17:30 - 22:00 4.50 FISH P INTERV POH to BHA. Flow checks showing well static. Well took 23 bbls on trip out. 22:00 - 23:00 1.00 FISH P INTERV LD 2.125" DC's & fishing BHA. 23:00 - 00:00 1.00 FISH P INTERV Clear rig floor. PU new BHA to floor, SLM same. 9/19/2002 00:00 - 01:00 1.00 FISH P INTERV MU 8.125" overshot fishing BHA. 01:00 - 04:00 3.00 FISH P INTERV RIH w/8.125" overshot on 5" DP from derrick to 10,111 ft. 04:00 - 05:30 1.50 FISH P INTERV Slip & cut drlg line. Service Top Drive. 05:30 - 06:00 0.50 FISH P INTERV Est pump rate of 4.5 BPM / 100 psi. Up wt 215k, Dn wt 175k, !Rot wt 195k, TQ 6500 ft/Ibs. Con't RIH w) 8.125" overshot on 5" DP from derrick to top of fish @ 10,182 ft. Work over fish to 10,188 ft. Up wt 230k, POH to 10,162 ft. Shut well in. 06:00 - 06:30 0.50 FISH P INTERV Bullhead 20 bbls down DP & casing @ 3 BPM / 1500 psi. Pressure held w/pumps off. 06:30 - 09:00 2.501 KILL P INTERV Bleed psi to 400 psi. Strip thru Hydril annular to 10,155 ft. Monitor following pressures: SIDPP 200 psi, SlCP 210 psi. Circ well thru choke staging pump rate / pressures as follows: 5 BPM, DP-250 psi, Csg-40, Choke full open. Slow pump to 2 BPM 50 bbls from btms up, w/gas at surface. Circ gas from well, stage pumps to 5 BPM observe dirty / oily SW at btms up. Con't circ 70 bbls to obtain clear SW. (Total 6 bbls lost) 09:00 - 10:00 1.00 KILL P INTERV Open well, observe well static. 10:00 - 15:00 5.00 FISH P INTERV POH w/fish to 854 ft. Flow checks & hole fill showing well static. No losses on trip out. 15:00- 16:00 1.00 FISH P INTERV LD fishing BHA. 16:00 - 16:30 0.50 FISH P INTERV Circ 20 bbls thru fish @ 4 BPM / 60 psi 16:30 - 18:30 2.00 FISH P INTERV LD fish. 100% recovery. (see remarks for details of fish) 18:30 - 19:30 1.00 FISH P INTERV Clear rig floor. Clean same from residue from fish. 19:30 - 20:30 1.00 FISH P INTERV MU 8.25" casing cutter. Make dummy run thru tight casing @ 50 ft. MU Top Drive & push thru, no restrictions after 2 passes. LD casing cutter. 20:30 - 21:30 1.00 FISH P INTERV Break out cut tbg from overshot & break out overshot extension. 21:30 - 22:30 1.00 FISH P INTERV MU & RIH w/double spear fishing BHA 22:30 - 00:00 1.50 FISH P INTERV RIH w/spears to 9,538 ft. 9/20/2002 00:00 - 01:00 1.00 FISH P INTERV Con't RIH w/spears on 5" DP from derrick to 10,298 ft. PU singles from pipe shed to 10,800 ft. 01:00 - 01:30 0.50 FISH P INTERV Est parameters @ Up wt 225k, Dn wt 185k, Rot wt 205k - 35 RPM, 6500 ft/Ibs TQ. Engage fish @ 10,810 ft. Slide spears to No Go @ 10,821. Made 3 attempts to release 'K' anchor utilizing rotation / torque. Grapples appear to be slipping. Jar free w/150k over string wt. POH to 10,791 ft w/5k over pull. 01:30 - 03:30 2.00 FISH P INTERV Cir¢ well thru full open choke. Pump rate / pressures as follows: 5 BPM, DP-320 psi, Csg-50, Choke full open. Observe Printed: 10/14/2002 9:45:41 AM BP EXPLORATION Page 5 of t3 Operations Summary Report Legal Well Name: A-22 Common Well Name: A-22 Spud Date: 4/14/1982 Event Name: WORKOVER Start: 9/1 1/2002 End: 10/8/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 10/8/2002 Rig Name: NABORS Rig Number: 2ES Date From -To Hours Task Code NPT Phase Description of Operations 9/2o/20o2 o1:30 - 03:30 2.00 FISH P INTERV dirty / oily SW at btms up. Con't circ 40 bbls to obtain clear SW. (No gas) (No losses) Open well, observe well static. 03:30 - 06:30 3.00 FISH P INTER¥ POH w/fishing assy. LD excess DP to 7,915 ft to leave safe working area around pipe skate / rig floor to LD 9 5/8" csg. 06:30 - 10:00 3.50 FISH P INTERV Con't POH w/fish racking pipe in the derrick to BH^ @ 233 ft. 10:00 ~ 11:30 1.50 FISH P INTERV LD BHA & fish. 95% recovery. (see remarks for details) 11:30 - 13:30 2.00 EVAL P INTERV RU Schlumberger wireline unit. MU 9 5/8" 'Fas Drill' BP. 13:30 - 17:00 3.50 TA P INTERV Schlumberger RIH w/9 5/8" 'Fas Drill' BP to 10,786 ft. Set same. POH w/setting tool. 17:00 - 18:00 1.00 EVAL P INTERV Pressure test 9 5/8" csg & BP to 2060 psi for 30 rains. O-K. Test witnessed by ^OGCC 18:00 - 00:00 6.00 EV^L P INTER¥ MU & RIH w/USIT logging tool on Schlumberger e-line. Log from 600 ft to surface. Con't RIH to 10,600 ft & log up. (See remarks) 9/21/2002 00:00 - 02:30 2.50 EVAL P INTERV Con't log 9 5/8" w/USlT on Schlumberger e-line. LD USIT tool. 02:30 - 04:00 1.50 TA P INTERV PU & RIH w/9 5/8" 'Fas Drill' BP on e-line. Set same @ 2,480 ft. POH w/setting tool. RD Schlumberger. 04:00 - 04:30 0.50 EVAL P INTERV Test 9 5/8" csg / BP to 2000 psi / 10 mins. Plot test against test on lower BP, confirm upper BP holding pressure. 04:30 - 06:00 1.50 CLEAN P INTERV RIH w/OEDP to 2,420 ft. 06:00 - 06:30 0.50 CLEAN P INTERV Service Top Drive 06:30 - 10:00 3.50 CLEAN P INTERV RIH to 2,450 ft. Circ well w/600 bbls 140 degree SW @ 10 BPM / 150 psi. Follow SW w/50 bbls spacer & 600 bbls 9.5 ppg dead crude @ 12 BPM / 220 psi. 10:00 - 10:30 0.50 CLEAN P INTERV Blow down surface equip. 10:30 - 11:30 1.00 CLEAN P INTERV POH w/OEDP. LD mule shoe. Clean rig floor. 11:30 - 13:00 1.50 TA P INTERV MU & RIH w/Baker 9 5/8" casing cutter to 1,970 ft. 13:00 - 14:30 1.50 TA P INTERV Est following parameters @ 1,970 ft. Up wt 64k, Dn wt 64k, Rot wt 64k. RPM 93, TQ 1000 ft / lbs. Cut 9 5/8" csg w/2.75 BPM / 650 psi, TQ 4500 ft / lbs. 14:30 - 15:00 0.50 TA P INTERV Observe well static. Attempt to circ thru 9 5/8"x13 3/8" annulus. Held 2000 psi 15:00- 15:30 0.50 TA P INTERV Repeat csg cut @ 1,970 ft w/2.3 BPM/620 psi, TQ 2500 ft / lbs. Observe well static. 15:30 - 17:30 2.00 TA P INTERV Shut in well. Circ 49 bbls 9.5 ppg dead crude @ 3 BPM ! 1650 psi thru 9 5/8"x13 3/8" annulus, gas at surface. Shut in well. 17:30 - 20:00 2.50 TA P INTERV Circ 437 bbls SW w/Barascrub spacer down DP & IA taking returns thru 9 5/8"x13 3~8" annulus. Follow pressure / pump schedule to ensure DP & IA fluids exit casing cut !simultaneously and not exceed 1900 psi. Gas at surface on btms up. 20:00 - 21:30 1.50 TA !P INTERV Mix 'Dirt Magnet' spacer & take on 9.5 ppg brine. 21:30 - 00:00 2.50 TA P INTERV Circ 200 bbls 9.5 ppg brine w/Dirt Magnet spacer, 11 ppg brine spacer down DP & IA taking returns thru 9 5/8"x13 3/8" annulus. Follow pressure / pump schedule to ensure DP & IA fluids exit casing cut simultaneously and not exceed 1900 psi. Gas at surface on btms up. 9/22/2002 00:00 - 00:30 0.50 TA P INTERV RD surface circ system. Observe well static. 00:30 - 01:30 1.00 TA P INTERV POH LD 9 5/8" csg cutter. 01:30 - 03:00 1.50. TA P INTERV Clear rig floor. PU & MU 9 5/8" csg spear. Back out lock down screws. 03:00 - 03:30 0.50 TA :~ INTERV Engage 9 5/8" csg. Pull 150k to set grapple. Pull 9 5/8" free w/ 275k. Printed: 10/14/2002 9:45:41 AM BP EXPLORATION Page 6 of 13 Operations Summa Report Legal Well Name: A-22 Common Well Name: A-22 Spud Date: 4/14/1982 Event Name: WORKOVER Start: 9/1 1/2002 End: 10/8/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 10/8/2002 Rig Name: NABORS Rig Number: 2ES Date From -To Hours Task Code NPT Phase Description of Operations 9/22/2002 03:30 - 04:30 1.00 TA P INTERV Pull 9 5/8" csg to rig floor. PU wt 110k. PU false rotary table & 9 5/8" slips. Dis-engage spear. LD fishing BH^. 04:30 - 06:30 2.00 TA P INTERV PU 9 5/8" handling equip. LD 9 5/8" csg mandrel hanger & 1st jt of csg. (see remarks) 06:30 - 08:30 2.00 TA P INTER¥ Circ 112 bbls 140 degree SW. Gas at btms up. Shut in well. SIDPP 0 psi, SICP 0 psi. Open well, observe well dead. Con't circ 480 bbls 140 degree SW. 8 BPM / 50 psi. 08:30 - 09:00 0.50 T^ P INTERV Blow down surface equip. 09:00 - 18:00 9.00 TA P INTER¥ POH & LD 48 jts and cut offjt of 9 5/8" csg. (see remarks) 100% recovery 18:00 - 19:00 1.00 T^ P INTERV RD csg handling equip. 19:00 - 19:30 0.50 T^ P INTER¥ Clean rig floor from residue from LD csg operation. 19:30 - 20:00 0.50 T^ P INTER¥ PU 8" DC, break offXO's from fishing operation. LD 8" DC. 20:00 - 22:00 2.00 TA P INTER¥ MU 12 1/4" tapered mill RIH tag @ 44.5 ft w/lk. LD 12 1/4" mill, PU 11 3/4" tapered mill RIH tag @ 46 ft w/lk. LD mill. 22:00 - 23:00 1.00 T^ P INTERV MU & RIH w/mule shoe on 5" DP to 2,480 ft. Tag 9 5/8" csg stump @ 1,970 ft. 23:00 - 00:00 1.00 TA P INTERV Circ well w/25 bbl 9.5 ppg 'Barascrub' spacer, 50 bbls 9.5 ppg 'Dirt Magnet' spacer followed w/300 bbls 140 degree 9.5 ppg brine displacing 9.5 ppg dead crude from below 9 5/8" csg stump @ 1970 ft. 12 BPM/200 psi. Returns becoming clear. :9/23/2002 00:00 - 00:30 0.50 TA P INTERV Fin circ well w/100 bbls 140 degree 9.5 ppg brine (total 500 bbls) displacing 9.5 ppg dead crude from below 9 5/8" csg stump @ 1,970 ft. 12 BPM / 200 psi. Clear returns to surface. Observe well static. 00:30 - 02:00 1.50 TA P INTERV POH w/OEDP to 180 ft. 02:00 - 03:30 1.50 TA P INTERV Circ well w/50 bbl 'Condet' spacer, 180 bbls 140 degree 9.5 ppg filtered brine. Let soak 30 mins, circ 150 bbls 140 degree 9.5 ppg filtered brine Ensure clear returns at surface. (Condet spacer came back clean) Observe well static. 03:30 - 04:00 0.50 TA P INTERV POH w/OEDP. LD mule shoe. 04:00 - 05:00 1.00 EVAL P INTERV RU Halliburton fiber optics hoisting unit. RIH w/camera to 15 ft. Fluid clarity cloudy. POH LD camera. RD hoisting sheaves. 05:00 - 06:00 1.00 EVAL P INTERV RIH w/mule shoe on 5" DP to 1,887 ft. POH same without filling hole dropping fluid level down to 106 ft. (52 psi hydrostatic) 06:00 - 07:00 1.00 EVAL P INTERV ~ RIH w/camera to 102 ft. Video 13 3/8" csg. POH LD camera. RD hoisting unit. 07:00 - 13:30 6.50 EVAL P INTERV RU Schlumberger. Run USIT log 1,950 ft to surface. Make repeat pass 500 ft to surface. LD USIT tool. 13:30 - 15:00 1.50 EVAL P INTERV Run 10.125" OD Kinley Multi arm caliper on Schlumberger wire line to 1,950 ft. LD caliper tool. 15:00 - 17:30 2.50 EVAL P INTERV Schlumberger re-run USIT log to verify data. LD USIT tool. RD wire line unit. 17:30 - 20:30 3.00 EVAL P INTERV PU / MU multi string cutter w/11.5" csg swedge for centralizer, unable to pass thru 46 ft. LD 11.5" swedge, PU 10.5" swedge for centralizer. 20:30 - 21:30 1.00 EVAL P INTERV Jack rig floor to open cellar doors to allow access for up coming operation. 21:30 - 23:00 1.50 TA P INTERV RIH w/multi string cutter to 71 ft. Verify csg collar, PU to 65 ft. Cut 13 3/8" csg. PU wt 32k, Dn wt 32k, Rot wt 32k, RPM 60, 3 BPM / 1030 psi, 3000 ft lbs TQ. Observe well static. 23:30 - 00:00 0.50 TA P INTERV Pull cutter to floor, dress w/20" csg cutters. RIH & commence Printed: 10/14/2002 9:45:41 AM BP EXPLORATION Page 7 of 13 Operations Summary Report Legal Well Name: A-22 Common Well Name: A-22 Spud Date: 4/14/1982 Event Name: WORKOVER Start: 9/11/2002 End: 10/8/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 10/8/2002 Rig Name: NABORS Rig Number: 2ES Date From- To Hours Task Code NPT Phase Description of Operations 9/23/2002 23:30 - 00:00 0.50 TA P INTERV cutting 20" csg. 9/24/2002 00:00 - 00:30 0.50 TA P INTERV Cut 20" csg @ 65 ft. PU wt 32k, Dn wt 32k, Rot wt 32k, RPM 60, 3 BPM / 980 psi, 1000 ft lbs TQ. Observe well static. 00:30 - 01:00 0.50 TA P INTERV POH dress csg cutter w/blades for 25" sweep, to ensure complete cut. RIH 01:00 - 02:00 1.00 TA P INTERV Make cutting pass thru 20" csg w/25" sweep cutters. PU wt 32k, Dn wt 32k, Rot wt 32k, RPM 60, 3 BPM / 980 psi, 875 fi lbs TQ. Circ well (Arctic Pack to surface, No gas) Observe well static. 02:00 - 02:30 0.50 TA P INTERV Break out & LD csg cutter BHA. 02:30 - 07:30 5.00 TA P INTERV ND BOPE and remove tubing spool. Secure cellar / rig floor for removal of drip pan to allow maxiumum clearance thru rotary table to LD 13 3/8" & 20" csg simultaneously. 07:30 - 12:00 4.50 TA P INTERV RD rotary table. Disconnect Flowline and Hole Fill line from 20" to Drip Pan. 12:00 - 14:00 2.00 TA P INTERV Remove Dresser Sleeve, cut out Rotary Table Drip Pan. 14:00 - 17:00 3.00 TA P INTERV PJSM. Make up Multi-String casing cutter with 13-3/8" knives. Snub and secure wellhead. RIH to 32.5'. ROT=32K, UWT= 32K, DWT= 32K, RPM= 60. Final torque= 5,000 fi-lb. Dry cut 13-3/8" casing at 32.5'. POOH, LD cutting tool, blow down surface equipment. 17:00 - 20:00 3.00 TA P INTERV PJSM. Remove well head snub lines, remove secondary annulus valve. LD fire blankets safeout the cellar. Cut off 20" x 30' wellhead cap. 20:00 - 23:00 3.00 TA P INTERV Lift wellhead and cap off of 20" x 30' casing. Stopped after 20" casing had pulled 25.5" with the wellhead. (no movement in the 13-3/8"). (The 20" had flared out where it had been cut). PJSM. Weld two pad eyes externally on the 20" casing. Rough cut the 20" casing 3' below the 20" x 30" cap. Pick up and LD wellhead and 20"x 30' cap. 23:00 - 00:00 1.00 TA P INTERV Weld straps to secure the 13-3/8" x 20' casing at the surface cut. 9/25/2002 00:00 - 01:00 1.00 TA P INTERV Continue to weld straps to secure the 13-3/8" x 20' casing at the surface cut. PU spear BHA. 01:00 - 03:30 2.50 TA P INTERV RIH and spear into 13-3/8" casing. Pull and retrieve 13-3/8" x 20" cut casing with max pull of 16K. Clean insulation off of 20" casing. Continue pulling with pull weight decreasing to 5.5K (string weight). 03:30 - 05:00 1.50 TA P INTERV Laydown cut casing. Clean and dress casing stub for welding on new landing ring. 05:00 - 06:00 1.00 TA P INTERV Continue dressing casing stub and install 20"x 30' FMC landing rig. 06:00 - 22:00 16.00 TA P INTERV Finish weld on of the 20"x 30" landing ring. Install 20" adapter to Drip Pan. Install flowline adapter flange. Install 20' Riser adapter. Install Diverter spool and 20" riser. Install Dresser sleeve. Reberm cellar and install new herculite liner. Fill and test Diverter system with fresh water - okay. Remove large pieces of insulation material from top of the Riser, that had peeled off of the 20" pipe. 22:00 - 00:00 2.00 TA P INTERV PJSM. Make up 9-5/8" mellon mill and 13-3/8" casing scraper BHA. 9/26/2002 00:00 - 01:30 1.50 TA P INTERV Continue making up BHA and RIH. Tag up on 13-3/8" casing stub (with scraper) at 65', work thru. Continue RIH and tag up Printed: 10/14/2002 9:45:41 AM BP EXPLORATION Page 8 of 13 Operations Sunama Report Legal Well Name: A-22 Common Well Name: A-22 Spud Date: 4/14/1982 Event Name: WORKOVER Start: 9/1 1/2002 End: 10/8/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 10/8/2002 Rig Name: NABORS Rig Number: 2ES Date From -To Hours Task Code NPT Phase Description of Operations 9/26/2002 00:00 - 01:30 1.50 TA P INTERV on 9-5/8" casing stub at 1,970'.. 01:30 - 02:00 0.50 TA P INTERV Work thru the top of the 9-5/8" stub twice. Rotate and polish with the watermellon mill. 02:00 - 02:30 0.50 TA P INTERV iContinue to RIH. No-go at 2,473' with the 13-3/8" casing scraper on the 9-5/8" casing stub. No fill at this depth. 02:30 - 03:30 1.00' TA P INTERV Sweep hole with 50 bbl Hi-Vis, at 10 BPM and 180 psi. Circulate hole clean. 03:30 - 04:30 1.00' TA P INTERV POOH. 04:30 - 06:00 1.50 TA P INTERV LD BHA, RU wireline perf tools. 06:00 - 08:00 2.00 PERFRE P INTERV PJSM. RU wireline tools. RIH to 2,350' wireline depth. Locate on depth and perforate 13-3/8" casing from 1,970'-1,965', with 5' gun, loaded 4 SPF (21 holes), 60 deg phasing. POOH and LD WL tools. All shots fired. 08:00 - 10:00 2.00 FISH P INTERV MU Backoff BHA. 10:00 - 13:00 3.00 FISH P INTERV RIH to filling pipe with fresh water. 13:00 - 16:00 3.00 FISH P INTERV Set bottom anchor at 2,002', top anchor at 1,977'. Worked Backoff tool up to 5,000 psi and broke 9-5/8" casing connection with the third try and 50,000 fi-lb. Continue to backoff casing stub a total of 5-2/3 turns with torque decreasing to 18,000 fi-lb. Release anchors. 16:00 - 19:00 3.00 FISH P INTERV POOH to BHA. LD Backoff tool and stand back DCs. Clear and clean rig floor. 19:00 - 21:00 2.00 FISH P INTERV PJSM. PU Casing Spear BHA. 21:00 - 21:30 0.50 FISH P INTERV RIH and tag up on casing stub at 1,970'. UWT= 63K, DWT- 62K. 21:30 - 22:00 0.50 FISH P INTERV Engage and swallow 10' of fish to the stop ring. Back fish out 4 turns with UWT-'63K. Increase UWT to 73K and make 5th turn. Casing stub broke free. 22:00 - 23:00 1.00 FISH P INTERV Sweep hole from 1,983' with 35 bbl Hi-Vis pill. 23:00 - 00:00 1.00 FISH P INTERV POOH to BHA. Release spear from casing stub. 9/27/2002 00:00 - 01:30 1.50 FISH P INTERV Lay down BHA and 13.0' of 9-5/8" casing stub with collar. 01:30 - 03:00 1.50 CASE P TIEB1 RU casing equipment and PU casing tools. PJSM. 03:00 - 05:30 2.50 CASE P TIEB1 MU OS Guide Sub w/BTC-M coupling, 1 Jt of 9-5/8" 47 lb/fi, L-80, BTC x NSCC casing, HES ES cementer. 05:30 - 10:00 4.50 CASE P TIEB1 Run 47 jts of 9-5/8", 47 lb/fi, L-80, NSCC csg. Average MU torque = 10K fi-lb. RIH to 1,983'. UWT= 105K, DWT=109K. 10:00 - 11:00 1.00 CASE P TIEB1 Wash down to and screw into 9-5/8" casing at 1,983' with 15 turns. Torque up to 10,500 fi-lb with Top Drive. Pressure test 9-5/8" casing with steady increase to 2,400 psi. ES Cementer sheared open. PU to 150K and verify tie-back is screwed in. Check pipe torque to 10,500 fi-lb and verify make-up torque. 11:00 - 12:00 1.00 CEMT P TIEB1 PJSM. RU cement head. 12:00 - 14:00 2.00 CEMT P TIEB1 Circulate thru ES Cementer at 7 BPM and 370 psi. Pump 5 bbl of water and test surface lines to 4,000 psi. Pump 10 bbl of water at 5 BPM, 155 bbl (401 sx) of 12.3 ppg Permafrost "E" lead cement at 5-6 BPM and 5-600 psi, followed by 15 bbl (90 sx) of 15.6 ppg, Permafrost "C" cement at 2-5 BPM and 4-900 psi. Shut down, clean lines drop wiper plug and displace with 145 bbl of 9.5 ppg brine at 6-2 BPM and 9-700 psi. Bump plug and pressure up to 2,500 psi. Hold pressure for 5 min, bleed off. CIP at 1400 hrs. Printed: 10/14/2002 9:45:41 AM BP EXPLORATION Page 9 of 13 Operations Summa Report Legal Well Name: A-22 Common Well Name: A-22 Spud Date: 4/14/1982 Event Name: WORKOVER Start: 9/11/2002 End: 10/8/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 10/8/2002 Rig Name: NABORS Rig Number: 2ES Date From -To Hours Task Code NPT Phase Description of Operations 9~27~2002 12:00 - 14:00 2.00 CEMT P TIEB1 Full returns during cement job and there was an estimated 25 bbl of cement circulated to the surface. 14:00 - 19:30 5.50 WHSUR P TIEB1 Clean out surface equipment of excess cement. RD Dresser sleeve from the Riser and cut 3' from the top of Riser. PU to 180 K on 9-5/8", and set slips with 75K on 9-5/8" casing. 19:30 - 20:30 1.00 1WHSUR P TIEB1 ND Riser and Diverter. 20:30 - 00:00 3.50 ~ WHSUR P TIEB1 Make final cut on 9-5/8" casing (29.34' below Rotary Table). Position FMC Transition Nipple and secure. Install Hothead and preheat casing. Weld on Transition Nipple. 9/28/2002 00:00 - 18:00 18.00 WHSUR P TIEB1 Heat FMC Transition Nipple to 850 deg. Wrap with insulation and let cool. Test choke manifold to 250/3,500 psi for 5/5 minutes. 18:00 - 19:00 1.00 WHSUR P TIEB1 MU tubing spool to FMC Gen 5 casing head. Install on Transition Nipple and orient to flowlines. Set BOPs on tbg spool. Test welds to 1,000 psi - okay. 19:00- 23:00 4.00 WHSUR P TIEB1 NU BOPs. : 23:00 - 00:00 1.00 WHSUR P TIEB1 Test BOPE 250 / 3,500 psi for 5/5 min: Top Pipe Ram w/ 3-1/2" x 6" Variable Rams, Blind Ram, Mud Cross, Lower Pipe Rams w/2-7/8" x 5" Variable Rams, Lower Mud Cross. Tested Blind Rams, Choke Manifold, HCR, Kill and Choke lines, IBOP. Test witnessing waived by Chuck Scheve of the AOGCC. 9/29/2002 00:00 - 02:30 2.50 WHSUR P TIEB1 Continue to test BOPE to 250 / 3,500 psi for 5/5 min: 02:30 - 03:30 1.00 WHSUR P TIEB1 Rig down test equipment, install Wear Ring. 03:30 - 04:30 1.00 REMCM~'P TIEB1 RU cementers for pumping Top Job cement. PU cleanout BHA. PJSM. 04:30 - 06:30 2.00 REMCM;'P TIEB1 Pump 25 bbl of 15.4 ppg Permafrost "C" cement at .75-1.0 BPM and 100-135 psi. Slow pump rate to .5 BPM for last 5 bbl. Cement job witnessed by Chuck Scheve of the AOGCC. CIP at 05:45 hrs. RD cementers. 06:301 08:00 1.50 FISH P TIEB1 PU 9-5/8" casing cleanout BHA. 08:00 - 09:00 1.00 FISH P TIEB1 Cut and slip 93' of drill line. 09:00 - 10:00 1.00 FISH P TIEB1 RIH and tag up on ES Cementer at 1,938'. 10:00 - 10:30 0.50 FISH P TIEB1 Pressure test 9-5/8" casing to 3,000 psi, for 15 min. - okay. 10:30 - 11:00 0.50 FISH P TIEB1 Drill ES Cementer from 1,938'-1,941'. UWT= 90K, DWT= 90K, ROT= 90K, Torque Off/On - 1 K/3K fi-lb. 11:00 - 11:30 0.50 FISH P TIEB1 RIH to 2,472' and tag FAS-Drill BP. 11:30 - 12:00 0.50 FISH P TIEB1 Pressure test 9-5/8" casing to 3,000 psi, for 15 min. - okay. 12:00 - 13:00 1.00 FISH P TIEB1 Drill (and push) FAS-Drill BP from 2,472'-2,508'. Drill 1/2" with WOB=5-7K, increase WOB to 20K, 170 GPM, 120 psi. 13:00 - 13:30 0.50 FISH P TIEB1 Break thru and continue rotating to 2,559'. CBU at 12 BPM and 350 psi. 13:30 - 18:00 4.50 FISH P TIEB1 Continue RIH 10,770'. PU additional DP from 8,642'. 18:00 - 18:30 0.50 FISH P TIEB1 Tag up on FAS-Drill BP at 10,779'. Circulate DP volume of new clean SW at 12 BPM and 950 psi. UWT= 245K, DWT- 195K. 18:30 - 20:00 1.50 FISH P TIEB1 Pressure test 9-5/8" casing to 3,000 psi, for 30 min. - okay. Testing witnessed by Chuck Scheve of the AOGCC. 20:00 - 21:30 1.50 FISH P TIEB1 Drill FAS-Drill BP from 10,779'-10,782. Drill with WOB=20-25K, 345 GPM, 480 psi. Chase pkr to 10,822' and drill to 10,830' Printed: 10/14/2002 9:45:41 AM BP EXPLORATION Page 10 of 13 Operations Summa Report Legal Well Name: A-22 Common Well Name: A-22 Spud Date: 4/14/1982 Event Name: WORKOVER Start: 9/11/2002 End: 10/8/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 10/8/2002 Rig Name: NABORS Rig Number: 2ES Date From -To Hours Task Code NPT Phase Description of Operations 9~29~2002 20:00 - 21:30 1.50 FISH P TIEB1 (top of 7" pkr). Continue to displace wellbore to clean SW while drilling). 21:30 - 23:00 1.50 FISH P TIEB1 Circulate Hi-Vis sweep at 12 BPM and 1,000 psi. Pump slug. 23:00 - 00:00 1.00 FISH P TIEB1 POOH to 8,928'. 9/30/2002 00:00 - 03:00 3.00 FISH P TIEB1 POOH to 4,454'. 03:00 - 04:00 1.00 FISH N RREP TIEB1 Repair Link Tilt on Top Drive. 04:00 - 05:30 1.50 FISH P TIEB1 POOH to BHA. 05:30 - 07:00 1.50 FISH P TIEB1 Handle BHA. Clear and clean rig floor. PU Packer Milling BHA. 07:00 - 11:30 4.50 FISH P TIEB1 RIH. 11:30 - 12:00 0.50 FISH P TIEB1 Mill 9-5/8" packer at 10,830'. UWT= 240K, DWT= 190K, ROT= 220K. Torque off = 5K fi-lb, Torque On= 6/11K fi-lb. 12:00 - 00:00 12.00 FISH ' P TIEB1 Mill 9-5/8" packer at 10,830'-31.6'. UWT-- 240K, DWT= 190K, ROT= 220K. Torque off = 6K fi-lb, Torque On= 7/16K fi-lb, GPM= 0-490, WOB= 15-37K, RPM= 50-78. Varied drilling parameters while milling. Dry drilled for up to 45 rain intervals. 10/1/2002 00:00 - 01:30 1.50 FISH P TIEB1 Continue to Mill 9-5/8" packer at 10,831.6'. UWT= 240K, DWT= 190K, ROT= 200K. Torque off = 7K fi-lb, Torque On= 8/16K fi-lb, GPM= 0-500, WOB= 33-37K, RPM= 75. ROP=0 01:30 - 05:30 4.00 FISH P TIEB1 Monitor well. Pump slug. POOH to BHA. 05:30 - 06:30 1.00 FISH P TIEB1 Handle BHA. Burn shoe only showed wear on the bottom lip (15% wear- estimated). 