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198-254
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Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 ~~~`~, `~~~~ ~ ~~~ Mr. Tom Maunder C~ ~ ~ ~"f Alaska Oil and Gas Conservation Commission ~ ~ /'., 333 West 7t" Avenue ~' ~ ~ lV Anchorage, Alaska 99501 ~' Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 f)atP~ 01/05/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-01 B 2042570 50029206960200 NA Sealed NA 15-02B 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-048 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-O6A 1982540 50029207420100 NA 6.7 NA 40.8 11R/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-08C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11111 /2009 15-10A 1880850 50029205010100 NA Sealed NA 15-11B 2041460 50029206530200 NA Sealed NA 15-128 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10!7/2009 15-25B 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-26B 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-29B 2090380 50029222590200 NA 0.1 NA 1.7 11!10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-316 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-33B 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-36B 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-37B 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-418 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-42B 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-45B 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11 /9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-486 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-496 2090640 50029226510200 NA 7.3 NA 51.0 11!8/2009 f STATE OF ALASKA 0 6 ALASKA* AND GAS CONSERVATION COMMIS. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other ;El Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re -enter Suspended Well f 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development C Exploratory r 198 -2540 3. Address: P.O. Box 196612 S tratigraphic Se � 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20742 -01 -00 7. KB Elevation (ft): 9. Well Name and Number: 63 KB - PBU 15 -06A ' 8. Property Designation: 10. Field /Pool(s): - ADLO- 028306 ' PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11288 ' feet Plugs (measured) None true vertical 8866.23 - feet Junk (measured) None Effective Depth measured 11241 feet true vertical 8863 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface - 110' Surface - 110' 1490 470 Surface 2597' 13 -3/8" 72# L -80 Surface - 2597' Surface - 2597' 4930 2670 Intermediate 8835' 9 -5/8" 47# L -80 Surface - 8835' Surface - 8210' 6870 4760 Liner 687' 7" 29# L -80 8535' - 9222' 7937' - 8563' 8160 7020 Tieback Liner 4255' 7X4 -1/2" 12.6# 4697' - 9222' 4800' - 8563' 8160 7020 Liner 2816' 2 -3/8" 4.43# L -80 8457' - 11273' 7866' - 8865' 11200 11780 Perforation depth: Measured depth: 9475 - 9500 9500 - 9525 9800 - 10270 10330 - 11239 True Vertical depth: 8790 - 8804 8804 - 8816 8844 - 8836 8831 - 8862 SS 4 "1 Tubing: (size, grade, and measured depth) 3 -1/2" 9.3# L -80 SURFACE - 8502' 7 "X3 -1/2" BAKER FB -1 8412' Packers and SSSV (type and measured depth) 7 "X3 -1/2" BAKER S -3 8311' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): t p� ((�� AiNgtelED MAR 08 LU [ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 422 24065 6 0 433 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory E Development Service r Daily Report of Well Operations X 16. Well Status after proposed work: Oil 14 Gas r WAG r GINJ r WINJ r WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564 -4944 Date 10/2/2007 Form 10 -404 Revised 04/2006 0 R 1 G I N A L t \ ,,,, Submit Original Only a . • 15 -06A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 9/2/2007CTU #9 w/1.5" CT. MIRU Drift coil w /1" ball, recover ball and perform BOP test. Have leaking swab and master valve, service with "Claire 501 ". POP off well and cap tree to resolve bonnet leak on "closed" hydraulic side of pipe rams. Fixed leaking 3" bull plug that was threaded into the chemical injection ring flange on the front of the flow cross. Swap out choke skid due to faulty block valves. Re- install BOPS on the well, function test pipe rams and re pressure test all surface lines. *'' Continued on 09/03/07 WSR * ** 9/2/2007, Blind leak) Repaired Blind flange leak on Companion side of Flowcross ,Redress nipple in blind flange, re -taped with Telfon and tested to 4,000 psi. 9/3/2007CTU #9 w/1.50 CT. * ** Continued from 09/02/07 WSR ' MU BOT 1.69" OD MHA and SLB memory GR /CCL with max OD of 1.75 ". RIH to 9,650' and log up to 8,800' at 60fpm painting a flag at 9,425'. POOH. Have good data. Make ( -6') correction to tie into 21- Jun -07 SLB MCNL. MU SLB 1.56" OD x 25' Perf Gun #1, knock down WHP and RIH. Correct to top shot at flag and perforate from 9500' to 9525' and =POOH. All shots fired. MU SLB 1.56" OD x 25' Perf Gun #2, knock down WHP and RIH. Correct to top shot at flag and perforate 9475' to 9500', never saw the first firing ball (1/2" aluminum) land after pumping coil volume plus. Dropped a second (1/2" steel) firing ball, saw it go on seat but the circ pressure never broke back to indicate the firing head shifted. POOH to inspect guns and firing head. *'' Continued on 09/04/07 WSR. 9/4/2007 CTU #9 w /1.50 CT. * ** Continued from 09/03/07 WSR" POOH with perf gun #2 to inspect firing head and investigate why there was no drop in circ pressure when ball went on seat. At surface, pop off and confirm that the perf gun HAS fired. Break down gun and firing head and only recovered "ONE" of the two firing balls we [dropped. Breakdown surface lines, pump a 1.00" OD ball around to confirm the 1/2" `aluminum ball is not in the CT. Notify pad operator of well status and RD. * ** JOB COMPLETE * ** FLUIDS PUMPED BBLS 20 1°/0 KCL w/0.6% SAFE LUBE 10 50/50 METH WATER 30 TOTAL Page 1 of l • • Maunder, Thoma (DOA) Thomas E From: Preble, Gary B (SAIC) [Gary.Preble @bp.com] Sent: Wednesday, October 03, 2007 1:27 PM To: Maunder, Thomas E (DOA) Subject: RE: DS 15 -06A (198 -254) Tom, I am resubmitting a 10-404 for 15 -06A (198 -254). It contains the correct perfs that I omitted on the previous submittal. Thanks Gary Preble Petroleum Data Management Engineer SAIC 907 -564 -4944 preb /egb'bp. com From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, September 24, 2007 3:26 PM To: Preble, Gary B (SAIC) Subject: DS 15 -06A (198- 254) Gary, I know you are gone right now, but this appears to be another one of those wells where all the information is not listed on the 404. Again, the entire perforated interval is not listed. The new perfs are listed, but the existing perfs from 9800 —10270 and 10330 —11239 are not listed. I wondered if the old perfs might have been isolated with a BP, but it was removed during the workover at the beginning of May 2006. It would appear that a new 404 is needed. Call me back when you return. Tom Maunder, PE AOGCC 10/16/2007 STATE OF ALASKA , LASKA . --' IV pr, ALASKA AND GAS CONSERVATION COMMISS1 -_.'1 REPORT OF SUNDRY WELL OPERATIONS 200;; 1. Operations Abandon bias Repair Well ❑ Plug Perforations ❑ Stimulate & Gag Performed: Alter Casing ❑ Pull Tubing Perforate New Pool Waiver Time Extension Anchora Om S4 Change Approved Program ❑ Operat. Shutdown❑ Perforate 0 -- Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory r 198- 2540: 3. Address: P.O. Box 196612 Stratigraphic r Service r 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 20742 -01 -00 7. KB Elevation (ft): 9. Well Name and Number: 63 KB PBU 15 -06A 8. Property Designation: 10. Field/Pool(s): ADLO- 028306 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11288 feet Plugs (measured) None true vertical 8866.23 - feet Junk (measured) None Effective Depth measured 11241 feet true vertical 8863 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface - 110' Surface - 110' 1490 470 Surface 2597' 13 -3/8" 72# L -80 Surface - 2597' Surface - 2597' 4930 2670 Intermediate 8835' 9 -5/8" 47# L -80 Surface - 8835' Surface - 8210' 6870 4760 Liner 687' 7" 29# L -80 8535' - 9222' 7937' - 8563' 8160 7020 Tieback Liner 4255' 7X4 -1/2" 12.6# 4697' - 9222' 4800' - 8563' 8160 7020 Liner 2816' 2 -3/8" 4.43# L -80 8457' - 11273' 7866' - 8865' 11200 11780 Perforation depth: Measured depth: 9475 - 9500 9500 - 9525 True Vertical depth: 8790 - 8804 8804 - 8816 Tubing: (size, grade, and measured depth) 3 -1/2" 9.3# L -80 SURFACE - 8502' 7 "X3 -1/2" BAKER FB -1 8412' Packers and SSSV (type and measured depth) 7 "X3 -1/2" BAKER S -3 8311' 0 0 0 1LACc£ 0 0 � 0 12. Stimulation or cement squeeze summary: p€' ri-- Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ' q C5 i 13 Representative Daily Average rroaucnon or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 422 24065 6 0 433 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory r Development Service r Daily Report of Well Operations X 16. Well Status after proposed work: Oil 1 Gas r WAG r GINJ r WINJ r WDSPL r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre Ai / Title Data Management Engineer Signature �% Z Phone 564 -4944 Date 9/5/2007 Form 10 -404 Revi ed 04/20011A 1 G 1 N A L Submit ' i �ly , • • 15 -06A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIYI1 ATE SUMMARY 9/2/2007; CTU #9 w/1.5" CT. MIRU Drift coil w/1" ball, recover ball and perform BOP test. Have leaking swab and master valve, service with "Claire 501". POP off well and 'cap tree to resolve bonnet leak on "closed" hydraulic side of pipe rams. Fixed leaking 3" bull plug that was threaded into the chemical injection ring flange on the front of the flow cross. Swap out choke skid due to faulty block valves. Re- install BOPS on the well, function test pipe rams and re pressure test all surface lines. * ** Continued on 09/03/07 WSR * ** 9/2/2007; ... e . _ .. . (Companion Blind leak) Repaired Blind flange leak k on Companion side of Flowcross Redress nipple in blind flange, re -taped with Telfon and tested to 4,000 psi. 9/3/20071 CTU #9 w/1.50" CT. * ** Continued from 09/02/07 WSR * *" MU BOT 1.69" OD MHA and SLB memory GR /CCL with max OD of 1.75 ". RIH to 9,650' and log up to 8,800' at 60fpm painting a flag at 9,425'. POOH. Have good data. Make ( -6') correction to `tie into 21- Jun -07 SLB MCNL. MU SLB 1.56" OD x 25' Perf Gun #1, knock down WHP and RIH. Correct to top shot at flag and perforate from 9500' to 9525' and POOH. All shots fired. MU SLB 1.56" OD x 25' Perf Gun #2, knock down WHP and RIH. Correct to top shot at flag and perforate 9475' to 9500', never saw the first firing ball (1/2" aluminum) land after pumping coil volume plus. Dropped a second (1/2" steel) firing ball, saw it go on seat but the circ pressure never broke back to indicate the firing head shifted. POOH to inspect guns and firing head. * ** Continued on 09/04/07 WSR. 9/4/2007 #9 w/1.50" CT. * ** Continued from 09/03/07 WSR * ** POOH with perf gun #2 to inspect firing head and investigate why there was no drop in circ pressure when ball went on seat. At surface, pop off and confirm that the pert gun HAS fired. Break down gun and firing head and only recovered "ONE" of the two firing balls we dropped. Breakdown surface lines, pump a 1.00" OD ball around to confirm the 1/2" :aluminum ball is not in the CT. Notify pad operator of well status and RD. * ** JOB COMPLETE * ** FLUIDS PUMPED BBLS 20 1`)/0 KCL w/0.6% SAFE LUBE 10 50/50 METH WATER 30 TOTAL 09/28/07 ~~i~tUm~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh !! 1 nn r1n~n~ini:nn NO. 4440 Company: State of Alaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n..~., o~ n_~_~ nn 15-06A 11661158 MCNL fs C 06/21/07 1 F-26B 11216200 MCNL >t[ v ~ O6/06/06 1 P2-11A 11285926 MCNL ~ 04/19/06 1 1 C-31B 11745223 MCNL -L/ 05/31/07 1 1 E-03A 11628773 MCNL ~ •C/ 05!09/07 1 1 K-12A 11745224 MCNL p _ ~ 06/02/07 1 1 18-106 11485771 MCNL '~ j 4/`}(0 11/08/06 1 1 C-086 11209599 MCNL -Lj (~ j ~$L 04/22/06 1 1 D-30B 11628774 MCNL - L '~ 05/10/07 1 1 rr.~vr i-.v.~~~v~~`.~vv~ ~~~v~,r ~ Ii1 JIV~~~nV I91\Y RCI VRI~11\V V17C VVr'i CNVrI 1 V. BP Exploration (Alaska) Inc. ~ ~, r~~ Petrotechnical Data Center LR2-1 9 ~~ '~, fi R, 900 E. Benson Blvd. '' ~ b ~ ~' i ~'"'` Anchorage, Alaska 99508 '~tt ff Date Delivered: ~~~.y9y (~ ~ ~ ~lt~ r ;~?; -Y?E11~S5~t'tK~ r~; ;; Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • • /(t¿" $J~/bb _ STATE OF ALASKA _ ALAS~IL AND GAS CONSERVATION CW'IMISSION REPORT OF SUNDRY WELL OPERATION!S\ 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. ress: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 028306 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Tieback Liner Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): 181 Repair Well 181 Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Time Extension o Other o Re-Enter Suspended Well 63' 11288 8866 11241 8863 110' 2597' 8835' 687' 4255' 2816' 4. Well Class Before Work: 181 Development 0 Exploratory o Stratigraphic 0 Service 99519-6612 198-254 6. API Number: 50-029-20742-01-00 9. Well Name and Number: PBU 15-06A 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 20" 110' 110' 1490 470 13-3/8" 2597' 2597' 4930 2670 9-5/8" 8835' 8210' 6870 4760 7" 8535' - 9222' 7937' - 8563' 8160 7020 7" x 4-1/2" 4967' - 9222' 4800' - 8563' 8160 7020 2-3/8" 8457' - 11273' 7866' - 8865' 11200 11780 9800' - 11239' 8844' - 8862' Tubing Size (size, grade, and measured depth): 3-1/2", 9.3# 7" x 3-1/2" Baker 'S-3' Packer; Packers and SSSV (type and measured depth): 7" x 3-1/2" Baker 'FB-1' packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): 13CrBO 1L-80 8502' 8311' 8412' Treatment description including volumes used and final pressure: RBDMS 8Ft MAY ~ (1 2006 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Tubin Pressure Re resentative Dail Gas-Mcf 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my nowe ge. Sundry Number or N/A if C.O. Exempt N/A o Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Contact Printed Name Terrie Hubble Signature Form 10-404 Revised 04/2006 Title Technical Assistant 05710- I. Prepared By Name/Number: Date ï l> (P Terrie Hubble, 564-4628 Submit Original Only Phone 564-4628 ORIGINAL TREE = WELLHEA[).= ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = MCEVOY FMC AXELSON 63' 37' 3000' 97 @ 10267' 11246' 8800'SS ~NOTES: e 15-06A AS-BUILT COMPLETION 35' -i 5-1/2" X 3-1/2" XO I 2146' 13-1/2" HESX-NIP, 10- 2.813" GAS LIFT MANDRELS TVD DEV TYÆ VLV LATCH 3433 21 MMG DCR-1 5815 30 MMG DGLV 7630 26 MMG DGL V RKP I 13-3/8" CSG, 72#, L-80 BTC, 10 = 12.347" ST MD 3 3454 2 6123 1 8197 PORT DATE 1.5" 05/05/06 1.5" 05/05/06 1.5" 05/05/06 Minimum ID = 1.901" @ 8457' 2-3/8" BKR LNR DEP SLV 9-5/8" X 7" BOT SBP LNR TOP PKR (SCAB), 10 = 6.250" 3-1/2" OTIS XN NIP, 10 = 2.635" (BEHIND 2-3/8" LNR) XN NIP MILLED TO 2.80" 10 7" X 4-1/2" XO, ID = 3.958" I , BAKER 7" X 4-1/2" S-3 PKR, 10 - 4.5" ,. I I , 3-1/2" HES X-NIP, 10 - 2.813" 3-1/2" HESX-NIP, 10-2.813" 3-1/2" HES XN-NIP, 10 - 2.75" 3-1/2"TBG, 9.3#, 13CR80, VAMTOP, .0087 bpf, 10 = 2.992" 3-1/2" MULE SHOE 7" X 3-/12" BKR FB-1 PKR, 10 = 4.000" I 2-3/8" BKR LNR TOP DEPL SL V, 10 = 1.926" 9-5/8" X 7" BOT LNR TOP PKR WITIEBACK, 10 = 6.250" 3-1/2" TBG, 9.3#, L-80, 1PG-8-RD, .0087 bpf, 10 = 2.992" 8502' -1 3-/12" WLEG (MULESHOE), 10 = 2.992" H ELMO TT NOT LOGGED I 9-5/8" X 7" BOT LNR HGR WITIEBACK ID = 6.250" 8502' 8835' 9-5/8" CSG, 47#, L-80 BTC, 10 = 8.681" 8826' -1 TOP OF CEMENT I PERFORATION SUMMARY REF LOG: SWS GRlCCL ON 03/06/99 ANGLEATTOPPERF: 88 @ 9800' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 1-11/16" 4 9800 - 10270 0 03/08/99 1-11/16" 4 10330 - 11239 0 03/08/99 7" LNR MILLOUT WINDOW 9222' - 9235' I 4-1/2" LNR, 12.6#, L-80 FL4S, 10 = 3.958" I 9603' DATE 06/01/82 10/21/90 03/08/99 04/11/01 05/04/03 09/11/03 17" LNR, 29#, L-80 BTC, 10 = 6.184" , 9620' 2-3/8" LNR, 4.43#, L-80 FL4S, .00387 bpf, 10 = 1.969" I REV BY COMMENTS ORIGINAL COM PLETION RWO CTD SIDETRACK CHlKAK CORRECTIONS ?ITP IBP/SVLN CORRECTIONS CMOITLP DATUM MD & PERF ANGLE DATE 10/31/03 08/26/04 05/05/06 REV BY COMMENTS JJITLP PULL IBP @ 8386' MDClTLP ECLIPSE PA TCHES GMH NABORS 3S COMPLETION PRUDHOE BA Y UNIT WELL: 15-06A ÆRMIT No: 11'1982540 API No: 50-029-20742-01 SEC 22, T11N, R14E, 971' FNL & 189' FWL BP Exploration (Alaska) e e 15-06A Rig Workover Prudhoe Bay Unit 50-029-20742-01-00 198-254 Accept: Spud: Release: Ri: 04/29/06 N/A 05/07/06 Nabors 3S PRE-RIG WORK 04105/06 ATTEMPTING TO LATCH UPPER WEATHERFORD PATCH WI NO SUCCESS. RAN IMPRESSION BLOCKS AND SUSPECT TOP OF PATCH POSSIBLY BENT INWARD. DRIFTED INTO TOP OF PATCH WI 5' X 1 1/2" STEM WI NO PROBLEMS. RAN 2.35" SWAGE TO ATTEMPT AND FLARE TOP OF PATCH BACK OUT. 04/06/06 PULLED UPPER 3.5" ECLIPSE PATCH FROM 5459' SLM, ELEMENT INTACT. RIH TO PULL UPPER AND LOWER PACKER ASSEMBLY. 04107/06 PULLED UPPER PACKER ANCHOR FROM 7089' SLM (MISSING ELEMENTS). FISHED ELEMENTS OFF TOP OF LOWER PATCH (ONLY RECOVERED ONE COMPLETE ELEMENT). PULLED LOWER PACKER ASSEMBLY FROM 7126' SLM (MISSING ELEMENTS). 04108106 MADE SEVERAL RUNS WI 3.5" BLB, WIRE GRAB RAN 2.7 CENT. 2.75 LIB, SAT DOWN AT 8453 SLM. MARK OF TOP OF DEPLOYMENT SLV. RDMO. 04/09/06 RIGGED UP HIGH PRESSURE BLEEDER TOOL TO TEST FITTING. 0 PSI ON VOID. TESTED AT 5000 PSI. PRESSURE BLED TO 4850 AFTER 15 MIN AND 4800 AFTER 30 MIN. BLED PRESSURE TO 0 PSI. FUNCTIONED AND TORQUED LDS AT 500 FT LBS. PPPOT-IC (PASSED) RIGGED UP HIGH PRESSURE BLEEDER TOOL TO TEST FITTING. 0 PSI ON VOID. TESTED AT 3000 PSI WITH NO PRESSURE LOSS AFTER 30 MIN. BLED PRESSURE TO 0 PSI. DID NOT TORQUE LDS. 04/10/06 SET MECH BP AT 8419'. CORRELATED TO ARCO TUBING TALLY DATED 21-0CT-1990 SET BAKER 255 QUIKDRIL COMPOSITE PLUG AT 8419' TUBING PUNCH INTERVAL = 8369' - 8371' STRING SHOT INTERVAL = 8379' - 8391' CUT 3-1/2" TUBING AT 8390' WITH 2-1/4 CHC, 2-1/8 ANCHOR, 108" X 2" OF BRF3, 14" OF GGG. SEVERING HEAD SHOWED CORROSION (CHEMICAL BURN) ON APPROX. >35% OF ONE SIDE OF HOUSING ALONG WITH A HOLE APPROX. SIZE OF GOLF BALL IN THE LOWER CYLINDER JUST ABOVE THE SEVERING HEAD. PROPLELLANT PORTS ON ONE SIDE OF SEVERING HEAD DID NOT INDICATE MIXTURE TO ACCOMMODATE A PROPER CUT. WELL LEFT SHUT-IN TIIIO 0/9010. e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-06 1 5-06 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/29/2006 Rig Release: 5/7/2006 Rig Number: Spud Date: 5/14/1982 End: 4/29/2006 00:00 - 01 :00 1.00 MOB P PRE Rig move from OS 1-31 to DS 15-06. Permit to work initiated, pre-job pad inspection completed wI DSO Kyle Moffat on 4-28-06. 01 :00 - 15:00 14.00 RIGU P PRE Rig on location. MIRU and spot equipment. Notified Lou Grimaldi with AOGCC of upcoming BOPE test. 15:00 - 21 :00 6.00 RIGU P PRE RU Stabbing board and PU Kelly. 21 :00 - 22:30 1.50 WHSUR P DECOMP Accepted rig @ 2100-hrs. PJSM. P/U lubricator. Pull BPV. UD lubricator. 22:30 - 00:00 1.50 KILL P DECOMP MIRU LRS. Pump 50 bbls. heated seawater from vac truck down IA to displace diesel from tubing taking returns to blowdown tank. 4/30/2006 00:00 - 03:30 3.50 KILL P DECOMP Swap pump lines. LRS pump 240 Bbls 120 degree seawater down Tbg taking returns from IA to Tiger Tank. Circulate all diesel from Well bore. Blowdown I rig down and secure lines and Wellhead. FMC set BPV and Blanking Plug in Tubing Hanger (11" stick up into Tubing Spool). Test to 1000 psi from below. 03:30 - 00:00 20.50 BOPSU P DECOMP ND Wellhead equipment and NU Drlg Spool with 135/8" BOPE. Necessary to split BOPE into 3 components to PUMU under rig floor. Required 4 lifts using bridge cranes. Completed nipple up process at OOOO-hrs. 5/1/2006 00:00-01:15 1.25 BOPSU P DECOMP Troubleshooting leaks and repairing same until 0115-hrs. 01:15 - 04:30 3.25 BOPSU P DECOMP PJSM. Pressure test BOPE per AOGCC and BP requirements - 250 psi LO/3500 psi HI. AOGCC-John Crisp waived witnessing of test. 04:30 - 06:00 1.50 PULL P DECOMP PUMU jt. 3-1/2" DP and blanking plug pulling tool. Pull blanking plug. UD jt. DP and blanking plug. PUMU lubricator and pull BPV. 06:00 - 11 :00 5.00 PULL P DECOMP Lay down BPV Lubricator and extension. PUMU landing joint and torque crossovers to 5 3/4" Acme for Tbg Hgr. Screw into Hanger w/9 1/2 turns. Break out LDS. PU Tubing and unseat Tbg Hgr. PU to 102K, Tbg pull free, no fluid losses. PU weight of Tbg = 78K. POH wI Tubing Hgr. 1 single 1/4" stainless control line with metal bands. Break out and lay down Tbg Hgr wI pup joint. Lay down 1 joint of 5 1/2" Tbg wI XO to 31/2" Tbg. 11 :00 - 15:30 4.50 PULL P DECOMP POH laying down 3 1/2" 9.3# L-80 IPC Tbg, spooling control line, laydown TRSSSV. Recovered 39 stainless steel bands. Lay down SLB spooler unit. 15:30 - 20:00 4.50 PULL P DECOMP POH laying down 3 1/2" Tbg. 160 jts. OOH. 20:00 - 00:00 4.00 PULL P DECOMP Finish POH laying down 31/2" Tbg. Recovered 259 jts. 3-1/2" tubing, 8 x 3-1/2" Camco MMG GLV's, 1 x 3-1/2" Otis SVLN SSSV nipple. Length of cut jt. 17.67'. 5/2/2006 00:00 - 06:00 6.00 WHSUR P WHDTRE PUMU 9-5/8" casing packing pulling tool. Connect bleed hose from OA to bleed trailer and verify 0 psi on OA before proceeding. BOLDS. Pull 9-5/8" casing packing mandrel. Pulled 25K# to remove old packing mandrel. Install new packing mandrel. RILDS. Pressure test same to 3000 psi and packing failed. BOLDS. Attempted to pull packing mandrel. mandrel moved upwards approx. 6" and stopped coming up. Pulled up to 40K# with no upward movement. Stop operations and formulate new plan forward. 06:00 - 09:30 3.50 WHSUR P WHDTRE PUMU 1 ea 4 3/4" DC and Baker 4 3/4" Bumper Sub with Printed: 518/2006 11 :55:35 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 5-06 15-06 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/29/2006 Rig Release: 5n/2006 Rig Number: Spud Date: 5/14/1982 End: 5/2/2006 06:00 - 09:30 3.50 WHSUR P WHDTRE Packoff running tool. RIH engage packoffs and work DC and Bumper Sub with air tugger. Free up packoffs and work with in 8" range upward and downward. Pull running tool, a piece of S-seal (metal seal) on top of running tool. RBIH and engage packoffs. Work packoffs pulling gradually and beating back down. With 55K overpull unseat packoffs. Pull to floor, indentations from LDS indicate packoffs were +/- 1" from being fully seated. Break off running tool and PUMU "swizzle stick" to wash packoff profile and clear any debris. 09:30 - 10:30 1.00 WHSUR P WHDTRE Drain stack. PUMU packoff running tool on 1 4 3/4" DC and Bumper sub. MU new packoffs and RIH. Space out and seat packoffs in Csg spool. RI LDS and test to 3500 psi. OK 10:30 - 12:00 1.50 WHSUR P WHDTRE Break out and lay down PO running tool. 12:00 - 14:00 2.00 FISH P DECOMP P/U and M/U BHA #1: 5-3/4" Overshot wI 3-1/2" Grapple, Extension, Pump Out Sub, Jars, and 6-joints 4-3/4" Drill Collars. 14:00 - 20:30 6.50 FISH P DECOMP RIH BHA #1 on Drill Pipe from Pipe shed. 124 jts. RIH @ 2030-hrs. 20:30 - 23:30 3.00 FISH P DECOMP RIH BHA #1 on Drill Pipe from Pipe shed. 124 jts. RIH @ 2030-hrs. 23:30 - 00:00 0.50 FISH N RREP DECOMP Pipe skate malfunction. Shut down operations to repair same. 5/3/2006 00:00 - 01 :30 1.50 FISH N RREP DECOMP Pipe skate malfunction. Shut down operations to repair same. 01 :30 - 03:30 2.00 FISH N DECOMP Resume RIH w/BHA #1 - O/S-Jars on DP through pipe shed 1x1. MU TIW valve to top of 259th jt. Tag top of fish at 8394'. Up wt. - 125K#. Down wt. 11 OK#. SO to 1 OK# down wt. on fish. Hook up vac truck to take on fluid to pits. 03:30 - 04:00 0.50 FISH N DECOMP PJSM. Jar on fish starting with 25K# overpull. Work overpull up to 170K# in 10K# increments. Fish jarred free at 45K# overpull. POH and UD jt. 259. MU TIW valve and kelly hose into top of jt. 258. Close annular preventer and break circulation through superchoke to gas buster. Circulating at 4 BPMat 440 psi. 04:00 - 07:00 3.00 FISH N DECOMP CBU 1.5 hole volumes to pits monitoring parameters. Fluid losses 6.4 bbls.!hr. 07:00 - 15:30 8.50 FISH N DECOMP Blow down Choke Line and POOH and SIB DP and DCs in Derrick. 15:30 - 17:30 2.00 FISH N DECOMP Break out and UD BHA #2 and UD fish. Recovered the 16.62' seal assembly. 17:30 - 18:00 0.50 FISH N DECOMP Clear and clean rig floor. Prepare to PUMU BHA #2 - mill/scraper. 18:00 - 19:00 1.00 FISH N DECOMP PUMU BHA #2 - milllscraper. 19:00 - 20:00 1.00 FISH N DECOMP Shut down rig operations. Conduct incident investigation regarding dropped jt. of DP that occurred at 0330-hrs. 20:00 - 00:00 4.00 FISH N DECOMP RIH w/BHA #2 and DP from derrick to top of Baker FB-1 packer at 8412'. 5/4/2006 00:00 - 01 :30 1.50 CLEAN P DECOMP Continue RIH w/BHA #2 and DP from derrick to top of Baker FB·1 packer at 8412'. 01 :30 - 02:30 1.00 CLEAN P DECOMP Tag top of FB-1 packer assembly at 8417' with jt. #259. UD jt. #259 and rig up head pin, safety valve and kelly hose to top of jt. #259. RIH and No/Go stacked out with bottom of Mill inside seal bore at 8438'. Pull mill out of seal bore and break reverse circulation at 3.0 BPM @ 350 psi circ. pressure. RIH w/jt. #259 and tag top of packer at 8417'. RIH to place mill at bottom of Printed: 5/8/2006 11 :55:35 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 5-06 1 5-06 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/29/2006 Rig Release: 5n/2006 Rig Number: Spud Date: 5/14/1982 End: 5/412006 01 :30 - 02:30 1.00 CLEAN P DECOMP seal bore @ 8438'. Break reverse circulation at 3.0 BPM @ 370 psi confirming with pressure increase that mill is inside packer seal bore. Entered into the Seal Bore 21.2' (+1-). 02:30 - 06:00 3.50 CLEAN P DECOMP Reverse circulate 2 x 15 bbl. hi-vis sweeps at 3.0 BPM @ 350 psi. to hold losses down followed by seawater flush. 06:00 - 17:30 11.50 CLEAN P DECOMP POH and UD DP through Pipe Shed. 130-joints OOH @ 1230-hrs. 250-joints @ 1630-hrs. 17:30 - 18:30 1.00 CLEAN P DECOMP Break out and UD DCs and Seal-bore Dress-off BHA. 18:30 - 00:00 5.50 CLEAN P DECOMP Clear and clean Rig Floor, pull Wear Ring, RIU Torque Turn equipment. Modify pipe skate backstop - added 7" to shroud. Fluid losses - 1.6 bbls/hr. 5/512006 00:00 - 00:30 0.50 CLEAN N RREP DECOMP Continue modify pipe skate backstop - added 7" to backstop shroud. 00:30 - 02:00 1.50 RUNCO RUNCMP All crew PJSM. PUMU RIH w/3-1/2" 13CR-80 completion string using compensator and torque turn equipment. Torque turn all thread connections to 2900 ft.lbs. 10 jts. RIH at 0200-hrs. 02:00 - 03:00 1.00 RUNCO RUNCMP Continue RIH w/3-1/2" 13CR-80 completion string using compensator and torque turn equipment. 25 jts. RIH at 0300-hrs. 03:00 - 14:00 11.00 RUNCO RUNCMP Continue RIH w/3-1/2" 13CR-80 completion string using compensator and torque turn equipment. Torquing all connections to 2,900 Ib-ft; using Jet-Lube Seal Guard Pipe Dope. 43 jts. RIH @ 0500-hrs. 180-jts @ 1300-hrs. Fluid losses 1 to 1.5 BPH. 14:00 - 21:30 7.50 RUNCO RUNCMP Continue RIH w/3-1/2" 13CR-80 completion string using compensator and torque turn equipment. Torquing all connections to 2,900 Ib-ft; using Jet-Lube Seal Guard Pipe Dope. Fluid losses 1 to 1.5 BPH. P/U wt. = 70K#. S/O wt. = 65K#. Tag bottom of packer seal bore at 8428' w/15K# dwn wt.. 29.60' in on jt. #261. UD jt. 261. P/U headpin and safety valve and rig up to reverse circulate corrosion inhibitor in place. 21 :30 - 00:00 RUNCMP Reverse circulate 580 bbls. 140F seawater containing 122 gallons of EC1124A corrosion inhibitor @ 3.0 BPM @ 170 psi. Taking returns to blowdown tank. 5/6/2006 00:00 - 01 :30 RUNCMP Continue reverse circulating 580 bbls. 140F seawater containing 122 gallons of EC1124A corrosion inhibitor @ 3.0 BPM @ 170 psi. Taking returns to blowdown tank. 01 :30 - 04:00 RUNCMP PUMU landing jt., safety valve and headpin and MU to tubing hanger. Drop ball and rod. PU landing jt. and hanger and MU to 260th jt. tubing. Attempt to land tubing hanger. Hanger seal rolled out of seal groove. Pulled hanger to floor and replaced seal ring. Land tubing hanger. 