06:30 - 07:30 1.00 FISH P TIEB1 Change out Burning shoe and RIH. 07:30 - 09:00 1.50 FISH P TIEB1 Cut and Slip 96' of drill line. Service Top Drive, and Crown. 09:00 - 11:30 2.50 FISH P TIEB1 RIH and tag up on packer at 10,832'. 11:30 - 20:00 8.50 FISH P TIEB1 Mill 9~5/8" packer to 10,835'. UWT= 250K, DWT= 200K, ROT= 225K. Torque off = 6.5K fi-lb, Torque On= 12/14K ft-lb, GPM= 0-250, WOB= 5-10K, RPM= 75. 20:00 - 20:30 0.50 FISH 3 TIEB1 Push packer assembly to 10,886' and set down 50K lb. 20:30 - 00:00 3.50 FISH 3 TIEB1 Circulate a Hi-Vis sweep at 10,886', at 12 BPM and 830 psi. I Flowback increased after approximately 1/2 of circulating :bottoms up. Shut down pumps, monitor well, shut-in well. SICP= 190 psi, SIDPP-' 40 psi after 15 minutes. Circulated an estimated 20 bbl gas bubble of released trapped gas, through the choke and gas buster, until casing pressure = drillpipe 3ressure. Shut down pumps, monitor well - small but steady loss rate (estimated at 8 bbl/hr). Continue to circulate sweep out with some gas breaking out. 10/2/2002 00:00 - 01:00 1.00 FISH ~ TIEB1 Continue CBU with Hi-Vis sweep at 10,886', at 5 BPM and 230 01:00 - 03:00 2.00 FISH ~ TIEB1 Monitor well. Seepage losses at 8 bbl/hr. Mix and spot a Hi-Vis pill on top of the packer. Pump slug. 03:00 - 06:00 3.00 FISH N RREP TIEB1 Trouble shoot Top Drive, change out dual pressure relief valves for Link Tilt float. Tighten bolts 'on Traction Motor. 06:00 - 10:00 4.00 FISH P TIEB1 POOH to BHA. 10:00 - 11:30 1.50 FISH P TIEB1 Handle BHA. (Burn over shoe had approximately 1/4" of wear on the bottom lip). 11:30 - 13:00 1.50 FISH P TIEB1 Make up Overshot BHA dressed with 6-3/4" grapple. Clean out junk baskets. 13:00- 14:00 1.00 FISH P TIEB1 RIH with BHA. 14:00 - 17:30 3.50 FISH P TIEB1 RIH to 10,819'. UWT-- 260K, DWT= 195K. 17:30 - 18:00 0.50 FISH P TIEB1 Continue RIH and tag up on fish at 10,876'. Push Packer to 10,889' and set down on with 40K lb., two times. Pull free with 375K. PU to 10,820' with 15-25K lb of drag. Slackoff and PU Printed: 10/14/2002 9:45:41 AM BP EXPLORATION Page 11 of 13 Operations Summary Report Legal Well Name: A-22 Common Well Name: A-22 Spud Date: 4/14/19@2 Event Name: WORKOVER Start: 9/11/2002 End: 10/8/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 10/8/2002 Rig Name: NABORS Rig Number: 2ES Date From -To Hours Task Code NPT Phase Description of Operations 10/2/2002 17:30 - 18:00 0.50 FISH P TIEB1 again with 275K. 18:00 - 23:00 5.00 FISH P TIEB1 Circulate at 9 BPM and 2,180 psi with gas breaking out at bottoms up. Slow pump rate to 3 BPM, and circulate 3,000 strokes past bottoms up with gas breaking out at a steady, and possibly increasing rate. Shut well in and SIDPP -- 70 psi, SlCP = 70 psi. Circulate through choke and gas buster at 3 BPM for an additional 2,500 strokes. Shut down pumps, flow check well, with gas still breaking out of mud. Continue to circulate gas cut mud at 9 BPM and 2,180 psi, until total circulation = 2x bottoms up. Gas percolation rate decreased. Shut down pumps and monitor well - static. 23:00 - 00:00 1.00 FISH P TIEB1 Blow down surface equipment, POOH to 10,400' with intermittent overpulls of 5-20K. Pump slug and continue POOH tp 9,708' 10/3/2002 00:00 - 04:00 4.00 FISH P iTIEB1 POOH to BHA. 04:00 - 08:00 4.00 FISH P ,TIEB1 Handle BHA, broke all connections. IBP found at 3-1/2 x 2-7/8 XO below packer. LD overshot and packer. Frac Sand found on top of IBP. 08:00 - 09:00 1.00 FISH P TIEB1 Change out handling equipment and LD 67.18' of 2-7/8" tailpipe. 09:00 - 11:00 2.00 FISH P TIEB1 Clear and clean rg floor. Service Top Drive. 11:00 - 12:00 1.00 FISH P TIEB1 PU and MU polishing Mill BHA. 12:00 - 16:00 4.00 FISH P TIEB1 RIH to 10,889'. 16:00 - 16:30 0.50 FISH P TIEB1 Tag up on Tie Back Recepticle and sting in to 10,894'. Polish with DWT= 20-40K lb, RPM-60, at 6 BPM and 250 psi. 16:30 - 20:00 3.50 FISH P TIEB1 Circulate Hi-Vis sweep at 10,894'. Displace hole with clean seawater at 11 BPM and 950 psi. 20:00 - 21:00 1.00 FISH P TIEB1 Cut and Slip 104' of drill line, and inspect brakes. 21:00 - 00:00 3.00 FISH P TIEB1 Monitor well and POOH laying down 5" DP to 6,555'. 10/4/2002 00:00 - 04:00 4.00 FISH P TIEB1 Continue POOH laying down 5" DP. 04:00 - 05:30 1.50 FISH P TIEB1 Handle BHA. Junk baskets were empty. Inspect Polishing mill for tattle-tail marks- intact LD same. 05:30 - 06:30 1.00 FISH P TIEB1 Clear and clean rig floor. 06:30 - 07:00 0.50 FISH P TIEB1 PJSM, RU Wireline tools. 07:00 - 12:00 5.00 DHB P TIEB1 RIH with 6" Gauge Ring and Junk Basket, to 11,400'. POOH w/o problems. No debris or frae sand in the junk basket. LD same. PU 7" RBP. RIH and set at 10,950' (WLM). POOH and LD wireline tools. 12:00 - 13:00 1.00 CASE P TIEB1 Test 7"x 9-5/8" casing annulus to 3,000 psi for 30 minutes. Test witnessed by John Crisp of the AOGCC. 13:00 - 15:00 2.00 BOPSUR P TIEB1 Install 7" Rams in upper Pipe Rams. Change out Ram door seals. Test upper Rams to 250 / 3,500 for 5/5 minutes. 15:00 - 15:30 0.50 BOPSUR P TIEB1 Pull WB. 15:30 - 16:00 0.50 BOPSUF P TIEB1 Test upper Rams to 250 / 3,500 for 5/5 minutes. 16:00 - 17:00 1.00 CASE P TIEB1 RU casing handling tools. 17:00 - 17:30 0.50 CASE P TIEB1 Make up Tie-Back stinger (with lower seals removed), JMZX LT Isolation packer. 17:30 - 00:00 6.50 CASE P TIEB1 Run 7", 26 lb/fi, L-80, BTC-M casing, with an average MU torque of 8,600 ft-lb, using Best-O-Life 2000 thread compound. 10/5/2002 00:00 - 04:00 4.00 CASE P TIEB1 Continue to run 7", 26 Ib/ft, L-80, BTC-M casing. 04:30 - 05:00 0.50 CASE P TIEB1 Change out to 300 ton elevators. RIH and tag up on 7" liner Tie-back recepticle. 05:00 - 06:30 1.50 CASE P TIEB1 Reverse circulate seawater with corrosion inhibitor down the 7" Printed: 10/14/2002 9:45:41 AM BP EXPLORATION Page 12of 13 Operations Summary Report Legal Well Name: A-22 Common Well Name: A-22 Spud Date: 4/14/1982 Event Name: WORKOVER Start: 9/1 1/2002 End: 10/8/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 10/8/2002 Rig Name: NABORS Rig Number: 2ES Date From -To Hours Task Code NPT Phase Description of Operations 10/5/2002 05:00 - 06:30 1.50 CASE P TIEB1 x 9-5/8" annulus, at 3 BPM and 150 psi. 06:30 - 08:30 2.00 CASE P TIEB1 Made multiple attempts to sting into Liner Top. 08:30 - 09:30 1.00 CASE P TIEB1 Reverse circulate 60 bbl of diesel Freeze Protect at 3 BPM and 260 psi. 09:30 - 10:30 1.00 CASE P TIEB1 Stab into Liner Tie-Back recepticle and set down with 100K lbs, setting Tie-Back packer. Pull to 315K. Had good surface indications of packer setting. 10:30 - 11:30 1.00 CASE P TIEB1 Test 7" x 9-5/8" annulus and LT packer to 2,500 psi for 15 minutes - okay. Test witnessed by John Crisp of the AOGCC. 11:30 - 12:00 0.50 CASE P TIEB1 Blow down hoses and drain stack. 12:00 - 14:00 2.00 CASE P TIEB1 ND BOPE at the Split Speed Head. 14:00 - 16:00 2.00 CASE P TIEB1 Set emergency slips with 50K of tension over string weight. Make rough cut on 7" casing. Remove landing join plus 10.59' cut joint. Make final cut on 7" csg and dress off stump. 16:00- 16:30 0.50 CASE P TIEB1 Set pack-off and RILDS. 16:30 - 18:30 2.00 CASE P TIEB1 NU BOPE and test packoff to 3,000 psi for 15 min. 18:30 - 19:00 0.50 CASE P TIEB1 Test 7"x 9-5/8" annulus and LT packer to 3,000 psi for 30 minutes - okay. Witnessing of test waived by John Crisp of the AOGCC. 19:00 - 20:30 1.50 WHSUR P TIEB1 Change out saver sub on Top Drive. 20:30 - 22:30 2.00 WHSUR P TIEB1 RU Sliokline unit to retrieve RBP. 22:30 - 00:00 1.50 FISH P TIEB1 Pressure test lubricator. RIH w/overshot. 10/6/2002 00:00 - 00:30 0.50 FISH P TIEB1 Continue RIH w/overshot. 00:30 - 01:30 1.00 FISH P TIEB1 RIH, latch onto RBP and pull to equalize pressure across the plug. Jar down on the packer and PU. Sheared off of plug, leaving Baker overshot on RBP. 01:30 - 02:30 1.00 FISH P TIEB1 POOH. RPB was not recovered. Change out GR to a GS shear tool. Add a sinker bar, RIH. 02:30 - 03:00 0.50 FISH P TIEB1 RIH with overshot. 03:00 - 03:30 0.50 FISH P TIEB1 Latch onto and jar up on the RBP. Jarred multiple times and pulled to 1,600 lb. Sheared off of tool. 03:30 - 04:30 1.00 FISH P TIEB1 Change out shear pins, RIH w/overshot. 04:30 - 12:00 7.50 FISH P TIEB1 Latch onto and work at pulling RBP. RBP would not pull free. Shut in well and pump up to 300 psi on the 7" casing, no leakoff of pressure. Release pressure, jar down on RBP to shear off and equalize sleeve, POOH. Close in well and pressure up on packer, pumped in at 3 BPM at 300 psi. RU 3-5~8" stem and 2-1/2" hydraulic jars, RIH, (#5), latch onto and pull packer free. 12:00- 14:30 2.50 FISH P TIEB1 POOH and LD RBP. 14:30 - 16:00 1.50 FISH P TIEB1 RD lubricator extension and lubricator. RD and LD slickline tools. 16:00 - 17:00 1.00 RUNCOkP COMP RU Torque Turn and casing equipment. 17:00 - 00:00 7.00 RUNCOr P COMP Make up and thread lock packer. Run 120 jts of 4-1/2", 12.6#, 13CR80, Vam-Ace tubing, with average MU torque of 3,600 fi-lb, using Best-O-Life PTC thread compound. 10/7/2002 00:00 - 08:00 8.00 RUNCOr P COMP Run 200 jts of 4-1/2", 12.6#, 13CR80, Vam-Ace tubing, with average MU torque of 3,600 fi-lb, using Best-O-Life PTC thread , compound. Continue running 4-1/2", 12.6 lb/fi, 13CR80, New Vam tubing to 10,811'. 08:00 - 10:30 2.50 RUNCO~/I~I DPRB 'COMP POOH with 4-1/2" tubing from 10,811' to 8,715'. Insert top 'X' nipple in string. 10:30 - 14:00 3.50 RUNCO~/P COMP Continue RIH with tubing to 10,920'. Ran a total of 200 jts of Printed: 10/14/2002 9:45:41 AM BP EXPLORATION Page 13 of 13 Operations Summa Report Legal Well Name: A-22 Common Well Name: A-22 Spud Date: 4/14/1982 Event Name: WORKOVER Start: 9/11/2002 End: 10/8/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 10/8/2002 Rig Name: NABORS Rig Number: 2ES Date From -To Hours Task Code NPT Phase Description of Operations 10/7/2002 10:30 - 14:00 3.50 RUNCOI~!~ COMP 4-1/2" tubing with Vam-Ace connection, 56jts of 4-1/2", 12.6#, 13CR80, New Vam tubing plus 9.87' and 9.86' pup joints. UWT= 150K, DWT-- 100K. 14:00 - 15:00 1.00 RUNCOI~I~ COMP MU hanger, land tubing, RILDS. 15:00 - 16:30 1.50 RUNCOI~!~ COMP Reverse circulate clean corrosion inhibited seawater @ 3BPM and 250 psi. 16:30 - 18:00 1.50 RUNCOI~ COMP Drop Ball/Rod. Pressure up on tubing, set packer. Pressure up to 3,400 - 3,325 psi and test for 30 minutes - okay. Bleed off tubing pressure to 1,000 psi. Pressure up 4-1/2" tubing x 7" casing to 3,000 psi and test for 30 minutes - okay. Bleed off tubing pressure and shear RP. (Pressure tests witnessed by John Crisp of the AOGCC). 18:00 - 18:30 0.50 WHSUR P COMP Install TWC and test to 1,500 psi for 15 min. Blow down lines. 18:30 - 20:30 2.00 RUNCOI~!~ COMP Change top pipe RAMS to 3-1/2" x 6" variable RAMS. ND BOPE. 20:30 - 22:00 1.50 RUNCOr~I= COMP NU Adapter Flange and Tree. Test Adaptor Flange to 5,000 psi for 10 min. 22:00 - 23:00 1.00 RUNCOr~I:' COMP Attempt to test Tree. No test. Pull TWC with lubricator. Change TWC. Test Tree to 5,000 psi for 10 minutes - okay. 23:00 - 00:00 1.00 RUNCOr~I:' COMP Pull TWC with lubricator. LD same. 10/8/2002 00:00 - 03:30 3.50 WHSUR P COMP RU circulating lines. Pump 75 bbl of diesel Freeze Protect. 03:30 - 04:30 1.00 RIGD P POST Install BPV. RD, remove secondary annulus valve, secure well. RIG RELEASE: 0430 hfs 10/8/2002 Printed: 10/14/2002 9:45:41 AM i MEMORANDUM TO: Camille O. Taylor, Chair State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 7, 2002 THRU' Tom Maunder, ~~/~ P. I. Supervisor to! ~c~ FROM: John Crisp, SUBJECT' Petroleum Inspector Tubing, Packer & Casing Test PBU A-22 PTD 1820180 Sundry 302-289 October 5, 2002: I traveled to Nabors Rig 2ES to witness the 7" casing, x 3 % tubing & Production Packer test on Bpx PBU well A-22. Summary: I witnessed the Production Packer set & 3 %" tubing tested internally to 3500 psi. Thetubing was pressured to 3500 psi. & Monitored for 30 minutes wi final test pressure observed@ 3450 psi. , , The 7" casing x 3 %" tubing (inCluding the production packer set @ 10867 MD) was tested to 3025 phi. The test Pressure was monitored for 30 minutes w/final test pressure observed @ 2925 psi. Non-Confidential Tbg,. Pkr. Csg. test PBU A-22 10-07-02jc.doc MEMORANDUM TO: THRU: Camille O. Taylor, ~ ,~"* Chair Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 5, 2002 FROM: John Crisp, SUBJECT: Petroleum Inspector Casing Test PBU A-22 PTD 1820180 Sundry 302-289 October 5, 2002: I traveled to Nabors Rig 2ES to witness the 9 518" x 7', annulus & tie back receptacle casing test on BPX PBU well A-22. Summary: I witnessed a successful 9 5/8" x 7" annulus & tie back receptacle casing test on ^-22. Tie back receptacle Packer depth 10894' MD. The initial test pressure 2480 psi. final pressure after 15 minutes 2470 psi. Non-Confidential Csg. test PBU A-22 10-05-02jc.doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor, ¢~ ~,v~ DATE: Chair Tom Maunder, P. I. Supervisor THRU: October 4, 2002 FROM: John Crisp, SUBJECT: Petroleum Inspector Casing Test PBU A-22 PTD 1820180 Sundry 302-289 October 4, 2002: I traveled to Nabors Rig 2ES to witness the 9 5/8'! x 7" Liner LapcaSing test OnBPX PBU well A-22. · AWLRBP was set 50' in the 7" Liner to isolate the Perforations for well control while running & setting 7" casing & tie back packer..The subsequent pressure test of the WLRBP allowed first liner lap test since original .completion of A-22. Summary: I witnessed a successful 7" WLRBP & liner lap test on PBU A-22. WLRBP depth 10950' MD. TOL 10886' MD. Initial test pressure 3025 psi. Pressure ~after.15 min. 3010 psi. Final pressure for test Was 3000 psi. after 30 Non-Confidential Csg. test PBU A-22 10-04.02jc.doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor, (~/~'~ DATE: Chair Tom Maunder, ~x~o~ P. I. Supervisor THRU: FROM: Chuck Scheve, SUBJECT: Petroleum Inspector September 29, 2002 Casing Cement Top Job BPX' PBU A-22 PTD#182-018 Sunday, September 29, 2002: I traveled to A Pad in the PBU and witnessed the cement Top Job on the Surface casing in well A-22.' The 9 5/8"surface casing in this well had been run and cemented to surface (20 bbls cement returns). After welding on the wellhead 1" pipe was run in 9 5/8 X 20"annulus and hard Cement was tagged at 45'. The top job was performed using 25 bbls of 15.4 ppg type C permafrost cement. Cement returns were noted at 12.5 bbls. SUMMARY: I witnessed the placement of a cement Top Job on the Surface casing in BPX well A-22 in 'the PBU. Attachments: None NON-CONFIDENTIAL MEMORANDUM _ State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor ~)'~'~.v~ Chairman THRU: Tom Maunder P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector DATE: September 29, 2002 SUBJECT: Casing Test BPX A Pad \~[_~. o'~ A-22 PBU Prudhoe Bay NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI A-22 I Typelnj. I I MD 110779 I Tubingl.,^ I,,^ I,,^I "'^ I lntervall P.T.D.I 182-018 ITypetestl ITestpsil 2695 I CasingI 0 I 3000l 3000 I 3000 I P/F I ---P Notes: Casing test during workover on producer WellI I Type Inj. P.T.D.I IType test Notes: WellI I Type Inj. P.T.D. I I Type test Notes: We,I I Ty.eInj. P.T.D.I IType test Notes: WellI I Type Inj. P.T.D.I I Type test Notes: Type INJ. Fluid Codes F = FRESH WATER IN J. G= GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) TeSt's Details I traveled to BPXs A Pad and witnessed 9 5/8" casing test on well A-22. A bridge plug and been set at 10779 and the casing had been replaced and cemented from 1983' to surface. Drill pipe was run in the hole to the top of bridge plug and the casing pressure tested to 3000 psi for 30 minutes with no leak off detected. M.I.T.'s performed': I Number of Failures: 0 Attachments: Total Time during tests: 1 hour cc: MIT report form 5/12/00 L.G. · Casing test A-22 9-29-02 CS1 .xls 1 O~3~2OO2 RECEIVED i SEP 2 0 ?,,,,. SEP ?. 0 2002 Ala~a~ & ~ com. Commission Al~aOil & ~ ~. ~~ BP E)~PLORATION - i ............................. Daily Ol~ra,t_LQEtARepo, rt .................. , ................... ,Page ~ =t 4 · Operator, I~P EXPLORATION Rig; NABOR$ 2E,.R Rep V~HI! A.2:~ Event; WORKOVER Dak 9/19/2002 :Field: PRUOflOE E~Y Weft ' C'~r~nt WMI Statua Depth MD: .... (R) Oasing Size: iin) ~4~te l,: ...... R~ AccaDt; .... t~;00 g/t~l Est. TVD: (fl) Casing ~ID): fit) D~ily Mb~l: 1,160 R~ Release: Program: (~) Next C~ming Si~e: On) Gum, Mue: 15,09B ~ Dat~: 4H411982 Auth Depth: 11 ,~00,0 (It) Next C.~ing (MO); (fl) Dally Well; ~2,~ WX Date; Hale SiZe: Next Casing (TVD); (fi) Cum. Well: 5~0.856 EUev ReP, MEAN :~l~, , LEVEL I;)OL/DFEdTatge~: Geol~gist; KB Elev; 'Engineer. PMI Smltl~ TeL Pemonnal; 32 i SuAe~ R, Ourd~ / I., veugi~an Progr;m: Co~t Ahlao 0, Days Ahead 2,thr ~mmaey: RIH wt & tt8" ova;aha, laJ~h a 1/'Z~ till. Mma¢ PEIR. Cireweli. F~H, LO fish, dummy run wi ~g cutter,. RIH wi 24hr Forecast; Can't RIH spears, latcl~ fill% Olrc, taCH Commen, ts~ .... No A~ldents, Ne I~la~ta, No Splila ........... HSE & Well Ggntrol ... : . Da~s*S'i~'~_~ ~'akt DAFwcI 194 .... All Foe Days: 9 L-st 80P larrups, T/at; 911~2002 Le~t ?rip Drill (Ot); gl1 g/2( )2, Naxt ~0P Press, Test: 9/22~002 LaSt Sal~lty Meeting: 9/19/2( 12 L~at Spill Oral: fl11612002 No. Sled Cards: I~gUliKOry Agenoy In$1~: N Non-ooml~llance Issued: N ................................... Pum~ .......... SlOW-P~'i~-¢'RAte~-(~'(~) ' ~ $1~ Pump Rams (C~e~,~)-' ' "al.~,'~ ~t""'(Al,) ' MAASSP: (pSi) Te~t Prei4Ure: (psi) Kick ToleranO$: (PPg) Kick Volume,: ~I~Pl} .... i ,. O'p'era,tl~),n'~it-P'arameters .................... , , ,, ,.... 'ReP D011)': Rgt~tiflg W~i~'~t: Daily I~it Hms -(fit) taamp 15t~tUa - Drilling al J Riaer ROD Oum,: Pick Up Wt.: Dally Slldln~ H~:O.OD (hr) PumO'?yPe Eft, SV01~'~'~'~' ;t~,e ~,lr¢, Rate WOIB (m~); Ch'¢. Rnta Ri~e~. RPM Min.: Cio, Rate HOle: Ann, Vel, Riaen [~m~n) RPM DH: Gin=, Off Battem; Ann, Vel, DC: TO~. a~ Bottom: CicG, On BOttom: Ann. Vel, DP: (fl/rain) t Tool. eft' BOttom: Ja' Hfs sifl;e I.=peo~. ,~r) j .. . , ......................... iSHA , t~h, N~: ~l .............. D'~j~'th-ln: 10,106.O ...... 'l~rt~ weight: .............. IBh,, 'r~Te: FISHING D~p;h Out~ 10.613.0 Wt Below J~rs: Campenent iComp~'r~;~t'O~iJ "' IJ;~ L=tlgtl~ ~.~'l,mgtn-'O'O ID Bmc~;'d~OemaAngle, Cenne1~ ~ ]PIB , ~ (fl) {It) (in) (~n) .......... (Iq) ....... (') S~e (in) Overarm; eo~I 1.7~ 2.26 8.t25 ~,.~O 'I - Top SubI~ 1.18 6,7B 9,125 3,000 xo Sub ~ 2.00 6,7'5 6,250 3,000 Pump out 8~,b ~ g,0O t0,63 6,375 2,062 ~Bum~erJir ~t 9.03 19.~ 6,250 3.~25 I ~011Jar t 11,50: t,36 8.250 2.250 I Dc'~ e 183.55 2q4.91 6,31B '~,~ Nef 4 ~ Depth In: t~':~5:b ' Oh& Weigh[~ ..... Bha T~pe; FISNl~ ~plh Out: ~ ael~ Jam: , eR) (e) (I,) (in) ,C;~) . (') ......... I_ S;~.~") ..... ~s,..,~,~o~'-' ~ ~':~ ...... ~.e~ ~,7~0z, ooo ( ISPwG,~o Gm~le t 3.28 6.93 5,7~0 2,000 ~lon ~ 3,2~ ~0,18 5,750 2,875 I ....................... .................. '" ~n~: RECEIVED OS/EO/OZ 07:12~ P.OO~ S EP ~ 0 2002 AlaskaOil&Ga~Co~.~ BP ~ml~PLORATION .... '"' ...................... '~aUy Ol~tions R~'p6~ .......... ' ........... . ~a~ ~ Even~ ~RKO~R Dat~ ~1~ R~: PRU~ ~T ~ T~: ....... .=- ...... .... '~1 ~~t ~11 I J~ ..... Cam Le~I OD ~D .... Br~e'OD~ ~gle~ XO~b ~ ~,~ 1~,~$ $,~$ ),~ PumpO~$~ 1 2.08 15.~ 6,375 2,~2 I ~u~erJat 1 g.O~ ~.97 6.250 3,125 ~OIl JSt ~ 11,S~S,47 6.250 2,250 , ~OC'$ 6 1~3,55 220,02 6,$?$ 2,876 , I~.~ ~ t2.95 2=~.~ ~.2so 2,~o Type', "S~ WA~R F'~-0'6~C'g6J~?- (l~lg0~ I Cm e00 '{m~) I ES~ TIm~: ~:00~IT t O m~ gels: (~110~} ~ K+; (m~)i Solids; Depth: ~0,~00. ~) Rluld Losa: (~min)~ C~CI2: (%) ~ Oil: (~ Funnel Vi~e,; ~ (~Qt) Oa~; (~2") $~; (%) Og3ly C~ings: ECD: ~Dg) MBT: (ppb} HGS: (ppb) Cum. Cuffings; PV: (cp) Lime: ~ppb) LGS: (PPb) Los~ D~nhole: ~ i.2 (bbl) YP: (l~O~) ~: <mL) ~tM~ I (m~L] Lest Su~: ~.=,,, 7,=...... . ........ ' Opamuo~a $~mma~ ....... . ............. ~rO~-TO Mr~ PnmBe T,s~ ~vi~ '~ Go~' NPT O~mtio~ Op, ~pth (hr) ........ 10,1~ ; t95k, TQ ~00 ~=s, Con't RIH w/~.~25" ovum,et on ~1 d~rl~ to top of~h ~ 10,182 ~. Work ~er ~sh ~ 10/ laP. Up~ '~:00.06;30 0,50 :~YE~FISH 8ULLHD P'" Bdllhe~'~~~l~~ I, Pr#~um 10,162 hel~ w/e~s e~ .... '-~' Biee~ ~O ~R~65 (, Me~or ~$T~g;09~O0--2T~- [NTE~9' '~E- ~ECO~I foliowln0 pressures; ~lOPP 200 ~si. SICP 2t 0 pSI. Ol~ ~ll thru 10, t ~ I choke s~9i~ p~p ~S I possums as ~lt~s: 5 BPN ~-2~0 ~i, [ 0~-40, Ghee full a~n, 51~ =ump to 2 BPM 50 bbl~ ,em M~ up. . S bbls I~ .~,, 8~ leSi~ e~ trip ~t, , "l~:OO-t6:O0 1,~ I~v FISH LO "~ '~:0~'t6:30" "0;~ i~-"rl'8H--; .... 'CiR ..... ~ p "'~'~ 4 ~PM / 60 psi ~6:3~tS:30 ~ IN~RV FiSH LO"" [ p ., LOeah. 100%m6~~ka~rde~lm'~f'~h ........................... '~:3d.19130 1.00 I~Y~" FISH GLN~ .... O ' - Ot#r fig flor, Glean ~eme from me~ue f~m f~h. [~U T$~ Drive & Ous~ th~U, ne t~ton~ e~l~ 2 ~n~a~ ~, LO easing I RECE)VED 09/20/02 07: 12A P. 009 ( , " e..X. Lo~'~i&a ............... : '" Dally Operations Report .... .,s~. ~ ...................... , .... ~00 Upham .......... .... o~. ~ J P~t ./ ,,,, ~0,~OOI ~ from ~t~ shed tO ~0,800 01',OO;'0~ ~ ~"'FI~ .... ~R P' ................. Est ~~k:~~ ~1 ' 36 RPM, 10.~1 ~ ~lbs TQ. " ; ;~Me ~h ~ 1~8~ 0 ~. 8lido s~a~ to No Go ~ lO,Z :1, Made 3 w; 5k ov~ ~UlI, ~q'~g~;~ ';,'00-~f~A~ FISH c[R-' "~ 'di~~~'/~u~6 a~ ~o~m~: ~ ..... t0,~9~ ~ BPM, DP.3~ ~i, ~ up, CO~t Clrc 40 ~b ~ ob~ln d#r 5W. (NO g~ (No tosses) ~,0~ 9 ~' ~. . ...... , - ~M ~id~F~ a, ~rgJons. ' ........ ' ..... . ............. '" ' ....... =' ' ' M~fl~ I-C~n~mptl~n , -. ............... , Pemonnel , .,. . ..... ..' ii ....... , .,., i i .' · , ,~ ~.~,~~-- '~~~" ' ......... .............. ~umul~l~e Phase Bm~kd~ ---- '" '~i~As~o ' ,_ ~ ' ...... C~.~e DECOMP 44.50 ~OO,0% ~. 0 307,4.5,75 INTEAV ~G.O0 ~00,~% ~--.~b,, , ...... " 'R~?ks ......... t~., ~.~ ~~2~,~'-~: .............. - 1 Seal ~y, 11,~ ~ 5SO assy 23,79 ff ~2jt 5112" tog 13J~ 3 I/~' t~g 410.09 ~ Gui ~3 1~" t~g 25.02 fl All compone~s ~snea lmm well ~ wi S~niillmtie, M~e~ for NORM. Ca~l~ msu~ (uR~lht) ~-2 FlOW chec~ ~owlBg ~11 Static On trip out, Total l~eg ~ ~e day - 34 bbl~ , · 11 i iii ii ,, , i mil , . 0@/20/02 07;'12~ P,00¢ Dally Operations Repo .rt, ........ P.ge 4 of 4 Well; A-~-~ ]~v~t: WORKOV~IN; ~te 9tt ~t ~la~: , ~~Y ,,, WeflTy~: .,, ~ ,~ ..... , Rema~ ..,:_ ...... i . L~ 9 5t~'xla ~a" l~ 13 ~S,~,r enn~lUa a~O ne ,omma~t~n ~ IA dung ~t~i~ contml~io~, . , ,,,,,, ..... , .., ............. . .............. REOE VED ............................................................. ~m: ~ s:~:~ A-22 RWO Addendum Subject: A-22 RWO Addendum Date: Thu, 19 Sep 2002 07:52:16 -0800 From: tom_maunder~admin.state.ak.us To: Jim Regg <jim_regg~admin.state.ak.us>, Cammy Oechsli <Cammy_Oechsli~admin.state.ak.us>, Daniel T Seamount JR <dan_seamount~admin.state.ak.us> Enclosed is the "revised" procedure for A-22. John Spaulding was sent this by the engineer (Phil Smith) on the rig last evening. Tom ~l A-22 Well Plan Addendum Name: 1 A-22 Well Plan Addendum Type: WINWORD File (application/msword) Encoding: base64 RECEIVED Alaska Oil & Gr~ Cons. Oommissio~ ^nd~or~e 1 of 1 9/19/2002 4:12 PM ECEtVED Alaska Oil & Gis Cons. Commlsslor,, Nabors 2ES A-22 RWO Well Plan Addendum #1 Change of Operations Due to Restriction Encountered in the 9-5/8" Casing Prepared by Phil Smith Approved By: Operations Drilling Engineer Date Senior Drilling Engineer Date GPB Rotary Drilling Manager Date Reason for Addendum: A restriction encountered in the 9-5/8" casing at -45 to 55', would not allow passage of the retrievable bridge plugs which were planned to be set in the well. Attempts to open up the restriction were unsuccessful, and therefore the plan is being adjusted to accommodate the use of a drillable bridge plug, which will pass through the restricted ID. The operations outlined below will begin once out of the hole with the IBP fishing BHA. RIH with overshot and packoff. Latch 3 1/2" tubing at 10,182'. assembly pulls free (75K lbs original pinning). Jar fish until PBR shears and seal o If fish is successfully pulled from the PBR, immediately close BOP's and bullhead down the drillpipe to expel gas from inside tubing below the IBP. Once tubing is flushed, bullhead down the casing side at max rate (up to 2000 psi) to. push gas into perforations. Calculated volume = 65 bbls, pump three times the calculated volume to the perfs or ~200 bbls. Then, CBU to remove any remaining gas from the well. Be prepared to shut in the well and circulate through the choke if necessary. As laying down the fish, break each tubing connection at surface as if trapped gas were present, though should be eliminated. o If fish does not jar free from the PBR, RU e-line and run 1-11/16" string shot as deep as possible through the drillpipe and perform a back off below the:GLM at ~10,220'. Skip bullheading and proceed to CBU. POH. A-22 Well Plan Addendum #1 09/18/02 Page 1 RU wireline, run 9 5/8" composite bridge plug (7.75" OD) and set at a minimum of 10,000'. Set within 20' of the PBR if fish jarred free. Test bridge plug to 2000 psi for 30 minutes. Run USIT from bridge plug to surface. Log areas of interest, especially tight casing near surface, at high resolution (300 fpm). Set a second composite BP at 2500' and test to 2000 psi for 5-10 minutes, POH. RIH with multi-string cutter to top of BP. Circulate at least two annular volumes of 140° seawater, and then displace the 9-5/8" casing above the BP to 110° 9.5 ppg viscosified dead crude (safe heating to 140°). Cut 9 5/8" casing at 2000' (higher if necessary after reading TOC from USIT). Once cut is made, close BOP and circulate out Arctic Pak w/110° dead crude at 2000 psi max. Once Arctic~,~,,,,,'-'-"~' Pak has been displaced, RIH to BP and displace the well to 9.5 ppg brine. o If the Arctic Pak is successfully circulated out, RIH to BP and displace the well to 9.5 ppg brine. Then pull up to 100' and make second cut as per original program, step #12. Proceed with original program from there on. o If the Arctic Pak cannot be circulated from the well, and there are signs of gas breaking out of the Arctic Pak, the 9-5/8" casing may be pulled at this point. This will allow the Arctic Pak to be cleaned from the well on a subsequent trip, prior to the extended operations without secondary well control at surface. If this path is chosen, proceed as follows: · POH with 9-5/8" cutter. · ~ ...... ~..,.,4~,.,. joint into RIH, Spear 9-5/8" casing VVl '~,l~Vy I~1 l'r~l, lll i~ . · Circulate out Arctic Pak with dead crude with mild (--one 30' stroke per 5 min) reciprocation of 9 5/8". · POH, LD casing. · RIH to 2000' 2500' w/string mill, circulate well to clean 9.5 brine. · Run camera as per original program. · Run Kinley and USIT in 13-3/8" casing from top of 9-5/8" stub to surface. Proceed as per step #18 in original program. Bill, we would like to modify step # 18, see Phil's Plan forward, dated 18, 2002 8:55 AM; located at bottom of page. A-22 Well Plan Addendum #1 09/18/02 Page 2 MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Camille O. Taylor, Chair Tom Maunder, P. I. Supervisor DATE: September 17, 2002 FROM: John Crisp, SUBJECT: Petroleum Inspector Casing Test PBU A-22 PTD 1820180 Sundry 302-289 Septe .mb.er 1.7,, 2002: I traveled to Nabors Rig 2ES to' witness the 9 518" casing test on BPX PBU well A-22. The well plan called for RBP to be run to a MD of 10000' to pressure test the 9 5/8",casing. The 9 5/8" casing was damaged @ 46' RKB. The RBP wi an OD of 8.25 would not pass thru restricted casing @ 46'. The Rig was attempting to swedge the casing to OD of 8.5 when I arrived on Site. This swedging .process had not been approved by AOGCC. ' BP requested I witness a pressure test of 2000 psi. Utilizing the Blind Rams on the BOPs. The Drilling Foreman stated that the test pressure of 2000 psi would meet State requirements of .25 psi per TVD foot of packer depth. I made the Drilling Foreman aware that the test pressure of .25 psi TVD foot was pressure criteria for proving mechanical integrity of Injection wells in State. I agreed that any successful pressure test of the damaged casing woUld probably have a positive bearing onthe AOGCC's approval of the next plan forward for A-22's Diagnostic work. After the successful casing test, I sPecifically requested a new plan forward from BP for approVal by our Engineers. The Operation after the 9 5~8" casing test waS to fish tubing Bridge Plug & exposing the production' perforations to the 9 5/8" casing & the wellhead, this plan was not approved or' reviewed by AOGCC. Approval of plan forward (after 9 5/8" casing test) could have quite poSsibly been granted by AOGCC if given the chance to review plan. The AOGCC's:approval should be required to allow workOver operations to Continue. on A-22 with Only 2000 psi. casing & lower wellhead test.. Summary: I Witnessed a successful 9 5~8" casing test on A-22. Packer depth MD 10821', TVD 8343. The initial test pressure 2070 psi. final pressure after 30 minutes 2025 psi. Confidential Csg. test PBU A-22 09-17-02jc.doc ALAS~ OIL AND GAS CONSERYATION COPlPIISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Randy Frazier Wells Delivery Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 September 11, 2002 Dear Mr. Frazier: A letter to BP Exploration (Alaska) Inc. (BPXA) dated August 27, 2002, advised that the AOGCC is actively conducting an investigation of the Prudhoe Bay Well A-22 incident. That letter requested information as part of our investigation. In response, you provided the following: 1. List of the wells operated by BPXA that were shut in; 2. A flow diagram and criteria used by BPXA to categorize wells with annular pressures; 3. Diagnostics to be performed by BPXA on the wells with annular communication; 4. Decision criteria used to recommend returning Wells that have annulus communication to production. An exchange of information during last week culminated in a meeting on Saturday, September 7, 2002, between BPXA and AOCJCC staff to specifically discuss the information provided that relates to items 3 and 4 above. Based on the Commission's review of the procedures and subsequent discussions, verbal approval was granted to restart production of wells shut in as a result of the Well A-22 incident. This letter formalizes the verbal approval for BPXA to proceed with production startup. Wells in category A/B3 (as defined by BPXA) are excluded from our approval. Also submitted for review and approval was a Sundry Application, Form 10-403, for a rig workover of Well A-22 (dated and received September 6, 2002). Proposed work is designed to establish well integrity to allow BPXA to re-initiate production from the well. The AOGCC has completed a review of the proposed workover. Attached is a copy of the approved Sundry application. The following conditions apply to the approval: 1. All work should be coordinated with AOGCC's North Slope Inspector so that pressure tests and critical operations of this workover can be witnessed; 2. The BOP equipment must be tested to 3,500 psi; 3. The outer annulus (OA), i.e., the space between the 9-5/8"inch and 7-inch casings, must be tested to at least 120% of the maximum anticipated operating pressure for 30 minutes. An acceptable test would be no more than 10% pressure loss with pressure approaching Stabilization at the end of the 30-minute test; 4. BPXA must submit a Subsequent Report with the workover results on Form 10-404; included with the Subsequent Report must be copies of the logs and tests that were run to confirm the pressure integrity of the production tubing, 7-inch casing, and 9-5/8-inch casing. 5. Any deviation from the written procedures requires additional review by the AOGCC prior to performing the work. Once production is re-established from Well A-22, BPXA must comply with the following: . BPXA must monitor and document pressures in all casing annuli daily. A record of such must be available to the AOGCC upon request. If sustained pressure is detected in Well A-22's OA, BPXA must, in addition to following its internal procedures, notify the Commission by the next working day and secure approval to continue to operate the well if it exhibits greater than 1,000 psi annulus pressure. You have mentioned that BPXA plans to conduct extensive evaluation of the failed 13-3/8" casing in Well A-22. The findings of BPXA's evaluation may affect the long-term operation of wells diagnosed with annular pressures and pressure communication. There were multiple barriers compromised in Well A-22 that led to the gas release and subsequent explosion. We encourage you to evaluate the other barriers and well components (wellhead sealing surfaces, tubing, gas lift valves, landing nipples, 9-5/8" casing) to learn as much as possible about this event so the long term decisions about operating wells with annular pressures can be improved. Please direct any questions regarding our approval to Jim Regg at 793-1236. Attach. Sincerely, Chair Mr. Randy Frazier September 11, 2002 Page 2 of 2 STATE OF ALASKA · ~' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL . 12. 1. Type of Request: [] Abandon [] Alter Casing [] Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 2298' NSL, 1704' WEL, SEC. 35, T11 N, R13E, UM At top of productive interval 3425' SNL, 4208; WEL, SEC. 02, T10N, R13E, UM At effective depth 3516' SNL, 4261' WEL, SEC. 02, T10N, R13E, UM At total depth 3835' SNL, 4445' WEL, SEC. 02, T10N, R13E, UM Present well condition summary Total depth: measured 12316 feet true vertical 9598 feet [] Suspend [] Repair Well [] Operation Shutdown t5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service [] Plugging [] Time Extension [] Perforate [] Pull Tubing [] Variance [] Other [] Re-Enter Suspended Well [] Stimulate Datum Elevation (DF or KB) KBE -- 76.7' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number A-22 9. Permit Number 182-018 10. APl Number 50- 029-20712-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Plugs (measured) IBP set at 10290' (08/2002) Effective depth: measured 11601 feet true vertical 8985 feet Junk (measured) Top of sand at 11601' Casing Length Size Cemented MD Structural Conductor 110' 20" x 30" 8 cu yds concrete 110' Surface 2705' 13-3/8" 3720 cu ft Permafrost II 2705' Intermediate 11401' 9-5/8" 1633 cu ft Class 'G', 130 cu ft PF 'C' 11401' Production Liner 1430' 7" 432 cu ft Class 'G' 10886' - 12316' TVD 110' 2689' 8819' 8411'-9598' Perforation depth: measured Open: Sag River: 11414'- 11434'; Ivishak: 11531'- 11601', 11608'- 11617', 11623'- 11662' Sqzd: 11444' - 11446' true vertical Open: Sag River: 8830'-8846'; Ivishak: 8926'-8985', 8991'-8999', 9004'-9037' Sqzd: 8854'- 8856' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 to 10821'; 2-7/8", 6.5#, L-80 to 10909' Packers and SSSV (type and measured depth) 9-5/8" Baker '3H' packer at 10821'; 3-1/2" Otis SSSV Landing Nipple at 2065' ~.,, '¢~: 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operai, ion September 8, 2002 16. If proposal was verbally approved Name of )rover Date Approved Contact Engineer Name/Number: Phil Smith, 564-4897 [] Detailed Operations Program ~ ..... 15. Status of well classifications as: .. :~::'iD r; .- ~.0~ []Oil []Gas []Suspended .... ~'- U 0 Service A~a. ska uii ~ (~J.S r~0~S, i~Oliiiiti~Siut 17. I hereby certify that the fo.~going is Irue and correct to the best of my knowledge Signed Billisaacson ~/.~'J~ ~t. Title Senior Drilling Engineer Prepared By Name/Nurnben Terrie Hubble, 564-4628 Date Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test X~ Location clearance Approval No. ~ ..... Mechanical lntegrity Test Subsequent form required l0- ~L/& C:) /'~ T~S~ ~O~E ~LO '~t:::)O ~o~i~. ' ~pproved by order (~f the Commission /' ...... "~ ~ ~ '- /~ - /7 ~-_ _ ~"'""-'~~ ~-,-m~c~t'-~ i'~ ~ ,~",~ ~ ~ ,;~. Commissioner Date ~ ~ ~ ',~ ':~ i: ? ~ ! Submit In Triplicate A-22 RWO Proposed Scope of Work Pre-rig: 1 2. 3. 4. Chemical cut the tubing just above the IBP at 10,290' MD Combo MIT tubing and 9 5/8" x tubing annuli Freeze Protect well. Set BPV, remove well house and other equipment from the vicinity. Proposed RWO: 1. MIRU. Pull BPV. 2. Circulate well to kill weight fluid. Set TWC. 3. ND Tree, NU and test BOPE. Pull TWC. 4. POOH and LD tubing. 5. RIH, set mechanical bridge plug at 10,000' in 9 5/8" casing. Test to 3000 psi (with test packer if necessary). Set a second bridge plug at 2500' MD. 6. Run SWS USIT to surface. Be prepared to spear and free point if TOC behind 9 5/8" casing is unclear (Calc TOC: 2200'). 7. Cut 9 5/8" casing with multi-string cutter in center of the first full joint above free point. 8. Spear and recover the 9 5/8" casing. 9. RIH w/casing scraper to top of stub and circulate out the Arctic Pack with diesel 10. Run Kinley Caliper the 13 3/8" casing. 11. RIH w/9 5/8" backoff tool and back of cut stub. Lay down same. 12. ND BOPs. 13. RIH w/multi-string cutter and cut the 13 3/8" casing at 20' below the wellhead. If the split is detected at 20' down, move down in one-ft increments until an appropriate cut point is found. Recover cut stub and existing casing head. (be prepared to jar, inspect derrick).. 14. RIH w/13 3/8" backoff tool to 40' below the tubing spool. Attempt to back off the top joint. Recover same if successful. 15. Position and weld an FMC landing ring directly onto the existing landing ring. Install diverter to allow returns to the pits. 16. Run 9 5/8" NSCC casing with a single 9 5/8" x 13 3/8" solid centralizer spaced 30' below the wellhead and screw into 9 5/8" casing below. 17. Set slips on 9 5/8" casing. RU false rotary table and run TAM collar tool. Open TAM collar and cement the 9 5/8" x 13 3/8" casing annulus to surface. Close TAM collar, POH. 18. Drain and nipple down the diverter, cleaning green cement from the wellhead. Cut 9-5/8" casing at proper height and weld on the FMC transition nipple. After pre-heat, welding, post-heat and testing of the transition nipple, install FMC Gen 5 USH Unihead. Test Metal to Metal seals to 1000 PSI. 19. NU and test BOPs 20. Recover storm packer and 9 5/8" bridge plug. 21. RIH w/overshot. Latch fish and attempt to rotate out the K anchor. Jar fish free if necessary. 22. Mill or burn over the 9 5/8" BOT packer and recover same. 23. RIH w/9 5/8" casing scraper, boot baskets, and 7" liner tieback receptacle polishing mill. Polish TBR and POH. 24. RIH w/7" casing with 7" x 9 5/8" packer weight-set packer. Locate into the 7" TBR. Reverse in inhibited seawater and 2200' of diesel to the 7" x 9 5/8" annulus. Slack off through the annular preventor and set the 7" hanger/packer. Bleed off annulus pressure. 25. Split the BOP Stack and set 7" C-21 slips / casing hanger with at least 30K lbs tension. 26. Cut and dress off the 7" casing, set pack-off either from the cellar or the Rig Floor.vT'est packoff to 80% of casing collapse. NU and test BOPs. "r"~ 7 '~ c,~. 27. Run new 3 Y2" 13-Cr completion. 9/6/02 A-22 Scope of Work 28. 29. ND BOPE. NU Tree. Freeze protect well. RDMO. Post-rig: 1. Install wellhouse and flow lines. 2. MIRU slick-line. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Pull the RP shear valve and install gas lift valves. Estimated Workover Time: 14 days Phil Smith Operations Workover Engineer 9/6/O2 A-22 Scope of Work TREE -~ 4" CIVV V)/ELLHEAt;;)~- ~:MC 11 G5 ACTUATOR= AXELSON KB. ELEV = 76.66' BF. ELEV = 51.84' KOP = 2000' Max Angle = 51 @ 7600' Datum MD = 11470' Datum 'rVD = 8800' SS A-22 r'roposed I 13-3/8" CSG, 72#, L-80, ID = 12.347" Id, 2705' SAFEr', ES: 13 318" surface casing has been cut and pulled at 20' below the wellhead. TOC behind the 13 318" casing is confirmed at 20'. The 9 5/8" tieback is cemented from the port collar to surface. 2000' I 2200' 2605' Id 9 5/8" Port Collar/cement to surface Id Calc'd TOC original 9 5/8" run J Id DV PKR W/CEMENT ON TOP I JKOP = 2000' MD 26#/ft L-80 NSCC Id 10,886' Tieback Receptacle I-i ~o, ss~' 3-1/2", 9.3#, V13-Or Vam Ace, 0.0087bpf, ID = 2.992" 10900' GAS LIFT MANDRELS ST MD 'FVD DEW TYPE SIZE LATCH 6 3050 2877 29 OTIS 1.5" RA 5 6325 '5203 51 OTIS 1.5" RA 4 8211 6396 50 OTIS 1.5" RA 3 8966 6944 44 OTIS 1.5" RA 2 9656 7450 43 OTIS 1.5" RA I 10221 7817 42 OTIS 1.5" RA 10865' Id3-1/2" OTIS X NIP, ID= 2.813" J 10821' I-~7"x 4.5"w/xo 3 1/2" BOT S-3 I ~OSTS' I-I~ ~,~,,x ~,, Baker JMZX packer I ~osss' I-I~-~,='' o~,s x.,.. ,0= ~oss5' I-1~-~2'' XN .~= 2.~so" I 19-5/8"CSG, 47#,L-80, ID=8.681" Id 11389' PERFORATION SUMMARY REF LOG: BHCS 05/01/82, CBL 05/05/82 ANGLEATTOP PERF: 36 @ 11414' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 11414-11434 O 04/13/88 2-1/8" 4 11444-11446 S 06/13/89 2-1/8" 6 11531-11601 O 01/07/91 2-1/8" 2 11608-11617 O 07/25/89 2-1/8" 2 11623-11662 O 07/25/89 11380' I--IMARKERJO'NT I I ~T':' I-'1' [ 7" LNR, 26#, L-80, U4S, 0.0383 bpf, ID = 6.276" 12273' 12316' DATE REV BY COMMENTS DATE REV BY COMMENTS 05/06/82 ORIGINAL COMPLETION 08/17/02 DDW/KK SET BKR IBP 01/31/01 SlS-MH CONVERTED TO CANVAS 08/23/02 JLA/KK DV PKR & CEMENT 03/02/01 SIS-LG FINAL 09/05/02 PGe Proposed post RWO Completion 05/21/01 RN/KAK CORRECTIONS 11/01/01 WBFFP SURF LOC CORRECTION PRUDHOE BAY UNIT WELL: A-22 PERMIT No: 182-0180 AP! No: 50-029-20712-00 SEC 35, T11N, R13E BP Exploration (Alaska) 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Phone (907) 279-1433 Fax (907) 276-7542 To: John W. Katz From: Lisa Weepie Fax: (202) 624-5857 Pages: 3 Phone: 564-5183 Date: 8/27/2002 Re: Incident on well A-22 CC: X Urgent [] For Review [] Please Comment [] Please Reply [] Please Recycle · Comments: 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Phone (907)279-1433 Fax (907) 276-7542 To: Fritz Gunkel From: Lisa Weepie Fax: 564-5200 Pages: 3 Phone: 564-5183 Date: 8/27/2002 Re: Incident on well A-22 CC: X Urgent [] For Review [] Please Comment [] Please Reply [] Please Recycle · Comments: ALASILA OIL AND GAS CONSERYATION COPl~IISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 August 27, 2002 FritZ Gunkel BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Dear Mr. Gunkel: The Alaska Oil and Gas Conservation Commission ("AOGCC") appreciates your participation and that of Messrs. Joe Anders and Randy Frazier in a meeting with our technical, staff on Friday, August 23, 2002 to provide an overview of the preliminary findings from the investigation by BP Exploration (Alaska) ("BPXA") into the gas release, and resulting explosion and fire at Prudhoe Bay Unit Well A-22. We understand that BPXA is currently reviewing the findings and recommendations prepared by your investigation team. Please be advised that 20 AAC 25.205 requires BPXA to submit a final written incident report to the AOGCC by September 16, 2002. During the August 23 meeting, you indicated that BPXA has identified more than 120 wells within, the Prudhoe Bay field that have outer annulus communication that warrant further investigation. Some wells require immediate action that BPXA is moving forward to implement. Further news reports this past weekend indicate that BPXA has now identified roughly 150 wells within the BPXA-operated North Slope assets affected by adverse annular pressure communication. As a precautionary measure, we understand that BPXA intends to shut in those 150 wells to facilitate well integrity investigations. The AOGCC is gathering information about this particular incident, well A-22's construction and history, operating practices, and the policies employed by BPXA for managing pressure in a well. The AOGCC investigation is also looking into the incident to understand the potential for other wells on the North Slope to similarly fail. Our investigation is interested not only in the cause of this incident, but also in how future incidents of this type can be prevented. To accomplish the objectives of our investigation, please provide the following information by Thursday, August 29, 2002: 1. List of the wells identified by BPXA that will be shut in; Mr. Fritz Gunkel August 27, 2002 Page 2 of 2 2. Sequence of shut-ins should they not occur at the same time. As part of this effort, provide written guidance on the decision criteria for allowing wells to remain in production pending the shut-in for diagnostic testing; 3. Diagnostics to be performed by BPXA on the wells with annular communication; and 4. Decision criteria used to recommend returning wells that have annulus communication back into production. Please coordinate with the AOGCC prior to returning these wells to production in order to allow for review of the test results and other relevant details. Workovers that are required to establish well integrity, and abandonment activities deemed necessary to eliminate well problems must be approved by the AOGCC prior to initiating work. It may be feasible to address groups of wells in lieu of individual approvals depending on the type of diagnostics and remedial work planned. Please .direct any questions regarding the AOGCC investigation and this letter to Jim Regg at 793-1236. cChaar~r y O~chsli Taylor Sincerely, Daniel T. Seamount, Jr. Commissioner STATE OF ALASKA · Al., ...,~ OIL AND GAS CONSERVATION COMMIS.. 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519.6612 4. Location of well at surface 2299' NSL, 1704' WEL, Sec. 35, T11N, R13E, UPM At top of productive interval 1855' NSL, 1076' EWL, Sec. 02, TION, R13E, UPM At effective depth 1783' NSL, 4250' EWL, Sec. 02, TION, R13E, UMi At total depth 1447' NSL, 840' EWL, Sec. 02, TION, R13E, UPM 12. Present well condition summary Total depth: measured Effective depth: REPORT OF SUNDRY WELL OPERATIQN ! Stimulate × Plugging Perforate Alter casing Repair well .. 5. Type of Well: Development Exploratory Stratigraphic Service true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Other .... 6. Datum elevation (DF or KB) KBE = 76.66 AMSL, ,feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-22 (13-02-10-13~ PBU 9. Permit number/approval numb;~r 82-18/9-441 10. APl number 50- O29-2O712 11. Field/Pool Prudhoe Oil Pool 12316feet BKB 9598feet Plugs (measured) 11560feet BKB 8874feet Junk (measured) fi#at 11800' MD (08/89) Length Size Cemented Measured depth True vertical depth -. BKB 110 20x30 8 c.y. 135 135 2680 13 3/8 3720 c.f. 2705 2689 11376 9 5/8 1763 c.f. 11401 8819 1430 7 432 c f. 10886-12316 8410.9598 measured 11414'-11434'(SagR) Sqzd: 11444'-11446' 11531'- 11601', 11608'-11617', 11623'-11662' (Ivishak) true vertical subsea 8753'-8770' (S.a~/ R) 8849'-8961' (two lvishak Intervals) Tubing (size, grade, and measured depth) 31/2" L-80 to 10821' with2 7/8" tailpipe to 10909' R E ~ E J V E D Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 10821'; 3 1/2" SSSV at 2065' APE{ 1 2 t99! 13. Stimulation or cement squeeze summary (see attachment) ' Alaska 0il & Gas Cons. C0[~iss Intervals treated (measured) /tnch0rag8 Treatment description including volumes used and final pressure 14. Reoresentative Daily Average Production or In!ectiop Dat~ OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 1140 1958 141 3160 v 3983 229 16. Status d wellclasslicationas: Oil X Gas .~ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ 9. ~ ~,~ Form 10-404 Rev 06/15'~8 1213 272P~ 1203 286 Service Supervisor Waterflood/Miscible Flood Date SUBMIT IN DIJPLICATE WELL A-22 (13-02-10-13) PBI. I REPERF/IVISHAK FRAC OPERATIONS 1/8/91 1/18/91 Rigged up Schlumberger and reperforated the interval 11531' - 11601' MD BKB using 2 1/8" carrier guns at 6 spf. Returned well to production and tested. Performed hydraulic fracture of the Ivishak interval. Cleaned out well and returned well to production and tested. t EC. EIVED APR 'I 2 ~99'! Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date: 01/16/91 T#:82004 FROM' SUBJECT: Information Control Well Records LR2-1 BP ~A~ED HOLE ~NALS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. A-22 PERF 01/08191 #1 10804-11684 SCH 5" Distribution: ARCO CHEVRON EXXON GEOSClENCES MOBIL PHILLIPS RI::RI~RVOIR .... E ARCHIVES RECEIVED dAN ~ ~ 19.c)! ~laska Oit & ~'~ Cons. Commission Ant, borage BP EXPLORATION November 10, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-22 (13-02-10-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of performing a cement squeeze and reperforation of the well. Yours very truly, Manager Production Engineering JAB: JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File RECEIVED chor' i STATE OF ALASKA AL, .-./~A OIL AND GAS CONSERVATION COMMIS,..,N _~.~ REPORT OF SUNDRY WELL OPERATI Stimulate X Plugging Perforate Repair well 5. Type of Well: Development ~( Exploratory. . Stratigraphlo Service.. , Plugs (measured) 1. Operations performed: Operation shutdown ...._ Pull tubing. Alter casing 2. Name of Operator (Alaska) Inc. 3, Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4, Location of well at surface 2299' NSL, 1704' WEL, Sec. 35, T11N, R13E, UPM At top of productive interval 1855'NSL, 1076'EWL, Sec. 02, TION, R13E, UPM At effective depth 1674' NSL, 970' EWL, Sec. 02, TION, R13E, UPM At total depth 1447' NSL, 840' EWL, Sec. 02, TION, R13E, UPM 12. Present well condition summary Total depth: measured true vertical 12316feet BKB 9598feet Other x GIN^[ 6. Datum elevation (DF or KB) KBE,, 76.66 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-22 (13-02-10.13) PBU 9. Permit number/approval number 82-18 / 9-441 10. APl number 50- 029-20712 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 11800feet true vertical BKB 9154feet Junk (measured) fill at 11800' MD (08/89) Casing Structural 'Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth .. 110 20x30 8 c.y. 135 2680 13 3/8 3720 c.f. 2705 11376 9 5/8 1763 c.f. 11401 Tubing (size, grade, and measured depth) ii 1430 7 432 c.f. 10886-12316 measured 11414'-11434' (Sag R) 11531'-11601', 11608'-11617, 11623'-11662' (Ivishak) true vertical subsee 8753'-8770'(Sag R) 8849'-8961' (two Ivishak intervals) 3 1/2" L-80 to 10821' with 2 7/8" tailpipe to 10909' True vertical depth BKB 135 2689 8819 Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. 9 5/8" BOTpacker at10821'; 31/2" SSSV at 2065' R ~_ ~_~ E j V E0 Nov 1 Alasla 011 & Gas Cons. Anchorage Reomsentative Daily Average Production or In!ectiorl Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 1280 1395 2569 1923 316 1580 1450 95 1439 302 I 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. Form 1~,-~4 Rev 06/15/88 ~/~/ Manager Production Engineering SUBMIT IN DUPLICATE WELL A.22 ¢13.02.10.13} PBU CTU CEMENT SOUEEZE OPERATIONS _ 6/2/89 6/12/89 6/13/89 6/18/89 7/12/89 7/16/89 7/18/89 7/23/89 7/25/89 7/26/89 Rigged up Schlumberger and shot squeeze perforations in the Sag R. formation (11444'-11446' MD BKB) using 2 1/8" carrier guns at 4 spf. Rigged up coiled tubing unit and pressure tested BOP's to 4000 psi. Performed a perforation cleanup using 2000 gal. 12% HC1. Liquid packed the well. Cement squeezed all perforations. Reversed out, then reversed in nitrogen blanket. Performed inflow test, okay. Rigged up Schlumberger and reperforated the following Sag R. interval using 2 1/8" carrier guns at 4 spf: 11414' - 11434' MI) BKB Performed a hydraulic fracture of the Sag R. formation. Cleaned out frac sand and returned the well to production. Rigged up Schlumberger and reperforated the following Ivishak interval using 2 1/8" carrier guns at 2 spf: 11623' - 11662' MD BKB Cleaned out wellbore of remaining frac sand. Rigged up Schlumberger and reperforated the following Ivishak intervals using 2 1/8" carrier guns at 2 spf: 11531' - 11601' MD BKB 11608' - 11617' MD BKB Returned well to production and tested. jam 10/26/89 RECEIVED t ov 1. lg Cons..Commlssi chor BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 08/17/89 Transmittal:80272 From: I°nformation Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact us at (907)564-4445. A-22 PROD-F 08-01-89 91 11300-11792 Camco C-04 CCL 08-03/04-89 91 9400-10688 Camco 5" F-02 TEMP/FM 08-06-89 91 8600-10600 Camco W-03 CCL 08-03-89 81 9000-9800 Camco 5' 'Y-10 GAS LiFT 08-06-89 81 500-9800 Camco 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCE HOUSTON MOBIL PHILLIPS RE~.ERVOt-~ ........................ , STATE OF ALASKA' . ARCHIVES BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (9O7) 561-5nl To: Distribution From: Subject: Information Control Well Records LR2-1 ~BP CASED HOLE FINAL LOGS Date: 04-AUG-89 Transmittal: 80226 Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907)564-4445. X-t9 CCL 07/30/89 91 9150- 9830 Atlas A-22 Completion 07/26/89 41 11333-11760. Sch Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL 'PHILLIPS RESERVOIR STATE OF A£AS A BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO HOUSTON ARCO CHEVRON EXXON MOBIL' PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR ARCHIVES Date: 07/28/89 T#: 80205 BP CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: A-22 Completion 07/12/89 #1 10654-11923 Sch 5" A-25 Completion 07/14/89 #1 11995-12747 Sch 5" E-28 CTU Prod 07/16/89 #1 10211-12247 Sch 5" F-23 Prod 07/18/89 #1 11000-12285 Sch G-18 Collar 07/19/89 %1 10070-10448 Atlas 5" G-23 TDT-P 07/14/89 %1 8508-10552 Sch 5" H-26 Completion 07/14/89 %1 8784-9984 Sch 5" J-08 Perf-R 07/18/89 %1 12000-12420 Sch 5" J-14 Perf-R 07/19/89 %1 10280-10524 Sch J-22 Completion 07/15/89 %1 9288-10481 Sch 5" Received: ,, Date: Information Control Well Records LR2-1 J. Dietz/S. McCurry BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Henson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution From: Subject: Information Control Well Records LR2-1 BP CASED HOLE FINAL LOGS Date: 26-JUL-89 Transmittal: 80211 Enclosed is Your copy of the material listed below. If you have any questions, please'Contact BP Well Records at (907)564-4445. A-22 Perforating 07/23/89 %1 11623-11662. Sch 5" H-24 Production 07/21/89 %1 9600-10000. Sch 5' J-24 SQ. Peri 07/22/89 %1 10550-11621. Sch 5" R-13 Perforating 07/23/89 %1 9600-9955 Sch 5" W-03 CBT 07/23/89 %2 9200-9895 Sch 5" W-03 Perforating 07/24/89 ~2 9250-9900 Sch X-17 Completion 07/24/89 %3 8975-9815 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS RESERVOIR STATE'OFALASKA BP EXPLORATION BP Exploration (Alaska) Ina. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To HOUSTON ARCO CHEVRON EXXON MOBIL ' PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR ARCHIVES Date: 06/09/89 T%: 80118 BP CASED HOLE FINAL LOGS The folloWing material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: A-18 Collar 06/05/89 %1 9235-10235 Atlas 5" A-22 Completion 06/02/89 ~1 11300-11783 Cch 5' A-35 Completion 06/02/89 ~1 9550-9775 Sch 5" C-26 Completion 06/03/89 ~1 11223-11754 Sch 5" F-07 GR 06/03/89 #1 9157-11590 Sch 5' J-02 Collar 06/04/89 ~1 9100-101184 Atlas 5" N-11A Gas Lift Temp Cur 05/17/89 %1 2500-10603 Camco 1"/5" N-19 Gas lift Temp Cur 05/17/89 ~1 2500-10010 Camco 1"/5" S-15 Temp-Sp,~n 05/20/89 %1 2500-11458 Camco 1"/5" Q-04 Completion 06/04/89 ~1 9365-9600 Cch 5" J-06 GR 05/16/89 %1 10000-11452 Camco 5" W-37. Pits 05/19/89 %1 9650-10214 Camco 5" GC-1C Collar 06/03/89 ~1 5-3585 Sch 5" GC-lC Straddle Ass Setting Record 06/03/89 %1 3368-3595 Cch 5" Received: Date: .~C '1 rmation Control J h ]989 Well Records LR2-1 J. Dietz/S. McCurry Naska0il&GasCons. Commission Anchorage STATE OF ALASKA '""~: AL,-,~KA OIL AND GAS CONSERVATION COMMIS~,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing Repair well Change approved program . 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2299' NSL, 1704' WEL, Sec. 35, T11N, R13E, UPM At top of prodUctive Interval 1855' NSL, 1076' EWL, Sec. 02, TION, R13E, UPM At effective depth 1528' NSL, 888' EWL, Sec. 02, TION, R13E, UPM At total depth 1447' NSL, 840' EWL, Sec. 02, TION, R13E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical operation Shutdown Re-enter suspended well. · Plugging Time extension Stimulate Pull tubing ~ Variance Perforate ...... 01~er X 5. Type of Well: Development x Exploratory Stratlgraphlo Service i i 6. Datum elevation (DF or KB) KBE , 76.66 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-22 (13-02-10-13) PBU 9. Permit number 82.18 10. APl number · 50- 029-20712 11. Field/Pool Prudhoe 0il Pool 12316 feet BKB 9598 feet Plugs (measured) 12126 feet BKB 9432 feet Junk (measured) fill at 12126'MD (05/88) Casing Length Structural -- Conductor 110 Surface 2680 Intermediate 11376 Production -- Liner 1430 Perforation depth: Size Cemented Measured depth True vertical depth BKB 20x30 8 c.y. 135 135 13 3/8 3720 c.f. 2705 2689 9 5/8 .1763 c.f. 11401 8819 7 432 c.f. 10886-12316 measured 11414'-11434' (Sag R) 11531'-11601', 11608'- 11617', 11623'- 11662' (Ivishak) true vertical subsea 8753'-8770' (S.a~ R) 8849'-8961' (two Ivishak intervals) Tubing (size, grade, and measured depth) 3 1/2" L-80 to 10821' with 2 7/8" taiip~e to 10909' 8410-9598 RECEIVED MAY 2 6 ]989 Naska 0ii & Cas Cons. Commlssl0fl Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 10821'; 3 1/2" SSSV at 2065' Anchorage 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation June 1989 16. if proposal was verbally approved Oil X Gas Name of approver Date approved Service i~. I'hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~~// TitleMana~lerProductionEn~lineerin~l FOR COMMISSION USE ONLY Condit~ns of approval: Notify Commission so representative maY witness Plug integrity BOP Test~ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- ~ 0~ 15. Status of well classification as: Suspended , Approved by order of the Commission Form 10-403 Rev 06/15/88 Commissioner t~ppro~ted CoPY SUBMIT IN TRIPLICATE · General Procedure A-22 NRWO March 22, 1989 Shoot squeeze perforations in the Sag River- 11444'-11446' , 4-6 SPF · . · · MIRU coiled tubing unit. Perform a perforation cleanup using 2000 gallons 12% HC1. Liquid pack the well. Perform a CTU squeeze. Squeeze to 3500 psi differential. Reverse out excess cement after holding squeeze pressure for 30 to 40 minutes. ** Reverse in nitrogen blanket· Leave well with 500 to 1000 psi overbalance during WOC. 7, Inflow test and pressure test to 3500 psi. Resqueeze if necessary. 8. Reperforate the Sag River formation· 9.. Frac the Sag River formation. 10. Reperforate Ivishak Formation. 1 1. Put well on production. RECEIVED MAY ~ 6 1~89 Oil & ~s Cons. ¢o~,'n~ssion Anchorage Coflcd Tubfng J31ow-Out-Prcvent~rs Co'/led Tubing oo P a c ~<-O f"~ " L_~ Bttnd Rams Cutter Rams '(-'~2" Chk::ksan (KI[[ Line) P~pe ~ams .Pump-in Sub (Circul. a t e."R e turn Head Swab Valve RECEIVE, ) MAY R 6 ]959 Alallka Oil & Gas Cons. Co~nmissio[~ Anchor-age :.. DALLAS ARCO CHEVRON EXXON TEXACO lO: MOBIL REFERENCE: PHILLIPS STATE OF ALASKA GEOSCIENCES ARCHIVES : SAPC CASED HOLE FINAL LOGS INDEXED STANDARD ALASKA PRODUCTION D~te: 05/12/88 T/: 78830 A--1 A-5 A-14 A-15 A-21 .... .'A.,--. 22 ~-0~ X-04 The following material Is being submll-fed herewith. Please acknowledge receipt by slgnlng a copy of this letter and returnlng It to thls offlce: PFC 03/31/88 #1 '7700-9167 Atlas 5" Collar 04/01/88 #1 .9000-11000 Atlas 5" Collar 04/01/88 #1 ' 8600-9851 Atlas 5" Collar 04/19/88 #1 10450-11000 Atlas 5" PFC 04/13/88 al 11150-12142 Atlas 5" Collar 04/13/88 al 11050-11800 Atlas 5" Collar 04/15/88 #1 10700-11800 Atlas 5" Collar 04/04/88-~ al 11100-11300 Atlas 5" Collar 04/14/88 al 8950-9400 Atlas 5" Collar 04/08/88 al 11156-11441 Atlas 5" Collar 04/02/88 al 9350-9620 Atlas 5" Race A un,,I ol ,he o,,9.,,,o! 5,ondo,d (~1 Co-po.). Fo,...'.ded ,.',,, Cle*el.r,d 0~,o. ,. 1870 Wel I Records LR2-1 I NDE XED DALI.AS ^Rco Sl'~l~l D~R D CHEV~O~ AL ASKA PRODI J(. TION E,~<ON Oate: 05/11/88 TE,v~c 0 TO: TI: 78824 MOBIL PHIl. LIPS STATE OF ALASKA REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material ls being submitted herewith. Please acknowledge receipt by slgnlng a copy of this letter and returnlng It to this offlce: ~2i'~ii.' Static Gradient 05/05/88 A-35 Static Gradient 05/05/88 C-19 Static Gradient 05/04/88 C-27 Static Gradient 05/04/88 C-30 Static Gradient 05/03/88 C-31 Static Gradient 05/04/88 H-12 BHPS static Gradient 04/30/88 H-22 BHPS Static Gradient 04/29/88 K-6 Static Gradient 04/28/88 X-5 BHPS Static Gradient 05/03/88 X-9 BHPS Static Gradient 05/03/88 X-15 Static Gradient 05/06/88 X-27 Static Gradient 05/06/88 Y-10 BHPS Static Gradient 05/01/88 Y-21 BHPS Static Gradient 05/01/88 Camco Camco Camco Camco Camco Camco Otis Otis Camco Otis Otis Camco Camco Otis Otis Recel red Alice Beck J NFORMAT I ON CONTROL Date Wel I Records LR2-1 u,,,! vt the INDEXED DALLAS ARCO CHEVRON STANDARD ALASKA PRODUCTION EXXON ': TEXACO " Date: 05/03/88 TO: MOBIL T#: 78788 GEOSC IENCES REFERENCE: SAPC CASED HOLE FINAL LOGS The following materlal is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: A-17 E-17 E-24 K-Il M-18 X-lO Y-24 Z-08 Water Injection Profile Production Cont. Flow Temp. Cont. Flow Temp. Cont. Flow Temp. Perf. Record Temp/Pump-in Completion Record Temp. 04/25/88 #1 9885-10216 Sch 5" 04/23/88 #1 11350-12122 Sch 5" 03/18/88 #1 10700-11181 GO 5" 03/19/88 #1 10300-10660 GO 5" 03/18/88 #1 11300-11620 GO 5" 04/27/88 #1 8252-9469 Sch 5" 03/23/88 #1 10600-10950 GO 5" 04/24/88 #1 13095-13319 Sch 5" 03/28/88 #1 SURF-7765 GO 2" -MAY Rece i red Date A u~et ol ,he O~'~rn. ol ~.~'o~do,d C)~l Com~ony ~ounded .,q Cle.elond. O~0o. ,. 1870 Victoria Aldridge I NFORMAT I ON CONTROL Wel I Records LR2-1 Standard Alaska ~ Production Company 900 East Benson Boulevarcl P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD April 29, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-22 (13-02-10-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of perforating the well. Yours very truly, B'. J. Policky,/ Supervisor Waterflood & Miscible Flood BJP: JAM ~ Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 A-22 Well File A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. '~-'"~ STATE OF ALASKA '~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Perforate [] Pull tubing [] Operation performed: Operation shutdown [] Stimulate [] Alter casing [] Other [] Name of Operator Standard Alaska Production Company Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2299' NSL, 1704' WEL, Sec. 35, T11N, R13E, UPM At top of productive interval 1855° NSL, 1076' EWL, Sec. 02, TION, R13E, UPM At effective depth 1465' NSL, 850' EWL, Sec. 02, TION, R13E, UPM At total depth 1447' NSL, 840' EWL, Sec. 02, TION, R13E, UPM Plugging [] 5. Datum elevation (DF or KB) KBE = 76.66 AMSL feet 6. Unit or Property name Prudhoe Bay Unit ~. Well number A-22 (13.02.10-13) PBU 8. Approval number 8-150 9. APl number 5 0 - O29-20712 0. Pool Prudhoe Oil Pool 1. Present well condition summary Total depth: measured 12316 feet true vertical BKB 9598 feet Effective depth: measured 12273 feet true vertical BKB 9560 feet Casing Length Size Structural -- Conductor 110 20x30 S u rface 2680 13 3/8 Intermediate 11376 9 5/8 Plugs (measured) Junk (measured) Cemented Measured depth True Vertical depth BKB 8 c.y. 135 135 3720 c. fo 2705 2689 1763 c.f. 11401 8819 Production -- Li ne r 1430 7 432 c.f. 10886-12316 8410-9598 Perforation depth: measured 11414'-11434'(Sag R) 11531'-11601', 11608'-11617', 11623'-11662' (Ivishak) true vertical subsea 8753'-87.70.' (S.ag .R) , . 8849'-8961' (two Ivishak mmrva~s! Tubing (size, grade and measured depth) 3 1/2" L-80 to 10821'with 2 7/8"tailpipe to 10909' Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 10821';3 1/2" SSSV at 2065'i:ii'~ 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure . Prior to well operation Subsequent to operation Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2180 1814 906 1660 2460 1753 900 1680 Tubing Pressure 250 263 4. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 5. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /.~v~~ ~)~ j~,~"~ Title SupervisorWaterflood/MiscibloFIood Form 10:404' Rev. 1~-1-8~" ,/ Date Submit in Duplicatu Well A-22 (13-02-10'13) PBU Additional Perforating Operations The followlng additi°nal intervals were perforated April 13-15, 1988 using Dresser Atlas 2 1/8" jUmbo~et II guns at 4 spf~ 11414' - 11434' MD BKB (8753' - 8770' TVDss) Sag ~. 11623' - 1'1662' 'MD';'BKB (8928'-'8961' TVDss) Z.4 Depths are referenced to:BHcs, 05/01/82. A lubricator was installed and tested to 3500 psi for all well work. The well was returned to prOduction immediately following perforating operations. 4/26/88 0800Z Standard Alaska .~x Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99.519-6612 (907) .561-5111 STANDARD ALASKA PRODUCTION March 3, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-22 (13-02-10-13)PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. BJP:JAM Enclosures (g) cc: J. L. Haas (MB12-1) A-22 Well File Yours very truly, · J. P6~lic~y, S~ervi~of/ Waterflood & Miscible Flood RECEIVED Al~sk~ Oil & ~s O0ns. Oommissio~J Anohorsge A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS · Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Pedorate [] Other [] 2. Name of Operator Standard Aleska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at'surface 2299' NSL, 1704'WEL, Sec. 35, T11N, R13E, UPM At top of productive interval 1855' NSL, 1076' EWL, Sec. 02, TION, R13E, UPM At effective depth 1465' NSL, 850' EWL, Sec. 02, TION, R 13E, UPM At total depth 1447' NSL, 840' EWL, Sec. 02, TION, R13E, UPM 5. Datum elevation (DF or KB) KBE, 76.66 AMSL feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number A-22 (13.02-10-13) PBU 8. Permit number 9. APl number 5 0 - 029-20712 10. Pool Prudhoe Oil Pool 1. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2680 Intermediate 11376 Production -- Liner 1430 Perforation depth: measured 12316 feet BKB 9598 feet 12273 feet BKB 9560 feet Size Plugs (measured) Junk (measured) Cemented 20x30 8 c.y. 13 3/8 3720 c.f. 9 5/8 1763 c.f. 7 432c. f. 11531'-11601', 11608'-11617' true vertical subsea 8849'-8922'(two intervals) Measured depth True Vertical depth BKB 135 135 27O5 2689 11401 8819 10886-12316 8410-9598 Tubing (size, grade and measured depth) 3 1/2" L-80 to 10821' with 2 7/8" tailpipe to 10909' RECEIVED Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 10821'; 3 1/2" SSSV~J~t~L~il & Gas Cons. C0mmiss[Gr~ Anchorage 2. Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation February 1988 4. If proposal was verbally approved Name of approver 5. I her?by 'ce,rtif~at th~b~/~ng~s~ true and correct to the best of my knowledge Signed ~.~~,,,~~ Title Supervisor Waterflood/Miscible Flood Commission Use Only Conditions of approval Notify commission so representative may witness IApproval No. [] Plug integrity [] BOP Test [] Location clearance I Date approved Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 12-1-85 Approved Copy Retur~d ~ (Jbmm~ss~oner by order of ~ ~,~ the commission Date ~:.-~ Submit in triplicate,~ Well A-22 (13-02-10-13) PBU ADDITIONAL PERFORATING PROPOSAL We propose to perforate the following intervals during February 1988 at 4 spf: 11414' - 11434' MD BKB (8753' - 8770' TVDss) Sag R. 11552' - 11662' MD BKB (8867' - 8961' TVDss) Z. 4 Depths are referenced to BHCS, 05/01/82 A lubricator will be installed and tested to 3500 psi for all well work. Following perforating operations, the well will be returned to production and tested. 0833Z 02/08/88 FLOW;TUBES & PACKOFF BOWEN PACKOFF .:.j.~_ HAND GREASE SEAL FLOWTUBE PUMP FLOWLINE GREASE LINE F£OWLINE VALVE RISER GREASE / MANIFOLD GREASE PUMP · BOP ~GREASE RESERVOIR DALLAS ARCO CHEVRON E Y,.XON TEXACO Date: 02/08/88 TO: MOBIL It: 78535 PHILLIPS STATE OF ALASKA GEOSCIENCES STANDARD AL A$~. REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: A-35 C-26 GC-2C J-1 N-7 R-23 Static Pressure Survey 01/27/88 H1 Static Pressure Survey 01/27/88 H1 Completion Record 01/28/88 #2 CBT 02/01/88 #1 Completion Record 01/30/88 H1 Production Log(Spinner/Temp) 02/01/88 Completion Record 01/29/88 H2 11349-12120 Sch 9628-9900 Sch 11480-11664 Sch 5" 40-5860 Sch 5" 7996-9078 Sch 5" H1 10300-10576 Sch 11490-12110 Sch 5" 11 Rece i ved Date A un,! 01 ,hr" or,(~,~ol Slondo,tt 0,1 [o,-pn,~y I:ou,,d~.d .,, (It'~.N.,,d CYmo ... 1870 Victoria Aldridge INFORMAl ION CONIROL Wel I Records LR2-1 Standard Alaska /.