04:00 - 09:00 5.00 WHSUR P RUNCMP Rig up circulating lines to headpin. Close annular preventer around landing jt. Pressure test across tubing hanger seals to 3500-psi. Troubleshooting leaks to obtain pressure test of tubing hanger seals. Pull Landing Joint and find damaged nose seal. Get ready to use FMC Tree Test Plug to blank off tubing for Seal PT. Don't need to install Tree Test Plug; more experienced FMC hand arrives who successfully tests the seal through the old Control Line penetration. Sting Landing Joint back into Hanger and make up wI Chain Tongs. 09:00 - 10:00 1.00 RUNCO P RUNCMP RIU lines to set and test the Packer. Chase leak to top of Stand Printed: 5/8/2006 11 :55:35 AM e - Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-06 1 5-06 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/29/2006 Rig Release: 5n/2006 Rig Number: Spud Date: 5/14/1982 End: Pipe. Pump down Tubing and PT to 3,500-psi. PT won't hold, remove Landing Joint, close Blind Rams and hold and record PT @ 3,500 psi for 30-minutes--good test. Bleed Tubing to 1,500-psi and hold. RUNCMP PT annulus to 3,500-psi and hold. Mud Pump relief valve popped @ 3,500 to 3,600-psi. SII test and reset relief valve, bleed off annulus to O-psi to ensure DCR had not sheared. Pressure up annulus to 3,500-psi, hold and record for 30-minutes--good test. Bleed off tubing and DCR sheared @ 1,100-psi tubing or 2,300-psi differential. Pump both ways through DCR--it's open! P/U and install FMC BPV and test. NID BOPE lines. NID BOP stack. N/U Production Tree. N/U production TREE. test void to 5000 psi. P/U lubricator. Pull BPV. Set Tree test valve. PIT Tree to 5000 psi. Good test. Pull Tree test valve. PJSM. MIRU LRS to FIP well. PIT lines to 3500 psi. Pump 150-Bbls diesel freeze protect @ 2.5 BPM. Pump rate limited by diameter of LRS pumping line. Blow down line to blowdown tank with air. Hook up hose from tubing to IA. U-tube diesel from IA into tubing. Allow pressure to equalize tubing by IA. P/U BPV, install, and test to 1,OOO-psi. Secure Tree and Cellar. Release rig @ 1200-hrs. 11 :30 - 14:00 14:00 - 23:00 9.00 BOPSU P RUNCMP 23:00 - 00:00 1.00 WHSUR P RUNCMP 5/7/2006 00:00 - 00:30 0.50 WHSUR P RUNCMP 00:30 - 02:30 2.00 WHSUR P RUNCMP 02:30 - 04:00 1.50 WHSUR P RUNCMP 04:00 - 10:00 6.00 WHSUR P RUNCMP 10:00 - 12:00 2.00 WHSUR P RUNCMP Printed: 5/8/2006 11 :55:35 AM 15-06A (PTD #1982540) Classified as Problem Well ) ) Subject: 15-06A (PTD #1982540) Classified as Problem Well From: "Anders; Joe L" <anders22@BP.com> Date: Thu, 31 Mar 2005 20:27:35 -0900 T(Ù cahalat@BP.com, ·tlRossberg, R Steven" <RossbeRS@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "GPB, Wells Opt"Engtl.. <qPBWellsOptEng@BP.com>, uAOGCC Jim Regg (E~mail)n <jim-.:.regg@admin.state.ak.us>, "AOGG,c: Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. "NSU'ADW Wß&. Co~pletion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>, "GPB,. Wel1 Pads D~GtI <GPBWellPadsDFG@BP.com>, tlGPB,.FS3 DSOpsLead" <GPBFS3DSOpsLead@BP.com> C~: "NSU, ADW Well Integrity Engineer" <NSUAbWWellIIltegrityEnghlee~@BP.com>,"R~e~es, Dqnald F" <ReevesDf@BP.com>, tlMielke, Robert L.",<:;robert.mielke@BP.com>, '''Corcoran, Kevin D (VECQ)" <Corcoran.Kevin@BP.com> ì.U..........Q". .. ,~:~ ·r·~I¡~~·ç:~;~·: .".:.!'. All, Well 15-06A (PTD #1982540) has sustained casing pressure on the IA and is classified as a Problem well. TIO's on 03/29/05 were 480/1420/100. The plan forward for this well is to load with kill weight fluid. Attached is a wellbore schematic. Please call if you have any questions. «15-06A. pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-51 00, x1154 Email: NSUADWWelllntegrityEngineer@bp.com . . .......................................................................................................,."."'i'NN'E:n..Þt~R 1 4 2.005 Content-Description: 15-06A.pJf{",A "! , 15-06A.pdrj[ Content-Type: application/octet-stream i , Content-Encoding: base64 PfbctRt.~~~ Pr~.;.5L(¡e $ ():J:.~ ) G~ M(+) WÃ-Tf,.<Z- ~~) :Þ~ ~'1f ~? ¿ 4~M1<¡ ft?h 2(0S" 2z.2'i7 Þ ~~ 30\ 0 v¿ --- ' ~^*' ( v '..MJ 21.\.)ç "Z2,'~73 b z.c:¡, 7zJ.. 30 (xc..:. "2.(..u4 2(, , 3'8 '703/2A 0 '31 SA gd70rf.. \4 2:0f5" \.Ie~ ( .? ~ ~J U\J4 '~ S-5- 7cA COL.- 0 "3D ~ ) CCI U'04 2'6 7-¡o {,35, '2(') ~ DA Ç3tt>r.}~ Ill? ~'I ~"S (,. <1 2 , <81 31 1 of 1 J~e1i ~1,lo'5' 4/1/2005 8:21 AM ) IVCEVOY FMC AXELSON ........... s·f 3i' 3000' ·····9i"··@i··1··6~Ù3i 11246' ······s8"ÖÖï§"S' TREE = WELLHEAD = ACTLLA. TOR = KB. ï:lE\t..;;" B Þ:·· ECE\I = KOP= iiJiäx· )Ùïgïe·; Datum MD = ÖätüïTifv b ;.. I 13-3/8" CSG, 72#, L-80 BTC, D = 12.347" 1-1 2597 Minimum ID = 1.969" @ 8457' 2-3/8" BKR LNR DEP SLV 9-5/8" X 7" BOT SBP LNR --1 4967 TOP PKR (SCAB), ID = 6.250" 9-5/8" X 7" BOT LNR TOP --1 84 79' PKR W/TIEBACK, ID = 6.250" 3-112" lEG, 9.3#, L-80, IFe-8-RD, -1 .0087 bpf, ID = 2.992" 8502' 9-5/8" CSG, 47#, L-80 BTC, ID = 8.681" H 8835' PERFORATION SUMv'lARY REF LOG: SWS GRlCCL ON 03/06/99 ANGLEATTOPÆRF: 88@9800' Note: Refer to Production DB for historcal perf data SIZE SPF IN1£RVAL Opn/Sqz DATE 1-11/16" 4 9800 - 10270 0 03/08/99 1-11/16" 4 10330 - 11239 0 03/08/99 4-1/2" LNR, 12.6#, L-80 FL4S, ID = 3.958" 1-1 9603' 17" LNR, 29#, L-80 BTC, ID = 6.184" 1-1 9620' 15-06A \ ) - ~ L ~ ~ tI 8 8 X ~M; fI 1 ~ .. .. ) . SAFETY NOTES: TRSV LOCKED 75' 1--1 5-1/2" X 3-1/2" XO I 2195' 1-3-112"OTISSVLNTRSVSSSV,ID= 2.813" LOCKED - OPEN 02/16/99 GA S LIFT I\i\ð. NDRElS DEV TYPE VLV LATCH o Mv'IG DV RK 26 Mv'IG DOfvE RK 28 Mv'IG DV RK 30 Mv'IG DV RK 29 Mv'IG DV RK 28 Mv'IG DV RK 28 Mv'IG SO RK 25 Mv'IG DV RKP ECLPSEPATCH, ID= 1.75" ECLPSEPATCH, ID= 1.75" PORT DAlE 10/21/90 03/13/99 10/21/90 10/21/90 10/21/90 10/21/90 03/13/99 10/21/90 8412' 1--1 7" X 3-/12" BKR FB-1 A<R, ID = 4.000" 1 8457' 1-1 2-3/8" BKR LNR TOP DEPL SLV, ID = 1.926" 8470' 1- 3-1/2" OTIS XN NIP, ID = 2.635" (BEHIND 2-3/8" LNR) XN NIP MILLED TO 2.80" ID 1--1 7" X 4-1/2" XO, ID = 3.958" 1 8494' 8502' 1-1 3-/12" VVLEG (IVULESHOE), ID = 2.992" 1--1 ElMDTTNOTLOGGBJ I 8535' 1- 9-5/8" X 7" BOT LNR HGR WIllEBA CK ID = 6.250" 8826' 1-1 TOP OF CEMENT I ~ ST MD TVD 1 2729 2729 2 4339 4238 3 5487 5261 4 6415 6066 5 7125 6682 Z 6 7770 7252 ~ 7 7982 7440 Z 8 8292 7717 I 5470-5510'1-1 8 17136-7196'1-1 z 8" 7' LNR MLLOur WINDOW 9222' - 9235' 2-318" LNR, 4.43#, L-80 Fl4S, .00387 bpf, ID = 1.969" H 11273 I DATE REV BY COMfvENTS 10/31/03 JJ/ll.P PULL IBP@ 8386' 08/26/04 WClTLP EQIPSE PA TCHES DA TE RBI BY CO Mv'I ENTS 06101/82 ORIGINAL COM PLETION 10/21190 RWO 03108199 CTD SIDETRACK 04/11,{)1 CH'KAK CORRECllONS 05104103 ?/TP IBFYSVLN CORRECTONS 09/11103 CMOfTLP DATUM MD & PERF ANGLE PRUDHOE BAY UNIT WELL: 15-06A PERI'vIT No: 1982540 API No: 50-029-20742-01 SEC22, T11N, R14E, 971' FNL & 189' FWL BP Exp loratio n (A !as ka) 07/16/03 Schlumberger NO. 2905 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Color Well Job # Log Description Date Blueline Prints CD e-36 I ~i (0 '-© ( r~c"~ LDL 07/09/03 E-10A [ C-('q -O L~_~- LDL 07/07103 J-18 ~ ~;?~) "' \(~)~ LDL 07/01103 '1 D.S. 15-06A'"'1 ~ - ,,~,~j L~ LDL 07/04/03 D.S. 15-27 _~(~).~{.~ LDL 07114/03 1-55/R-25 ['7~q~- (~-~ \ ' LDL 07/09103 2-52/S-14 ~<~'~ '- (~ ~ PROD PROFILE W/DEFT & GHOST 07113/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 .... Date Delivered: JUL 2.6 ....... " XXXX Schlumberger GeoQuest 3940 Arctic BIvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor DATE: May 15, 2001 FROM' Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit DS 15 Tuesday, May 15. 2001' I traveled to BPXs Drill Site 15 and witnessed the safety valve system testing on cycle producers 15-6, 15-26 and 15-30. The above mentioned well had recently been cycled on production. All components functioned properly and passed their tests. Mike Hensel performed the testing today; he demonstrated good test procedures and was a pleasure to work with. Summary: I witnessed the testing of the safety valve systems on 3 cycle producers at BPXs DS 15. PBU DS-15 3 well 6 components 0 failures Attachment: SVS Cycle PBU DS 15 5-15-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS Cycle PBU DS15 5-15-01 CS Aia~ Oil and Gas Conservation "-~' Commission Safety Valve System Test Report Operator: BPX Operator Rep: Mike Hensel AOGCC Rep: Chuck Schcve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Prudhoe / PBU / DS 15 Separator psi: LPS 174 ' I-IP~ 5/15/01 i ii i i ii i i i Well Pemit Separ Set L~ T~t Test Test Date ~ WAG, G~J, ~umber Number PSI PSI T,~p Cqde Code ,, Code P~,ss~ G~ orate 15-01A 1~82~20 ,,, , ., , ,. , , ~ ~ , , ,,, 15-02A 1961630 ~15.03 1820300 1~-04' 1820370 ................ I, , , . .,~ , . , 15-05A 1950340 ~15,06A 1982540 '174' ' 1~0' '150 ~ 'P ............ CYCLE :i~.07B ' 2000980 ............... 1 2o8B 1971826 .... , ~, t _. , ,, ,.. 15-09A 1931380 . , ,, , . , . , ~ . ~, ~ ,, 15-10A 1880850 , ~ ., ., , , . ,,..,_ 15-1 lA 1982480 , ., . .. . .. ~ , . . . , , 15-12A 2000610 . : . . .. . ~ ~ . - ,, ., . . 15-13A 1'991240 s-i4'' i'8117oo ,.,. . , ,. 15-15A 1982410 . . , 15-16 1840740 , ..... ., , , , ., ,, , . 15-17 1840890 15-18 1920600 , ., 15-19A 1990990 15-20A 1990480 15-21A 1990290 , ,, . , . .. ,~. . , .. ~ , i'5-22 ' 1800970 ,, , , , . . . , . , ,~ . . t, , i ,, ,, . , . 15-23 1911350 ,. , ,, , , , , , , , . . , 15-24 1911280 15-25A 19908~ ....... 15'26A 1970170 ~74 150 120 P''~ .......... cYCLE 15227 1920060 .................. 15.2'8 1920150 .............. ., .. .~, , , , , , 15-29 1920350 , , , . ,, , 15'30 1920780 174 350 250 P P CYCLE , , 15-31 1920870 , 15-32 1940470 . ,. . , [ , , , 15-33A 1990600 , , , , . . . , , , , . , , . . . 15-34A 2001370 ~ J .., , , . ,,. . . . ., 15-35 1940880 15-36 1940720 ~'~200 ............. ~l~~n/~ 6720: P~2~ 1 el2 qXIq C~I~ ~I~1~ ~nllBq 1~ ~_lq_nl CS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 15238 1941040! , , , 15'39 1941150~ 15-40A 1980980 ............... 15-42 1951850 15-42A 2000690 , ,,, , i , , 15-43 1960830 15-44 1961100 1~-45 1960690 .... f5-45'A 2000680 ................ 15-46 1960610 15-47 1951740 ........... i5-48 ' 1952080 ......... 15'49/( .... 2001130 ............. Wells: 3 Components: 6 Failures: 0 Failure Rate: 0.00% l-lo0 oar Remarks: RJF 1/16/01 Page 2 of 2 SVS Cycle Wells PBU DS 15 5-15-01 CS State of Alaska AOGCC, Lori Taylor 3001 Porcupine St. Anchorage, AK 99501 Well Reference Data: Well No: 15-06A Field: County: State: Date: Prudhoe Bay Unit API No: North Slope Alaska 04/26/99 500292074201 BHI Job#: 103820 Enclosed is the following data as listed below: Log Ty~e Bluelines Navigam~a USMPR ~DL/MN~ TOTALS: Navigamma USMPR Dm~/MDL/MD~' Bluelines 2" + 5" Measured Depth Logs Folded Sepias Rolled Sepias 1 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias 1 Mylar Film Mylar Film LAS Disks Survey Listing ASCII Disks LIS Tape Image File Disks LIS Verification Report & Listings Depth Shift Monitor Plot Upon Receipt, Please sign and fax to: Baker ~.~19s~~Q Attn: Stuart Sutherland State of Alaska AOGCC, Lori Taylor 3001 Porcupine St. Anchorage, AK 99501 Well Reference Data: Well No: Field: County: State: 15-06A PB1 Prudhoe Bay Unit North Slope Alaska Date: 04/2 6/99 API No: 500292074270 BHI Job#: 103820 Enclosed is the following data as listed below: Log Type Bluelines Navigamma USMPR MDL/~NP D~/~DL/~DP Log Type Navigamma USMPR ~DL/~N~ DPR/MDL/MDP Bluelines 2" + 5" Measured Depth Logs Folded Sepias Rolled Sepias 1 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias 1 Mylar Film Mylar Film LAS Disks : Survey Listing ASCII Disks : LIS Tape Image File Disks : LIS Verification Report & Listings : Depth Shift Monitor Plot : Upon Receipt, Please sign and fax to: Baker Hughes INTEQ Fax#: (907) 267-6621 At tn~ ~ %~~r~ 1 and ~a~ 0~,. & Gas Cons. Commi~ton 198-254-0 PRUDHOE BAY UNIT Roll #1: Start: Stop Roll #2: MD 11288 TVD 08866 Completion Date: 15-06A 50- 029-20742-01 Start .~' Stop L~3~/99 Completed Status: 1-OIL BP EXPLORATION (ALASKA) rNC Current: T Name Interval D 9135 L.~~' 16-26 BH GR OH D 913~ 7-15 BHGR PBI OH L GR-MD FINAL 9233-10670 PB1 OH L GR-MD f-/ FINAL 0218-11288 OH L GR-TVD °'~ FINAL 8493-8809 PB1 OH L GR-TVD ~ FINAL 8495-8799 OH L MNCL ~-'~'~' FINAL 8220-11249 CH R SRVYLSTNG ~ BH 9200-11288. OH R SRVY LSTNG f""'~- BH 9200-10542. PB1 OH T 9033 [~' 1 SCHLUM MCNL CH [ Sent Received T/C/D 4/26/99 5/5/99 4/26/99 5/5/99 4/26/99 5/5/99 D 4/26/99 5/5/99 D 4/26/99 5/5/99 4/26/99 5/5/99 2 3/25/99 3/26/99 T 3/18/99 3/18/99 3/18/99 3/18/99 3/25/99 3/26/99 Wednesday, March 28, 2001 Page 1 of 1 3/25/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATrN: Sherrie NO. 12460 Compan~ Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 85. oC~ t Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape D.S. 1-29 -~ ~O'~' 98519 RST 980628 1 I 1 D.S. 7-29A d~ ~O~ 99124 MCNL 981223 1 1 1 D.S. 14-24 ~1,4:~ I OOQ 99139 EST 980809 1 1 1 D.S. 15-06A-o, ~0~'~ 99130 MCNL (PDCI 990306 1 1 1 L5-16 ~ ~O~(-~ 99140 EST 990312 1 1 1 .Al~a Oil & Gas Cons. Commission Please sign and return one copy of this lransmittal to Sherrie at the above address or fax to (907) 562-6~/~~k you, STATE OF ALASKA ALAS~JOIL AND GAS CONSERVATION COMM;'~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ~] Gas D Suspended r'~ Abandoned D Service D 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 98-254 3. Address 8. APl Number P. O, Box 100360, Anchorage, AK 99510-0360 50-029-20742-01 4. Location of well at surface~ ? ~:-i ~i'i~'!~ ii~,: i':-.-~ 9. Unit or Lease Name At Top Producing Interval !~~J 10. Well Number At Total Depth .... 11. Field and Pool 423' FNL, 1444' FEL, SEC. 21, T11N, R14E, UM :~~ Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 63 feetI ADL 028306 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore ~16. No. of Completions February 15, 1999 March 5, 1999 March 9, 1999I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thick~ess of Permafrost 11288' MD / 8866' TVD 11241' MD / 8863' TVD YES ~] No [~I 2151' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MEM CNL/GPJCCL, MWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 92.5# H~40 Surface 110' 30" 375 Sx Permafrost II 13-3/8" 72# L-80 Surface 2597' 17-1/2" 2000 Sx Fondu & 400 Sx PFC 9-5/8" 47# L-80/S00-95 Surface 8835' 12-1/4" 600 Sx Class G & 50 bbls PFC 7"/4-1/4" 26# / 12.6# L-80 4966' / 8493' 9222' 8-1/2" 488 Sx Class G 2-3/8" 4.43# L-80 8457' 11274.5' 3" 14 bbls 15.8 ppg LARC 24. Perforations open to Production (MD + TVD et Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9800' - 10270' MD; 8844' - 8836' TVD; @ 4 SPF 5-1/2" 0075' 4966' 10330' - 11239' MD; 8831' - 8862' TVD; @ 4 SPF 3-1/2" 8412' 8479' 8412' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack- Sum .,rr~7~y !or ~D~a,i~ls)~- 27. PRODUCTION TEST ", ,t ',~ "~ Date First Production Method ot Operation (Flowing, gaslift, etc.) ORIGINAL.,__ March 15, 1999 Flowing , ...... .. )ate of Test Hours Tested =roduction for OIL-BBL GAS-MCF WATE R-B BL CHOKE S,ZE "'7 ::' :::~:O''~. ,. ~., ,., ,~'~:..