--~. Production Compan 900 East Benson Boul~ P 0 Box 196612 Anchowoge, AIo$1~o 99519-6612 !9071 564.51 ! I INDEXED DALI~S A~CO STANDARD CHEVRON ALASKA PRODUCTION EXXON Date: 08/05/87 TEXACO 78106 TO: T#: MOBIL PHILLIPS STATE OF ALASKA REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of thls letter and returning It to this office: A-1 A-22 A-26 A-29 A-32 A-35 D-9 D-25 D-26 D-27 D-28 D-29 G-19 G-25 G-31 H-21 H-22 H-24 H-26 J-22 U-2 U-6 07/09/87 Camco Static Gradient 07/12/87 " " " 07/09/87 " " " 07/11/87 " " " 07/13/87 " " " 07/13/87 " " " 07/21187 " " " 07/10/87 " " " 07/10/87 " " " 07/07/87 " " " 07/22/87 " " " 07/22/87 " " " 07 / 08 / 87 " " " 07/08/87 " " " 07/07/87 " " " 07/25/87 " " " 07/25/87 " " " 07/25/87 " " " 07/25/87 " " " 07/27/87 " " " 07/17/87 " " " 07/17/87 " " " U-8 07/16/87 " " " U-12 07/15/87'" "/'~~'~ X-2 07/27/87 "/~ ~.,. ,Al " Y-1-2 07/15/87 ~vod ,, I I~'~ ~ ge CONTR~ INDEXED TO: DA~DAS A~CO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES (Transmittal Only) STANDARD ALASKA PRODUCTION Date: 01/08/87 77647 Page 1 of 2!! REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herevith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: ~A-1 Static Gradient 12/28/86 Camco -'~'A-5 " " 12/28/86 Camco ~A-22 " " 12/25/86 " ~--A-26 Static 12/22/86 GO '~-A-29 Static " 12/26/86 Camco ~A-30 Static 12/23/86 GO ~A-32 " " 12/23/86 Camco '~"A-35 " " 12/25/86 " ~-B-1 " " 12/27/86 " ~"~C-15 Static 01/02/87 GO -"~-C-32 " 01/02/87 GO -~'~-D-9 " 12/30/86 " ~D-10 " 12/30/86 GO ~xG-30 " 11/24/86 Camco ~M-4 " " 12/11/86 Camco ~M-10 Static Survey' 12/11/86 GO '"'-M-16 Static Survey ' 12/11/86 GO ~M-19 Static Gradient'" 12/12/86 Camco ~'M-2! Static Gradient 12/11/86 Camco ~N-7 " " 01/02/87 Camco ~N-9 " " 12/13/86 Camco ~N-15 " " 12/12/86 Camco ~N-18 Static Survey 12/12/86 GO ~N-19 Static Su~r~ey /~ 12~12/86 GO ~-. . Received ~..~..~,.,V~l,/r.,~~~,////~/~/"' k-~Victoria Aldridge Date ~ / ' J, _ .... Well Records LR2-1 INOEXED DALLAS ARCO CHEVRON EXXON Date: 01/08/87 TEXACO 77647 TO: TI: MOBIL' PHILLIPS :. Page 2 of 2!! STATE OF ALASKA STANDARD ALASKA PRODUCTION REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of thls lel-ter and returning it to this office: Static. Gradient 1! II 11 " Survey Static Gradient II II " Survey " Gradient Static Survey " Gradient II Il II II ill I! 11 11 Static i2/i4/86 i2/i4/86 i2/i3/86 12/15/86 i2/i7/86 12/17/86 12/19/86 12/16/86 12/14/86 i2/05/86 12/07/86 i2/26/86 12/20/86 12/20/86 12/07/86 PLS-P=es. Survey 11/04/86 Cgmco ti Camco Camco Camco Camco Camco Camco Camco Camco Dres 4. Rece i ved ~, ..... age [ounded ,n Cie.cio.ct ~,o ,n Victoria Aldridge I NFORNAT I ON CONTROL Nel I Records LR2-1 Standard Alaska Production 900 Eost Benson , ~ord P.O Box 196612 Anchoroge, Alos~o 99.519-66 1907) .564-5 I I I INDEXED DALLAS ARCO CHEVRON EXXON TEXACO DaCe: 08/18/86 TO: MOBIL T#: 77265 PHILLIPS STATE OF ALASKA GEOSC IENCES STANDARD AL. ASK/'-,, PRODUCTION REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by slgnlng a copy of this letter and retur'ning it to this office: A'2E]'~ i Dr~7~ZTs/~OPI~S '"i ~)~/0i-786 #1 ]1350-Z1850 oo 5" A-31 PLS 05/09/86 #1 9390-9700 DRES 5" F-5 DFT 07/06/86 H1 SURF.-g700 GO 5" G-1 DFT/WOPITS 07/03/86 H1 9680-10087 GO 5" H-24 Cont. Flow Survey 07/13/86 Hi 9600-9900 GO 5" H-25 Cont. Flow Survey 07/14/86 #1 10300-10650 GO 5" R-12 Carbon/Oxygen/GR 05/02/86 H1 10550-10994 Dres 5" U-13 GR 05/16/86 H1 10200-11515 Dres 5" X-27 Cont. Flow Survey 05/12/86 H1 11300-11650 Dres 5" Rece i ved Date VictorJ. a A].dridgc LR2-1 I NFORMAT I ON CONTROL Well Records LR2-1 Standard Alaska Production Compa~-"~ 900 East Ben$on BoL rd P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-51 ! ! INDEXED TO: DALLAS STANDARD CHEVRON ALASKA PRODUCTION EXXON Date: 07/29/86 TEXACO T~: 77227 MOBIL PHILLIPS , GEOSCIENCES REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge receipt by slgnlng a copy of thls letter and returning it to this office: -~A-22 Static ?A-30 BH Pressure data ..... A-30 PBU C-1t~- Static G-t~;~ Static ~ G-16 Static .... H-6 Static H-6 Static H-24~ Static ~ H-25 Static .... M-4. Static ..... N-9 Static ~R-i' Static --S-2 S tat ic - S-2 ~Static ~S-10 Static ..... S-i3 Static ~S-15 BHPD & PBU ~X-25 BHPD & PBU /Y-~O BHPD & Flow test & PBU Rece I ved Dale 07/01/86 06/19/86 06/18/86 06/20/86 07/03/86 07/05/86 06/21/86 06/24/86 07/01/86 07/01/86 06/07/86 06/16/86 06/20/86 07/04/86 07/06/86 07/03/86 07/07/86 07/05/86 06/23/86 06/1 GO GO GO Camco GO. Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco GO GO 5/86 GO ts.ka Cons. CommiSsion Anchorage Victoria Aldridge LR2-1 ~NFORMA/~ ON CON/ROt Wel I Records hR2-1 Founded ,n Clevelond Oh,(). ,. 1870 INI)EXED SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON To~ SFO/UNIT/STATE: TEXACO (-Marathon) MOBIL PHILLIPS S~ATE BPAE (Transmittal Only) 311 1 "C" STREET ANCHORAGE, ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 11-25-85 REFERENCE: SOHIO FINAL DATA- PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- ~,, A-22 D-5 ~ D-18 ~ J-1 · ~~ R-19 R-24 10-28-85 Flowing Gradient Camco 11-09-85 Static Gradient Otis 11-03-85 Static Gradient Otis 11-08-85 Static Gradient Otis 11-04-8 5 Flowing Gradient otis 11-06-8 5 Flowing Gradient Otis 10-28-85 PBU & BHPD GO 10-31-8 5 PBU GO 11-05-85 Static Gradient Otis RECEIVED OATE _ __ Anchorage Cathy Perkins LR 2-1 Technical Documentation Records Management SOHIO ALASKA PETROLEUM COMPANY SFO ARCO ~ CHEVRON 311 1 "C" SlREET ANCHORAGE. ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 TO: SFO/UNIT/STATE: (-Marathon) EXXON GETTY MOBIL PHILLIPS ~-~_:~._ Date: 1-23-84 CC#: 74991 BPAE (Transmittal Only) _ CENTRAL FILES (CC#'s - Transmittal Only). REFERENCE: SOH~INAL DATA - PRESSURE SURVEY DATA /-~e following material is being submitted herewith. Please acknowledge receipt by signing a ~'cop¥ of this letter and returning it to this office:-- A-22 j_ C-25 ~ C-27~' D-6~ R-9--' S_6~;~ Static Gradient Static Gradient Static Gradient Static Gradient Static Gradient Static Gradient Otis 3-23-83 Otis 1-08-84 Gearhart 1-06-84 Gearhart 1-14-84 Can~co i-05-84 Gearhart 1-13-84 ~/82) RECEIVED DATE Carolyn Bishop Development Geology Well Records SOHIO.ALASKA PETRO-LEUM COMPANY SFO ARCO CHEVRON EXXON :il ~ 1 "(;" STREE] ANCHORAGE, ALASKA TELEPHONE (90'7) 265.0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 GETTY SFO/UNIT/STATE: ., (-Marathon) MOBIL PHILLIPS BPAE (Transmittal Only) CENTRAL FILES (CCI!' s-Transmittal Only) Date :~5/17/8.3 , CC#: 74452 REFERENCE: ~I,O,, cAsE____~.D HOL__.__~_E FINAL LOGS. JThe following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- . .... SFL/UNIT/STATE.:- G-7 TDT-M R-20 TDT-M E-13 Spinner X-18 Spinner B-1 Fluid ID R-18 Temperature ~2~2' Completion C-2 EPL H-il GST 3/13/83 #2 10350-11357 Sch 5" 3/4/83 #1 11200-12096 Sch 5" 4/8/83 #2 10900-11300 Otis 5" 4/26/83 #1 10630-11115 Otis 5" 4/21/83 #1 9550-9850 Otis 5" 4/30/83 #4 9800-10400 Camco 5" 3/14/8'3 #1 10680-12235 Sch ~5" 4/14/83 #1 9800-10110 Sch 5" 3/7/83 #2 9'142-9566 Sch 5" (4/82) DATE " ;~t ,'~ .~-~ Victoria Aldridge ~¥'~'~ "/ i~i~![ Development Geology ~9 Well Records TP1-5 Alaska Oi~ SOHIO ALASKA PETROLEUM COMPANY April 7, 1983 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Well A-22 (13-02-10-13) PBU Enclosed, in duplicate are the following forms for the above-named well. 1. Form 10-407, Completion Report; 2. Form 10-403, Sundry Notice and Reports on Wells; 3. Form 10-404, Monthly Report of Drilling and Workovers. Yours very truly, GJP:JLH:pjw Enclosures cc: J. D. Hartz Geology Well File #17 G. J. Plisga District Petroleum Engineer APR 1 o %,.. . Alaska Oil ,~,. Gas (,~ ,~o~ A,,...n STATE OF ALASKA ALASKAOIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ' 1. Status of Well Classification of Service Well OIL i'~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Sohio Alaska Petroleum COmpany. 82-18 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20712 4. Location of well at 'surface 9. Unit or Lease Name Prudhoe Bay Unit 2299' NSL, 1704.' WEL, Sec. 35, TllN, R13E, UPM At Top Producing Interval top of Sag R. Sst. 10. Well Number 1855' NSL, 1076' EWL, Sec. 02, T10N, R13E, OPM A-22 (13-02-10-13) At Total Depth 11. Field and Pool 1447' NSL, 840' EWL, Sec. 02, T10N, R13E. UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) t 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 76.66' AMSL~ ADL 47472 , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No.' of Completions 4/14/82 4/30/82 5/6/82I feet MSL One 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionalSurvey [ 20. Depth where SSSV set I 21. Thickness of Permafrost 12316'MD 9598'TVD 12273'MD 9560'TVD YES~-] NO[] 2065' feetMD 2060' , 22. Type Electric or Other Logs Run BHCS/DIL/SP/GR, FDC/CNL/GR/CAL, CBL/VDL/CCL/GR, Gyroscopic survey , 23. CASING, LINER AND CEMENTING RECORD sETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , 20"x30" [nsulated2onductor Surface ]]0' 36" 8 cu.yds, concrete 13 3/8" 72# L-80 Surface 2705' 17 1/2" 3720 cu. ft. Permafl;¢st II 9 5/8" 47# L-80 Surface 11401' 12 1/4" 1633' cu. ft. Class C: 130 cu.ft. Permafr¢~tC , , 7" 26# L-80 ]0886' ]2~]R' 8 1/2" 432 cu. fti Class G. iw/1R% · 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) [VID T~DSS SIZE DEPTH SET (MD) PACKER SET (MD) -- 3 1/2" 10910' 10821' Prudhoe Bay Unit top: 11531' 8849' Bottom: 11617 ' 8922 ' 2~. ACID, FRACTURE, CEMENT SQUEEZE, ETC. · DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 11531' - 11601' BKB (8849' -(8908' TVDss) 11608' -11617' BKB (8914' -(8922' TVDss) . _ , . .. 27. PRODUCTION TEST , Dare'First Prodaction . " " I Method of Operation (FIowing,.gas lift, etc.) I . March 16, 1983 Flowing Date of Test Hours Tested pRoDuCTION FOR OIt-BBl_ GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ , Flov~ Tubing Casi'ng Pressure CALCULATED OIL-BBL GAS-~CF 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. . None · Alaska Oil Form 10-407 Rev. 7-1-80 ~ubmit in duplicate CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Subsea Sag R. SST. 11413' 8752' Shublik 11424 , 8761, Ivishak ~' 8847 ' ! J J I 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best 6f my knowledge Signed~.~./3 ~.~~~~--~_~~~ TitleDistr. Petroleum Dat. c/ Enainee.r I NSTRUCTI ONS 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 otherv,,ise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in-item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing an~! 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. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 82-18 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50- 029-20712 4. Location of Well 9. Unit or Lease Name at surface: Prudhoe Bay Unit OTHER [] 2299' NSL, 1704' WEL, Sec. 35, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 76.66' AMSL 6. Lease Designation and Serial No. ADL 47472 10. Well Number A-22 (13-02-10-13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool 12. 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 :J~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] Pull 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). The following intervals were perforated March 16, 1983, using Schlumberger 2 1/8" Hyperdomes at 4 spf. A lubricator was installed and tested to 3600 psi on all well work. 11531' - 11601' BKB (Ref. BHCS/GR, 4/31/82) 11608' - 11617' BKB ( " ) An SSSV was set and tested in the ball valve nipple at 2065'. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use 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 PERFORATING DATA - Well A-22 (13-02-10-13) PBU March 12, 1983: Pressure tested tubing and inner annulus. March 16, 1983: March 21, 1983: Rigged up Schlumberger and perforated the following intervals using 2 1/8" Hyperdomes at 4 spf: 11531' - 11601' BKB (Ref. BHCS/GR, 4/31/82) 11608' - 11617' BKB ( " ) Put well on production. Shut well in to prepare for static pressure survey. March 23, 1983: March 26, 1983: Ran static pressure/temperature survey at 8800' TVDss. Set and tested SSSV in ball valve nipple at Well on production. ~- STATE Or: ALASKA .~--~ ~ ~.~ .., ALASKA ("-h_ AND GAS CONSERVATION CO. .,~ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation [] 2. Name o_f operator_, . ~onlo a±asKa Petroleum Company 7. Permit No. 82-18 3. Addres~ouch 6-612, Anchorage, Alaska 99502 8. A~_m~_~r712 50- 4· Location of Well at surface · . 2299' NSL, 1704' WEL, Sec. 35, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ADL 47472 KBE = 76.66' AMSL 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. A-22 (13-0 2-10-13) 11. Field and Pool Pr udhoe Bay Prudhoe Oil Pool For the Month of. March ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 13. Casing or liner run and quantities of cement, results of pressur9 tests ~14. Coring resume and brief description 15. Logs run and depth where run ~.16. DST data, perforating data, shows of H2S, miscellaneous data See Attached. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. !SIGNE TiTLEDiStr. Petroleum 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 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276,5111 MAIL: POUCH 6.612 ANCHORAGE, ALASKA 99502 January 20, 1983 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Wells~A-13,~A-22, A-23, A-24, A-25, A-26, A-27 and A-28 PBU Gentlemen: Enclosed, in triplicate, are Forms 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These contain our proposal to perforate--these wells. District Petroleum Engineer GJP:JLH:lh Enclosures cc: J. D. Hartz Geology W~ell File #17 RECEIVED JAN2 ]983 Alaska Oil & Gas Cons. CommiSsion Anchorage ?" STATE OF ALASKA --'~ ALASKA L,~L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. SOHIO ALASKA PETROLEUM COMPANY 82-18 3. Address Pouch 6-612, Anchorage, Alaska 4. Location of Well 99502 At Surface: 2299' NSL, 1704' WEL, Sec. 35, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KBE = 76.66' AMSL I ADL 47472 12. 8. APl Number 50-- 029-20 712. 9. Unit or Lease Name .,. 10. Wel) Number A-22 (13-02-10-13) 11. Field and Pool Prudhoe Bay 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). The following intervals will be perforated February/March, 1983, using Schlumberger 1 11/16" Hyperdomes at 4 s.p.f. A lubricator will be installed and tested to 3500 psi for all well work. 11531' - 11601' BKB (Ref. BHCS/GR, 4/31/82) 11608' - 11617' BKB ( " ) An SSSV will be set and tested in the ball valve nipple ca. 2000'. RECEIVED SuBsequent Work BePortert JAN2 51983 Alaska Oit & Gas Cons. Commission Anchorage 14. I hereb~rtify that~e~oing is true and correct to the best of my knowledge. Signed ~/'~'7~.¢_),~_,,,~~[.,~_/~_ ~ Title District Petroleum Enqineer The sp~below for~mmission use ~ Date ~./,~. ~ / (~"/ ~ Conditions of Approval, if any: ORIGINAL SIGNED BY LOH~lE C SM!IIi Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 June 14, 19 82 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C.'V. Chatterton Gentlemen: Well A-22'(13-02-10-13) Enclosed, in duplicate, is Form 10-407, Completion Report, for the above-named well together with the Well History, Well Logs, and Directional Surveys. This well has been completed as an unperforated oil well. RHR:jm Enclosures cc: Well File #17 Geology , Yours very truly, R. It. Reiley District Drilling Engineer JUN 1 ~ 19B2 N~sk~ 0'~ & Gas Cons. Commission Anchorage ., ~ STATE Of ALASKA --,. _ _ , ,. · ' ALASK;. ~J_ AND GAS CONSERVATI.ON C. ~-.tMISSI(~I 1~ ! ~1 I ~ ~ [ ,WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well . . OIL [] GAS [-}' SUSPENDED [] ABANDONED I~1' SERVICE [] -; · 2. Name of Operator ' - 7. Permit Number Sohio Alaska Petroleum Company 82-18 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20712 ., 4. Location of well at surface --- , , _ 9. Unit or Lease Name I LOCATIONS Prudhoe Bay Unit 2299' NSL, 1704' WEL, Sec. 35, TllN, R13E, UPM i VERIFIF_O At Top Producing Interval top of Sag R. SST. 10. Well Number 1855' NSL, 1076' EWL, Sec. 02, T10N, R13E, UPM Surf. ~ . A-22 (13-02-10-13) At Total Depth B.H._ ~,E : 11 Field and Pool _ 1447' NSL, 840' EWL, Sec. 02, T10N, R13E, UPM Prudhoe Bay -5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 76.66' AMSLI ADL 47472 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 4/14/82 4/30/82 5/6/82I feet MSLI one 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 12316'MD 9598'TVD 12273'MD 9560'TVD YES~ NO~] 2065' feetMDI 2060' 22. Type Electric or Other Logs Run BHCS/DIL/SP/GR, FDC/CNL/GR/CAL, CBL/VDL/CCL/GR,' gyroscopic survey' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOL~'SlZE CEMENTING RECORD AMOUNT PULLED 20"x30" Insu]ate¢[ Conductor Surface 110t 36t'' 8 cu.wds, concrete - 13 3/8" 729~ L-80 Surfacel 2705~ 17 1/2'" 3720 cu.ft. Permafr~st II 9 5/8" 47# L-80 -' Surface: 11.40.1"· 12 1/4'i" 1633. cu,ft, Class G: 130 cu. ft. Permafr~st C 7" 26# L-.80 10886; 12316t 8 1/2'" 432 cu.ft. Class G w/18% salt 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) -' None ' 3 1/2" 10910' 10821' " : · : '~6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED · , · ' ' · ~ ' -, ; ~, ~, t .' · . ' , - · · .. . r.. : . .. ! ! .~ .. -. :- . . · 27. ' '-': PROD'UCTI'0N 'TE~ST '" Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL ' 'GAS-M(~F~ WATER-BBL C'HOKESIZE IGAS-OILRATIO TEST PERIOD I~ flowTubing · Cas'ingPt:essure : CALCUEATED'i~ OiL:BBL :" GAS'McF WATER,BBL OILGRAVITY-APi(corr) -Press. ~ ~'''' -" " :24-hOOR R~tE ~ '1~' ' ?' ' ""' : 28. -- :" ;" '~'' "" "' CDR E DATA '' llaska 0il & .~ .. ~ --,. :' .-, : ,. Form 10-407 " " SUbmit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Subsea Sag River SST. 11413' i! 8752' Shub lik 11424 ' i 8761 ' Ivishak 11528 ' 8847 ' 31. LIST OF ATTACHMENTS Well History~ Well Logs~ Directional Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge R. H. Reile¥ Engineer 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 attachmenl~'s. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records:for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- WELL A-22 (13-02-10-13) WELL HISTORY Spudded well at 1200 hours, April 14, 1982. Drilled 17 1/2" hole to 2710'. Ran 70 jts. 13 3/8" 72# L-80 Buttress casing to 2705'MD (2700'TVD). Cemented with 3720 cu. ft. Permafrost II cement. Installed and tested BOPE. Cleaned out to 2663'; tested casing to 3000 psi, okay. Directionally drilled 12 1/4" hole to 11410'. Ran 292 jts. 9 5/8" 47# L-80 Buttress casing to 11401'. Cemented in two stages: First stage with 1633 cu. ft. Class G cement; second stage through D.V, packer at 2605' with 130 cu. ft. Permafrost C cement preceded by Arctic Pack. Cleaned out D.¥.; tested casing to 3000 psi, okay. Cleaned out float equipment and directionally drilled 8 1/2" hole to 12316'. Ran open hole logs. Ran 34 j ts. 7'" 26# L-80 IJ4S liner to 12316'. Cemented with 432 cu.'ft. Class G cement with. 18% salt. Cleaned out to 12273'; tested casing to 3000 psi, okay. Changed well over to NaC1; ran CBL. Ran 334 j ts. 3 1/2" 9.3# L-80 EUE 8rd tubing to 10910'. Landed tubing with ball valve at 2065'. Installed and tested tree. Displaced tubing to diesel; set packer at 10821'. Tested tubing to 3500 psi, okay. Released rig at 1800 hours, May 6, 1982. JUN 1 ~ ~982 Alaska Oil & Gas Cons. Commission Anchorage SOHIO ALASKA PETROLEUM PAD.A (13- 02. lO- A'22 Controlled Drilling LES HENDERSON 349-3114 Consult.ants _ '~ ','i :i-' _;:' 'i' '.}.' :iii: :t': ": ' :' ' ri e. ':~/.-::,:.:~.,' ;:-.':.-~"..!.'t..i.?i'.::'::::::.i' Anch0f~ge, Alaska 99502' ~ -':.'~-":-.':", ' "' '-'-:'-~':~: ": ~'~:::.' '".- ,(907) 349-3114 - ..,. -.. . . - . . ' ' ! .' ..': : . .: '.',:: ". . : . . .. . . -. ~- , ..... April 29, 1982 Mr. Brian Rose Sohio Alaska Petroleum Company Pouch 6-612 Anchorage,. AK 99502 . .. RE: Magnetic Single Shot Survey Job No. 0482-0027 ' ~-'~ Well A-22 (13-02-10-13) . , Prudhoe Bay Field North Slope, Alaska Date of Survey: 4-13-82 to 4-27-82 · Dear Mr. Rose:.- Please~find enclosed the "original'' and six (6) copies of our Magnetic Single Shot .Survey on the above well. The method used in calcUlating this survey was Radius of Curvature. The depth of the survey was 1882~to 11,360. Thank you'for, giving us this opPortunity to be of Service. .., Yours very truly, Controlled Drilling Consultants C..W. Harrington Directional Supervisor COMPUT£D FOR CDC BY O0~ANTECH(FM LINDSEY & i~SSOC,) 0 0 0 ,00 -76,66 S .OOW ,00 8 ,00 W ,00 $ '90 0 0 ~ ,000 2003 ~ 30 J940,:00 i863.:34 S 2.0OW 2002.99 1926.33 Si2.00W 23<)2 !0 30 2389,93 2313,27 $22,00W 2471 13 45 2467,16 2390,50 $22,00W 2762 23 45 274J.76 2665'I0 518.00~ 28:54 26 45 2824.96 2748,3:0 $18' 00~ 2:947 ~R 0 ~907 55 ~30 3069 30 45 3013,85 2937.19 S27,08W 3196 33 ~5 3~21 ~55 3044,89 S24,00W 3447 40 30 3323,64 3246.98 :35~:~9 .44 { 5 3413,76 3337 ~ 4JO7 47 15 37e9, I~_ 37!~ 46 ~4 4603 46 15 4128,97 4052,3f $24,00W 5099 46 ~5 447t,96 4395,30 $25.00W .35 i ,5.4 34,39 S 14,0J W 37,J3 $ 22 9 57 bi 3,228 37,1 49,77 S 20,22 t~ 53,72 S 22 6 53 W 4,J14 53,72 139,64 $ 51.57 ~ 148,86 S 20 16 It ~ 2.9~6 148 i76.96 S 63,70 W J99.07 $ 19 47 47 W 3.261 1 ~ !6.57 _~'_ 79,7 0 W ~~~_2[_~. i 5 ~~~ .... 270,12 S 106,40 ~ 298,3~ $ 2i 29 57 ~ 2,264 290,27 330,eS S 135,37 ~ 357,4e S 22 i5 6 ~ 2,093 357,47 467,09 $ J~.4.~I W 5:06.01 $ 22 37 5 ~ 542,20 S 228.04 ~ 588.20 S 22 48 48 ~ e94,2~ S ~_ ~ ~ ..... ,,~~.,,~:~,_._~_~,~ ...... ,_:___~:558 ~224.24 S 531.71 W 1334,73 $ 23 28 34 ~ .202 1334 550.27 S 680.29 ~ 1692.97 S 23 4t 34 ~ .146 1692.64 R E CO RD 0 F SUR V E Y DEPTH At4GLE DEPTH SEA D IREC D I STANCE ANGLE DEG/100FT DtSTANCE D M DEG, D M 2774,86 $ 24 1 3. t W , t95 2773,97 ,214 3234,9'0 9906 43 15 7667,e4 7'591,18 S21,OOW 4871,13 S 20t6,69 W 4922,16 S 22 42 lO W 5272,09 $ 22 29 24 W 305 4922, '14 ,3t4 5272.09 TRUE I ?? 1 ??, t O0 0 277 277, 200 0 cOO S , O0 8 .00 W 777 777. 700 0 877 877'. 800 0 ,00 $ ,00 S ~--~ O0 S ,00 W ,00 W I377 4477 ! 577 377, 13 00 0 477. t 400 0 577, ! 500 __8 ?oo o 3799 1977 1977. 1900 0 2077 2077. 2000 0 2! 77 2177. 2!00 - 0 2277 2277. 220 O 0 2;379 2377. 2300 1 24~1 2477, - 2400 4 2585 2577, 2500 8 2691 2677. 2680 14 ~800 ~?77: 2700 23 2912 2877, 2800 35 3026 2977, 2900 4~ ~ 43 3077. 3000 6~ 3262 3177. 31 O0 e5 3386 3277. 3200 l 09 3477. 3400 Ie0 222 3577 ,' 3500 0 0 0 0 0 0 .00 . O0 , OOS . O0 , O0 1.00 4.00 O- ........................... J~_, 4! 0 I 32,17 , 00 id .00 W ,00 ~00 kl .06 W ,88 W ....... 3.05 kl 7 ,.0:8 W 13,09 kl 3 14 20 24 32 39 42 5_LUgf~_S ........ ~.kil_W 79.25 8 31.32 W 113,80 S 43.05 W 1~~ .......... _56_~6__W 201.77 S 72,98 W 250.76 S 96,62 W 364.78 S 150.28 W 431,84 S 179.~0 ~ SS:e, 67 S 253. t 9 ~ 690,48 S 294,06 ~ . : .::~:~:: :::::::::::! .::.::::: ::; ..:;:.:::::; :.::::: ...::: !..::.:::::: .; ::.::.::::: : .i. :::~7 : :.: :~:.::~:::::: .:::::..::?' i:::.;.:::: ::::: TRUE 3943 3677, 3600 266 44 7'84,87 S 33.6,09 W 4089 3777, 3700 312 46 88t,92 $ 379,30 W 4817 4277. 42. 