=~.- ~.' r~: ::~: 3/17/1999 3.0 Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 376 psi 24-Hour Rate > 4283 7296 0 28. CORE DATA Brief description of lithology, porosity, l'ractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved January 8, 1999 (Permit #98-254) Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. NAME Top of Sag River Sand Top of Shublik Top of Sadlerochit Zone 1B GEOLOGIC MARKERS MEAS. DEPTH 8857' TRUE VERT. DEPTH 8230' · -.~., FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 8900' 8957' 9420' 8269' 8321' 8749' 31. LIST OF ATTACHMENTS Summary of 15-06A CT Sidetrack Drilling Operations + Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed~h' P.E. ~ ~;~"~ Title AAI Coil Tubing Drilling Supervisor Date INSTRUCTIONS Prepared by Paul Rau! 263-4990. General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. -~ .:i~,' ::!:. Item 28: If no cores taken, indicate "none". Form 10-407 15-06A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 2/13/1999: MIRU CTU. 2/14/1999: PT'd BOPE. RIH & milled XN nipple located @ 8740' MD. Tagged TOC @ 9184' MD & POOH. RIH w/UR. 2/15/1999: UR Cement f/9179' to 9216' MD. POOH. RIH w/window milling assembly & milled Cement to 9219.5' MD. Began window milling sequence through the 4-1/2" & 7" casing f/9218.5' to 9223.3'. 2/16/1999: 2/17/1999: Time milled to 9235' MD & POOH. RIH w/BHA but unable to pass SSSV. POOH w/BHA. RU slickline unit. RIH w/lockout tool & locked SSSV open. POOH. RD slickline unit. RIH & completed window milling operations. TOW = 9222' & BOT = 9231'. Drilled into FM to 9235' & POOH. RIH & dressed window interval. 2/18/1999: Continued to dress window interval. POOH. RIH & performed LOT to EMW of 9.2 ppg, Drilled to 9280' & POOH w/BHA. RIH & drilled to 9371'. POOH. 2/19/1999: 2/20/1999: RIH & drilled to 9386'. POOH to changeout orienter. RIH & drilled to 9389'. Orienter problems persist so POOH, RIH & reamed/backreamed f/9350' - 9389'. Drilled to 9557'. POOH. RIH & resurveyed OH. Drilled to 9630' MD & POOH. Performed BOPE test. RIH & reamed/backreamed f/BTM to 9590'. 2/21/1999: 2/22/1999: Drilled to 9980'. Circulated Crude. Swapped to new mud. Drilled to 10135'. Drilled to 10225'. Reamed/backreamed f/9700' - 9800'. Drilled to 10280' & POOH. RIH & drilled to 10406'. Circulated Crude. 2/23/1999: 2/24/1999: Drilled to 10511' & POOH. RIH & drilled to 10600'. Drilled to 10670' MD. POOH. RIH w/CT & pumped 7 bbls of 17 ppg Class G Cement to form plugback in OH. Layed in Cement f/10330' - 9532'. Contaminated Cement w/Biozan & cleaned out to 9815'. WOC. 2/25/1999: POOH w/CT. RIH & tagged hard Cement @ 9817'. Drilled off KOP to 9930'. Backreamed to 9800'. 2/26/1999: POOH. RIH & drilled to 10045'. POOH. 2/27/1999: RIH & drilled to 10205'. POOH. 2/28/1999: 3/01/1999: Tested BOPE. RIH & drilled to 10341'. Displaced to new mud. Drilled to 10500'. Drilled to 10561' & POOH. Drilled to 10677' & circulated Crude. Displaced well to new mud. Drilled to 10738' & POOH. RIH w/bi-centered bit. Sidetrack Summary Page I 15-06A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 3/02/1999: 3/03/1999: 3/04/1999: 3/05/1999: 3/06/1999: 3/07/1999: 3/08/1999: 3/09/1999: RIH & drilled to 10792'. Diff stuck. Freed w/Crude. Re-logged last 50'. Drilled to 10804 & stuck again. Pumped Crude & freed CT. POOH. RIH & drilled ahead to 10830' MD. Drilled to 10953' & POOH. RIH & drilled to10970'. Drilled to 11274'. Drilled to TD @ 11288'. Conditioned OH for liner. POOH while displacing OH to FIo Pro. MU 2-3/8" FL4S liner. RIH & landed liner @ 11279' MD. Pumped 14 bbls of 15.8 ppg LARC to cement liner in place. Contaminated Cement w/Biozan & jetted contaminated Cement f/wellbore. Cont to cleanout liner & POOH w/CT. Corrected TOL=8457' & BOL=11274.5'. RIH w/ CNL/GR/CCL tools & tagged PBTD @ 11241'. Logged wellbore. POOH w/logging tools. PT'd BOPE. PT'd liner to 2000 psi- bled off to 1750 psi in 30 min. RIH w/perf guns & shot 1379' of initial perforations @' 9800' - 10270' (Zone 1 B) 10330' - 11239' (Zone 1 B) Used 1-11/16" carriers & shot all perfs @ 4 SPF, 0° phasing, random orientation, & overbalanced. POOH w/guns. ASF. FP well. RDMOL. Placed well on initial production & obtained a valid well test. Sidetrack Summary Page 2 ARCO Alaska, Inc. D.S. 15 15-06A 15-06 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEG Your ref : 15-06A Our ref : svy69 License :API 500292074201 Date printed : 16-Mar-99 Date created : 23-Feb-99 Last revised : 16-Mar-99 ORIGI-NAL Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 675901.341,5961480.369,999.00000,N Slot location is n70 17 51.767,w148 34 25.367 Slot Grid coordinates are N 5960514.230, E 676115.120 Slot local coordinates are 970.94 S 191.12 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED ¢:~AR 18 1999 Alaska Oil & Gas'C~s. Comm~ ARCO Alaska, Inc. D.$. 15,15-06A Prudhoe Bay,North Slope, Alaska SURVEY LIST[NG Page 1 Your ref : 15-06A Last revised : 16-Mar-99 Measured [nclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOft Sect Easting Northing 9200.00 23.88 325.93 8479.11 2197.82N 1664.57~ 0.40 -2286.50 674399.67 5962672.34 9235.00 17.20 325.00 8511.86 2207.94N 1671.52W 19.11 -2296.99 674392.49 5962682.29 9259.00 11.00 328.70 8535.13 2212.81N 1674.74W 26.09 -2302.03 674389.15 5962687.08 9299.00 11.80 306.80 8574.36 2218~52N 1680.00~ 10.94 -2308.03 674383.75 5962692.67 9340.00 19.60 281.30 8613.84 2222.39N 1690.13W 24.98 -2312.45 674373.54 5962696.30 9379.00 23.90 275.50 8650.06 2224.43N 1704.42W 12.31 -2315.28 674359.21 5962698.01 9419.00 34.30 251.60 8685.08 2221.63N 1723.29W 38.55 -2313.53 674340.41 5962694.77' 9459.00 45.30 236.50 8715.84 2210.17N 1745.96W 36.45 -2303.33 674318.01 5962682.78 9499.00 58.60 220.90 8740.53 2189.24N 1769.19~ 45.11 -2283.73 674295.29 5962661.32 9540.00 66.50 198.30 8759.61 2157.80N 1786.75~ 52.45 -2253.30 674278.46 5962629.47 9580.00 74.00 176.40 8773.26 2120.75N 1791.36~ 54.75 -2216.56 674274.72 5962592.32 9609.00 84.00 173.40 8778.79 2092.43N 1788.82W 35.94 -2188.15 674277.93 5962564.08' 9669.00 90.00 179.00 8781.93 2032.70N 1784.86W 13.67 -2128.29 674283.28 5962504.46 9720.00 91.40 173.10 8781.31 1981.84N 1781.35~ 11.89 -2077.32 674287.98 5962453.70 9754.00 90.80 172.70 8780.66 1948.11N 1777.15~ 2.12 -2043.40 674292.97 5962420.08 9772.00 90.90 168.70 8780.39 1930.35N 1774.24~ 22.23 -2025.51 674296.29 5962402.40 9808.00 87.40 162.20 8780.92 1895.54N 1765.21W 20.50 -1990.25 674306.14 5962367.80 9839.00 88.50 154.20 8782.03 1866.80N 1753.71W 26.03 -1960.92 674318.31 5962339.34 9874.00 89.20 149.80 8782.74 1835.91N 1737.28~ 12.73 -1929.17 674335.45 5962308.85 9917.00 90.40 147.40 8782.89 1799.21N 1714.88~ 6.24 -1891.28 674358.70 5962272.69 9956.00 89.20 142.80 8783.02 1767.23N 1692.58~ 12.19 -1858.12 674381.75 5962241.24 10002.00 90.30 138.20 8783.22 1731.75N 1663.33~ 10.28 -1821.08 674411.82 5962206.45 10042.00 92.80 133.30 8782.14 1703.12N 1635.44W 13.75 -1790.95 674440.37 5962178.49 10089.00 88.70 137.80 8781.53 1669.58N 1602.54W 12.95 -1755.65 674474.04 5962145.73 10125.00 87.20 142.60 8782.81 1641.95N 1579.52W 13.96 -1726.78 674497.70 5962118.65 10161.00 91.70 143.10 8783.16 1613.27N 1557.78~ 12.58 -1696.94 674520.10 5962090.48 10191.00 95.20 149.10 8781.35 1588.43N 1541.09W 23.12 -1671.22 674537.37 5962066.04 10223.00 96.00 151.70 8778.23 1560.74N 1525.36W 8.46 -1642.70 674553.74 5962038.73 10267.00 96.80 159.00 8773.32 1521.03N 1507.13~ 16.59 -1602.04 674572.89 5961999.46 10299.00 94.20 159.80 8770.25 1491.21N 1495.93~ 8.50 -1571.65 674584.79 5961969.92 10332.00 92.90 162.70 8768.21 1460.03N 1485.34~ 9.61 -1539.93 674596.10 5961938.99 10373.00 94.40 169.30 8765.59 1420.35N 1475.45W 16.48 -1499.77 674606.92 5961899.56 10414.00 94.70 176.10 8762.34 1379.84N 1470.26~ 16.55 -1459.03 674613.06 5961859.18 10450.00 92.00 176.80 8760.23 1343.97N 1468.03W 7.75 -1423.09 674616.12 5961823.38 10499.00 87.60 174.20 8760.41 1295.14N 1464.19~ 10.43 -1374.12 674621.11 5961774.65 10530.00 89.70 175.20 8761.14 1264.28N 1461.33~ 7.50 -1343.15 674624.69 5961743.87 10566.00 90.00 178.70 8761.23 1228.34N 1459.41W 9.76 -1307.16 674627.45 5961707.99 10598.00 89.20 181.50 8761.45 1196.34N 1459.471~ 9.10 -1275.22 674628.14 5961676.00 10641.00 90.00 184.00 8761.75 1153.40N 1461.53~ 6.10 -1232.45 674627.08 5961633.02 10680.00 90.30 187.30 8761.65 1114.59N 1465.37Y 8.50 -1193.92 674624.16 5961594..14 10726.00 90.30 186.50 8761.41 1068.92N 1470.90W 1.74 -1148.63 674619.70 5961548.36 10762.00 89.40 186.70 8761.51 1033.16N 1475.03~ 2.56 -1113.15 674616.40 5961512.52 10789.00 88.90 189.60 8761.91 1006.44N 1478.86~ 10.90 -1086.68 674613.20 5961485.71 10831.00 84.70 187.00 8764.25 964.96N 1484.91W 11.76 -1045.60 674608.12 5961444.10 10855.00 84.60 183.20 8766.49 941.16N 1487.04~ 15.77 -1021.95 674606.55 5961420.27 10890.00 84.90 185.90 8769.69 906.42N 1489.80W 7.73 -987.42 674604.60 5961385.47 10923.00 85.40 184.00 8772.48 873.67N 1492.64~ 5.93 -954.87 674602.53 5961352.66 10955.00 85.40 184.70 8775.05 841.86N 1495.06~ 2.18 -923.25 674600.86 5961320.81 10986.00 86.60 187.30 8777.21 811.11N 1498.29~ 9.22 -892.72 674598.35 5961289.99 11020.00 84.50 191.00 8779.85 777.65N 1503.68~ 12.48 -859.61 674593.75 5961256.42 ALL data in feet unless otherwise stated. CaLculation uses minimum curvature method. Coordinates from 15-06 and TVD from rkb - MSL = 63ft. Bottom hole distance is 1724.58 on azimuth 288.62 degrees from wellhead. Vertical section is from wellhead on azimuth 176.83 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. D.S. 15,15-06A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : 15-06A Last revised : 16-Mar-99 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R ! D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOft Sect Easting Northing 11054.00 85.10 193.60 8782.93 744.57N 1510.8914 7.82 -826.98 674587.31 5961223.18 11086.00 86.20 198.40 8785.36 713.91N 1519.6914 15.35 -796.85 674579.24 5961192.32 11115.00 85.40 205.40 8787.49 687.09N 1530.4714 24.23 -770.67 674569.09 5961165.26 11142.00 82.90 211.10 8790.24 663~44N 1543.171.1 22.95 -747.76 674556.94 5961141.32 11176.00 84.50 213.30 8793.97 634.85N 1561.18W 7.97 -720.21 674539.61 5961112.32 11208.00 85.00 220.30 8796.90 609.35N 1580.25W 21.84 -695.80 11238.00 85.60 221.50 8799.36 586.75N 1599.83~ 4.46 -674.32 11249.00 85.60 224.00 8800.21 578.70N 1607.2714 22.66 -666.69 11288.00 85.60 224.00 8803.20 550.72N 1634.291.1 0.00 -640.26 674521.14 5961086.38 674502.10 5961063.33 674494.84 5961055.11 674468.50 5961026.51 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 15-06 and TVO from rkb - MSL = 63ft. Bottom hole distance is 1724.58 on azimuth 288.62 degrees from wellhead. Vertical section is from wellhead on azimuth 176.83 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Ataska, Inc. D.S. 15,15-06A Prudhoe Bay, North SLope, ALaska SURVEY LISTING Page Your ref : 15-06A Last revised : 16-Mar-~9 Targets associated with this wettpath Target name Geographic Location T.V.D. RectanguLar Coordinates Revised 15-06Aehs 674565.000,59605-/5.000,999.00 8820.00 97.05N 1548.3714 8-Dec-98 15-06Abhs 674410.000,5952280.000,999.00 8765.00 1805.32N 1663.42W 8-Dec-98 ARCO Alaska, Iz c. Structure · D.S. 15 Slot : 15-06 Field · Prudhoe Bay Location · North Slope, Alaska <- West (feet) 3000 28o0 2~00 240o 220o 2o00 1800 1.00 1400 1200 1000 8oo 600 400 I I I I I I I I I I I I I I I I I I I I I I ! I I I I I Created by plonnar Dote plotted: 16-Mor-99 Plot Reference ia 15-06A Version Coordinates are In feet reference 15-06. True Vertical Depths are refecence rk~ - MSL - 6~ft. --- Baker Hughes INTEO --- Tie on - 8479.11 Tvd, 2197.82 N. 1664.57 W t2400 2200 ORIGINAL RECEI'VED ~ ] 8 1999 Alask~ C~I & Gas Cons. Commission ~no~o~ 15-06Abhs "4-- 8000- 8200- r-~ 8400 8600 -.4=- 8800 I V 23.88 Inc, 9200.00 Md, 8479.11 Tvd, -2286.50 Vs 15-06Abhs =._____.._ ~ J 15-06A J J 15-06PB'j Plan]' 15-06Aehs · 15-06Aehs 9000 9200 i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i ii i i i i 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 400 600 800 Vertical Section (feet) -> Azimuth 176.83 with reference 0.00 S, 0.00 E from 15-06 2000 ' 1800 1 600 1400 1200 1000 800 600 400 2O0 ARCO Alaska, Inc. D.S. 15 15-06A 15-06 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 15-06A Plugback Our ref : svy83 License :API 500292074270 Date printed : 16-Mar-99 Date created : 16-Mar-99 Last revised : 16-Mar-99 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 675901.341,5961480.369,999.00000,N Slot location is nTO 17 51.767, w148 34 25.367 Slot Grid coordinates are N 5960514.230, E 676115.120 Slot local coordinates are 970.94 S 191.12 E Projection type: alaska - Zone 4, Spheroid: Ctarke - 1866 Reference North is True North ORIGINAL RECEIV .ED ~,~AR 18 1999 ARCO Alaska, Inc. D.S. 15,15-06A Prudhoe Bay,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 9200.00 23.88 325.93 8479.11 2197,82N 1664.57~4 9235.00 17.20 325.00 8511.86 2207.94N 1671.52W 9259.00 11.00 328.70 8535.13 2212,81N 1674.74W 9299.00 11.80 306.80 8574.36 2218~52N 1680.00~ 9340.00 19.60 281.30 8613.84 2222.39N 1690.13~ SURVEY LISTING Page 1 Your ref : 15-06A Ptugback Last revised : 16-Mar-99 Dogleg Vert G R ! D C 0 0 R D S Deg/lOOft Sect Easting Northing 0.40 -2286.50 674399.67 5962672,34 19.11 -2296.99 674392.49 5962682.29 26,09 -2302.03 674389.15 5962687,08 10,94 -2308.03 674383.75 5962692,67 