00 5;3'9 44 13.64.95 8 5:94.99 W 496't 437'7. 4300 '584 4,5 1459,95 S 638.4,4 W 5678 4877. 4800 $01 $824 4977. 4900 847 33 5 t 77 ~ 5J' O0 9 55 ~0 5277, 5280 ~ 3 66'10 5477. 5400 ~ 133 6771 5577. 5500 t J 93 ~932 5&77, 5~ 0 O I ~55 70.93 5777. 5700 ~ 316 7254 5877. 5~00 J 377 7575 6077, 6000 1498 7734 6177. 6~ O0 1557 789 J 6~77, 6200 J 6 L4 8048 6377. 6300 1670 8203 6477, 6400 1725 8507 6677. 6600 1830 8655 6777. 6700 1878 ~RO0 ~~ ._~._ !927 44 46 _5.1 57 58 59 6I 60 2005.20 $ 868,40 W 2021,93 S 900.20 W 2.~t~. 79 S ....~~2.2_..~ 2234:, S 996.42 bt S 1046.35 W 2575.12 8 2690.62 S 1147,719 W I 198. O8 W 61 2923,90 $ 1295.72 61 3041.24 S 1343.1 61 :3157.7l_ S .... 60 3273,24 S 1436,93 W 59 338:7,82 S 1483.t6 W 5?- .......................... ___Z~OI~S_ ...... ~~25. W .................................................... · 56 3612o91 $ 157'2. 55 3723,34 S 16 J 4.47 ki -:.: 54_ ........................ ~Jll_._~ ..... 16~.~16_.~L .................... .......... 51 3938,41 S 1693.70 W 48 4041.39 8 1730.44 W 4._=J 4 ! 4 0_. 99.__S.. _ iZ65.35 4237,56 $ 1798.61 W 9226 7~??, ?~ O0 2048 10055 7'777, 7'700 2278 37 ~ O 19 'I 7877, 7800 2314 3'6 4966.03 $ 2053.39 5052.09 S 2087. ! 2 0857 83?7, 8300 2480 3'0 5458,85 S 2255,2t W ~0986 8477, 8400 2509 29 5533.~8 S 2288,46 W TRUE 3000 2954. 2:877, 239,33 $ 8000 9000 6346. 7017, 6269. 3578.87 t558,77 ~ ~'HORIZONTAL VIEW i SOHIO ALASKA PETROLEUM i WELL'"A- 22 ~ RADIUS OF C~JRVATURE .. I MAGNETI,C,, sINGLE-.~...... SHOT ~ . SCALE= = ...... [._APRIL · 28 May 19, 1982 Mr. Gary Plisg~ Sohio Alaska Petroleum Ccnpany Pouch 6-612 Anchorage,.Alaska. 99502 .. Re: "Our Boss Gyroscopic Survey. Job No. SU1.75-16021 Well No. A-22 (SEC 35 TllN R13E) Prudhoe Bay Field North Slope, Alaska Survey Date: May 12, 1982 Operator: McGuire, Afflerbach Dear Mr. Plisqa: Please find enclosed the "Original" and sixteen (16) copies of our Boss GyrOscopic Multishot Directional Survey c~ the above well. Thank you for giving us this .~portunity to be of service. Sincerely, N.L SPERRy-SuN,' INC. Ken Broussard District Manager KB/cd Enclosures RE[EIVED JUN i 4 Ai2sk2 Oil & Gas Cons. Commissbn Anchorage SOHIO ALASKA PETROLEUM COMPANY t-_~___(.~;~: _',i5 _Yll N R13EO PRUDHOE BAY ALASKA SF'ERRY-SUN, WELL SLIRVEYING COHF'ANY A NCHC~FiIAGt::: ALA:St<A · COHF'UTATiON DATE 1'1A Y J. 8, 1 'P ::2:2 - PAGE i DATE OF" SURVEY HAY 13., i,,'''.~''' _ ,-. ,-, /- . /.:, LEVEL ROTC![~ GYRO ,JOB NLII"tBER SL1-1,75-I6(')21 KELL. Y BUSHING ELEV. = 76, 66 F--T. CIF:'EF;:A]" OF<-HC GU ! RE MEASURED DEPTH T..BME ............. SU.B.,...'--'iE& ............ L,O JR.:,E VERT I CAL VERT I CAt_ I NCL I NAT I ON DEPTH [~ EF' TH DEG M I N COI.IFCF.;E ..... DF'!G,LEG D I REC:T 101',I SEVER i TY D E G R E E S fi E G / 100 100 : 10'0, O0 °"~. ' ' ,"5" ,4;'- Ci 0 ~ OU 00 :300 297.99 4 00 .~, o,:~ 9 9 ................ :~ (~P .............. ~ ??. ? 2 600 599. '~'-', ,=, 700 699.98 000 999.97 ':723. :_--: 1 0 25 I!:!.Q ........... ~1_C~_9_'.~_.. ?7 .... 1023, :'::1 ....... 0.. 1.? . '-' ') ' ':'":' ~- .::.L t) 11 -'--' - WY...o7 11 ----._,. .'dI O. 1,-, :300 1299.97 1..- -,.'"'":'~. 31 : 0 30 .!__40]}_ ......... _i._~.?~.,.~?A, _.. 1.;--::2~:, 3!;L ..... ' . !'_J 4.0 150(3 14.'.?9. '.-.?5 1423. '29 0 49 1600 15'F.,"P. '..-? 4 F,,'-"-, F,,:' '..-' ,:: 0 ._ .-, 17(30 ' 1699..'2:3 162:3.27 0 55 1800 1799.91 172:3 · 25 1 0 1900 1899.89 1823.23 1 19 2000 1999. :--:4 1923.18 2 19 '---' 100 2099 7 0 "'" c' '""'-' ..,.... . ..' .,..'._-',. 04 3 :30 220(] 2199 39 '---'I'--'"':-' 7:':-: = '-'~-- . · . .,_ .' ~' · ...I ." ._l '2:--:00 229:_:: 69 ":'":"-'":' 0:3 :z: 0 · · d~.. d~ .:~. '" · 2400 2397.21 2320.55 11 40 2500 2494.46 2417.80 15 10 2600 2590.14 '-'= - ~, 13.4~: 18 34 2700 ..~o~°"~. ~2 2607 .26 .~.o 0 - c, '='--' 96 '-' = 2800 2775.6'.." ~6 ./~,. ~ w 0 2900 o,=, = -. ~o6~,. 27 2788.61 27 2:4. ]"r'rTF. iL ......... R E C: 'T A N F:i Lt L A R F': ri A R D 11'4 A T E S I'.IORTH/SCILITH EAST/WEST VERT :[ CAL ::_:; E C: T I :=;F'ERRY-SLIN WEL. L .SLtRVEY I NG _ CFINF'ANY · ANCHORAGE ALASKA ']OHIO ALASKA PETROLEUM COMPANY ~-22 (SEC 35 T11N R13E) O]MPUTATION BATE ='RUDHOE BAY MAY 18, 1982 ~LASKA ~ERTICAL SECTION CALCULATED ALONG CLOSURE ATE OF .=,UR~;~v MAY 1:3, 1':):=: ..... =, JI-~VE¥ 7.5 LEVEL RF~TF~R GYRF~ ""~-' ' 0 B N U I'IB E R S LI- 1 / .J- ;t/:, j...:' 1 KELLY BUSHING ELEV. = 76.66 FT. 0 F'E R ¢4 T 0 R- M C G LI 11:4 E ............................................... T R_._E_ ? L!B ='==,E. A .................. L: U LI R,~,E ........................... L. U J I-~.=, E D 0 G- L E G T 0 T A L 'IEAL=:URED VERT I C:AL VERT I _.AL I NCL I NAT InN D I RECT I ON E:EVER I ]'Y REF:TANGULAR COORD INA. TES VER'F I r:AL DEPTH DEPTH 'i - ' ' [ EF ] H BEG Id I N DEGREES BEG/1 O0 NORTH/SFilJTH EAST/WEST SEF:T i ON 3000 ,-.,o=.--, 50 287/:,, :=:4 '28 '=' <'/- - - .....-,.,.: ..... 4 'S ..-_, /:,0 W ...... 71.?;:3 '"~"-' '74 S 100 O'F/ , .,:;.._,.',. :3100 :3040 34 .-,o~.,-, 6:=: 30 4c~ .c; 27 ~' " .- (.~ W Z. 2.9 2.97. 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C o ,'-, ::: ._=i . 47 '=' ':' -":' 0:3 W 6 ./,.,, a,._ o506 46 ._,4,~ ,~u ;47 1.'5 S '"~' 60 W ':' ],-' ':~ · · .... =,0o 3573.9? 3~??..'~1 47 4.9 .-,': .... ~4~'. '-'- ~F ..... ' "~' '~ ' ' '-' '-' '-'~ ~ '-' ' '-' '-' '-' ' ' 34 '-" . · _ .. uu o641..s, I .-,. ,A4.6., 47 .-,~) .-, ~4. ,-,~ ~ ~ ~ ~. 7/-,c/ .... ~7 S o'-"4._, 400 F~ 37 F~.9.08 '~ .... "=' ' ..... . _ . 4100 :2:777..1. 8 :37 C) 0..=;':" 47 0 :=; :=': 5. 0 W 0 · 1 ::: =., L ..-. 40 '.:, 407. :_=: 6 W 'F' 'F' 0.07 ............ 4200 '-'"' "=' '-"-' / .: 47 0 07 ?/:, 8 71 ':' 4 ::-::=: 21 W i 0 ¢':, .=,,=,.~..,..=,,:,:2:76 :=:· -' '~' 0 . ...,':' 24. :=:_ 9. W . . ,= .... 4300 391'3.7.9 38.'_=:7 1:3 4/=, 40 S 24.89 W 0 '-"-' 1(:):34 :=:6:=; 4/:,8.'F¢2 W 1136:1:=', . · .-,.:, · 4400 3982,= '-'¢~("= 9F) 4/:, '-'= ,'--':'F, ~,6 ~ =..,~,_. ............................. p ............. _0_ !4 ............ 0._'2./:! .11 O0 /-':' . ~ _....~.....I .~_._ · ~ _,~...~ ,.=~ , . · . · 4 -06 ....... i .........,,.. oo 1. o ,:: ....... = 1. o _t 1./:./=. ......................... 4600 41_':' :1 · 0'=-' 4044 ,36 4/:, ¢]. S..":'._='~ . :E: 0 Id 0 .18 ~ '..:, :E: 1 · 30 s 4700 41.90 64 411. 2. 98. 45 45 ':'._, ~--,'-'= .... 3"} Id 0 26 1 :-':'96. :17 ':' ~'-'.,' :1./:,6 W 14'.--'4 77 · ._1 · '-"-' ~-- 4800 4~:60, :11 41. ,:,,=,, 4,-, 4/=, 1 ~'- . ' _ · _, S '::"6 O-'W 0.6/=, 't:E:/:.O,'.='9 :_=; /:,2=-='. ~ :14F.~/:, 67 4.900 .'4~2.9 36 4252. 70 46 4 S '-'= -- - .~ . ~=.:,. ~;y W 0. :1 :=: :1'~.' ,., '~ "~= · ':'~,_,._ ~ /=.54.4'-.=. W. 15/'.:::_ _ _. 77 5000 '-' - 4..-.98.78 "'-'""=' '*.-' ~ ~ · ~ '=" ' 46 0 :'E; ,. .:, 0 W 0 · :]: 0 14 ?/0.4.9 S 6 :E: 6. 0'.'3' ~ :164 ~"~. 70 51 O0 4468, ~.°'-.-., ........ 43.91 :-~.-:i3 45 55 F-'; 26.30 W 0.08 1 ,_,~-='._, ...... 4. '.;.' 3 ::,:: 717..94 W 1712.53 ="-' ' ' 'T-'~ ._,~uL) 4538 17 4461 = - · . .., :1 45 -._ ':'._, :." 7. :30 t.4 0 · 87 16:1 :=: · 7',=: S / ._ _, . :19 1,4 17 :=::3 · 9. :::_ 5300 460,_~. :'4,,_6 453t· 70 45 25 S 2/:,. 69 N 0· 4:2: :1682.24 5400 4678.77 4602.11 45 4 ':' 26,'-'9 . . . " . · _, ,=,.. W 0 37 17'T5 A:3 S 814 F,.% W 1926 05 5500 4749"93 4673.27 44 10 S '='/- 60 W 0,~}::: 18.0F: '::6 S :---:4/:. i6 W I':,':,A 21 5600 4821 4744 4.9 45 "0- ':' 26 89 W 0-"-.'_8./.~,~ .... ~871,04 S 877,76 W 206/=,. :3:3 570F) 4~, ~ 1 ls'~ 4,_-, 14 .=i':' 46 4 S 25 6.9 W i "'"-' 1 .~c:,..,.~)...' '-' :x . ' ' .....~ ~, . o,:. :., t :,. :37 W ..' 1 .:,7 o4 ~o,.,.0 4959 87 47 10 2000 82" .... .-.:'40.26 W 2210 :'--:1 4 .......... 21 S 24 60 W i '-'~' mm · . . ", ....i I~_ ' -~ ~9¢')c') ._,(.)..6 · 77 4'.~('). 11 48 4.9 S :24.1 'F' W _. 1, "-' . ....... .... 6,;. 206:E:,4-':-.'' S ?70,?5 W 2284 61 -- SPERRY-SUN WELL_SLIRVEYING COMPANY ANRHORAGE ALASKA SOHIO ALASKAI PETROLEUM F:OMPANY A-22 ( SEC PRLIDHOE BAY ALASKA O-~RT i-l~-" ~T i oN-'-CALCULATED -AL,]biG -i--'-,-. , ..LLI.=,LIRE .... COMRUTATION..DATE MAY 18, 1982 F'AGE 5: -- DATE OF St lRVEY MAY 13 1:;,:,..' =' .................. 1_, 7--, .LEVEL ROTC!R JOR NLIMBER SLI- 1.7._,- 16(. ~ 1 KELLY BUSHING ELEV. = 7/_-,. 6/_-, Fl'. .... (] F' E R A T 0 R- M C G LI I R E MEASLIRED DEPTH ::;I ,=-' · L.I i,.I .-,E I.U ! oE IUU- -U _:_ZBLJ_E ............... ....--:.WB_,:$:EA .... z .............. R ....................... ~.B~ ................ ;[ ........ LE VERT I CAL VERT I L:AL I NCL I NAT I ON D I RECT I ON ::--;EVER I ]"Y RECTANGLtLAFi DEPTH DEPTH BEG M I N [;EbREEo-' ' '-' DEG/100 IWORTH/:::OUTH C: F,3 R D I N A 1" E S EAoT~ WEST 6000 '=n,~ ~ 71 x.,l~... I · 6100 51'55, O~ 6200 5217, 57 6300 5280.06 6400 ,5342.54 6500 54.05.13 6600 5467.88 6700 5530.76 6800 '.'55~3,35 6~00 5655.66 7000 5717.74 7100 577~.82 7200 5842.1~ 7300 :5~04.88 TOTAL VERTI CAL S E C: ]' I 0 N 5015 C)5 .'=';c)i 0 S '-'"' 10 W 1":.... ,=,'"' '"' . - - ~.--:.. I .U"' ,::'- 14 ::':: 1001.44 W I~. ,", .--,- .'t', '. · _,07,_,, 5:7 5:1. 15 S z:.4-..:,0' N. 1 ......... 'F)'-? 2'.'.'F)m 2.7 .~'-' 1,J..:,l;"-' . ~"~.-.:'.=, 5140. :~1 ........ ._5;~... _ 1/.-7< ....... .'~i_2~2_._6';7.{._~_ ............ Q... 4.7 .............. 2281 .. !:0_ ".LEi ......... ]_J.0~:2./~.2_'..N .... 52 ¢]::: 40 F,, I 19 ':' '::"-':' '-" ,=,0 W 0. ")'-' ":":'F,':' 10 '-' (- ,:, 1C)c;2 61 W 5'-'~ ~ · _ Lo.J. :E:8 .- .[ 19. S ..'."'"-' . 69 W 0, ("~B ~4~:'" '-'"'" ..... 10 .... '.--, 11'-"-' ,~."-, 81 W · ~'~"~"-~ 47 ._M 1 1 (]'-' o.-, /.,,{~ -. =.;.-, ,_ ._i .. i_ · - · '-- u .. -- . . ~:,.=-' N 0.1 .=; 2497 (')~ '.5 11 ._ ~:. ;, ! ~ .-, ,.-t .-:, .-:, ,.--~ ,: .... , ~=~ · ,-, ,;::. ,.-, .-:, · _,,:,..'. 1=~. ._ 1 4. "-'":',~., :30 N 0. '-"::'._',._, ~.._ o,:,, '::~::: ._, 11 70 5454 10 ~ 0 '-"':' "w · '* 72 .. :1. S .10 14 0 6 :':~ z :,40 '-' . ~.,-, . . o 12:1.2.7:i. . ~ ~ · ~1 ~ ..-, ,-. ."~.~, ' r.':=r ' . i=-,- .-, ..-, -.=, ~ ,-. · .... , ,...-, -- ~- · ._,.. 16, 6; ,., ~ .:,0 .=,z:.-: .... ,0 N O.._, :,~ ,~ 71 .-'..:, ~ .:, 1 ~: 1-._',. 5,., ~1 ~: ~4 0 W 0 4(:) 278:3 '~':_.:: S _ _ . .,:....I ~ - ~ . - .1..~. / -- · 5641.08 51 49 .'_--; ~:'-'._-,'-' .80 W c). 44 ,~"' ,-,'-' ._~ ._"-";. 61 .:,'-' '1 '-.d c)'/:,, o~:'-' '-' W · =i7(]:T~. 16 .¢, '-'= '-''-'"' '" · . 1 O. 2927 ':":":' '-' ~.c, .:,$.--,. ~-,.=~ N 4.2 .37 S - :.- 1 ......... ,:,/ ~-,. z ~- ~ .-, .-:, r.- .-, .-:, ..:, · _ ,. o.j.._ .'- ...51 ~.._, S z. 4 , 0 N 0 , ~..-, 2998.8/'_', . .=,'" l'-'-'r~ / .) · O0 W '' I~l '~I I~1 ' ~- .'""l .,,' (- 5,:,,~,=,,~'''..-~. . · .'5_,0_.5._'5 '.-,..-4. 0 N 0 . ,5(]. .d.)70 .03 o'-' 1401.6,S' 2:3/.:,0, ,':-, 4 '.':;'4'- -' _ · .d ::,. (') 3 · .' ._, 16,. 04 25'P ;]-. 10 2672.16 .,s / ._,u · 2827.96 · " 7 .)0 6':.';' 2983,/-:'7 :.i', 061. :--': 9 · :, 140.2:--: 321 :--:. 6:-:i: :E:296 ,-,= · · :,..74 7F, 7400 5967.:70 7500 6030 1'..' ._; ~.,~. 46 7600 6c')'~2 54 6015 ':":' - , · i i_1 i~1 ..... 7 _7..(!(2 ....... a__z,$ 5_4_.._~,7 6078,01 7:::00 6216.58 61 :_::9.92 7900 6279.51 o.-' .~..'. 8000 ' 6343,. 51 62A6 :Bi(.')() 6407. ~0 603I. 24 ~200 6472.62 6.:, Y._,. 96 _ .-~ 646 ! · 57 8400 6604.60' 6527.94 8500 6671,62 6594.96 8600 6739.50 ' 6662.84 8700 6808.17 6731.51 :$:800 6877.79 6oL'=' ] 1 . 13 89(]0 d, ~4o. 70 687'2.04 51 51 51 51 50 50 49 49 48 48. 47 ,47:0 46 1= 45 30 · 44 1(") _=. S 20. C) W ':.'' F) 5[")'. .-,ocr-, =,-, ...... :"..-__::_ Z_~ _,_._, c., S 2(:) 10 W 0 75 4060 ':'/- S 19· 6 C) W C) .8:3 412 8. .:,'-'-'/ S 19. 0 W 1.40 41'P4.91 SOHIO ALASKA PETROLEUM COMPANY A-22 (SEC 35 T11N R13E) PRUDHOE BAY ALASKA ::,FERRY-'.=,JN WELL. SI IRVEYING CFIHF'ANY_ F'AEiE 4 ANL. HURAbE ALA.~ KA DATE OF :'--,LRVEY MAY i3, 19F32 COMPUTATION BATE ............. 1.75 LEVEL ROTOR t~YBO.. SURVEY MAY 1,:,'-', 19:::2. _ ,JOB NLIMBER SU- i. -'=/.::,- 16021 KELLY BUF:H I NG ELEV = 7/:, /-/- F'T OF'ERATOR-MCGU I RE VERTICAL ¢' F" ]'-' ,- ,.,E_.FION CALCULATED ALONG F:LL.:,URE ........................... TRUE ............... ;~UB.SE~ ....... ,._-5OURSE MEASURED VERT I gAL UERT I CAL I NCL I NAT ~ ON DEPTH DEPTH DEF'TH DEG MIN .... C OUR L=_;E ............ D F'!G, L., E G ........ TO T AL ............................. D I RECT I FiN SEVER T T Y REF:TANGULAR CFiORD I NATES DE _',REE.=, BEG/1AO, IqC~R'I'H / SOUTI4 EASI'/WEST 9000, 7020,, 54 6 ~4._,. o7 44 -0 .=,':" 1,:,./-,0' '-' .. W o. ":'"::'._,._, '426,::1 .77 1871.'-'=''.:,,., W 9100 7092.47 701 ~ 81 44 0 '-' · ._. :-:, 1 _9.. 1'9 W 0.42 4:3:2/-,. 49 'q._ .,.~" q'-":~.-..._, 85 W 9200 7164.20 7087.._ 4.~ ...................... 44 I:..'? ......... ;';o ...... 1,:,. 6U:-'_ ....... T ........... W O, ..,.:,'].. "'T'-' .... 4.:,; z.. 44). '-'":,"-' ......................... :S l'T.' 1 ¢,'._ ............... 4-2..': W 9300 7235. '"'-' ~'-? ,=,,:, 71 17 44 10 ':'1 '-' '~'' ' ='-' :/,:,,:,, 79 W ......· _, =,. ,=, u W 0.21 44._,,=,. ~T(]_. S 1 '- '-"-' 9400 7307 96 7231 30 43 30 S 19, .~ 0 W ("). '-"-' 4.~'.-.':':::. ':;'--.' · :E; 1961. :~ A W 950(] 73F-:0. "' .... 'F ,:,0 7:--:04 14. 4:3 0 :.-., .~ 3 A W 0 61 ~"'-"-' 4._,,:,o .4,1 S 1';':=:4 /- !~ W .- VERT I C:AL F.; E C T I 0 N 472:2.7 i 4792. 1 :t .... 48/:, 1.._, ~ ,:,'-' 49 :-40 .'=;':' 5067, l 7' · ,1 64 9800 9900. . . 7672, .,:. ._'":' ~ .., ....'""' R '-",,"-='-:: ._,. 59. 4.'_--: 0 ._':.; 21. :30 W 10000 7745.68 76/:.9.02 42 30 S ..' 1./:.0"' W :1A 1 O0 7a 19.61 7742..'.?5 42 10 '.-] ""-' ~.:, 10 W 1 oat o 7893.57 7816.91 4Z '-': · ~, '.:3~.:,'80. W 10300 7967.64 7890 o,-, . · ..;,:, 42 0 S ":' .,:..4.1';' W 10400' '8041.86 7965,20 '42 10 S 24,1F) W 0. :33 4 L--: 44. 1:5: S 20 :_=:2.77 W 0 F.; .... ' (- · . ..'- 1 J7 6(3) W · _4 4'F.'n7:36 c. 1 06 4;~,_',.~. /:,4 c 2133 20 W ~'} ~.-, ~.-.-, ,-. - .... :, ..,U..:, 1 "" . . o,:, .:, '.." 159.98 W 0 ~'-' 50'-?2 75 '-" '-~ .JU ~.1_,7.31 W .-~ ...,~. ~ .,- · 0 I8 =~"" ':~ ~' ....;.'14.7._-: W 0 62 F,'-, , '-"-' '-' · .-..'14 77 :i; il4i. 14 W 0 28 ."~'-' .=;' '2269.73 W .... · " 7.-. :2:1 S ....'.-.' 06. ._ ._-,o4 .'=;'-"-' · . ._.,.~'.~' S ..... .-: ..- ;'-"-":/7. ,.,_,~':' W 0, / a, ='-"- . o ~.,.,:zS. '-" ._,o y 1 · 77'-' --:,c,.- - - O.s.?9 ..,447.79 ':' '-.'":'~" '-"=' · . ._, .~..,._1 ~r · -",.-I W 10500 8116. o.-'-"-' 8039.. 66 41 34 :=; 24. :39 W 106 O0 8190.97 :--: 114.31 41 49 :=; 24.6 A W 10700 :=:266.57 818';?. 91 a-,"~ 55 'F; 25.80 W 10800 . 8343.55 8266.89 ,39 25 S 26./:,9 W 10900 :" -~' '~- 30 ~ 27 2o W ~4.-1.30 '-'~' - o.-,44.64 '-"-' 11000 8499 47 om~--~ o- ~,~-.'=. ~,i '~8 4n S 27..6'.-} W · ....... '~_ ............. 11100 8577..91 8501. ,.-~,'~= 3A_ 0 S ~'-"/-=,. o'-' u' W 11200 8657.11 .... o.,. 45 37 1 ~=; ._,'2 27. ~0_. W 11300 :E:737. 10 8660 44 ._6 30 :Z: :Zb:. 60 W 11400 .8817,91 8741.25 o'-"= 40..,:::: 11500 8899',. . 9,~. _ ,9.::::23 . .-:,c, ,.4'.] 0 .;.,':' 11600 8983 9:-} 87~07. '-"3 '-' . ...-,... .:, 1 40 ':' · _ ,:.7.'-, 47 5:5:40.28 lb,- ,' · -,4U / 5 547'4.87 .=;':i · '-' .... 4.:. 0/_-. 5609.08 5/--. / .. :::3 5742.3/-. F-;'--'A 7 77 · _o/1.56 · _ .':,.:,4 35 ..... ':,.c ':"-" 0 9068, 95 b:~'.~'.-", ~../ ,.,~. ._ 9153 52 9076. A" ,_ c, ..:,'.-" 3 A "" :.']238 40 9161 74 '-'1 19 '=; 700 :--: A 0 900 0.8/:, ~ '-' ~7 · _ 61 S 1 0("~ ~/ "= %"=' · ._ Dc.,._,.._ .-, :5; 2':;' ,:,0 W 1 (]9 = ~ ...... _,~ 16.'F."4 S · ~;-' '-,"1 S 31 (') W 1 81 ._ ,, c.o. .,_ 2::2.50 W '-';2.47 5:--: 1:3, 02S 30 '-"- . o:=~ W 0 ~'~' ..... _~ ._,:,..,,:, 72 S :30.69 W 0. ~'"" · J.", 5904.67 '.'--; 28.60 W 1.61 5950.60 :~ . . ........ :~ ................................ ..F.ERI~Y.oL!N WELL SURVE.Y. ING CO,IF'ANY . ,::: ;~;?':' . . .. ANCHORAGE ALASKA SOHI0...AL~S.KA. FETROLEUM. COMPANY. · BATE OF SURVEY 'M~Y Z3, Z 9'82 _A.~Z~ ( SEC 's ............... · -,~ T t 1N .RI'3E ) .,: _ ~_L_:._L,,. ....................... 601~BL~TI ON_..D~TE.:.::.. :.~_'......~.... :..'. 1 ,..'.7 LEVEL.. RO~TOR.._..G~RO _SUI~VEY PRLIDHOE BAY MAY o - o,-,.-, _ 1,_,, 1 :, o~ ,JOB NLIMBER SU- 1. 751-16021 ALASKA KELL. Y BJoHINC~"I '-' ELEV. = 76.66 FT. ........................ OPERAT 3R.MC:GU Z RE VERTICAL SECTION _.ALUULATED ALONG CLOSURE .... ,::: .; : .:: ~..: ; ,. :. : TRUE e..~ "'l I '~ ..- . ;~U~ l. ,.%:E~ _.~l~!lT~ ~E~SLIRED VERT Z E:~L VERT Z C~L Z NCL Z N~T Z ON D Z RECT Z ON SE~ER Z TY RECTaNGULaR COORD Z N~TES VERT Z C~L DEPTH DEPTH El EF' TH DEG M Z N El EL~REEo'-' 12000 ,m--,-:..,o o* ,~o .~- .':,. - ,:-.-:,,.-~ ':,,Z " :"-' ._,YY ..... :=:6 S ..'¢,..,7...~7 W · ,-',.~,~,, ~ ~, ...~. 47. ,. U .~, 1 IL) .=,/.' ....... V IAI (3.._, .:, :'" '- '= '-" '= "-' 12100::::':-:. :~4:I0:,':.'.05 ~'~'---"~ '--'~- ":"'":: ''" ! 2200 ". "':j ""'" ' '=' oC).' .-, 30 · c,( ...... '- - o.?., :--, ,-- '..,' .... -,,~,' ..... ) W (.), / U c,O,-,w., ]:,~ .=, .~/07, .-",o W 1 '-"-' ' ' .. ,_1 ~ioII b:--'" .~ .... ) 7 17 3 ('i :~: 0· :'"~II ...._.~ (.) (...~ ,.-,~ c-,_-.,._-, -,.-, ,-, p-;, (- .-., .... ..-.-'P ~; W 0 O0 61'-'= 64 b; 27:32 '-"-' 12316. :-}5.97 76 ':;5":' 1 2'_:.~ /_-, 1 '=' .._.~.. 10 ""'" '-' 30 30 W 0 O0 .... ' · ..:, L) .=, 4-4 2736 '-'¢ · ,-' .) W : HORIZONTAL. DISPLACEMENT = 6715. I8 FEET AT $OU]'H 24 DEG. _'~' MIN. WE~,T.¢' -) 6707. :'::4- 671..., ~':' . 18 THE CALCULATION PROCEDURES ARE I--B_A.S_'.E.~L_[:--.LKLTIHE_.ll.!.-_I~iE._~IE_.THREE..I]!Ii~IE~.S'I_C!NAL._R~: ' 1'zBI Ll.~ ...... g~E L. UR~A]]L!Fo:E_~_iETI~OLO- ' - .... ....................SPERRY-.=,JN WELL =,JI-.,VI=¥ ING COMPANY ANCHORAGE ALASKA ~" ' '!- - """'1 -';OHIO ALA..KA FETRJLEUM L:CHF'ANY :'RLIBHOE BAY ~LASKA L. UMF'L _!'~Ti ON DATE I'1A Y 1 c, 19 :::";.' F'AGE ,'.-. DATE FIF .:,JRVE¥ MAY 1:3 1'.-'.)82 JOB I',IUMBER SU-1.75-16021 I<ELLY F{USHING ELEV. = 76. c::, FT. 0 P E R A T 0 IR- M C: G U I R E , , 'j I NTERFLLATED VALUES FOR EVEN 1000 FEET OF MEAE;URED DEF"TH TRLIE 'SUB-SEA TOTAL I 'IEAL:;LIRED VERT I CAL VERTICAL REF:TANALILAR C:F,]RDII',IATES MD-TVD 5l- ' - '-' / '-' ~. EF TH DEPTH DEPTH NORTH/SOLITH EA.:,T. WEoT D I FFERENF:E VERT I CAL F: Fi R R E F: T I 0 N 0 0. O0 - 76.66 0.00 0'. 00 0. (:) 0 .1. 000 999... 97 92~.:.. 31 0 .16 !',1 ._,'~. ,..~... W 0 . ¢]'-'._-, 20AO 1999 "'""~ ..... W'.."..:,. 18 10,7 9 'E; 8.91 W 0.1 ,'"', · _000 2953.50 ~,:,76. ,.:'::"T ~.._":'.:;,*:,._,. 74 .--: 1 cJC). 0'.~ W 46..=;,n_. 4000 .'-,7(]. ' . .-',6._-,.,:. 43 ':"-'=' '.~'F.,' 0,:, 376 46 W 29C). '-.72 · 5006 .....'""-' '~-' 4._-, .9 o. 7 o "~ ':' ''') '-' 4 Y 0.4. .'/ ~., .. · .-,,:,,:-~.. 12 1 :' 686. (]'P W 601. ,:..~'-"-' · 6000 50."F,~l 71 o015 05 '" ":":' · ~ 1 14 '-' 1001 44 W 'P()8 2':.) · ~, ~ · -_,~ ~ · . ~ , '0.03 (]. 1:3 46. :34 24.4.41 :310.ol :307.06 7000 5717.174 ~, ',:, '' ._-,,-,=~. c. -':,'" ,:,---, --.,,:,.-, .':,_ ..,o41.0,_, ..:,.-,._,..,. 61 ._, i ._,06 .... .." W 1 ~.,.:,.,:...../: .... 7 ....... .,. c, Ot)(.) z..~,.'i .':, ?,. /. '-' '-'=' ("F,":' c. ,:.:, ~-,.--~ ....1 ,'..-'66 '-'= o._, ,:,.., 7 J 161 40 W 165/', 4'P :374 'z,':, · ._ ._~ · 9000 7020...4..~, 4~'P4F:_ o _. 87 4260 .77 ._,c' 1:_--:71. ._,._'--'.~ W 197'.-.9 .46 ._,....-:,oc,.L. '~7 ..... · .'z.._ 4 274 '-'=' 10000 7745.68 766'.P 02 4907 ,.,4.,:..-', 81 11 ::, . z4::,'. ':'1 ." ,_ ,..1 .I. '"1 · · 12000 '-'-'""':' '-' ~,:, .- ._, . .':-/ /:, 9247 00 · .'::; '""/ ':" ~ . 86 S .-.,/..~,..:, .-.,..;, , · ..... ~.",._,... , 1 "-,,:o16'-' 9577, 76 o:',...1'-, · ~0 : 61,:,~..'"'" 4-4 .:,'-' '"~7.,,6,'-' ...'0'-' ' W .,. 7J ,_,_.":" ':' .-'_4"' .... ~,.'2_'!'" ............... THE CALCLILATION PROCEI]LIRES ARE BA:_:;EI] FiN THE USE OF THREE DIMENSIONAL RAI]IUS OF CLIRVATURE METHAD. .-';OHIO ALASKA PETROLEUM COMPANY q-22 ¢ SEC: 35 T 11N . R.I:~.)_ ......................... :'RUDHOE BAY qLASKA .................... · :,FERRY-.::,JN WEI_L_.F:;I!RVEYING I".'~-IFiPAI',IY I-':'AGE 7" ANCHORAGE ALASKA DATE OF '.=;URVEY MAY 1:'=::, 1'~.?:~:2 COMF'UTATION DATE I'1A Y 1 '~-'1 '-:?'-R'=' KELLY BLISHING ELEV· = 76.6./-, FT. OPl--RA TC~R-I'tCGU :]:. IRE I NTERFLI, ATED VALUES FOR EVEN 100 FEE"F: OF SUB-SEA DEF'TH TRUE ~IEASURED VERTICAL VERTICAL RE_.TANbULAR C:00RD I NATE'.=-; MD-TVD VERTI _.AL ]EF'TH DEPTH [IEF'TH N~]RTH/:=:~]I ........ I]'H EAST/WEST D I FFERENCE F:C;RREF:T. I ON 176 176 66 1 O0 O0 0 '-':=' .... · .'- .... S 0.68 W 0.00 0.00 276 276.66 200. O0 0 . c:.-,7.:, ._,':' 0 .75 W 0 .01 0 . O0 376 376.66 300.00 1.17 L=; 1. :34 W 0.0:l " 0.00 · 476 476.66 400·00 1..06 $ 1.65 W 0.01 0.00 576 576.66 =-( ' '-"/- · ._,. }(.; 00 I ,.z, 0. O0 ~.., S '.';' W 0.01 I i ,4.,, i -,-_1 ~6: '' 67~ 66 600 00 1 72 '~' '-' ..... . ~..72 W 0.02 0.00 776 776.66 876 876.66 :~76 976.66 1076' .': .:':,., :t.0~6.66 1176' . .': .:: :.: 1':1.7:6'.-66 ,.: . ::., 1276 . :.:' ;-': 1276 700.00 1·00 S 2.96 gl O.t--.'r-' 0.00 ~=, U U· 0 0 0.5 9 $ .:,.'-' 5 4 W 0.0..':' (').. O0 '."? (') (-') . 0 0 0.0 4 N '-' 6A W 0 0 ::: 0.0 0 1000. O0 . .. 0.2'-? N ,..':' 26 W 0 0:3 o.00 100. O0 0 '-"~ ~'' ':' ' · . ~.,...:, .... 17 gl , O. 0::: 0,'00 .~ - .-) . . . -_, ,-. .-, ~.. . . -).-, .,:ti(.. O0 · '. 0 ·/-,~ :=, o. 4.-., W , t~. (. .:, . 0 O0 ............................... % ...................................................................... .. ................ :L_..L 1376 1376.66 1300.00 1.25 S 4.19 W 1476 1476.66 1400.00 1.74 S 5.32 W 1576 1576.66 1500.00 2.60 S 6.53 W '-167& 1&7~:'~-~ ........1600 O0 ...... ~.~'-75 :,'-' ' 763W. 1776 1776.:66 1700.00 5.23 S 8.27 W 0.04 0.00 0.04 0.01 0.06 0.01 0.07 0.01 0.08 0.01 -) SOHIO ~" , ALA..,KA PETROLEUM COMPANY -RUE~HUE BAY qLASKA TRUE ~EASURED VERTICAL DEPTH DEPTH , 1876:~ 187'6/66 1976 1976.66 2076 2076.66 2177 2176.66 2277 2276.66 Z37:-.? 2o76,'66 2481 'i: 2476.66 SF'ERRY.SUN WELL ::,_R~/EY. I NG COMPANY ...... F'AGE ?-:_ ALA;=,t',.~.~ ANCHORAGE "'~ .... " / C 0 M F' U T A T I 0 N. D ATE MAY 1'--' 1':~c''-' ,.T.'~ ~, ::- v." DATE OF .::JRVEY MAY .:, 19::::2 · :, U- l. /.-,- l (:, d ,.' 1 ,_lOB NUMBER" .... =' '""-' KELLY BUSHING ELEV. = 76, 6,:~:, FT,, L]PERA TOR-MCGU I RE INTERPOLATED VALLE._, FOR EVEN 100 FEET OF SUB-SEA DEF'TH TOTAL , i-o ' ~o 'l VERT I CAL RE_. FANULILAR COORD I NATES MD-TVD DEF'TH NURTH/.:,OU] H EA.:,T/NE.:,T DIFFERENCE VERT I C:AL -]~ '' F' ' L. JRRE -:T I ON 1:::00 00 7 13 S '=' -'" ..... ,_-.. :.::.:, W 0.10 1 '-?0 0 0 0 : ss' ':-'-'=' '=' :-": 6 7 W 0 14 · ."t~OC~ 00 14 '-'F '-' ..,.) 9 99 W 0 25 · '~' ' ] · .'- IOL 00 '"' ~¢.~ '-"-' · · ._ . .,:,,=, ._ 12 46 W 0 ~1 2200.00 :31· 02 o'-' 16· ..:,'-"<:, W 1 . 1 iL 2:300. O0 4~, 9'7 :_-': 21 · '24 W 2.39 2400.00 /-.7 '--'":' '- ..... .,... ?...._,.., .=, i.-"::,.'.'."-"¢ W 4.;~73 · .-585 .-576.66 25¢]0. O0 ;?:'¢5 05 ::~ ""-' ~:,,:,. 76 W '.'/. i5 . .......... %__ .............. _:.,..~. .1___-- .... ~ ............................................... 2692 2676.66 2801 2776.66 291'2 2876.66 3026 2976.66 3142' 3076.66 3261' 3176.66 3384 3276.66 3515 3376.66 2600.00 12'.:?, ._,4..:,'-' 50 ,45 W 1'-._,, 5 :_.::_ 2700· 00 170..,:.6 S 64 · 43 W 24 49 2800.00 .,_'$' 16 . ~....,~":' .=,'-' :::_ 2 .63:1,4 · 36 .19. 2900.0.0 265.(.~]'-' '.=;-' 1t)._' Pi. 74 W 49.72 ~, .~00.00 '" . · :,17 14 S lo.-. · ~._, W 6M 66 3100.00 375.77 S 1 _ ~, .-/. 45 W :--:4. a,/_-, 3200 00 441 75 o 1,-"--~ · .._, ,=, ~.. 