24.98 -2312.45 674373.54 5962696.30 9379.00 23.90 275.50 8650.06 2224,43N 1704.42~ 12,31 -2315.28 674359.21 5962698.01 9419.00 34.30 251.60 8685.08 2221.63N 1723.29t~ 38,55 -2313.53 674340.41 5962694.77 9459.00 45.30 236.50 8715.84 2210.17N 1745.96~ 36.45 -2303.33 674318.01 5962682.78 9499.00 58.60 220.90 8740.53 2189,24N 1769.1914 45.11 -2283.73 674295.29 5962661.32 9540.00 66.50 198.30 8759.61 2157,80N 1786.75W 52,45 -2253.30 674278,46 5962629,47 9580.00 74.00 176.40 8773.26 2120,75N 1791.36~ 9609.00 84.00 173.40 8778.79 2092.43N 1788.82~ 9669.00 90.00 179.00 8781.93 2032.70N 1784.86~ 9720.00 91.40 173.10 8781.31 1981.84N 1781.35~ 9754.00 90.80 172.70 8780.66 1948.11N 1777.15W 9772.00 90.90 168.70 8780.39 1930.35N 1774.24W 9808.00 87.40 162.20 8780.92 1895.54N 1765.21~ 9868.00 88.00 157.90 8783.33 1839.20N 1744.75~ 9927.00 93.10 161.20 8782.77 1783.94N 1724.15~ 9955.00 92.90 156.90 8781.30 1757.84N 1714.15W 54,75 -2216.56 674274.72 5962592.32 35.94 -2188.15 674277.93 5962564.08 13,67 -2128.29 674283.28 5962504.46 11,89 -2077.32 674287.98 5962453.70 2.12 -2043.40 674292.97 5962420.08 22,23 -2025.51 674296.29 5962402.40 20.50 -1990.25 674306.14 5962367.80 7.23 -1932.86 674327.91 5962311.96 10.29 -1876.56 674349.80 5962257.21 15.35 -1849.94 674360.40 5962231.34 10008.00 90.70 164.80 8779.63 1707.84N 1696.79W 15.46 -1799.05 674378.92 5962181.77 10068.00 90.60 169.80 8778.95 1649.33N 1683.61~ 8.33 -1739.90 674393.48 5962123.59 10111.00 89.40 175.50 8778.95 1606.70N 1678.11~ 13.55 -1697.04 674399.97 5962081.10 10160.00 86.80 174.80 8780.58 1557.90N 1673.97~ 5.49 -1648.09 674405.25 5962032.42 10202.00 85.00 171.30 8783.58 1516.33N 1668.90~ 9.35 -1606.30 674411.29 5961990.98 10235.00 85.90 169.90 8786.20 1483.87N 1663.53W 5.03 -1573.59 674417.42 5961958.66 10286.00 83.80 166.80 8790.78 1434.14N 1653.28W 7.32 -1523.36 674428.83 5961909.18 10327.00 84.30 162.60 8795.03 1394.81N 1642.52W 10.26 -1483.51 674440.51 5961870.12 10369.00 84.80 166.10 8799.02 1354.56N 1631.24~ 8.38 -1442.69 674452.72 5961830.14 10426.00 85.90 164.00 8803.64 1299.67N 1616.59~ 4.15 -1387.08 674468.66 5961775.62 10474.00 86.60 163.50 8806.78 1253.69N 1603.18W 1.79 -1340.42 674483.13 5961729.97 10505.00 88.90 166.40 8808.00 1223.78N 1595.14W 11.93 -1310.12 674491.87 5961700.26 10542.00 93.20 166.20 8807.32 1187.85N 1586.38~ 11.63 -1273.75 674501.47 5961664.54 All data in feet unless otherwise stated, Calculation uses minimum curvature method. Coordinates from 15-06 and TVD from rkb - MSL = 63ft. Bottom hole distance is 1981.81 on azimuth 306.83 degrees from wellhead. Vertical section is from wellhead on azimuth 176.83 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes [NTEQ ARCO Ataska, [nc. D.S. 15,15-06A Prudhoe Bay,North Stope, Alaska SURVEY LISTING Page 2 Your ref : 15-06A PLugback Last revised : 16-Mar-~ Targets associated with this wettpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 15-06Aehs 674565.000,.5960575.000,~)~c).00 8820.00 97.05N 1548.3714 8-Dec-98 15-06Abhs 67~10.000,5~62280.000,~.00 8765.00 1805.32N 166~.~2W 8-0ec-98 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenso~ DATE: Chairman February 27, 1999 THRU: Blair Wondzell, .~~ FILE NO: agpglgf. DOC P. I. Supervisor FROM: Lawrence M Wade=~~¢' SUBJECT: Petroleum Inspector BOP Test Nabors 3S PBU DS 15-06A PTD 98-254 F. ebruary 27,1999: I traveled to ARCO's DS 15 to witness a BOP test on Nabors/Doweil coil tubing drilling rig. This is their second well on the same pad and the rig looked to be clean and well stocked with tools from rigs that have recently been stacked out. While inspecting the rig and stack i found a~loc, k 90_ on the kill line upstream of the manuals installed backwards. I showed it to the driller and he is to change it. The BOP test went well as all the valves were serviced prior to the test. SUMMARY: Witnessed a BOP test on Nabors 3S, {~ failures, 3.5 hours. Attachments: agpgblgf, xIs cc; NON-CONFIDENTIAL .. STATE OF ALASKA .... , OIL AND GAS CONSERVATION COMMISSION Coil Tubing Unit BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7 Test: Initial X Workover: DATE: Nabors/Dowell Rig No. 3S PTD # 98-254 Rig Ph.# ARCO Rep.: Ga~ Goodrich DS15-11 Rig Rep.: Set @ 9,620 Location: Sec. 22 T. Weekly X Other 2./27/99 Dave Duerr 11N R. 14E Meddian Umiat BOP STACK: Coil Tubinq Unit: Pipe/Slip Rams Pipe/Slip Rams Blind Rams ~eel Isolation Valve Deploy ,ment: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Test Test Quan. Pressure P/F Pressure 250/3000 250/3000 P 250/3000 P 250/3000 P 1 1 1 25012500 P 1 250/3000 P I 250/3000 P I 250/3000 P 1 250/3000 P 2 250/3000 P CHOKE MANIFOLD: Quan. No. Valves No. Flanges 22 Manual Chokes Hydraulic Chokes ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 ~ 2250 250/3000 Funcb~ned Func~oned P/F P P P P 3,000 2,200 minutes 8 sec. minutes 33 sec. , X Remote: X Psig. MUD SYSTEM: Visual Alarm MISC. INSPECTIONS: Trip Tank X X Location Gen.: ok Pit Level Indicators X X Housekeeping: ok Moth Gas Detector X X Permit to ddll: X H2S Gas Detector X X Standing Order Posted X Well Sign X Drl. Rig X Hazard Sec. X Number of Failures: [ O~ ,Test Time: 3.,5 Hours. Number of valves tested '/7 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your call is not returned by the inspector within 12 hours please contact the P. !. Supervisor at 279-1433 II II REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade Form Revised 2/20/97 L.G. agpgblgf, xls 313/99 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Januars., 7, 1999 Bruce Smith Arco Coil Tubing Drilling Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Prudhoe Bay Unit 15-06A ARCO Alaska, Inc. Permit No: 98-254 Sur Loc: 971'FNL, 189'FWL, Sec. 22, TllN, R14E, UM Btmhole Loc. 723'FNL, 3776'FWL, Sec. 21, T1 IN, R14E, UM Dear Mr. Smith: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincer~~ ,/~ / Robert N. Christenson, P. E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . STATE OF ALASKA ALASKAO/L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Alaska 0i! & Gas Cons. C0mmisskm la. Type of work: Drill __ Redrill __X [ lb. Type of well. Exploratory __ Stratigraphic Test __ Development Oil __X Re-entry __ Deepen __[ Service __ Development Gas __ Single Zone ~X Multiple Zone _ 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 63 feet 3. Address 6. Property Designation Prudhoe Bay Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL28306 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 971' FNL, 189' FWL, SEC. 22, T11 N, R14E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 1143FSL, 1417' FEL, SEC. 16, T11N, R14E, UM 15-06A #U-630610 At total depth 9. Approximate spud date Amount 723' FNL, 3776' FWL, Sec 21, T11N, R14E, UM January 15, ~ J ¢i~;¢~V~0 $200.000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) feetI No Close Approach feet 11702' MD /8908' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth: 9230' MD Maximum hole angle 90° Maximum surface 2500 psig At total depth ('I-VD) 3300 psig @ 8800' 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD -I-VD MD TVD (include stage data) 2-3/4" 2-3/8" 4.6 L-80 FL4S 3252' 8450' 7859' 11702' 8908' 13 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 9620 feet Plugs (measured) PBTD tagged @ 9554' MD (5/08/98) tree vedical 8928 feet Effective Depth: measured 9554 feet Junk (measured) true vertical 8867 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 20" 375 Sx Permafrost II 110' 110' Surface 2569' 13-3/8" 2000 Sx Fondu & 400 Sx PFC 2597' 2597' Production 8807' 9-5/8" 600 Sx Class G & 50 bbls PFC 8835' 8210' Scab Liner 3527' 7"/4-1/2" 488 Sx Class G 9603' 8912' Liner 1085' 7" 350 Sx Class G 9620' 8928' Perforation depth: measured 9490' - 9510'; 9532' - 9535'; 9542'- 9546'. truevertica, 8808'- 8826'; 8847'-8849'; 8856'- 8860'. (¢) I G I N A L 20. Attachments Filing fee __X Property Plat __ BOP Sketch ~X Diverter Sketch __ Drilling program _X Drilling fluid program __ Time vs depth plot __ Refraction analysis __ Seabed report __ 20 AAC 25.050 requirements __ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Dan Kara@ 263-4837. Signed ~~ 0~' ~~ ""~,.~,~ Title Arco CoilTubing Drilling Supervisor Date' Bruce Smith Prepared by Paul Rauf 263-4990. Commission Use Onl,~ Permit Number [ AP. number [ Approvaldate~ [Seecoverletter ~- ~__..~"/--~/ 50- O.~-..-,? - Z O ~'5'/'~_.-O,] 1.-~ ~'""'~¢ Ifor other requirements Conditions of approval Samples required __ Yes ~'No Mud log required __ Yes __"~No Hydrogen sulfide measures __ Yes ~' No Directional survey required ~"Yes __ No Required working pressure for BOPE __2,; __3M; __5,; __ 10M: __ 15M (X 3.500 pSi for (~TU) __ Other: ORIGINAL SIGNED.By by order of Approved by J~°be~ N- ChJ"J$[e,soi~ Commissioner the commission Date /" Form 10-401 Rev. 12/1/85 · Submit in triplicate DS 15-06A CT Sidetrack and Completion Intended Procedure Objective: Install mechanical whi[stock. P&A well with 15.8 ppg cement. Mill window from whipstock. Directionally drill a horizontal well from the existing wellbore. Complete with 2-3/8" cemented liner. Perforate appropriate intervals. Intended Procedure: · Install mechanical whipstock at 9230'. P&A existing perfs with 15.8 ppg cement. Bullhead cement below whipstock. Clean out cement to whipstock tray. Mill 2-string window in 4-1/2" and 7" liners at 9230' md. Drill 10' of formation and perform Leak off test to 9.0 ppg, 0.5 ppg above the highest anticipated mud weight (8.5 ppg FloPro). Directionally drill 2-3/4" x -2470' horizontal well to access Romeo reserves. · Run 2-3/8" blank liner to TD, cement in place. · Perforate, place on production. Drilling fluids will be injected into disposal wells at Pad 3 or CC2A. December 10, 1998 DS 15-06A Potential Drilling Hazards POST ON RIG No H2S gas production has been measured. BHP: 3400 psi @ 8800' ss (7.4 ppg EMW), BHT 190 °F (estimated values based on offset wells). No over pressured zones are anticipated. Maximum anticipated WHP w/full column of gas: 2500 psi. Gas saturated intervals are expected in build section. No major faults or loss circulation zones are anticipated. December 10, 1998 DS 15-06A Proposed CT Sidetrack Horizontal 7" Scab Liner 4966'-8493' 7" Liner Top @ 8353' 3-1/2" XN Nipple @ 847~ 3-1/2" Tbg Tail @ 8502' 3-1/2" 3-1/2" Otis SSSVN @ 2195' 3-1/2" x 7" Packer @ 8412' --4-1/2" Scab Liner Top @ 8493' 9-5/8" Shoe @ 8835' Top of 2-3/8" Liner in 3-1/2" tail Initial Perfs 2-3/4" Open hole Window cut in 4-1/2" & 7" liner at -,9230' TD @ - 11702' 4-1/2" Scab Liner Shoe 9603' 7" Liner Shoe @ 9620' Current perforations :ement squeezed 2-3/8" liner, cemented Drilling Wellhead Detail ~ CT Injector Head Methanol Injection ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ I -- 7" Riser Otis 7" WLA , , Quick Connect ~ I Annular BOP (Hydril),7-1/16" ID 5000 psi WP Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE ~- Flanged Fire Resistant Man Kelly Hose to Dual HCR Choke Manifold Cutters or Combination Cutter/Blinds Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Tubing Hanger 9-5/8" Annulus 13-3/8" Annulus ARCO Alaska Inc $1oi : 15-06 Locotion ' North Slope, Alosko Structure : D.S. 15 Field : Prudhoe Bay <- West (feet) 2800 2600 24 O0 2200 2000 1800 1600 1400 1200 1000 800 600 400 Created by planner Dote plotted: 10-Bec-98 Plot Reference ia 15-06A Version #2. Coordinates or~ in f~¢t rc¢crcnc~ 15-06. True Verticol Depths ore reference rkb - MSL ,- 63ft. --- Baker Hughes INTEQ 8000 8200 840O .-- 8600 I v KOP - 9230 MD, 8506.55 TVDss / T.D. & End of Drop - 8845.0D Tvd, 250.00 N, 1695.00 W ~ 15-06Aehs 23.88 Inc, 9200.00 Md, 8479.11 Tvd, -2286.50 Vs /~ KOP - 9230 MD, 8506.55 TVDss [ / ._....~ 3 - 8780' TVDss 8800 15-06Aehs 15-06Abhs 9000 T.D. & End of Drop/Turn - 86.96 tnc, 11 701.64 Md, 8845.00 Tvd, -343.35 Vs 9200 i I I I ] ...... %"-"--1 ...... I I I I T I I I' I I I I ] 1 .... I ] 1 ...... l I I I I I I I I I I l"-'"-"q-----} I I I 2800 2600 24.00 2200 2000 1800 1600 14.00 1200 1000 800 600 400 200 0 200 400 600 800 1000 1200 Verticc~l Section (feet) Azimuth 176.83 with reference 0.00 S, 0.00 E from 15-06 2400 22OO 2O0O 1800 1600 1400 1200 1000 800 6OO 4OO 200 ARCO Alaska, Inc. D.S. 15 15-06 Prudhoe Bay North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 15-06A Version #2 Our ref : prop123 License : Date printed : 10-Dec-98 Date created : 8-Dec-98 Last revised : 10-Dec-98 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 675901.341,5961480.369,999.00000,N Slot location is nT0 17 51.767,w148 34 25.367 Slot Grid coordinates are N 5960514.230, E 676115.120 Slot local coordinates are 970.94 S 191.12 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. D.S. 15,15-06 Prudhoe Bay,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 9200.00 23.88 325.93 8479.11 2197.82N 1664.57W 9225.00 23.80 326.07 8501.97 2206.20N 1670.22W 9230.00 23.79 326.10 8506.55 2207.87N 1671.35W 9250.00 26.84 315.09 8524.64 2214.42N 1676.79W 9275.00 31.59 304.50 8546.46 2222.14N 1686.18W PROPOSA~L LISTING Page 1 Your ref : 15-06A Version #2 Last revised : 10-Dec-98 Dogleg Vert G R I D C 0 0 R D S Deg/100ft Sect Easting Northing 0.00 -2286.50 674399.67 5962672.34 0.38 -2295.18 674393.82 5962680.58 0.38 -2296.92 674392.66 5962682.23 28.00 -2303.76 674387.06 5962688.65 28.00 -2311.98 674377.49 5962696.15 9300.00 36.99 296.58 8567.12 2229.22N 1698.32W 9325.00 42.80 290.48 8586.30 2235.57N 1713.02W 9350.00 48.87 285.61 8603.71 2241.08N 1730.07W 9375.00 55.11 281.57 8619.11 2245.67N 1749.20W 9400.00 61.47 278.12 8632.24 2249.29N 1770.15W 9425.00 67.90 275.06 8642.93 2251.86N 9450.00 74.38 272.27 8651.01 2253.36N 9471.56 80.00 270.00 8655.79 2253.77N 9475.00 79.76 269.05 8656.39 2253.74N 9500.00 78.08 262.13 8661.20 2251.86N 28.00 -2319.72 674365.19 5962702.94 28.00 -2326.87 674350.35 5962708.94 28.00 -2333.32 674333.18 5962714.05 28.00 -2338.96 674313.94 5962718.20 28.00 -2343.73 674292.92 5962721.32 1792.58W 28.00 -2347.54 674270.43 5962723.37 1816.18W 28.00 -2350.34 674246.81 5962724.31 1837.19W 28.00 -2351.91 674225.80 5962724.23 1840.57W 28.00 -2352.07 674222.41 5962724.12 1865.02W 28.00 -2351.55 674198.02 5962721.67 9525.00 76.58 255.12 8666.69 2247.06N 1888.91W 28.00 -2348.07 9550.00 75.27 248.03 8672.78 2239.40N 1911.90W 28.00 -2341.70 9575.00 74.17 240.86 8679.38 2229.01N 1933.65W 28.00 -2332.53 9600.00 73.32 233.63 8686.38 2216.04N 1953.82W 28.00 -2320.69 9625.00 72.72 226.33 8693.69 2200.68N 1972.12W 28.00 -2306.37 9650.00 72.38 219.00 8701.20 2183.16N 1988.27W 28.00 -2289.76 9675.00 72.32 211.66 8708.79 2163.74N 2002.03W 28.00 -2271.14 9700.00 72.52 204.32 8716.35 2142.71N 2013.21W 28.00 -2250.76 9725.00 73.00 197.00 8723.77 2120.39N 2021.62W 28.00 -2228.93 9750.00 73.73 189.74 8730.94 2097.10N 2027.16W 28.00 -2205.99 9775.00 74.71 182.54 8737.74 2073.20N 2029.72W 28.00 -2182.27 9800.00 75.92 175.41 8744.09 2049.04N 2029.28W 28.00 -2158.12 9825.00 77.33 168.36 8749.88 2024.98N 2025.85W 28.00 -2133.90 9850.00 78.93 161.39 8755.03 2001.38N 2019.46W 28.00 -2109.99 9875.00 80.68 154.51 8759.46 1978.59N 2010.23W 28.00 -2086.72 9900.00 82.57 147.69 8763.11 1956.95N 1998.28W 28.00 -2064.46 9918.13 84.00 142.79 8765.23 1942.16N 1988.02W 28.00 -2049.12 9925.00 84.14 143.02 8765.94 1936.71N 1983.90W 4.00 -2043.45 9950.00 84.67 143.88 8768.37 1916.72N 1969.08W 4.00 -2022.68 9975.00 85.20 144.73 8770.58 1896.50N 1954.55W 4.00 -2001.68 10000.00 85.73 145.58 8772.55 1876.05N 1940.31W 4.00 -1980.47 10025.00 86.27 146.43 8774.30 1855.37N 1926.37W 4.00 -1959.06 10050.00 86.80 147.27 8775.81 1834.48N 1912.72W 4.00 -1937.44 10075.00 87.33 148.12 8777.09 1813.38N 1899.38W 4.00 -1915.63 10100.00 87.86 148.97 8778.14 1792.07N 1886.35W 4.00 -1893.64 10125.00 88.40 149.81 8778.95 1770.56N 1873.62W 4.00 -1871.46 10150.00 88.93 150.66 8779.54 1748.87N 1861.22W 4.00 -1849.11 10175.00 89.47 151.50 8779.88 1726.99N 1849.13W 4.00 -1826.60 10199.92 90.00 152.35 8780.00 1705.00N 1837.40W 4.00 -1804.00 10200.00 90.00 152.35 8780.00 1704.93N 1837.36W 3.00 -1803.92 10225.00 89.64 153.00 8780.08 1682.72N 1825.89W 3.00 -1781.11 10250.00 89.28 153.66 8780.31 1660.38N 1814.67W 3.00 -1758.19 10275.00 88.92 154.32 8780.71 1637.91N 1803.71W 3.00 -1735.15 10300.00 88.56 154.98 8781.26 1615.33N 1793.01W 3.00 -1712.01 10325.00 88.20 155.64 8781.97 1592.62N 1782.57W 3.00 -1688.76 674174.25 5962716.31 674151.44 5962708.12 674129.95 5962697.22 674110.09 5962683.78 674092.16 5962668.00 674076.42 5962650.11 674063.12 5962630.37 674052.44 5962609.09 674044.55 5962586.57 674039.56 5962563.17 674037.56 5962539.21 674038.56 5962515.07 674042.56 5962491.10 674049.49 5962467.66 674059.26 5962445.09 674071.71 5962423.74 674082.31 5962409.20 674086.56 5962403.85 674101.84 5962384.21 674116.84 5962364.34 674131.55 5962344.22 674145.97 5962323.88 674160.10 5962303.31 674173.94 5962282.53 674187.46 5962261.54 674200.69 5962240.34 674213.60 5962218.94 674226.19 5962197.35 674238.43 5962175.64 674238.47 5962175.57 674250.46 5962153.64 674262.20 5962131.57 674273.68 5962109.37 674284.91 5962087.04 674295.88 5962064.59 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 15-06 and TVD from rkb - MSL = 63ft. Bottom hole distance is 1713.34 on azimuth 278.39 degrees from wellhead. Vertical section is from wellhead on azimuth 176.83 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. D.S. 15,15-06 Prudhoe Bay,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 15-06A Version #2 Last revised : 10-Dec-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O 0 R D S Depth Degrees Degrees Depth C 0 © R D I N A T E S Deg/100ft Sect Easting Northing 10338.79 88.00 156.00 8782.42 1580.05N 1776.92W 3.00 -1675.89 674301.82 5962052.15 10350.00 87.99 156.34 8782.82 1569.80N 1772.39W 3.00 -1665.41 674306.58 5962042.01 10375.00 87.96 157.09 8783.70 1546.85N 1762.52W 3.00 -1641.95 674316.99 5962019.30 10400.00 87.93 157.84 8784.60 1523.78N 1752.94W 3.00 -1618.38 674327.10 5961996.46 10425.00 87.90 158.59 8785.51 1500.58N 1743.67W 3.00 -1594.70 674336.92 5961973.48 10450.00 87.87 159.34 8786.43 1477.26N 1734.70W 3.00 -1570.93 674346.43 5961950.38 10475.00 87.84 160.09 8787.37 1453.83N 1726.04W 3.00 -1547.05 674355.63 5961927.16 10500.00 87.81 160.84 8788.32 1430.28N 1717.69W 3.00 -1523.08 674364.53 5961903.82 10525.00 87.78 161.59 8789.28 1406.63N 1709.64W 3.00 -1499.02 674373.13 5961880.37 10550.00 87.75 162.34 8790.25 1382.88N 1701.91W 3.00 -1474.88 674381.41 5961856.80 10575.00 87.73 163.10 8791.24 1359.03N 1694.49W 3.00 -1450.65 674389.39 5961833.13 10600.00 87.70 163.85 8792.24 1335.08N 1687.38W 3.00 -1426.35 674397.06 5961809.36 10625.00 87.67 164.60 8793.25 1311.04N 1680.59W 3.00 -1401.97 674404.41 5961785.49 10650.00 87.65 165.35 8794.27 1286.92N 1674.12W 3.00 -1377.52 674411.45 5961761.52 10675.00 87.62 166.10 8795.30 1262.71N 1667.96W 3.00 -1353.01 674418.17 5961737.47 10700.00 87.60 166.85 8796.34 1238.42N 1662.12W 3.00 -1328.44 674424.58 5961713.33 10725.00 87.57 167.60 8797.39 1214.06N 1656.59W 3.00 -1303.81 674430.67 5961689.10 10750.00 87.55 168.35 8798.46 1189.63N 1651.39W 3.00 -1279.13 674436.44 5961664.80 10775.00 87.52 169.10 8799.53 1165.14N 1646.51W 3.00 -1254.41 674441.90 5961640.43 10800.00 87.50 169.86 8800.62 1140.58N 1641.95W 3.00 -1229.63 674447.03 5961615.99 10825.00 87.48 170.61 8801.71 1115.97N 1637.71W 3.00 -1204.82 674451.84 5961591.48 10850.00 87.45 171.36 8802.82 1091.30N 1633.80W 3.00 -1179.98 674456.33 5961566.92 10875.00 87.43 172.11 8803.93 1066.59N 1630.21W 3.00 -1155.10 674460.50 5961542.29 10900.00 87.41 172.86 8805.06 1041.83N 1626.94W 3.00 -1130.20 674464.34 5961517.62 10925.00 87.39 173.61 8806.19 1017.03N 1624.00W 3.00 -1105.27 674467.86 5961492.90 10950.00 87.37 174.36 8807.34 992.19N 1621.39W 3.00 -1080.33 674471.06 5961468.13 10975.00 87.35 175.12 8808.49 967.32N 1619.10W 3.00 -1055.37 674473.93 5961443.32 11000.00 87.33 175.87 8809.65 942.43N 1617.13W 3.00 -1030.41 674476.47 5961418.48 11025.00 87.31 176.62 8810.82 917.51N 1615.50W 3.00 -1005.44 674478.69 5961393.61 11050.00 87.29 177.37 8812.00 892.57N 1614.19W 3.00 -980.47 674480.59 5961368.71 11075.00 87.27 178.12 8813.19 867.62N 1613.21W 3.00 -955.50 674482.15 5961343.79 11100.00 87.25 178.87 8814.38 842.65N 1612.55W 3.00 -930.54 674483.39 5961318.85 11125.00 87.23 179.63 8815.58 817.69N 1612.23W 3.00 -905.59 674484.30 5961293.90 11150.00 87.22 180.38 8816.79 792.72N 1612.23W 3.00 -880.66 674484.88 5961268.94 11175.00 87.20 181.13 8818.01 767.75N 1612.55W 3.00 -855.74 674485.14 5961243.97 11200.00 87.18 181.88 8819.24 742.79N 1613.21W 3.00 -830.86 674485.07 5961219.00 11225.00 87.17 182.63 8820.47 717.84N 1614.19W 3.00 -806.00 674484.67 5961194.04 11250.00 87.15 183.38 8821.71 692.90N 1615.50W 3.00 -781.18 674483.94 5961169.08 11275.00 87.14 184.14 8822.95 667.99N 1617.14W 3.00 -756.39 674482.89 5961144.14 11300.00 87.12 184.89 8824.20 643.09N 1619.11W 3.00 -731.64 674481.51 5961119.21 11325.00 87.11 185.64 8825.46 618.23N 1621.40W 3.00 -706.95 674479.80 5961094.30 11350.00 87.10 186.39 8826.72 593.40N 1624.01W 3.00 -682.30 674477.77 5961069.42 11375.00 87.08 187.14 8827.99 568.61N 1626.96W 3.00 -657.71 674475.41 5961044.56 11400.00 87.07 187.90 8829.27 543.86N 1630.22W 3.00 -633.17 674472.72 5961019.74 11425.00 87.06 188.65 8830.55 519.15N 1633.81W 3.00 -608.70 674469.71 5960994.96 11450.00 87.05 189.40 8831.83 494.49N 1637.73W 3.00 -584.30 674466.37 5960970.22 11475.00 87.04 190.15 8833.12 469.89N 1641.97W 3.00 -559.97 674462.71 5960945.52 11500.00 87.03 190.90 8834.42 445.34N 1646.53W 3.00 -535.71 674458.72 5960920.88 11525.00 87.02 191.65 8835.72 420.86N 1651.41W 3.00 -511.53 674454.42 5960896.29 11550.00 87.01 192.41 8837.02 396.44N 1656.62W 3.00 -487.44 674449.78 5960871.76 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 15-06 and TVD from rkb - MSL = 63ft. Bottom hole distance is 1713.34 on azimuth 278.39 degrees from wellhead. Vertical section is from wellhead on azimuth 176.83 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. D.S. 15,15-06 Prudhoe Bay,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 3 Your ref : 15-06A Version #2 Last revised : 10-Dec-98 Dogleg Vert G R I D C 0 0 R D S Deg/100ft Sect Easting Northing 11575.00 87.00 193.16 8838.33 372.09N 1662.14W 3.00 -463.44 674444.83 5960847.29 11600.00 86.99 193.91 8839.64 347.82N 1667.98W 3.00 -439.52 674439.56 5960822.89 11625.00 86.98 194.66 8840.95 323.63N 1674.14W 3.00 -415.71 674433.97 5960798.56 11650.00 86.98 195.41 8842.27 299.52N 1680.62W 3.00 -391.99 674428.06 5960774.31 11675.00 86.97 196.17 8843.59 275.49N 1687.42W 3.00 -368.38 674421.83 5960750.13 11700.00 86.96 196.92 8844.91 251.56N 1694.52W 3.00 -344.88 674415.28 5960726.04 11701.64 86.96 196.97 8845.00 250.00N 1695.00W 3.00 -343.35 674414.84 5960724.47 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 15-06 and TVD from rkb - MSL = 63ft. Bottom hole distance is 1713.34 on azimuth 278.39 degrees from wellhead. Vertical section is from wellhead on azimuth 176.83 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. D.S. 15,15-06 Prudhoe Bay,North Slope, Alaska PROPOSAL LISTING Page 4 Your ref : 15-06A Version #2 Last revised : 10-Dec-98 Comments in wellpath MD TVD Rectangular Coords. Comment 9230.00 8506.55 2207.87N 1671.35W KOP - 9230 MD, 8506.55 TVDss 10199.92 8780.00 1705.00N 1837.40W 3 - 8780' TVDss Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 15-06/kbhs 674410.000,5962280.000,999.00 8780.00 1805.32N 1663.42W 8-Dec-98 15-06Aehs 674565.000,5960575.000,999.00 8845.00 97.05N 1548.37W 8-Dec-98 ARCO Alaska, Inc..~' ¢~c~,,~¢,: AAI PAYABLES Date: :1.:2/10/98 Page of00100069~3 0 0 6 9 3 P.O. Box 102776 Pay Entity: Vendor #: Anchorage, AK 99510 0201 N00072020221 12/10/ 98 VR121098SJ}{01 Cll5P 129 B SJH 100 . 00 100 . 00 FILING FEE FOR PERMIT TO )RILL CTD S£DETRACK ELL 15-06A . :,-:;',:~: 7 100.00 100.00 Questions regarding this remittance can be made by calling or writing: FRT 907/265-6904 P.O. BOX 103560, Anchorage, AK 99510-3560 MATLS 907/265-6904 P.O. BOX 103560, Anchorage, AK 99510-3560 SVCS 907/265-6080 P.O. BOX 103240, Anchorage, AK 99510-3240 DIAL 907/263-4422 Detach check before depositing .... .... (*'Amount Not To Exceed /i25,000.00") ' ' ' '. :' '" ' 12-10-98 **************100.00' TO the order of: ALASKA DEPT OF REVENUE Date ' Amount ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE . Void after-90 days .. ANCHORAGE AK 99501 '. -: .' . -- -- ' '~ ' ' . · · ..... ' ~: . ~' .T~:O:~ignatures r~uired ....... ~' ..... ' -. - - . . -. : -:.- . ' ~-:: ' : . - fo~'.am~unt~ 'ove~ $~,00t1.~0.' . ' i--- ' '-" - co pyE~l~+ ~i'~I~R ~[.I O pROT~ON. PATENTS 4 21D~: 4~7.720:4.3 ~0.1 ~0; 5.t ~?.755: ~.3~.1'5~ ...- - . ,.ooooloor=qs,. ,:OP. -% qO L, ~ F= 2.: O q qOOOO"" WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION 1. _WELL NAME /~..4 /'5'?'~/"'~,~. PROGRAM: exp [] dev~[~redrll~serv r-I wellbore segil ann. disposal para reql, · GEOL AREA UNIT# ON/OFF SHORE o ,"'-) .... Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well Iocaled proper dislance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unil ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... N N N N Y ~ ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMl- vol adequate to circulate on conductor & surf csg ..... 17. CMI vol adequate to tie-in long string to su[f csg ........ 18. CM I' will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to _";J ~ O .psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. APPR DATE Permit can be issued w/o hydrogen sulfide measures ..... Dala presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ..... ' ........ Seabed condition survey (if off-shore) ............. Con, tact,nam, elphon,e .for weekly progress reports ....... lexpmrarory omyj GEOLOGY 3O. 31. 32. 33. /~I:)R I~A)'E_. 34. ANNULAR DISPOSAL 35. ~N Y® With proper cementing records, this plan (A) will contain_waste in a suitable receiving zo ,~,~. ...... (B) will not conta~reshwater; or~rilling waste... to surface; (C) will not imp~a~~e well used for disposal; (D) will nol d~malion or ,-i'i'~.recovery from a pool; anjJ, (E) will no~'~ 20 AAC 25.252 or 20 AAC 25.412. Y N Y N___ Y N Y N ............................................................. Y N APPR DATE GEOLOGY: ENGINEERING: UIC~An~lar COMMISSION: JDH ~ RNC co Cc ~_~.~/,~.~ Comments/Instructions: M chelillsl rev 05/29/9~ Well History File APPENDIX Information of detailed nature that is not "%. particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Tape Subfile 1 is type: LIS **** REEL IlEADER **** MWD 99/ 4/21 BHI 01 LIS Customer Format Tape **** TAPE IIEADER **** MWD 99/ 4/21 103820 01 1 3/4" NaviGa~mla, Gamma Ray DaLa LIS CC~4}4ENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 Remark File Version 1.000 Extract File: Header.las ~Version Information VERS. 1.20: WRAP. NO: -Well Information Block ~LS loq ASCII Standard -VERSION 1.20 One line per frame ~MNEM.~IT Data T%~me Information STRT. F 9215.0000: Starting Depth STOP. F 11300.0000: Ending Depth STEP.F 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPAh~: ARCO Alaska, Inc. $~ELL. WELL: 15-06A FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 971' ~NL CNTY. COUN,"~f: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker lluqhes INTEQ TOOL. TOOL NA~ & TYPE: 1 3/4" NaviGamma, Gamma Ray REF . JOB REFERENCE: 103820 DATE. LOG DATE: 04 March 99 API . API NUMBER: 500292074201 -Parameter Information Block ~MNEM.UNIT Value Description FL 189' FWL : Field Location SECT' 22 : Section TOWN.N llN : Township RANG. 14E : Ranqe PDAT. M.