69 w 108.24 3300.00 517.oo'---, ~,R 22a,. 78 w 1 :~:9_. .32 · --, I::' ---, .--, ..... .~-'~ · o6.,6 ~476.66 ._-,41 ~0.00 a, ua,. 48 :E; 269. 15 W 17'~ ._ 1 3804 · 3576.66 A ' ' ~5U0.00 704.8'~ S 315 75 W 227 35 3952 3676.66 3600.00 804.24 S ._ ............................................ __~ ........................ .:_,FERRY-.. Jt~ WELL SLIRVEYINI]. F:OMPANY ANCHORAGE ALASKA OHIO ALASKA PETROLEUM COMPANY DATE OF ,-'l-,'"' · ~, J k 9 E Y MA Y i :3 19:32 _o-:, <SEC: ~..~,.:TI I:N:.RIoE) COMF'LITATION DATE RLIDHOE BAY MAY ]8, 1982 ,JOB NLIMBER SLI- LASKA KELLY BLtSHING ELEV. = ~ : · INTERPOLATED VALUES F'qL R' EVEN:: i00 FEET OF c.,,LiB_.:,E~,-. ~ DEF'TH :': TRUE c. ,:. - ~,IJB-._,EA ]'OTAL '-' I' i~ _ _ IEAz, L RED VERT I _.AL VERT I CAL REF:TANGULAR C:ClORD I NATES MD-TV[I VERT I E:AL ~g~'_.~_ ............. ~g~,]~ ............ DEp.~.H ........ !~'ORTH/SOIJTH EBS~T/.WEST 4~:4., 387&. 66 4391 3976.66 4536 4076.66 4679 4176.66 4823 4276.66 4968 :4376,66 5112 :i4476~66 · _~-~ 4576.66 5397 4676.66 557:7 4776.5,6, · .:, Y 0 U. 0 C) 1095.0 c, :.3 4 (] 00. A_ 0 1. 1 ,_-,;~'-"-. 71 ..,':' 4100.0 (] '-"-' '-' 1 ...,:,.:,. 20 S 420(], O0 1:'::76,., '='-' '-' ,.J...:, :.":,. · 4300.00 146.'FY, '~5 '-':o 4400· 00 15/_-,2, 6:-': .--,':' ' 070¢. O0 "-- ' ':"":"-" 701 '"'"' ' . _ ...., . , .-, .~, ~, .':1. 3,qO0. c]() ,:.,":'~9..11 S 4~].~, '::.c W "" '- 49'6. 'F~ 1W 414. 541 29 W =- · 4 ._l '.~/· 5',::5.51 W !5 C):::. 630.44 W 54.7. 675.94 W 5'.:."~ 1. 721. ,77 W '-'~ 4500.00 1653.51 S 768.05 W 67:-':. 4600.00 1743.75 S ',_:: 13.59W 720. 4700.00 1,::o1'- '-' . ._7.~, c'-' ......... c,.=l.7 79 W 7 A 0. 5679: 5824 5976 4876.66 4976': 66. 5076-66 6,134 6454 5176.66 5276.66 5376.66 6613' 6773 5476.66, :: 557.6.66 .. :. '¢ ."-~U..' _ W 802. 48 JO, O0 1921,4:3 S '- "-', :::3 4900.00 2017 '--"': "" '-' '-' .... ~ y, .:, 947.8 C) W ,:,4,:,. 5000. O0 : 2121.5:3 S 994.35, W · ?-.,c, . ._. 957. 5100.00 ~.._,4.02 ,.E: 1042 ~':.) W 5200.00 2:349.1 ::: S 10 .'20.97 W 1017. - - . '-~ ._.~ .~. · ................... ._~::!QQ_...!:).Q .............. ~4_64,40.:--; ..... $.1'-"--~ 25 w 1077. 5400 00 : 2579.04 S 118A. ~'-' :' . : . _ <,z W 11:37. .. ~ 50o. 00 2693.10 S 1 '"'-':' z.:,._,. 19 W 1196, 77 4.5 '=,'-' 44 ,:1.4,67 ::: (') " 4:3 ':" l .~,:, 43. ""-' ~(').. 44. .,:.~.'-"-' 37 -: .......... .4:Y, 87 1 :E: 42. :--: 1 :z:6 432.-". Ic',_, 5, 0 4 C). :24 ..... 41.7'P : 04 4.5. o4 ,=,'-"4 . ........ =F-: 1 .. '",:4!' ......... i"', ..:i ...j,:,. (..j 9' C) 6, 0.0.1. 92 60..02. · -, .~c., .-q · ,:, :IL ._ :.,...... F;2 5'.--./. 21 F'AF'iE ':) 76.66 F'T. OHIO ALASKA PETROLEUM COMPANY _.-.,.-~ ,_-. -~ .=,~ , '~| ~ (~.E~ ...... , T11N R1..E) RUDHOE BAY ~LASKA .=,FERR~-.=,JN WELl_ SLIRVEY!NG COMPANY F" A F~E t 0 ANL, HURAOE ALASKA £R!E OF .=,URV~¥ MAY 1 COMPUTATION I. mTb ~ MAY 1'", .'- ,-,.' ,:, 1 ':',"='":' ,_lOB I'4LIi'"iIT~ER Si_I- 1.75-16021 KELLY BUSHING ELEV. = 7/--,. 6//:, FT. OF'ERATOR-MCGU i RE I NTERFULATEI.: VALLIES F~qR EVEN 100 FEET OF SUB-SEA f'IEF'TH TRUE ._ LIB ._,EA TOTAL '-'!1 ' lEA.=, _ RED VERT I CAL VERT I CAL IEF'TH DEPTH DEF'TH L. UUR£ I NATES MD-TVD !FFEREN-.E EAoT/WE.-T D 1 ..'._ 7 tZ d 1 .... ::7 i ':2:7 Fi"._ ~'~'...., 437./..,6 49' 7.97 558. '~;":.-,' ~ ' ~ ...~60.).00 6.933 .,,676,'66 =: ' (' 7094 5776, 66 5700.00 .........7 .- ,_,.-, ;;; =':~" ........ -='c--,._,,.,76. ........ 66]5c ............ ._,,_,0 U .~;?";" (.):'f'.] 7414 .:) Y76.66 5'.~00. O0 7574 6076.66 6000.00 77.:.u, 6176,.66 6100 ¢]0 RECTANGULAR NORTH / SOUTH · , o (.J 7 "-~':,~ ':'"~ '="=' =' ....... .:,~ =~;.._,. 77 t4 · ':,.,:'~.-,.-, "~.'~' c..' :-. ~ '="-'/-, ,q(" W 303:=:· 25 S 1387.54 N 3~5~. ~0 S 143:=:,:'-:5N 3265.27 S ~4:=:9.'F¢6 N .... · .-, .-~ ,-, ~-) ,_-. ._-,._-,o,.. 84 .., 1540,64 W VERT I C:AL r": r"[ R R E I-: T I FI N Z",t") ='" ..~L) : ,. 6.1..~.. &C , .~. 27 59.11 60. ::: 1 6I. 02 · . 8051 6376" 66 8206 6476.66 8357 6576.66 8507 6676.66 8654 · 6776.66 8798 : 6876.66 8.938 :6976.66 9078 7076.66 9217 7176.66 .. ,=.,_.6 7..-76.66 7'.-.'00 · O0 44..;.5. :::9 ............................................... ,'""_" .-_ -.. t" ~' ' 94..;.4 7.376.66 7300. O0 .. 4584.76: 9631 :' 7476 · 66 7400· 00:. 4672. '"~' : ' : ) ' :i:, · .' : ! i' ·: ::.i :..:: :::: 6 ,' C 0.00 · · i ='-''-' -~ 0 ,:,,:, · ..,,=,o.,., W 1618 86 .=,':.'~, '-'"' , .-, - - ,'-, " .-',,_-~ ~-. "=,":, C:, · '-"- ' '.~ ' '-' /:,.:,UO. 00 ,:,6U7. z.,_-, ::, 16.=,,:., ,_,4 W 1674. ,=,'.'/ -: .,. 6 · o,:, ' : . .:::;;:T"-~=- .~ /.. ~-,4i)i:~:]:~-i.:~ .................. ~,;~-~-~-?.~.;7 S 1675. '2/-, N _17 ..' .-/..-,.-, ._ :~. 51 75 ........ =4. :37 1714. c,.:=: W 1781 .=. 1 6500 00 ':":'"':' ': .... ' ,.,.-/..-~.,. 75 ._, 17._ .:,. 0'.:.? W 1E:30 80 . · 6600 · 00 ':,,- -:,,:, '.:- F]'-' ......... . .... 49 50 · " 40..~. :D9 ''~ - · - 6700.00 '-' . · ._. ~ 17:--:'?~,92 W 1877 7:2: 46 ".-~::: 1 ,:, ..' ,:) ~' 1921 72 4:3 . .-'-.'~ .L:,; · 6,,,r,.~O. 00 4127 '-": '-"-'=" 23 · ... ,,..."~ · 4~.,.._ P;':'.,' ::, :I. o._ 7.77 W , 176.,:,. 690 ("~ 00 .'..,".' o · ._. ,-,.'=, ' '='· ...,~'=' '=' 40 · Pi '- 7000 ..................... 00 ' 4312 .07 ._,':' :L "",:, o"",.,':l. ,.,':' ._,':' W 2001 · :36 :39 · 7100.00 440:z:. '.~4 S 1 '.-.-~20. :z:o W 2040. 76 39. :::'.;' .:, 1 ':}.=; 1 · ~c:' W 20:::o 17 39 · 41 · ...- _. --. ~-. -_"t- , _ c 1 ':~E"~ ..... o4'-' 'W :2117 6:=: '::7 .=,._ 1 · ' *-..,*i*~& ,-'=' '.R 2015 '-"- W . · _ . ,=,:z ~ ,..__ ,=,,_, :2:7 . · _, K ..... N_t.4 _ .--,_ .....ING COMPANY PAEiE 1 ................................... ~ ..... , ................. FE RY.-~II ELL -'JRUI--V ANCHORAGE .ALASKA 0 '"' ' OHIO ALA:,KA PETR'-'" M COMPANY ':;:: DATE OF SURVEY"IdAY 1.~' ............. :.: :. . i ~: ';:'.~/, - . '. RUDHOE BAY iflAY 18, l'-'="- y,.,z JOB NUMBER ,-'! - .- · :, J- 1 7._ - 1602 i-. LAoKA KELLY BLISHII'qG ELEV. =: 76.66 FT. 0 P E R A T 0 R -j"l C G U I R E I NTERPLLATED VALUES FOR EVEN 100 FEET FIF SUB-SEA DEF'TH ., ]'RUE .=,UB-.:,EA TOTAL EA.:,L RED VERT I CAL VERT I C:AL REC:TANRI ILAR COORD I NATES MD-TVD EPTH DEPTH E El- TH N JRTH/.:,UUTH EAST/WEST D I FFERENC:E VERT I E:AL C:ORRECT I ON -. 9768 ;") :" :, ::-17576266 ':;' :.' 7500.' OC) 9906'". 7/:,76,66 '7600. O0 10042 7776.66 10177 7876.66 10312 7976.66 10446 8076.66 10580 8176.66 4760. m'-, ~"'; 2050. · '- 1 ':/'-'". ", '-'" '~ '-, ' ,--, 4o4o. U 1 W ~0,_,4. ~7 7700. O0 49:_--:3. 74.., '=' 2118 .06 W ."-"-'/.' =,._, = . ._-,'-'=._, 7800 00 M 017.24 '-' '-" ='-' · =, ~ 1 74 W 2300.4-:3 ,.-~ (-)p .--, 4:_=: 7 .... ,. 00 ~ 1 (')C) 1.6 ,., ..' 1':?0 64 W '-"-"-'~ · _ . . .. . ,, .~..", ,-, - . -! ~,;, .-,.-, - .-, c.,UO(.. 00 ~- ':'":' o l,_,~.. 64 S 2227.._, W ,~..:,7U. ,'7 8100. O0 ='-"'-"._,,"o,:, 66 .=,'-' "-"'.-'64.40 W 2404. .1'--' 1071.3 '. "....R"-'~ .."76.' :'66 ']'-' ", '-,"D'-, 1 t ,:,4--- 8376.66 8:300.00 541/:, .05 S ...._,.:,,:,. 0:3. W '2466.18 10970 8476.66 '-' ' ' '-"':' ,=,400 00 ~4R6 95 '-' ..... =, .~._,74.66 W 2494. I ~'-' 11098 RF,-~z=._.~,. 66 -:=:50A_ .. 00 =:~.:,._,._,7 .:,c, S 2411 11 W '""?]'-' · ............................ ._,.,.., ~ .... .' 1 . 7.. 5 11224 ~,676.66 '-' ' ' ,=,6UO. 00 ~/-,2.~. 76 :=, 2446.27 W . ..... 1 "" c .: . : ,-, -- = ,~ ,-.' .-., ,:, l~4Y . 8776./_-,~ oTOO, O0 - ._,6Y i , .17:. o ~.4,., 1 , 11471..: ':' ~ '- "' .... = :-:., -:, .,2 .-:,= ,..~76.66 ,::~o0, Oo .:.,7._,,. · 7,- ,., ~_.., 17.1 29.70 27.94 :27 ·/'-':' ~.d,. 14 24-.: 61 '"'":" 70 '_ ..... 1':2 ~'--' 17.71 18..'_--:4 _ .. 17 o5 · ._, :7 11591 8976 66 '--'" ' ' ,:, Y 0 U. 00 .'-] 8 A 9 (') ':;, S '? F, 5 A '-"-' ............ :,._', W 2614.73 11709 9076 .... 66 .':?000.00 58/-,2 o,:,'-'"' ':',_, ..',.,o'-'="-' 1. :::::.:-- W .,.'-':'/-':"-.'_,,.,.. 4:':-: ...... !!827 .w176.66 . .. 9100.00 . 5917."4= ......... - . ._._, :i; '.;"./:,IS:. 54 W 2650 7:3 11944 ¢27~, 66 9200 ,00 5971 · ti'-',- S 2 d-,43 , ,::'-,:,'-' IAI ~.c,'-'!- ~'~.=,'-' · 1 ,.'-'.- 12061 937&, ~6 9300 00 ~U~,.,' '-":'. '-'= '=' '-' '-' . , -,..;, ._. 2~72, 7/=. W ...-6o4, 72 OHIO ALA;_-,KA PETROLEUM COMPANY ~-22 ¢ SEE: "'= '" o~, Tl lN Rlc, E) 'RUDHOE BAY ~LA'.E;KA · :,FERRY-.=,JN WELl_ SURVEYINC~ C:OMPANY ANL. HuRAc E ALASKA COMPLITAT ION DATE MAY I :-:, 1':.?::-:2 F'A GE J. ;2 DATE OF SLIRVEY MAY lc:, 1':":'":' JOB NUMBER ::';U'~'-'I., 75"~60:21 KELLY BLiSFIING ELEV, - 76 '' FT --. . C:, C:~ CIPERATOR-MCGU t RE INTERFLLA]ED VALUES FOR EVEN 100 FEET OF SLIB-SEA DEF'TH TRUE IEASURED VERTICAL IEPTH DEPTH 12176 9476.66 .-~ .~ ~ ~ i~91 ,._,76.66 'RI '-' · :. JB-.=,EA TOTAL VERTICAL REF:TANRULAR COORDINATES MD-TVD DEPTH NORTH/:::O~JTH EAST/WEST D I FFERENCE 9400.00 6073.29 S 2701.63 W 2700.21 9500.00 6122.13 S 2730.18 W 2715.10 VERT I CAL CORRECT I CIN 14 .' :--:. 14- THE CALCULATION PROCEDLIRES I...=,E A LINEAR INTIERF'OLATION BETWEEN THE NEARE..,T 20 FOOT MD (FROM RADIL.=, OF E:URVATURE) F'OINTS Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. - b~e~ato~, 'Del 1 'N~ame and Number Reports and Materials to be ~received by: ~ --~-- ~-Date Required Date Received Remarks , Cc~p letion Report. Yes .Well_.. Histo~. ~ , . .... Yes ~ ~ , , , , , ,, . ~re ~ips ' ~ Core ~scription /:~,/~ ~'*~ Registered S~ey plat ~ e.._'~; Inclination Su~ey ~ Drill Stm Test Returns d~/~O ~,/~ , SOHIO ALASKA PETROLEUM COMPANY TO: SFO/UNIT/ STATE: SFO . , CHEVRON"" EXXON GETTY .: HARATHON MOBIL 311 1 "C" 5'I'REET ANCHORAGE. ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 PHILLIPS * STATE OF AK · . BPAE (Transmittal Only). · .. :.. REFEREN&:~NTRAL FILES (CCI/' s-Transmittal Only) .. ., . .. SOHIO OPEN HOLE FINAL LOGS '. The following material is being submitted herewith. Please ac~r~wledge receipt by signing a copy of this letter and returning it to this office:-- ..... · '·.*'"':Dace to State STATE ONLY: DIRECTIONAL SURVEYS: Magnetic Single Shot Directional Survey Gyroscopic DirectiOnal Survey Date: JUN']. 1982 -- DATE 9 7[laska 0il & .Gas Cons. ~om~T~ion Anchora§"~ SOHIO ALASIiA pET;qOLEUM CO;:'!PAi'~Y SFO ARCO EXXON PHILLIPS STATE OF CENTRAL ¥ILES(CC#'s-Transmittal Onlx ... 3111 "C" S]REEI ANCHORAGE° ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 6/2/82 Date: Trans.#: 1614 CC#: 49614 REFERENCE: MAGNETIC LIS TAPES & LISTINGS . ~..- , . material is being submitted herewith.-Pleas-e ~cknowledge receipt by signing a etter and returning it to this office:-- A-22 O.H. Sch ACC 65106 DIL/BHC/FDC-CNL/ 5/1/82 CH CNL C'2/ C.H. Sch ACC 65107 CH CNL 5/17/82 S-1 RD#1 O.H. Sch ACC 65104. DIL/FDN/BHC 5/2/82 X-16 O.Ho Sch ACC 65074 PIL/FDN/BHC 5/5/82 D-19,·:' O.H. Sch ACC 65105 DIL/FDN/LSS/BHC/ 5/7/82 SO1 #1 Tape pos. #01764 #5 Tape pos. #01765 #1 Tape pos. #01766 #1&2 Tape pos. #01767 #1 Tape pos. #01768 (4/8~ *SFO & EXXON' AnAsterisk~(*) next to a listing abouve means you should have eceived the Tape(s)" 'and Listing(s) dire_ct_ly from the respective service company. Please conf~rm ,t-hi~_/5~/.. ~._ ',~ ~,V~_ D K aren Mestas / va ~. .j~Ri-. ,, ~..~.,z. ~s ___ Well Records DATE Ancl~u[age Bobby F~ ~'' ' Ap=il 20, Z982 Witness BOPE test c~ SOHIO's A-22 Sec. 35, TLIN, RI~ Peri, it %82-18 ~ .tu~ April 17, .1982: I tra~.~ this date to S0EIO's A-22 and witnessed the BOPE tes~'~'. ~he test-began at 1!~3~ p.m. -4-17-82 and was concluded at 2:30 a.m. 4-18-82. · h~~ly o~a~ cho~. ~s va1~ ~ to Ue r~ ~ th~ A.O.G.C.C. office notified. ~" In ~ I witnessed the BOPE 'test c~ Sf~IIO's A-22. Attach: The A.O.G.C.C. office Was notified c~ the 4-20-82 by Garland Goodwyn that the val~ in ~ ~ manifold ~_4 been rep~?~d and tested. -O&G 4/80 STA'£E OF AI,ASKA ALASKA OIL & GAS CONSERVATION COblMISSION B.O.P.E. Inspection Report Operator ~ ~/~ ,~t' ' · Representative ' or' '-'-~-~-W~ .~,O Well,~' '~ ~~ ' Permit ~ Location: Sec ~ ~//~R/~[.i ~ /J~casing set ofT/~ ft. Drilling Contractor~/~,~~~' ' Rig Location, General Well Sign General Housekeeping Reserve pit. BOPE Stack Annular preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pres sure Test Results: Failures ACCUMULATOR SYSTEM Full Charge Pressure~~/O psig Pressure After Closure/~O psig 200 psig Above Precharge Attained: -- mil sec Full Charge Pressure Attained: ~ miL O sec Controls: Master.._ ~, Remote~3 Blinds switch cover..~ Kelly and Floor Safety ,Valves Upper Kelly / Test Pressure Lower Kelly L Test Pressure Ball Type / Test Pressure /L)/? Inside BOP / Test Pressure ~/~'-- Choke Manifold._~/~J Test Pressure No. Valves /~ No. flanges ~ Adjustable Chokes ~ Hydrauically operated choke / Test Time -,_~. hrs.. Repair or Replacement of failed equipment to be made within -~., days and Inspector/Commission office notified. Remar.ks:_~'~ JZ4~O ,~//A/,~ ~~ ,' ~ ~ ~~~/ ~~ / . , DLs~rLbu~Lon ori~'- AO&~C cc - Operator cc - Supervisor Ins l~ir. R. H. Reiley District Drilltnt~ l~ngineer Sohio tlaska Petroleum Co~pany Pouch 6-612 Anchorage, Alaska 995(~2 Re., Prudhoe 'Bay Unit A--22 Sohio Alaska Pet~,oleu~ Company Permit No. 82-18 Sur..Loc. 22t}9'NSL, I?04'WEL, Sec 35,'TllN,-R13E, UPM. ~'tt~ole ~e~ 1484'~SL, 376'~, Sec 2, T10N, R13E, Dear Mr. Reiley: Enclosed is the approved application fo~ permit to drill the above referenced wel I. Well samples and a m,~,d 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 loc information shall be submitted on all logs for copyin~ except experimental lo~s, vetoctty surveys and dipmeter surveys. ~iany rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Opel*attons in these areas are subject to AS 16.05.870 and the ret~ul'ations promulgated thereunder (Title 5, Alaska Administrative COdeS. Prior to emr~.encin,,~ operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by A5 46, Chapter 3, Article ? and the reiu.~lattons promulgated thereunder (Title 18, Alaska Administrative Code, Chapter ?§) and by the Federal Water Pollution Control Act, as amended. Prior to c~enciag operations ~ou may be contacted by a representative of-:. the Department of Environmental Conservation. ~/~. R, It. lteil6 Prudhoe Bay Unit A-ii To aid us in seheduli,~ field work, we would appreciate your notifying this office within .48 hours after the well is spudded. t~e would also Ilke to be notified so that a representative of the Commission m-a7 be present to witness testing of blowout preventer equipment before surface easing 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. Var7 truly yours, C. V. Chat tef t on Chairman of BY O~DER OF Ttt~ COMM~$$;ON Alaska Oil and Gas Conservation C~tssion Eno 1 o sure Department of Fish & Game, Habitat Section w/o enel. Departn~ent of Environmental Conservation w/o encl. CrC ~be SOHIO ALASKA PETROLEUM COMPANY January 27, 1982 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Con~nission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: Well A-22 (13-02-10-13) Enclosed are the following documents, in triplicate, for the above-named well together with our check for $100.00 to cover the permit filing fee. 1. Application for Permit to Drill, 2. Proposed Drilling Program Outline, 3. Blowout Prevention Equipment Diagram, 4. Surveyor's plat showing well location, 5. Directional Map. If you have any questions, please contact either R. H. Reiley at 263-5183 or K. W. Kolthoff at 263-5176. RHR:ja Enclosures cc: Well File #17 Yours very truly, District Drilling Engineer RECEIVED JAN 2. 9 ]982 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASK 0IL AND GAS CONSERVATION ;MMISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE I~ MULTIPLE ZONE [] 2. Name of operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage,~ Alaska 99502 4. Location of well at surface 2299' NSL, 1704' WEL, Sec. 35, TllN, R13E, UPM At top of proposed producing interval (target) 2100' NSL, 700' EWL, Sec. 02, T10N, R13E, UPM At total depth !484' ~.qT,. 376' EWL: Sec. (2: T10N: R13E: UPM 5. Elevation i~-~-e~t'(indicate KB, DF etc.) 6, Lease designation and serial no. Est. KBE = 65' AMSL ADL 47472 9, Unit or lease name Prudhoe Bay Unit 10. Well number A-22 (13-02-10-13) 11. Field and pool Prudhoe Bay Prudhoe Oil Pool 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number Safeco Ins. 2975387 Amount :$200,000o00 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed NW' of D~adhorse 10 miles well A-16 2800 feet 14. Distance to nearest property or lease line east of ADL 47471 700 feet 16. Proposed depth (MD & TVD) 12384 'MD 9630 'TVD feet 17. Number of acres in lease 18. Approximate spud date 2560 March 27, 1982 20. Anticipated pressures 3330 psig@ Surface o (see 20 AAC 25.035 (c) (2) 4390 psig@ 8800 .ft. ~ 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1800 feet. 21 MAXIMUM HOLE ANGLE 45 Proposed Casing, Liner and Cementing Program SIZE Hole Casing Weight 36" 20x30 17 1/2 13 3/8 72# 12 1/4 9 5/8 47# 8 1/2 7 26# 22. Describe proposed program: Insutat CASING AND LINER Grade J Coupling :ed Conductor L-80 ]BUtt. I L-80 /Butt- L-SO / IJ4S Length SETTING DEPTH MD TOP TVD 80 SurfaCe 2725 Surf~ace 11119 Surface I 10619 ~, 8383 1765 MD BOTTOM TVD 110 I 110 2725~ 2700 11119 I 8736 i 1238411 9630 QUANTITY OFCEMENT (include stage data) concr~ 3720 cu.ft. Permafros 1630 cu.ft. Class G 130 cu. ft. Permafros 420 cu.ft. Class G w/18% salt See attached proposed drilling program outline. RECEIVED JAN 2 9 1982 Alaska 0il & Gas Cons. Commission Anchorage ii 23. I hereby ce, r,~ify that the foregoing is true and t to the est of my knowledge SIGNED (~ ~,w~.~ .%~_~_ _~ TITLEDistrict Drillinq En.qinee~ATE The space below for commissl'lS'n use Ro H. Reiley '~ CONDITIONS OF APPROVAL SampleS[]YES re~2~ Permit number Mud log required I-lYES ~O Approval date Directional Survey required 'u~YES []NO APl number 50- O 1. ? - '~ ~ '7 I SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE February 2, 1982 by order of the Commission Form 10-401 Rev. 7-1-80 Submit in triplicate PROPOSED DRILLING & CCMPLETION PROGRAM WELL A-22 (13-02-10,13) Dry bucket 36" hole to 80' below ground level and cement 20" x 30" insulated conductor to surface using 8 cu.yds, concrete. Drill 17 1/2" hole to 2725' and cement 13 3/8" 725 L-80 Buttress casing to surface using 3720 cu.ft. Permafrost II cement. Blowout prevention equipment consists of 5000 psi W.P. pipe rams, blind rams, and annular preventer from 13 3/8" casing point to T.D. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Directionally drill 12 1/4" hole to 8740'.TVD. Run 9 5/8" 475 L-80 Buttress casing to 8736' TVD and cement first stage with 1630 cu. ft. Class G cement. Cement second stage through D.V. packer collar at 2600' with 130 cu.ft. Permafrost C cement. 9 5/8" casing will be hung at surface; the 9 5/8" x 13 3/8" annulus will be Arctic Packed. Drill 8' 1/2" hole to T.D. at 9630' TVD. Cement 7" liner to 500' inside 9 5/8" casing shoe with 420 cu. ft. Class G cement with 18% salt. Run 3 1/2" 9.35 L-80 A/Bmod. EUE 8rd IPC tubing with gas lift mandrels and a production packer assembly at 8347' TVD. A subsurface safety valve with dual control lines will be placed at 2100'. Displace tubing to diesel. Install and test Xmas tree. Suspend well for perforating subsequent to rig release. Details of proposed perforations to be submitted on Sundry Notice to follow. RECEIVEi) JAN 2 9 1982 Alaska Oil & Gas Cons. CoJrlmJssJorl A[]chorage 1:5, TRIPLE RAM 5000 PSI WP STAC~ DRILLING ,, J ANNULAR PREVENTER PIPE RAMS ,IL · BLIND RAMS 2" KILL LINE CHECK GATE GATE DRILLING SPOOL CHOKE LINE GATE HYDR. ASST. GATE PIPE RAMS 03 40 I0 20 30 ~ 40 ! i0 20 30 40 I ~ ~ .......... I , O:S ; I, 700'~ (Propo,ed): 1200' I A- 20 I o, I / WELLS II (~.4- OI - lO- SUMP PAD DETAIL I I~ SCALE: 1"=400' PORTION OF .m. I0 I~.11N.,R. 15..E.,U.M, SCALE: I"= I/2 MILE CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered to practice land surveying in the State of Alaska and that this plat represents o location survey of the wellpad shown and the wells thereon. This survey was made by me or under my supervision and oll dimensions and other details are correct. Bottom hole locations are furnished by others. Date ADDED ............ .~uRVE,~OR-, - ~ECE!VED JAN 2 Oil & Gas Cons. ,R?/~ I - 23, PLAT 3 OF $ PAD "A" EXTEN S ION LlOotl,d nO I I SurvIyed for SOHIO ALASKA PETROLEUM CO. ........ SUrvlYld bY ;i~r? F M. LINDSEY & ASSOC, LAND & HYDROGRAPHIC SURVEYORS 2502 Wilt Northern Lights Boulevord Box 4-08t An;hor~i .................. ......... A A-22 3989 A-22. 2841 A-14 5210 TT:t Scale 1" - 500' CHECK LIST EOR NEW WELL PERMITS Company LeaSe & Well No. IT~ APPROVE DATE /('2 thru thru 11) (4) Ca sg ~~ /-2~_~ 2- 1 ~2 thru 20) 1 1 1 1 (5) BOPE ~~ /~~ ('2i ~hru 24) · 3. 4. 5. 6. 7. 8. e 2 4. 5. 6. 17. 18. 19. 20. 21. 22. 23. 24. YES NO REMARKS Is the permit fee attached .......................................... Is well to be located in a defined pool ............................ Is well located proper distance from property line ................. Is well located proper distance from other wells .................... 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 administrative approval needed. ....... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... ~±11 cement tie in surface and inte'rmed±ate or production str±ngs ... ~±11 cement Cover all known product±ye hor±zons ..................... ~ill surface casing protect fresh water zones ....................... ~ill all casing give adequate safety in collapse, tens±on and burst. Is this well to be kicked off from an existing wellbore . ........... Is old wellbore abandonment procedure included on 10-~03 ............ Is adequate well bore separation proposed ..................... ~... Is a diverter system required .............. , .................... _ ~ Are necessary diagrams of diverter ~ BOP e~uipment attached . Does BOPE have sufficient pressure rating - Test t° ~LDz~° p~ig~~- Does the choke manifold comply w/API RP-53 (Feb.78) .................. ,,~ (6) Add: 25. Additional requirements ............ ................................. Additional Remarks: © ~z Geology: Enginge~ring: HWK __ LCS f~'-BEW~ WVA ~, J KT ~-~I~AD ~ JAL( ~t~TM re/01/13/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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 APPEN. DIX~ oo No 'special'effort has been made to chronologically organize this category of information. LIS TAPE VERIFICATION LISTING bVP 010 H01 ,,ERIFICATION LISTING PAGE ** REEL HEADER SERVICE NAME :SERVIC DATE :82/05124 ORIGIN : REEL NAME :REEL ID CONTINUATION # :01 PREVIOUS REEL COMMENTS :REEL COMMENTS ** TAPE HEADER ** SERVICE NAME :SERVIC DATE :82/05/24 ORIGIN I1070 TAPE NAME :65106 CONTINUATION # PREVIOUS TAPE COMMENTS :TAPE COMMENTS EOF ********** ** FILE HEADER ** FILE NAME :SERVIC.O01 SERVICE NAME : VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : ** INFORMATION RECORDS MNEM CONTENTS CN : WN : FN ~ RANG: TOWN: SECT: COUN: STAT: CTRY~ MNEM SOHIO A-22 (13-02-10-13) PRUDHOE BAY 11N 35 NORTH SLOPE ALASKA U,S,A. CONTENTS PRES: DILO01E ** RECORD TYPE 047 UNIT TYPE CATE SIZE CODE 000 000 005 065 000 000 018 065 000 000 012 065 000 000 004 065 000 000 004 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 006 065 UNIT TYPE CATE SIZE CODE 000 000 007 065 ) ) ) LVP OIO,HO! VERIFICATION LISTING PAGE ** RECORD TYPE 047 *~ RECORD TYPE 047 COMMENTS *~ SCHLUMBERGER ALASKA COMPUTING CENTER COMPANY = SOHIO ALASKA PETROLEUM COMPANY WELL FIELD = PRUDHOE BAY COUNTY = NORTH SLOPE BOROUGH STATE = ALASKA JOB NUMBER AT ACC RUN #1, DATE LOGG BOTTOM DEPTH TOP DEPTH CASING BIT SIZE TYPE FLUID DENSITY VISCOSITY : 10707,65106 ED: i MAY 82 = 12294 FT. = 11389 FT. = 9 5/8 IN. = 8 1/2 IN. = LIGNOSULFONATE = 9 3 LB/G = 3~.0 bVP 010,HOi V~RIFICATION LISTING PAGE PM = 9,5 FLUID bOSS = 6,0 C3 RM = 2.850 ~ 77.0 DF RMF = 2,870 ~ 77,0 DF RMC = 4,275 ~ 77.0X DF RM AT BHT = 1,113 ~ 205.X DF MATRIX LIMESTONE ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 I 66 1 $ 4 73 60 9 4 65 .liN 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API API API API FILE SIZE PROCESS SAMPLE REPR ID ORDER # LOG TYPE CLASS MOD NO. DEPT FT 0 0 0 0 0 4 SFbU DIL OHMS 7 0 0 0 0 4 IL~ DIL OHMS 7 0 0 0 0 4 ILD DIL OHMS 7 12 46 0 0 4 SP DIL MV 7 I 0 0 0 4 GR DIL GAPI 7 31 32 0 0 4 NPHI FDN PU 42 68 2 0 0 4 RHOB FDN G/C3 42 35 1 0 0 4 GR FDN GAPI 42 31 32 0 0 4 CALl FDN IN 42 28 3 0 0 4 DRHO FDN G/C3 42 44 0 0 0 4 NRAT FDN 42 42 1 0 0 4 NCNb FDN 42 34 92 0 0 4 FCNL FDN 42 34 93 0 0 4 DT BHC US/F 60 52 32 0 0 4 GR BHC GAPI 60 31 32 0 0 4 bEVEL CODE 0 ! 6B 0 I 6B 0 1 6B 0 I 68 0 1 68 0 1 6B 0 1 68 0 1 68 0 ! 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 6B ** DATA ** LVP DEPT SP GE NCNL DEPT SP NCNB DEPT NCNB DEPT SP NCNL 010.H01 VERIFICATION LISTING [2329.5000 SFLU -999,2500 GE 92.2500 CALI 3132.0000 FCN5 1230-0i~0002273 G~$FLU 98 2500 CALI 3202 0000 FCNL 12200 0000 SFLU -70:6875 GR 39,6563 CALI 4026,0000 FCNB 12100,0000 SFLU -94,4375 GR 30.~500 CALl 3506. 000 FCNL DEPT 12000,~000 SFLU SP -74, 375 GE GR 20,2187 CALI NCNB 3340.0000 FCN5 DEPT GR NCNb DEPT SP NCNB DEPT SP GR NCNL DEPT SP GR NCNB DEPT SP NCNB DEPT SP GR 1i900,0090 SFLU -62.93 5 GE 24,9844 CALI 3648,0000 FCNL 11800 0000 SFLU -76,5625 GR 18.0781 CALl 4704.0000 FCNL 11700.0000 SFLU -78.3125 GR 25 3594 CALI 3566'.0000 FCNL 11600.0000 SFLU -58.2813 GR 22'2031 CALI 3514,0000 FCNL 11500 0000 SFLU -0~9019 GR 73,2500 CALI 5684.0000 FCN5 11400.0000 SFLU 14.6328 GR ~00.1875 CALI -999.25O0 -999,2500 NPHI 4,5469 DEMO 1407,0000 DT 5.1562 IBM 91,9375 NPHI 6.0586 DEMO 1415.0000 DT 7,6523 IBM 39,6250 NPHI 8,5625 DEMO 1977.0000 DT 4,4297 27,4219 NPMI 8,4609 DEMO 1473.0000 DT 4.4180 ILM 21,1406 NPMI 8,4766 DRMO 1444.0000 DT 9,8984 26,0313 NPHI 8 9531 DRHO 1513:0000 DT 14,5625 IBM 18.6250 NPMI 8,3984 DEMO 2468.0000 DT 5.0820 IbM 26,0469 NPHI 9,3750 DRHO 1380.0000 DT 16.2031 IbM 23.2187 NPHI 8.9453 DRHO 1369.0000 DT 483.7500 ILM 68.9375 NPHI 9.6719 DEMO 4684.0000 DT 1.4209 IBM 106,9375 NPHI 10.8750 DRHO -999.2500 ILD 21.2402 EHOB 0.0107 NEAT -999,2500 GE 4.3359 ILD. 20.8984 RHOB 0,2051 NEAT 72.7500 GR 2,9570 ILD ,0005 NEAT 84.1875 GR 2,4063 19'1406 RHOB ~0,0156 NEAT 6.5625 GR :7o,o 3359 RHOB 0.0415 NRAT 91,0000 GR 4.3203 ILD 19,5313 RHOB 0,0337 NRAT 88.3750 GR 5,8047 ILD 12,1094 RHOB 0,0547 NEAT 70,3750 GR 1,9717 22,6074 RHOB 0,0156 NEAT 90.3750 GR 10,8281 ILD 22,5098 RMOB 0,0645 NEAT 94,3750 GR 59,3125 ILD 1.9531 RHOB 0,0889 NEAT 60.1875 GR 1.2031 37.4512 RHOB 0.3525 NEAT PAGE 4 -gg9 2500 I 7344 2 1797 -999 2500 4,0430 2'2031 2,2500 91.9375 ,8437 3652 39~ 0 2.3105 2.3945 1.5898 2,2383 2,3027 21.1406 3,9023 2.3008 2,3555 26,0313 5,0156 2,4082 1.8125 18,6250 1 7754 2i2578 2 5996 26,0469 13.7422 2,3164 2,5547 23.2187 55 0938 2',6934 375 1.1758 2 5605 3:6895 bVP OlO.MO1 VERIFICATION LISTING PAGE 5 NCNL 1584.0000 FCNL DEPT 11300 0000 SFLU SP -999,2500 GR GR 86,4375 CALI NCNL -999.2500 FCNL DEPT li200.0000 SFLU SP -999,2500 GR G~ 70,7500 CALI NCNL -999.2500 FCNL DEPT 11100.~000 SFLU SP '999, 500 GR GR 72,2500 CALI NCNL -999'2500 FCNL DEPT 11.000 0000 SFLU SP -999:2500 GR GR 55,0625 CALI NCNL -999,2500 FCNL DEPT 10900 0000 SFLU SP -999:2500 G~ GR 57,4688 CALI NCNL -999.2500 FCN5 DEPT 10800.0000 SFLU SP -999,2500 GR G~ 70.3750 CALI NCNL -999,2500 FCNL DEPT 10700,0000 SFLU SP -999,2500 GR GR 65,3750 CALl NCNL -999,2500 FCNL DEPT 1~600,0000 SFbU SP 999.2500 GR GR 71,9375 CALI NCNL -999.2500 FCNL DEPT 1~500.0000 SFLU SP 999.2500 GR GR 55,21~7 CALI NCNL -999,2500 FCNL DEPT 10400.0000 SFLU SP -999'2500 GR GR 39~2157 CALl NCNL -999.2500 FCN5 DEPT 10300.0000 SFLU SP -999,2500 GE 420,0000 DT -999,2500 -999.2500 NPHI -999,2500 DRHO -999.2500 DT '999.2500 NPH! :99 2500 DT -999 2500 ILM -999:2500 NPMI -999,2500 DEMO -999.2500 DT -999,2500 -999,2500 NPHI -999,2500 DRHO -999.2500 DT -999,2500 -999,2500 NPHI -999,2500 DEMO -999.2500 DT -999.2500 -999 2500 NPHI -999:2500 DRHO -999.2500 DT -999.2500 -999 2500 NPMI -999!2500 DRHO -999 2500 DT -999,2500 -999.2500 NPHI -999,2500 DRHO -999.2500 DT -999.2500 -999.2500 NPHI -999.2500 DRHO -999.2500 DT -999.2500 -999,2500 NPM! -999.2500 DRHO -999.2500 DT -999,2500 -999,2500 NPH! 102.0000 G:E 106.9375 :999,2500 ILD -999,2500 999. 2500 RHOB -999,2500 -999,2500 NEAT '999,2500 -999.2500 GR -999.2500 -999. 2500 I[~D -999. 2500 -999, ~500 RHOB -999,2500 -999.~500 NEAT -999,2500 -999.2500 -999.2S00 2999.2500 ILD .-999.2500 RHOB .,999,2500 999,2500 .999' 2500 NEAT -999,2500 999,2500 GE -999,2500 -999. 2500 ILD -999,2500 999,2500 RMOB '2999,2500 -'999.2500 NEAT -999,2500 -999,2500 GR -999. 2500 -999 2500 I[~D -999,2500 -999:2500 RHOB -999.2500 -999,2500 NEAT -999,2500 . 999,2500 GR -999,2500 -999,2500 ILD -999,2500 -999.2500 EHOB -999,2500 -999,2500 NEAT -999,2500 '999.2500 GR '999.2500 '~99. 2500 ILD '999::2500 ' 99.2500 RHOB '999 2500 '999.2500 NEAT '999 2500 '999.2500 GE -999 2500 '999. 2500 I[~D -999. 2500 '999. 2500 El'lOB '999. 2500 '999.2500 NEAT '999.2500 '999.2500 GR '999.2500 '999 2500 ILD -999 2500 '999:2500 RHOB '999:2500 '999.2500 NEAT '999:2500 '999.2500 G. -999 2500 -999.2500 RHOB 999 2500 -999. 2500 NEAT ~999:2500 LVP OR NCNb DEPT SP NCNb DEPT GR NCNb DEPT SP NCNb DEPT SP NCNb DEPT SP NCNb DEPT SP OR NCNb DEPT SP OR NCNb DEPT SP NCNb DEPT SP NCNb DEPT GR NCNb DEPT OIO,HO1 VERIFICATION 62,6250 '999.2500 lO2O°.OOOO '999.2500 . 60'2187 999,2500 1~100,0000 999.2500 60,5313 -999,2500 10000.0000 -999,2500 .i04.5000 999'2500 ~900.0000 999,2500 135.0000 -999.250O 9800,0000 ' 99,2500 ~06,7500 -999,2500 700,0000 ~999.2500 66.8750 -999,2500 ~600!0000 999 2500 83 6250 -999.2500 500 0000 94 0000 -999.2500 9400.0000 -999,2500 111.8750 -999.2500 9300.0000 -999.2500 86'9375 -999.2500 9200,0000 CALI FCNL SFLU CALI FCNL SFLU OR CAbI FCNL SFLU G~ CAbI SFLU GR CALI FCNb SFLU CALl FCNL SFLU GR CALI FCNb SFLU GR CALI FCNL SFLU CALI FCNL SFbU GR CALl FCNL GR CALI FCNL SFLU LISTING -999,2500 DRMO -999.2500 DT -999,2500 15)4 -999,2500 NPMI -999.2500 DEMO -999~2500 DT -.999.2500 IbM 999.2500 NPMI -999,2500 DRHO -999.2500 DT -999.2500 IbM :999,2500 NPHI 999.2500 DRHO '999,2500 DT ~999,2500 IbM 999.2500 NPHI -999,2500 DEMO -999,2500 DT -999,1500 IbM -999 500 DT -999,2500 IbM -999.2500 NPHI -999.2500 DRMO -999.2500 DT -999,2500 -999 2500 NPMI -999:2500 DEMO -999,2500 DT -999.2500 IbM -999.2500 NPH! -999,2500 DRHO . 999,2500 DT -999.2500 IbM '999,2500 NPHI -999,2500 DEMO -999,2500 DT -999.2500 IbM ~.i99!2500 NPHI 99 2500 DEMO 99 2500 DT -999,2500 IL~ -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 9 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -g99 .2500 .2500 .2500 ,2500 ,2500 ,2500 ,2500 ,2500 ,2500 ,2500 .2500 ,2500 .2500 .2500 .2500 .2500 ,2500 .2500 .2500 ,2500 ,2500 .2500 2500 :2500 .2500 .2500 .2500 .2500 .2500 .2500 :]500 500 ,2500 ,2500 ,2500 ,2500 .2500 .2500 .2500 ,2500 ,2500 .2500 ,2500 NEAT GR RHOB NRAT GR RHOB NRAT RHOB NRAT GR RHOB NRAT ILD RMOB NRAT GR RHOB NRAT GR IbD RMOB NRAT GR RHOB NRAT GR RHOB NRAT GR ILD RMOB NRAT GR IbD PAGE '999,2500 '999.2500 -999,2500 '999,2500 '999,2500 '999.2500 '999,2500 '999, O0 '999.2500 -999,2500 -999 500 -:999,2500 ~999,2500 999.2500 -999,2500 -999,2500 -999 2500 -999i2500 -999 2500 -999 2500 -999.2500 -999,2500 2500 -999.2500 -999 2500 -999: 9oo -999.2500 -999 2500 -999:2500 -999 2500 -999;2500 -999,2500 -999,2500 -999.2500 -999.2500 ;999,2500 999.2500 -999.2500 -999.2500 -999,2500 bVP OlO.HOl VERIFICATION LISTING PAGE 7 NCNb DEPT SP GR NCNb DEPT GR NCNb DEPT SP NCNL DEPT NCNb DEPT SP NCNb DEPT NCNb DEPT SP NCNb DEPT $P NCNL DEPT $P GR NCNb DEPT SP GR NCNb -999.2500 GE 56.4375 CALl -999.2500 FCNL ~99,2500 NPHI 99,2500 DRHO -999,2500 DT 9100 0000 SFLU -999 2500 GE 47 7500 CALI -999 2500 FCNb -999,2500 IbM -999.2500 NPHI -999,2500 DRHO -999.2500 DT 0000000 SFLU 999:2500 GR 32,4063 CALI -999,2500 FCNL -999,2500 -999,2500 NPHI -999,2500 DRHO -999,2500 DT 8900.0000 $FLU -999,2500 GR 46,9687 CA5I -999;2500 FCNL -999.2500 -999,2500 NPHI -999,2500 DRHO -999,2500 DT 8800.0000 SFLU -999,2500 GR 55,4688 CALl -999.2500 FCNb -999,2500 I5~ -99~,2500 NPHI -99 .2500 DEHO -999.2500 DT 87O0 0000 SFLU -999i2500 GR 53 0625 CALI -999 2500 FCNL -999,2500 -999,2500 NPHX -999,2500 DRHO -999,2500 DT 8600.0000 SFLU -999 2500 GR 47",0938 CALI -999,2500 FCNL -999 2500 IbM -999i2500 NPHI -999 2500 DRHO -999,2500 DT 500.0000 SFLU ~999.2500 GR 56,5000 CALl -999.2500 FCNL -999 2500 -999:2500 NPH! -999 2500 DEMO -999:2500 DT 8400.0000 SFLU -999.2500 GE 50.2187 CALl -999.2500 FCNL -999.2500 -999,2500 NPHI 999 2500 DRHO :999: 2500 DT 8300.0000 SFLU 999.2500 G~ 41.8125 CALl 999.2500 FCNL -999,2500 ILM -999 2500 NPHI -999!2500 DRHO -999 2500 DT 8200.0000 SFLU -999 2500 GR 46:1562 CALl -999,2500 FCNL -999 2500 IbM -999i2500 NPHI -999 2500 DEHO -999,2500 DT -999,2500 RHOB -999.2500 NEAT -999.2500 GR -999,~500 I~P '999, 500 RHOB -999,:~500 NEAT -999. 500 GR -999 -999 -999 -999 2500 ILD 2500 RHOB 2500 NEAT ,2500 GR -999,2500 -999,2500 RHOB -999 2500 NRAT -999:2500 GR -999.2500 -999,2500 RHOB -999,2500 NEAT -999,2500 GR -999.2500 ILD -999.2500 EHOB -999 2500 NRAT -999:2500 GR -999.2500 -999,2500 RHOB -999,2500 NEAT '999,2500 GE '999.2500 ILD '999.2500 RHOB '999.2500 NRAT -999,2500 GR -999.2500 -999 2500 RHOB -999:2500 NRAT -999.2500 GR -999 2500 -999:2500 RHOB -999 2500 NEAT -999:2500 GR -999.2500 IbD -999.2500 RHOB -999.2500 NEAT -999.2500 GR '999,2500 '999,2500 '999.2500 '9:99,2500 '999.2500 '999,2500 -999.2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999:2500 -9.99,2500 '999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999 2500 '999::i500 -999 500 -999 500 -999.2500 -999 2500 -999!2500 -999 2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 :999 2500 9 e:2 oo -999,2500 999 2500 :999:2500 :999.2500 999.2500 -999.2500 -999,2500 -999,2500 -999,2500 bVP DEPT SP GR NCNb DEPT GR NCNb DEPT SP NCNb DEPT SP NCNb DEPT SP GR NCNL DEPT SP NCNb DEPT SP GR NCNL DEPT NCNb DEPT SP NCNb DEPT SP NCNb DEPT SP NCNb OiO,HO1 VMRIFICATION 8100,0000 SFLU -999,2500 GR 56.9062 CAbI -999.2500 FCNL 8000,0000 SFLU -999,2500 GR 60.5313 CALI -999.2500 FCNL 7900,0000 SrbU -999,2500 GR 57,3125 CALI -999.2500 FCNL 7800.0000 SFLU -999 2500 GR 55!0000 CALI -999 2500 FCN5 7700,~000 SFLU -999, 500 GR 56,6250 CALI -999.2500 FCNL 7600,0000 SFLU -999.2500 GR 50,0625 CALI -999,2500 FCNb !500 0000 SFLU 999:2500 GR 43,5938 CALI -999.2500 FCNL 7400.0000 SFLU -999.2500 GR 40.4063 CALI -999.2500 FCNb l~O0 0000 SFbU .99:2500 GR 33.9062 CAbI -999.2500 FCNL 7200.0000 SFLU -999.2500 GR 42,8750 CALI -999.2500 FCNL 7100.0000 SFLU -999.2500 GR 46,8125 CALI -999.2500 FCNL LISTING -.999 2500 IL~ 999".2500 NP}~I -999.2500 DRHO -999.2500 DT 999,2500 IbM 999,2500 NPHI 999.2500 DRHO -999.2500 DT -999 2500 IbM -999,2500 NPHI -999,2500 DRHO -999.2500 DT -999.25OO -999,2500 NPHI '999,2500 DRHO -999,2500 DT -999 2500 IbM -999' ,2500 NPHI '999,2500 DRHO -999.2500 DT ~999i2500 IbM 999 2500 NPHI -999 2500 DRHO -999,2500 DT -999,2500 IbM -999.2500 NPHI -999,2500 DRHO -999.2500 DT -999,2500 IbM -999,2500 NPHI -999.2500 DRHO -999.2500 DT -999,2500 IbM -999.2500 NPHI -999.2500 DRHO -999,2500 DT -999,2500 -999,2500 NPHI -999.2500 -999.2500 DT -999.2500 IbM -999.2500 ~PHI -999,2500 DRHO -999.2500 DT -.99~,2500 ,2500 RHO8 -999,2500 NEAT -999.2500 GR -999.2500 IbD -999.2500 RHOB -999.2500 NRAT -999,2500 GR -999,2500 -999.2500 RHOB -999,2500 N~AT -999,2500 GR -999.2500 IbD -999,2500 RMOB -999.2500 NRAT -999.2500 GR :~99,2500 99,2500 RHOB -99~,2500 NEAT -99 .2500 GR -999 2500 -999:2500 RHOB -999.2500 NRAT -999,2500 GR -999,2500 -999,2500 RHOB -999,2500 NEAT -999,2500 GR -999.2500 IbD -999.2500 RHOB =999,2500 NEAT -999,2500 GR -999.2500 ILD -999.2500 RHOB -999,2500 NRAT -999.2500 GR -999.2500 -999.2500 RHOB -999,2500 NEAT -999.2500 GR -999 2500 IbD -999:2500 RHOB -999,2500 NRAT -999.2500 GR PAGE -999,2500 -999,2500 -999.2500 -999.2500 -999,2500 -999,2500 -999,~500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999,250:0 .-999,2500 999,2500 '999,~500 '999, 500 '999,2500 '999,2500 '999 2500 '99912500 -999 2500 -999 2500 -ggg 2500 .9 9: soo -999,2500 -999,2500 -999.2500 -999 2500 -999".2500 -999,2500 -99 2500 -99 2500 -999.2500 2999.2500 999.2500 =999.2500 -999 2500 -999 2500 -999:2500 LVP OIO.HOI VERIFICATION LISTING PAGE 9 DEPT 7000,0000 SFLU -999.2500 ~ ~.~oo c~ -~.~oo ~ ~oo.oooo ~ .~.~oo ~c.~.~.~oo ~¢.~-~.~oo ,oo.oooo G~ 22,5469 CAbI 999,2500 DRHO NCNL 999,2500 FCNL 999,2500 DT ~ ~oo.oooo s~ .,,,.~oo ~ ~oo.oooo ~ -~ ~oo DEPT 6500,0000 SFLU -999 2500 SP -999,2500 GR -999:2500 NPMI GR 41,4375 CALI -999: 2500 DRHO NCNL -999.2500 FCNL -999 2500 DT DEPT 6400 0000 SFLU -999,2500 SP -999~2500 GR -999.2500 NPHI ~c.~ -~.~oo fC.~ -~.~oo DEPT 6300.0000 SFLU -999.2500 SP -999,2500 GR -999,2500 NPHI ~c~ -~.~oo ~c~ -~,~oo ~ ~oo.oooo s~u -~.~soo GR 28:4844 CALI -999,2500 DRHO NCNL -999,2500 FCN5 -999,2500 DT DEPT 6100.0000 SFLU -999 2500 IbM SP -999,2500 GR -999:2500 NPH! GR 39.0000 CALI -999,2500 DRHD NCNL -999.2500 FCNL -999.2500 DT DEPT 6000.0000 SFLU -999 2500 SP -999,2500 GR -999:2500 NPH! GP 42.8750 CALI -999,2500 DRHO -999.2500 ILD -999,2500 RHOB -999.2500 NRAT -999.2500 -999,2500 -999.2500 RHOB -999,2500 NRAT -999,2500 GR -999,2500 -999,~500 RHOB -999, 500 NRAT -999,2500 GR -999,2500 -~.~5oo -~,:~oo -999 500 GR -999.2500 :999,2500 RHOB 999.2500 NRAT -999,2500 GR -999,~500 -999. 500 RHOB -999.2500 NRAT -999,2500 GR -999,2500 ILD -999,2500 RHOB -999,2500 NRAT -999,2500 GR -999,2500 -999,2500 RHOB -999,2500 NRAT -999,2500 GR -999.2500 -999 2500 RHOB -999:2500 NRAT -999,2500 GR -999.2500 -999,2500 RHOB -999,2500 NRAT -999,2500 GR -999,2500 ILD -999,2500 RHOB -999,2500 NRAT ) -999.2500 2999,2500 ~999,2500 999,2500 -999 2500 -999:2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 ~99.9,2500 999,2500 -999,2500 -999.2500 -999 2500 -999!2500 -999 2500 -999 2500 -999 2500 -999!2500 -999 2500 -999 2500 -999,2500 -999,2500 -999,2500 -999,2500 -999 2500 -999i2500 -999 2500 -999,2500 999,2500 99,2500 99,2500 -999,2500 -999 2500 -999:2500 -999,2500 -999,2500 :999,2500 999,2500 -999,2500 LV~ NCNL DEPT SP GR NCNL DEPT NCNb DEPT GR NCNb DEPT SP GR NCNb DEPT SP GR NCNb D£PT SP NCNb DEPT SP ~R NCNL D£PT SP gR NCNb DEPT GR NCNb DEPT SP GR NCNb DEPT SP 010.HO1 VERIFICATION LISTING -999.2500 FCNL -999.2500 DT ~00.0000 SFLU 99.2500 GR 23.3906 CALI -999.2500 FCNL -999,2500 IbM -999.2500 NPHI -999,2500 DRHO -999.2500 DT 5800.0000 SFLU -999.2500 GR 29.4844 CALI -999.2500 FCNL -999.2500 ILM -gg9 2500 NPHI -999i2500 DRHO -999 2500 DT 5700,0000 SFLU -999,2500 GR 45,~938 CALI -999. 500 FCNL -999 2500 ILM -999,2500 NPHI -999,2500 DRHO -999.2500 DT 5600.0000 SFLU 25 GR -999.2500 FCNL -999,2500 ILM -99 2500 DRHO -999.2500 DT 5500 0000 SFLU '999' ,2500 GR 46,2500 CALI -999,2500 FCNL -999 2500 ILM -99912500 NPHI -999 2500 DRHO -999 2500 DT 5400.0000 SFLU -999 2500 GR 27i6250 CALI -999 2500 f'CNL -999 2500 IL~ -999~2500 NPHI -999.2500 DRHO -999,2500 DT 5300 0000 SFLU -999!2500 GR 26 2187 CALI -999 2500 FCNL -ggg 2500 -999~2500 NPHI -999 2500 DRHD -999:2500 DT 5200.0000 SFLU -999.2500 GR 40.7813 CALl -999.2500 FCNL -999.2500 -999 2500 NPHI -999:2500 DRHO -999.2500 DT 5100.0000 SFLU -999.2500 GR 53.0938 CALI -999.2500 FCNL -999.2500 IBM -999,2500 NPH! -999,2500 DRHO -999.2500 DT 5000.0000 SFLU -999.2500 GR 45.0938 CALI -999.2500 FCNL 999 2500 ILM -999 2500 DRHO -999:2500 DT 4900.0000 SFLU -999.2500 GR -999.2500 ILM -999.2500 NPH! -999,2500 GR -999,2500 ILD -999,2500 RHOB -999,2500 NRAT -999,2500 GR -999.2500 ILD -9999 2500 RHOB -99 ".2500 NRAT -999,2500 GR -999,2500 ILD -999.2500 RHOB '999,2500 NRAT -999,2500 GR -999.2500 ILD -999 25oo -999:2500 NRAT -999,2500 GR -999 2500 ILD -999:2500 RHOB -999,2500 NRAT -999,2500 GR -999,2500 ILD -999.2500 RHOB -999,2500 NRAT -999,2500 GR -999.2500 ILD -999.2500 RHOB -999,2500 NRAT -999,2500 GR -999.2500 ILD -999.2500 RHOB -999,2500 NRAT -999.2500 GR -999,2500 -ggg,2500 RHOB -999.2500 NRAT -999,2500 GR -999,2500 ILD -999.2500 RHOB -999.2500 NRAT -999.2500 GR -999.2500 ILD -999,2500 RHOB PAGE 10 -999,2500 -999,2500 -999.2500 -999,2500 -999.2500 -999.2500 -999,2500 -999.2500 -999,2500 -999 2500 -999 2500 -999 2500 -999 2500 -999,2500 -999,2500 -999,2500 -999.2500 -.999 500 999:2~500 -999 2500 -999~2500 -999.2500 -999.2500 .-999 2500 999:2500 -999 2500 -999i2500 -999 2500 -999,2500 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -.999 2500 999:2500 -999,2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 bVP OlO,M01 VERIFICATION LISTING PAGE DEPT 4800.0000 8FLU SP -999,2500 GR GR 24,7344 CALI NCNb -999.2500 FCNb DEPT 4700.0000 SFbU SP -999,2500 ~GR GR 45,5938 CALI NCNb -99912500 FCNL DEPT .4600 0000 SFLU SP 999:2500 GR GR 47.8437 CAbI NCNb -999,2500 FCNb DEPT .4500 0000 SFbU SP 999: 2500 GR GR 30.4375 CAbI NCNL -999,2500 FCNL DEPT 4400,0000 8FLU SP -999.2500 GR GR 44 4375 CALI NCNb -999:2500 FCNL DEPT 4300.0000 SFLU SP -999,2500 GR GR 15,8906 CALl NCNb -999,2500 FCNL DEPT 4200,0000 SFLU SP -999 2500 GR NCNb -999.2500 FCNb DEPT .4100.0000 SFLU SP 999,2500 GR GR 47.0625 CALl -999,2500 DRNO -999,2500 DT -999,2500 IbM 99,2500 NPMI -999"2500 DT -999,2500 IbM -999,2500 NPHI -999,2500 DRMO -999,2500 DT -999 500 NPHI -999'2500 DRHO -999,2500 DT -999 2500 -999 2500 -999 2500 -999 2.500 IbM DRHO DT -999,2500 IbM -999 2500 NPHI -999i2500 DRHO -999 2500 DT .!99.2500 99,2500 NPHI 99.2500 DRHO -999.2500 DT -999.2500 IbM ~999 2500 NPHI 999:2500 DRHO -999,2500 DT -999,2500 IbM -999,2500 NPHI -999,2500 DRHO -999,2500 DT -999.2500 IbM -999.2500 NPHI -999.2500 DRHO -999.2500 DT -999,2500 IbM -999.2500 NPHI -.999 2500 DRHO 999:2500 DT -999,2500 IbM -999.2500 NRAT -999.2500 GR -999.2500 IbD -999.2500 -999.2500 NRAT -999.2500 GR -999,2500 -999,2500 RHOB -999,2500 NRAT -999.2500 GR '999,2500 '999,2500 RHOB -999.2500 NRAT -999,2500 GR -999,2500 -999 500 GE '999,2500 ILD -999,2500 RMOB '999,2500 NRAT -999.2500 GR -999,2500 -999,2500 RHOB -999,2500 NRAT -999,2500 GR -999,2500 -999,2500 RHOB -999.2500 NRAT -999,2500 GR -999,2500 -999,2500 RHOB '999,2500 NRAT -999.2500 GR -999.2500 -999.2500 RHOB -999.2500 NRAT -999.2500 GR -999,2500 -999.2500 RHOB -999.2500 NRAT -999.2500 GR -999.2500 ILD -999,2500 -999.2500 :999.2500 999,2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999,2500 -999 2500 -999:2500 -999,2500 999 2500 999 2500 -999,2500 -999,2500 -999,2500 -999,9-500 -999.2500 -999,2500 -999,2500 -999,2500 2 oo 9:2500 -999,2500 -999,2500 -999,2500 -999,2500 -999 2500 -999:2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 LVP SP GR NCNL DEFT SP NCNb DEFT SP NCNb DEFT SF GE NCNb DEFT SP NCNb DEFT SP NCNb OlO.HOl VERIFICATION -999.2500 GE 50.9062 CALI -999.2500 FCNL 3700 0000 SFLU -999.2500 GR 36,0938 CALI -999.2500 FCNL 3600 0000 SFLU -999:2500 GR 40,7813 CALI -999.2500 FCNL 3500,0000 SFLU -999,2500 GR 36,7500 CAbI -999.2500 FCNL 3400.0000 SFLU -999.2500 GR 36.7500 CALI -999.2500 FCNL 3300 0000 SFLU -999,2500 GR 45.3750 CAbI -999.2500 FCNL LISTING -999 -999 -999 -999 -999 -999 -999 999 999 999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 DEFT .)200.0000 SFLU -999 $P 999: 2500 GE -999 GR 30 4063 SAki -999 NCNb -999.2500 FCNb -999 i00 0000 SFLU 45 6563 CAbI -999~2500 FCNL DEFT SP GE NCNL OEPT SP GR NCNb DEFT SP GR NCNb DEFT SP NCNb 3000.0000 SFLU -999.2500 GR 36.2187 CALl -999.2500 FCNL 2900.0000 SFLU -999.2500 GR 42.5000 CALI -999.2500 FCNL 800 0000 SFbU -2999 !2500 GR 34 0938 CALI -999.2500 FCNL -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 ,2500 ,2500 ,2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 2500 2500 2500 2500 ,2500 .2500 2500 :2500 2500 :2500 :2500 2500 2500 500 .2500 2500 : soo 5oo : 5oo .2500 .2500 .2500 .2500 .2500 .2500 ,2500 .2500 .2500 .2500 .2500 .2500 NPHI DRHO DT NPHI DRHO DT IbM NPHI DRHO DT IbM NPHI DRHO DT IbM NPHI DRHO DT NPHI DRHO DT IbM NPHI DEMO DT IbM NPHI DRHO DT IbM NPHI DRHO DT IbM DRHO DT NPHI DRHO DT -999.2500 RHOB -999.2500 NEAT -999.2500 GR -999.2500 IbD -999.2500 RHOB -999,)500 NEAT -999, 500 GE -999.2500 -999.2500 RHOB -999.2500 NEAT -999.2500 GR -999.2500 ILD -999.2500 RHOB -9'99,2500 NEAT '999.2500 GR -9'99.2500 ILD 999,2500 EHOB 999,2500 NRAT 999,2500 GE -999 2500 -99912500 EHOB -999,2500 NEAT -999.2500 GE -999 2500 ILD -999i2500 RHOB -999 2500 NEAT -999.2500 GR -999 2500 -999:2500 EHO~ -999.2500 NEAT -999.2500 GR -999.2500 ILD -999.2500 RHOB -999.2500 NRAT -999.2500 GR -999.2500 lbD -999.2500 RHOB ~999 2500 NEAT 999:2500 GR -999.2500 IbD -999.2500 RHOB -999.2500 NRAT -999.2500 GR PAGE 12 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999,2500 -999.2500 m999,2500 '.999.2500 1999.2500 999.2500 -999,2500 -999.2500 -999,2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999 22500 -999: 500 -999 500 -999,2500 -999.2500 -999,2500 -999,2500 -999,2500 -.999,2500 999,2500 -999,2500 -999.2500 .-999.2500 999.2500 -999.2500 -999 2500 -999i2500 -999 2500 -999.2500 LVP OIO.HOI VERIFICATION LISTING DEPT !700.0000 SFLU SP 999,2500 GR GR 27.2656 CAbI NCNb 999.2500 FCNL -999,2500 IbM -999,2500 NPHI -999.2500 DRHO -999.2500 DT DEPT 260~,0000 SFLU SP -99 .2500 GR GR 13,6484 CALI NCNb -999.2500 FCNL -999 ~500 -999 SOO DT DEPT 2596 5000 SFLU SP -999:2500 GR GR 13,3359 CALI NCNL -999.2500 FCNL -999.2500 IbM -999'2500 NPHI -999,2500 DRHO -999,2500 DT ** FILE TRAILER FILE NAME :SERVIC.O01 SERVICE NAME VERSION # DATE : MAXIMUM LENGTH : 1024 FILE TYPE NEXT FILE NAME -999.2500 ILO -999.2500 RHOB -999,2500 NRAT -999.2500 GR -999.2500 ILO -999.2500 RHOB -999.2500 NRAT -999.2500 GR -999,2500 -999.2500 RHOB -999,2500 NRAT -999"2500 GR PAGE 13 .999.2500 ,.999.2500 999,2500 -999,2500 ~999 2500 999: 2500 '999,~500 '999. 500 '999,2500 '999,2500 '999.2500 '999.2500 ** TAPE TRAILER ** SERVICE NAME :SERVIC DATE :82/05/24 ORIGIN :1070 TAPE NAME 165106 CONTINUATION # :01 NEXT TAPE NAME : COMMENTS :TAPE COMMENTS ** REEL TRAILER ** SERVICE NAME :SERVIC DATE :82/05/24 ORIGIN : REEL NAME :REEL ID CONTINUATION # 101 NEXT REEL NAME : COMMENTS :REEL COM~ENT$ .)