$.L. : Permanent Datum EPD .F 63' : Elevation Of Perm. Datum LMF . KB : Loq Measured From FAPD. F 63 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 63' : Elevation Of Kelly Bushing EDF .F N/A : Elevation Of Derrick Floor EGL .F N/A : Elevation Of Ground Level CASE. F 103820 : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. {4) Well 15-06A is represented by runs 16 through 26, which are all Directional with Gamma Ray. (5) Well 15-06A was kicked off @ 9817' MD (8781' TVD), on Run 16 from the wellbore of Well 15-06A PB1. Further details could be obtained from the logs for Well 15-06A PB1. (6) The log for the open hole sidetrack 15-06A has been consolidated with that for the Well 15-06A PB1, extending up to the window milled in the casing. (7) Well 15-06A was drilled to TD @ 11288' MD (8799' TVD) on Run 26. The TD depth was adjusted to 11288' MD (8799' TVD) from 11276' MD (8799' TVD) after a tie-in. (8)The interval from 11255' MD (8799' TVD) to 11276' MD (8799' TVD) was not logged due to the.Gamma Ray sensor to bit offset. (9) The Gamma Ray log has been depth shifted to match the Schlumberger Well Services MCNL Samma Ray logged on 06 March 1999. (10) A Magnetic Declination correction of 27.84 degrees has been applied to the Directional Surveys. ~Mnemonics ROPS -> Rate of Penetration (ft/hr) GNAX -> Gamma Ray MWD-API [MWD] (MWD--API units) TVD -> True Vertical Depth, feet ~Sensor Offsets RUN GAMMA DIRECTIONAL 16 14.68 ft. 18.88 ft. 17 15.00 ft. 19.19 ft. 18 13.97 ft. 19.04 ft. 19 15.00 ft. 19.20 ft. 20 21.00 ft. 25.20 ft. 21 22.55 ft. 26.75 ft. 22 20.70 ft. 24.90 ft. 23 21.28 ft. 25.28 ft. 24 20.85 ft. 25.05 ft. 25 15.74 ft. 19.93 ft. 26 20.99 ft. 25.19 ft. Tape Subfile: 1 80 records... Minimum record length: 14 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS **** FILE HEADER M~D .001 1024 *** INFORMATION TABLE: CONS MN EM VALU LCC 150 CN ARCO Alaska, Inc. WN 15-06A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ !!!!!!!!!!!!~!!!!!! Remark File Version 1.000 1. The data presented here has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by ARCO Alaska, Inc. 3. The PDC used is the Schlumberger Well Services MCNL Gamma Ray data, dated March 06, 1999. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAX 2 ROP ROPS * FORMAT RECORD (TYPE~ 64) Entry Type( 1) Size( 1) Repcode(66) Data record type is: 0 Entry Type( 2) Size( 1) Repcode(66) Datum Specification Block Type is: 0 Entry Type( 3) Size( 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type( 4) Size( 1) Repcode(66) Logging direction is down (value= 255) Entry Type( 5) Size{ 1) Repcode{ 66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode(68) Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode(65) Frame spacing units: [F ] fndun c [F ] 1.00000000 3 Entry Type(11) Size( 4) Repcode( 68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode{ 66) One depth per frame (value= 0) Entry Type(16) Size( i) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry t%~mes encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 [] FRAME SPACE = 0.500 ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GR MWD 68 1 API 4 2 ROP MWD 68 1 4 * DATA RECORD (TYPE~ 0) 1014 BYTES * Total Data Records: 50 Tape File Start Depth = 9215.000000 Tape File End Depth = 11285.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet 0.0 O.O API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 LIS representation code decoding summary: Rep Code: 66 1 daLum Rep Code: 68 12427 daLul~s Rep Code: 79 2 daL,,,ns Tape Subtile: b'! records... Minimum record length: b4 bytes Maximum record length; 1014 bytes Tape Sub~ile 3 is type: LIS M~O .001 1024 *** INh'OIiMAI'tON TAOLE: CONS LCC 150 CN Al{CO, Alaska, l~c. ~N 15-06A ~ Prudhoe Bay Unit COON Nor'th Slope STAT Alaska LiS CO~4.ENT RMCOtLO(s): 12345678901234567890125456789012345678901234567890123456789012345678901234567890 {!!!!![{!!!~!!!![[~ Remark File Version 1.DO0 1. The data presented here i~ the unedited tield raw data. *** ±Nb~IiMATION TAJ3LE: Clb~ MNEM CHAN DIMT L-REAM ODEP t Gl{AX ~l,La2,4. 0.0 2 ROP$ ROP$ 0.0 FORMAT RECORD (~fPE~ 64) Entry Tk~e( 1) Size( 1) Repcode(66) Data record type is: 0 Entry Type( 2) Size( 1) Repcode( 66) Datum Specification Block Tk~e is: 0 Entry Type( 3) Size( 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type( 4) Size( i) Repcode(66) Logging direction is do~ (value= 255) Entry Type( 5) Size( 1) Repcode( Optical Log D~pth Scale Units: Feet Entry Type( 8) Size( Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode(65) Frame spacing units: [F ] fndun c IF ] 1.00000000 3 Entry Type(11) Size( 4) Repcode( 68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depLh per frame (value- 0) Entry Type{ 16) Size( 1) Repcode( 66) Datum Specification Block Sub-type is: 1 Entry Block terminator. E,u~nary of enLL'y Lyl3e-'~ ~ncounLe£'ed: 1 2 3 4 5 6 7 8 9 I0 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1- 0 ~ 0 1 0 0 1 Rep Code CounL byLe~ 68 2 8 Sum; 2 8 fadun a [F ] 1.00000000 FRAME SPACE - 0.500 * F ONE DEPTH PER FRAME Tape depLh ID: F 2 Curves: Name Tool Code Samples Units Size 1 GRAXMWD 68 1 4 2 ROPS MWD 68 1 4 * DATA RECORD (~fPE~ 0) 1014 BYTES * ToLal DaLa Recordm: 50 API API API /UPI Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 Tape File Start Depth = 9215.000000 Tape File End Depth = 11280.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding sm~ary: Rep Code: 66 1 daLum Rep Code: 68 12397 daLums Rep Code: 79 2 daLums Tape Subfile: 3 57 records... Minimum record length: 54 bytes Maximum record length: 1014 bytes Tape Subfile 4 is tk%ae: LIS **** TAPE TRAILER **** 99/ 4/21 103820 01 **** REEL TRAILER **** 99/ 4/21 BHI 01 Tape Subfile: 4 2 ~ecords... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 21 APR 99 6:30a Elapsed execution time = 1.54 seconds. SYSTEM R/~TURN CODE - 0 Tape Subfile 1 [] Tape Subfile 2 is type: LIS is type: LIS DEPTH 9215.0000 9215.5000 9300.0000 9400.0000 9500.0000 9600.0000 9700.0000 9800 0000 9900.0000 10000 0000 10100.0000 10200 0000 10300.0000 10400 0000 10500.0000 10600 0000 10700.0000 1O80O 00O0 10900.0000 11000 0000 11100.0000 11200 0000 11285.0000 GR ROP -999.2500 -999.2500 -999.2500 -999.2500 20.5400 35.6000 33.8630 80.0000 59.9810 78.1660 137.6320 70.5000 143.0920 42.8000 82.9920 38.7000 -999.2500 -999.2500 71.4400 116.1000 106.5800 75.0000 80.2040 38.2000 106.5800 88.1280 44.4490 162.8730 113.8800 138.4000 43.8000 112.5000 37.9600 124.1000 121.1320 -999.2500 50.6870 24.8750 60.6360 26.8230 62.7800 46.6940 71.3900 70.9910 -999.2500 -999.2500 [] Tape Tape File Start Depth = 9215.000000 Tape File End Depth = 11285.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Subfile 3 is type: LIS DEPTH 9215.0000 9215.5000 9300 0000 9400.0000 9500 0000 9600.0000 9700 0000 9800.0000 9900 0000 10000.0000 10100 0000 10200.0000 10300 0000 10400.0000 10500 0000 10600.0000 10700 0000 1O800.0000 10900 0000 11000.0000 11100 0000 11200.0000 11280 0000 GRAX ROPS -999.2500 -999.2500 -999.2500 -999.2500 20.5400 58.4700 40.7700 80.0000 122.3100 80.0000 135.9000 39.0140 154.0200 18.7000 79.2920 51.2870 -999.2500 -999,2500 89.3670 108.6500 106.5800 75.0000 90.5200 37.3730 66.5940 124.1000 96.6470 64.0870 78.7790 116.1000 51.7570 107.8790 37.0930 188.6790 75.0510 -999.2500 39.5200 15.9330 73.0000 33.8180 67.1600 31.2350 72.5130 42.7160 -999,2500 -999.2500 Tape File Start Depth = 9215.000000 Tape File End Depth = 11280.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS RECEIVED ¥ 0 5 1999 eska Oil & Gas Cons. Commission An orage * ALASKA COMPUTING CENTER * . . . ............................ * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NAME : DS 15-06A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API N-JMBER : 500292074201 REFERENCE NO : 99130 ~;~,AR 2. 6 ~999 Aj~ 0ii & Gas C~ms. ~m'~'~°n LIS Tape Verifi~L-uion Listing Schlumberger Alaska Computing Center 19-MA~-1999 11:34 ~/ PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/03/19 ORIGIN : FLIC REEL NAME : 99130 CONTINUATION # : PREVIOUS REEL : CO~4ENT : ARCO ALASKA, PRUDHOE BAY, DS 15-06A, API #50-029-20742-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE · 99/03/19 ORIGIN : FLIC TAPE NAME '. 99130 CONTINUATION # '.1 PREVIOUS TAPE COMMENT '. ARCO ALASKA, PRUDHOE BAY, DS 15-06A, API #50-029-20742-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 15-06A API NUMBER: 500292074201 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 19-MAR-99 JOB NUMBER: 99130 LOGGING ENGINEER: C. YON OPERATOR WITNESS: BRADLEY SURFACE LOCATION SECTION: 22 TOWNSHIP: liN RANGE: 14E FNL: 971 FSL: FEL: FWL: 189 ELEVATION(FT FROM MSL O) KELLY BUSHING: 63.00 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (?T) WEIGHT (LB/FT) 1ST STRING 2. 375 11274.0 4.60 2ND STRING 7. 000 9233.0 26. O0 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (M~ASURED DEPTH) LIS Tape Verifi'O~-~ion Listing Schlumberger Alaska Computing Center 19-MAR-1999 11:34 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: DIL LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 1982 LOGGING COMPANY: BASELINE DEPTH 88888.0 9224.0 9222.0 9218.5 9211.0 921 O. 5 9204.5 9194.5 9186.0 9166.0 9164.5 9156.5 9155.5 9153.5 9144.5 9143.5 9134.5 9129.5 9121.0 9118.0 9111.5 9108.0 9106.5 9104.0 9102 0 9098 0 9095 5 9091 0 9090 0 9086 5 9082 0 9074 5 9071.5 9070.0 9067.5 9066.0 9064.0 9059.0 9054.0 9053.5 9051.5 9043.0 9039.0 9034.0 9029.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNT 88887.0 88887.5 9223.0 9221.0 9210.5 9203.5 9192.0 9184.5 9163.0 9156.5 9155.0 9144. 0 9132 0 9128 5 9119 0 9117 0 9110 0 9107 5 9102.5 9099.5 9097.5 9095.0 9089.5 9087.5 9071.0 9069.0 9065.5 9054.0 9051.0 9044.0 9039.0 9029.0 9218.0 9210.5 9184.5 9166.0 9156.0 9155.0 9144.5 9107.5 9102.5 9099.5 9093.0 9082.5 9074.0 9068.0 9066.0 9061.0 9056.0 9035.0 PAGE: LIS Tape Verifi~-=6ion Listing Schlumberger Alaska Computing Center 9021.5 9017.5 9014.5 9013.0 9009.5 9006.5 8999.5 8998.5 8985.5 8981.5 8978.0 8974.0 8966.0 8960.5 8957.0 8954.0 8953.0 8950.5 8943.0 8941.5 8939.5 8938.0 8933.0 893 O. 5 8928.0 8926.5 8921 0 8919 5 8917 5 8916 5 8913 5 8907 0 8902.5 8899.5 8897.5 8897.0 8893.5 8889.5 8881.0 8872.5 8871.0 8864.0 8863.0 8859.5 8857.0 8850.5 8845.5 8840.5 8834.5 8762.5 8762.0 8761.0 8750.0 8749.5 8727.5 8723.5 9020.5 9019.0 9015.5 9012.0 9008.0 9000.0 8985.5 8978.0 8973.5 8960.0 8957.5 8953.0 8941.5 8940.0 8937.5 8933.0 8930.5 8927.5 8921.0 8919.5 8917.5 8907.0 8903.0 8900.0 8896.0 8893.5 8888.5 8882.0 8871.0 8863.5 8859.5 8857.0 8847.0 8843.0 8834.5 8762.5 8760.5 8749.5 8725.0 9019.0 9010.0 8999.5 8982.5 8967.0 8957.5 8953.0 8945.0 8940.0 8927.5 8921.0 8918.0 8903.0 8900.0 8878.0 8867.5 8859.0 8851.5 8762.5 8749.5 8729.0 19-MAR-1999 11:34 PAGE: LIS Tape Verifi~ion Listing Schlumberger Alaska Computing Center 8722.5 8721.0 8716.5 8715.0 8712.5 8707.5 8702.5 8702.0 8693.5 8686.5 8667.0 8663.5 8652.0 8628.0 8617.5 8615.5 8612.5 8608.0 8597.0 8596.0 8592.0 8588.0 8577.0 8576.0 8552.0 8550.0 8549.5 8538.0 8528.0 8527.5 8520.0 8516.5 8514.0 8506.5 8502.5 8497.0 8493.0 8492.0 8486.0 8484 0 8477 0 8475 0 8467 0 8465 5 8464 5 8456 5 8453 0 8446.0 8438.5 8433.0 8428.5 8425.5 8411.0 8410.5 8406.0 8403.0 8721.5 8717.5 8709.5 8702.5 8694.0 8685.5 8652.5 8627.0 8616.0 8613.0 8606.5 8596.5 8589.0 8578.0 8551.5 8550.0 8527.5 8516.5 8502.5 8493.0 8485.5 8478.0 8474.5 8469.0 8466.0 8457.5 8454.0 8445.5 8439.5 8433.5 8428.0 8409.5 8407.0 8724.5 8717.5 8714.0 8704.0 8694.5 8668.5 8663.5 8615.5 8596.5 8593.0 8577.5 8550.0 8539.5 8527.5 8520.5 8516.5 8508.5 8498.0 8493.5 8486.0 8466.0 8439.0 8428.0 8410.5 8404.0 19-MAR-1999 11:34 "~' PAGE: LIS Tape Verif~'~c~ion Listing Schlumberger Alaska Computing Center 19-MAR-1999 11:34~ 8400.0 8393.5 8386.5 8377.5 8371.0 83 61.0 8359.0 8356.5 8353.5 8346.0 8333.5 8322.0 8315.0 8312.0 8311.0 8306.0 8302.0 8298 5 8294 5 8291 0 8289 0 8281 5 8281 0 8277.0 8274.5 8271.5 8266.5 8265.0 8253.5 8252.0 8251.5 8239.5 8235.5 8231.5 8228.0 8227.5 100.0 R~KS: 8401.5 8394.5 8386.0 8378.0 8372.5 8362.5 8358.0 8358.0 8354.5 8346.0 8335.0 8322.5 8316.5 8312.0 8312.5 8306.0 8303.0 8298.5 8295.0 8292.5 8289.5 8281.5 8281.5 8277.5 8276.5 8273.0 8267.5 8265.0 8256.0 8252.0 8253.5 8241.0 8234.0 8231.5 8226.5 8228.0 100.5 98.5 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE MCNL DATA AQUIRED ON ARCO ALASKA'S DS 15-06A WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE DIL GA~k4A RAY, ALSO PASS #1 ArRAT AND THE DIL GA~94A RAY, CARRYING ALL MCNL CURVES WITH THE NR~T SHIFTS. THE DIL OR IS FROM THE PARENT DS 15-06 HOLE. CORRELATIONS ARE MADE DOWN TO KOP AT 9226', CARRYING THE LAST SHIFT TO TD. THIS LOG IS THE PDC. $ $ PAGE LIS Tape Verif~ution Listing Schlumberger Alaska Computing Center 19-MAR-1999 11:34~-.~.. PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE ~ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11233.0 8225.5 CNT 11231.5 8223.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNT REMARKS: THIS FILE CONTAINS CASED HOLE MCNL PASS #1. NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 LIS Tape Verifi'u~-~ion Listing Schlumberger Alaska Computing Center 19-MAR-1999 11:34~J' PAGE: TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNT CAPI O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNT V O0 000 O0 0 1 1 1 4 68 0000000000 GR DIL GAPI O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11233.000 GRCH. CNT 136.500 NCNT. CNT -999.250 NRAT. CNT -999.250 CCL.CNT -999.250 GR.DIL -999.250 DEPT. 2596.000 GRCH. CNT -999.250 NCNT. CNT -999.250 NRAT. CNT -999.250 CCL.CNT -999.250 GR.DIL 46.906 FCNT. CNT FCNT. CNT -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verifi~ion Listing Schlumberger Alaska Computing Center 19-MAR-1999 11:34~--~i PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SU~94ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9947.0 9724.5 CNT 9953.5 9723.5 $ CURVE SHIFT DATA - PASS TO PASS (BiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888 0 9943 5 9941 0 9939 0 9936 5 9933 5 9933 0 9926 5 9921 0 9920 0 9918.0 9909.5 9906.5 9903.0 9901.0 9900.0 9897.5 9893.0 9881.5 9879.0 9877.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNT 88885.0 88893.5 9940.5 9935.0 9933.5 9931.5 9918.5 9908.5 9906.0 9902.0 9898.5 9898.0 9897.0 9892.0 9880.0 9946.5 9936.5 9929.5 9921.0 9918.5 9908.5 9884.0 9882.0 LIS Tape Verif~'~Tion Listing Schlumberger Alaska Computing Center 19-MAR-1999 11:34~ ..... PAGE: 9874.5 9871.5 9869.5 9864.0 9860.5 9858.5 9852.5 9843.5 9842.0 9833.5 9833 0 9827 5 9824 0 9821 5 9819 0 9817 5 9809.0 9807.5 9804.5 9799.5 9792.0 9791.5 9781.0 9777.5 9776.0 9772.5 9768.0 9767.0 9765.5 9762.5 9762.0 9753.0 9749.5 9748. $ 9742.0 9740.5 9736.0 9735.0 9730. $ 9729.5 100.0 $ 9874.0 9865.0 9859.5 9853.5 9843.5 9842.5 9833.0 9825.0 9821.0 9816.5 9806.0 9791.0 9778.5 9776.0 9765.5 9762.5 9752.0 9747.0 9735.0 9729.0 99.5 9877.5 9870.5 9861.0 9832.5 9827.0 9820.0 9809.5 9808.5 9803.5 9799.5 9792.5 9779.5 9772.5 9768.5 9765.0 9762.5 9748.5 9741.0 9739.0 9736.0 9729.0 98.5 RE~ARKS: THIS FILE CONTAINS CASED HOLE MCNL PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NRAT PASS #2 AND NRAT PASS #1, CARRYING ALL MCNL CURVES WITH THE NRAT SHIFTS. $ LIS FORMAT DATA LIS Tape Verifi'c~ion Listing Schlumberger Alaska Computing Center 19-MAR-1999 11:34 PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNT GAPI O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNT V O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9953.500 GRCH. CNT -999.250 NRAT. CNT 10.878 CCL.CNT 85.000 DEPT. 9723.500 GRCH. CNT -999.250 NRAT. CNT 13.652 CCL.CNT 85.000 NCNT. CNT 9242.719 FCNT. CNT NCNT. CNT 6527.750 FCNT. CNT 601. 641 375.250 ** END OF DATA ** LIS Tape Verifiu~'ion Listing Schlumberger Alaska Computing Center 19-MAR-1999 11:34'.~J PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2~ CNT REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1 & 2.THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 19-MAR-1999 11:34~' PAGE: 12 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNT GAPI O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNAV CPS O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNAV CPS O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNAV O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9960.000 GRCH. CNT NRAT. CNAV -999.250 DEPT. 9700.000 GRCH. CNT NRAT. CNAV -999.250 71.098 NCNT. CNAV -999.250 FCNT. CNAV -999.250 120.229 NCNT. CNAV -999.250 FCNT. CNAV -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verif~%~ion Listing Schlumberger Alaska Computing Center 19-MAR-1999 11:34~ ..... ' PAGE: 13 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O . 1000 FILE SU~R4ARY VENDOR TOOL CODE START DEPTH MCNL 11251.0 $ LOG HEADER DATA STOP DEPTH 8207.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) '. LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAiVR4A RAY MCNL MEMORY COMP NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 06-MAR-99 RELOO35E 11288.0 11251.0 8225.0 11232.0 1800.0 TOOL NUMBER MGR 123 LTTN Al3 11274.0 LIS Tape Verif~t-~ion Listing Schlumberger Alaska Computing Center 19-MAR-1999 11:34~-~' PAGE: 14 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 35000 TOOL STANDOFF (IN): REMARKS: Depth correlated to PDC reference log. Upper zone between 9000-9150' used for correlation. All depth determination information provided by co rep. Ail depth tie-ins witnessed by co rep. Logging procedure: Logged from 8250-TD just as a precaution. Made repeat pass on 9750'-9950' interval because of perforating importance. Main up pass made from TD (11251')-8208' All passes made at 30 FPM. THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT LIS Tape Verifi~-~'~ion Listing Schlumberger Alaska Computing Center 19-MAR-1999 11:34' .... PAGE: 15 TYPE REPR CODE VALUE .............................. 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 4 1 1 4 68 0000000000 CVEL PS1 F/HR O0 000 O0 0 4 1 1 4 68 0000000000 GR PS1 GAPI O0 000 O0 0 4 1 1 4 68 0000000000 NCNT PSi CPS O0 000 O0 0 4 1 1 4 68 0000000000 FCNT PS1 CPS O0 000 O0 0 4 1 1 4 68 0000000000 NRAT PS1 O0 000 O0 0 4 1 1 4 68 0000000000 CCLD PS1 V O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11251.000 CVEL.PS1 3.028 GR.PS1 FCNT. PS1 -999.250 NRAT. PS1 -999.250 CCLD.PS1 -999.250 NCNT. PS1 -999.250 -999.250 DEPT. 8207.500 CVEL.PS1 -999.250 GR.PS1 -999.250 NCNT. PS1 -999.250 FCNT. PS1 -999.250 NRAT. PS1 -999.250 CCLD.PS1 85.833 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verif~t-~J~ion Listing Schlumberger Alaska Computing Center 19-MAR-1999 11:34~ .... .~ PAGE: 16 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O. 1000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MCNL 9974.5 $ LOG HEADER DATA STOP DEPTH 9711.1 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GANR4A RAY MCNL MEMORY COMP NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G) '. SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) '. FLUID LEVEL (FT) : 06-MAR-99 RELOO35E 11288.0 11251.0 8225.0 11232.0 1800.0 TOOL NUMBER MGR 123 LTTN Al3 11274.0 LIS Tape Verif£'c~a~ion Listing Schlumberger Alaska Computing Center 19-MAR-1999 11:34~-~-~~/ PAGE: 17 FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 35000 TOOL STANDOFF (IN): REMARKS: Depth correlated to PDC reference log. Upper zone between 9000-9150' used for correlation. All depth determination information provided by co rep. Ail depth tie-ins witnessed by co rep. Logging procedure: Logged from 8250-TD just as a precaution. Made repeat pass on 9750'-9950' interval because of perforating importance. Main up pass made from TD (11251')-8208' Ail passes made at 30 FPM. THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 O. 1 9 65 FT LIS Tape Verif~t-~ion Listing Schlumberger Alaska Computing Center 19-MAR-1999 11:34~~ PAGE: 18 TYPE REPR CODE VALUE 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 5 1 1 4 68 0000000000 CVEL PS2 F/HR O0 000 O0 0 5 1 1 4 68 0000000000 GR PS2 GAPI O0 000 O0 0 5 1 1 4 68 0000000000 NCNT PS2 CPS O0 000 O0 0 5 1 1 4 68 0000000000 FCNT PS2 CPS O0 000 O0 0 5 1 1 4 68 0000000000 NRAT PS2 O0 000 O0 0 5 1 1 4 68 0000000000 CCLD PS2 V O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9974.500 CVEL.PS2 3.514 GR.PS2 -999.250 NCNT. PS2 FCNT. PS2 -999.250 NR~T. PS2 -999.250 CCLD.PS2 -999.250 DEPT. 9711.100 CVEL.PS2 -999.250 GR.PS2 -999.250 NCNT. PS2 FCNT. PS2 -999.250 NRAT. PS2 -999.250 CCLD. PS2 85.000 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verif~W~ion Listing Schlumberger Alaska Computing Center 19-MAR-1999 11:34~=~ PAGE: 19 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/03/19 ORIGIN : FLIC TAPE NAME : 99130 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, PRUDHOE BAY, DS 15-06A, API #50-029-20742-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/03/19 ORIGIN : FLIC REEL NAME : 99130 CONTINUATION # : PREVIOUS REEL : CO~4ENT : ARCO ALASKA, PRUDHOE BAY, DS 15-06A, API #50-029-20742-01 Tape Subfile 1 is type: LIS **** REEL HEADER **** MWD 99/ 4/16 BHI 01 LIS Customer Format TaPe · ** TAPE HEADER MWD 99/ 4/16 103820 01 1 3/4" NaviGamma, Gamma Ray data LIS COMMENT RECORD(s): ~23456789~~234567890~234567890~23456789~~234567890~234567890~234567890~23456789~ !!!!I!I!!I!!!!!!!!! Remark File Version 1.000 !!!!!!!I!!!!!!!!!!! Extract File: HEADER.LAS -Version Information VERS. 1.20: WRAP. NO: -Well Information Block SMNEM. UNIT Data Type STRT. F 8220. 0000: STOP. F 11300. 0000: STEP. F 0.5000: NULL. -999. 2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: REF . JOB REFERENCE: DATE. LOG DATE: API. API NUMBER: ~Curve Information Block #MNEM.UNIT API Codes DEPT. F 0 1 0 1: GRAX. API 0 0 0 1: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value A/{CO Alaska, Inc. 15-06A PB1 Prudhoe Bay Unit 971' FNL North Slope Alaska Baker Hughes INTEQ 1 3/4" NaviGamma, Gamma Ray 103820 23 Feb 99 500292074270 Curve Description Depth Gamma Ray Apparent Real-time (MWD) ROPS. 0 0 0 1: N/A -Parameter Information Block ~MNEM. UNIT Value FL 189' FWL SECT i 22 TOWN. N llN RANG. 14E PDAT. M.S.L. EPD .M 63' LMF . KB FAPD. F 63 DMF . KB EKB . F 63' EDF. F N/A EGL. F N/A CASE. F 9233 OS2 . DIRECTIONAL Description Field Location : Section : Township : Range : Permanent Datum : Elevation Of Perm. Datum Log Measured From Feet Above Perm. Datum : Drilling Measured From : Elevation Of Kelly Bushing : Elevation Of Derrick Floor : Elevation Of Ground Level : Casing Depth : Other Services Line 2 RECEIVED 0-.6. 1999 Gas Cons. Commission ~Remarks (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well 15-06A PB1 is represented by runs 7, 8, 9, 11, 12, 13, 14 and 15 which are all Directional with Gamma Ray. (5) Well 15-06A PB1 was kicked off @ 9233' MD (8509' TV]D) from the wellbore originally drilled for Well 15-11. Sidetrack 15-06A PB1 was later plugged back. (6) Well 15-06A PB1 was drilled to TD @ 10670' MD (8801' TVD) on Run 15. The TD depth was adjusted to 10670' MD 18801' TVD) from 10660' MD (8801' TVD) after a tie-in. (7) The gap in the gamma ray log from 9992' MD (8780' TVD) to 10004' MD (8780' TVD) was due to a depth adjustment applied after a tie-in. (8) The interval from 10645' MD (8801' TVD) to 10670' MD (8801' TVD) was not logged due to the Gamma Ray sensor to bit offset. (9) The Gamma Ray log has been depth shifted to match the Schlumberger Well Services Cased Hole MCNL gamma ray logged on 06 March 1999. (10) A Magnetic Declination correction of 27.84 degrees has been applied to the Directional Surveys. ~Mnemonics ROPS -> Rate of Penetration (ft/hr) GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) TVD -> True Vertical Depth, feet -Sensor Offsets RUN GAMMA DIRECTIONAL 7 15.71' 19.91' 8 15.71' 19.91' 9 16.33' 20.53' 1t 16.33' 20.53' 12 16.33' 20.53' 13 14.52' 18.72' 14 14.49' 18.69' 15 14.98' 19.18' Tape Subfile: 1 82 records... Minimum record length: 14 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS FILE HEADER MWD .001 1024 INFORMATION TABLE: CONS LCC 150 CN ARCO Alaska, Inc. WN 15-06A PB1 FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~234567890~23456789~~23456789~~234567890~234567890~23456789~~234567890 !I!!!!!!!!l!!!!!!!! Remark File Version 1.000 1. The data presented here has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by ARCO Alaska, Inc. 3. The PDC used is the Schlumberger Well Services data, dated March 06, 1999. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR 2 ROP * FORMAT RECORD (TYPE# 64) Entry Type 1) Size( 1) Data record type is: Entry Type 2) Size( 1) GRAX ROPS Repcode(66) 0 Repcode (66) Datum Specification Block Type is: 0 Entry Type 3) Size( 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type 4) Size( 1) Repcode(66) Logging direction is down (value= 255) Entry Type 5) Size( 1) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type 8) Size( 4) Repcode(68) Frame spacing: 0.500000 Entry Type 9) Size( 4) Repcode(65) Frame spacing units: [F ] fndun c IF ] 1.00000000 3 Entry Type(ll) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a IF ] 1.00000000 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size i GR MWD 68 1 API 4 2 ROP MWD 68 1 4 DATA RECORD (TYPE# 0) 1014 BYTES Total Data Records: 35 Tape File Start Depth = 9215.000000 Tape File End Depth = 10670.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet 0.0 0.0 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 I 9*** FILE TRAILER 9*** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 8737 datums Rep Code: 79 2 datums Tape Subfile: 2 42 records... Minimum record length: 54 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS 9*** FILE HEADER 9*** MWD .001 1024 **9 INFORMATION TABLE: CONS MNEM VALU LCC 150 CN ARCO Alaska, Inc. WN 15-06A PB1 ~N Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~234567890~23456789~~234567890~23456789~~234567890~23456789~~234567890~234567890 !!!!!!!!!!!!!!!!~!! Remark File Version 1.000 1. The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0 . 0 FORMAT RECORD (TYPE# 64) Entry Type( 1) Size( 1) Repcode(66) Data record type is: 0 Entry Type( 2) Size( 1) Repcode(66) Datum Specification Block Type is: 0 Entry Type( 3) Size( 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type( 4) Size( 1) Repcode(66) Logging directioa is down (value= 255) Entry Type( 5) Size( 1) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode(68) Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode(65) Frame spacing units: [F ] fndun c [F ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 21 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 i 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a IF ] 1.00000000 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GRAX MWD 68 1 4 2 ROPS MWD 68 1 4 [] * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 35 Tape File Start Depth = 9215.000000 Tape File End Depth = 10670.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet FILE TRAILER LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 8737 datums Rep Code: 79 2 datums Tape Subfile: 3 42 records... Minimum record length: 54 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS **** TAPE TRAILER MWD 99/ 4/16 103820 01 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 **** REEL TRAILER MWD 99/ 4/16 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 16 APR 99 11:52p Elapsed execution time = 1.37 seconds. SYSTEM RETURN CODE = 0 [] Tape Subfile 1 is type: LIS [] Tape Subfile 2 is type: LIS DEPTH GR ROP 9215.0000 -999.2500 -999.2500 9215.5000 -999.2500 -999.2500 9300.0000 22.1200 53.1230 9400.0000 33.8630 80.0000 9500.0000 59.9810 78.1660 9600.0000 137.6320 70.5000 9700.0000 143.0920 42.8000 9800.0000 77.0100 17.9000 9900.0000 60.4000 57.1000 10000.0000 -999.2500 80.0000 10100.0000 81.1080 102.8000 10200.0000 89.0900 128.5000 10300.0000 91.0410 49.9950 10400.0000 132.8800 18.8000 10500.0000 161.4670 21.0000 10600.0000 95.1300 50.0330 10670.0000 -999.2500 -999.2500 Tape File Start Depth = 9215.000000 Tape File End Depth = 10670.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 9215.0000 -999.2500 -999.2500 9215.5000 -999.2500 -999.2500 9300.0000 20.5400 58.4800 9400.0000 40.7700 80.0000 9500.0000 122.3100 80.0000 9600.0000 135.9000 39.0140 9700.0000 154.0200 18.7000 9800.0000 79.2920 51.2870 9900.0000 60.4000 94.7000 10000.0000 -999.2500 54.5000 10100.0000 81.5400 85.0670 10200.0000 68.1800 128.5000 10300.0000 115.2630 15.0360 10400.0000 107.2100 21.5000 10500.0000 170.6300 -999.2500 10600.0000 140.4300 38.1390 10670.0000 -999.2500 -999.2500 Tape File Start Depth = 9215.000000 Tape File End Depth = 10670.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS REOE VED t¥ 0 8 1999 Gas Cons. Commiss Anohor e.
