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196-012
NOT OPERABLE: S -29AL1 (PT1.960120) Reclassified as Not Operableue to Out -... Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, October 12, 2009 6:31 PM To: Ohms, Danielle H; NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: Williams, Carrie Subject: RE: NOT OPERABLE: S -29AL1 (PTD #1960120) Reclassified as Not Operable Due to Out -of -date Compliance Testing Hi Danielle, I understand that is how the well is referred to in you DB, however on the "official side" of the fence such things as shutting in the well and MITs are formally recorded against the motherbore. I have seen reports for corrosion inhibitor treatments that also reference a lateral name and permit number which is not correct.. There are some activities that should properly be reported for the lateral if that work is truly conducted in the lateral. There are other activities such as shutting off a lateral at the junction that should be reported both for the lateral and the motherbore. Please call and we can discuss. Tom Maunder, PE AOGCC From: Ohms, Danielle H [mailto:Danielle.Ohms @bp.com] Sent: Mon 10/12/2009 2:43 PM To: Maunder, Thomas E (DOA); NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr West (GC2 /WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: Williams, Carrie Subject: RE: NOT OPERABLE: S -29AL1 (PTD #1960120) Reclassified as Not Operable Due to Out -of -date Compliance Testing Tom, The whole well is SI and freeze protected (laterals S -29A and S- 29AL1). S -29AL1 is how this well is referenced in our databases and thus the reference to it being the name of the we ll reclassified as Not Operable. Let me know if you need any more info. Danielle Ohms GPB WWF Lead Production Engineer v' _ j APR p (907) 564 -5759 office From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Sunday, October 11, 2009 9:16 AM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr West (GC2 /WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Ohms, Danielle H; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: Williams, Carrie Subject: RE: NOT OPERABLE: S -29AL1 (PTD #1960120) Reclassified as Not Operable Due to Out -of -date Compliance Testing 4/6/2011 NOT OPERABLE: S-29AL1 (P~ #1960120) Reclassified as Not Oper~ Due to Out-... Page 1 of 1 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, October 11, 2009 9:41 AM To: Maunder, Thomas E (DOA) Subject: RE: NOT OPERABLE: S-29AL1 (PTD #1960120) Reclassified as Not Operable Due to Out-of-date Compliance Testing Correct, it is S-29A. Torin ~'~G~~~~~ ~,~~ ~a :~ ~ 2Q~~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Sunday, October l i, 2009 9:16 AM To: NSU, ADW Well Integrity Engineer; Regg, ]ames B(DOA); Schwartz, Guy L(DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Ohms, Danielle H; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: Williams, Carrie Subject: RE: NOT OPERABLE: S-29AL1 (PTD #1960120) Reclassified as Not Operable Due to Out-of-date Compliance Testing Torin, What about S-29A? Aithough S-29AL1 was likely the last segment drilled, the IA technically is in S-29A. Your thoughts? Tom Maunder, PE AOGCC From: NSU, ADW Well Integrity Engineer [maiito:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Fri 10/9/2009 7:30 PM To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Ohms, Danielle H; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: NSU, ADW Well Integriry Engineer; Williams, Carrie Subject: NOT OPERABLE: S-29AL1 (PTD #1960120) Reclassified as Not Operable Due to Out-of-date Compliance Testing All, Well S-29AL1 (PTD #1960120) is a produced water injector that was due for regulatory compliance testing on 10/08/09. The well has been shut-in since 06/03/09 because there has not been any off-take in the area. The well has been reclassified as Not Operable. A state witnessed MITIA will be required when the well has been placed on injection and thermally stable. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 10/12/2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~~~G~ V ~Q!..!'`y`s" ~~ ~ ~~~ ~ ~ ~~~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ ; a~ (~aSl Performed: Alter Casing ~ Pull Tubing~ Perforate New Pool ~ Waiver~ Time ExtensionQA~~.~,~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Weil ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: tvame: Development ~ Exploratory ~ 196-0120 3. Address: P.O. Box 196612 Stratigraphic #~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22082-60-00 7. KB Elevation (ft): 9. Well Name and Number: 68.17 KB PBU S-29AL1 8. Property Designation: 10. Field/Pooi(s): ADLO-028261 Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 14268 feet Plugs (measured) None true verticai 8872 feet Junk (measured) None Effective Depth measured 14268 feet true vertical 8872 feet Casing Length Size MD ND Burst Collapse Conductor 83 20" 91.5# H-40 27 - 110 27 - 110 1490 470 Surface 2764 13-3/8" 68# NT-80 26 - 2790 26 - 271710 5020 2270 Production 11720 9-5/8" 47# NT-80 25 - 11745 25 - 8182 6870 4760 Liner 1148 7" 29# L-80 11533 - 12681 8050 - 8855 8160 7020 Liner 1569 4-1/2" 12.6# L-80 12699 - 14268 8862 - 8872 8430 7500 Slotted Liner 1508 4-1/2" 12.6# L-80 12737 - 14245 8875 - 8870 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 3-1/2" 9.3# L-80 23 - 12452 0 0 - Packers and SSSV (type and measured depth) 3-1/2" Baker S-3 Packer 12394 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: ~__ h,,, ,~_- ~~r„~ ~~ ~'~~~~'A " `~' `? "~~ Intervals treated (measured): ~ % dY" ' 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: 69 Subsequent to operation: 388 14. Attachments: 15. Well Class after oroposed work: Copies of Logs and Surveys Run Exploratory ~ Development r; Service ~ Daily Report of Well Operations X 16. Well Status after proposed wo • Oil ~ Gas ~ WAG GINJ ~ WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowiedge. ~'~y~ Sundry Number or N/A if C.O. Exempt: ~ ~~'~~ 305-200 Contact Gary Preble Printed Name Gary Pr ble Title Data Management Engineer Signature -~ Phone 564-4944 Date 7/29/2009 Form 10-404~`Revised 04/2006 g--~~~ Submit Ori inal~ nl ~~S `~' ~ ~ ~ ~~~ g~~-'-'~=%> ~,~ S-29AL1 196-012 PFRF OTTOCHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base S-29AL1 2/24/96 SL 12,737. 14,245. 8,875.04 8,870.42 S-29AL1 5/10/96 BPS 12,703. 12,713. 8,863.82 8,867.58 S-29AL1 5/25/96 BPP 12,703. 12,713. 8,863.82 8,867.58 S-29AL1 8/10/96 BPS 12,703. 12,713. 8,863.82 8,867.58 S-29AL1 12/1/96 BPP 12,703. 12,713. 8,863.82 8,867.58 S-29AL1 7/14/05 APF 12,283. 12,285. 8,626.51 8,628.04 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE S-29AL1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~~ ro~ _ ~ ~.- ~ ~, , a ~ ~, b ~~, ~ ~~ 8/22/2005~*** WELL SHUT IN ON ARRIVAL*"" (PRE INJ SWAP) ~ ;SET SLIP STOP CATCHER SUB, PULL S/O FROM STA#1 @ 4416' SLM, SET j ~ i ~DUMMY VALVE IN SAME, PULL S.S. CATCHER SUB ~ NOTIFY PAD OPER OF WELL STATUS, MAY NEED TO BE FREEZE 'PROTECTED I t***WELL LEFT SI, TURNED OVER TO PAD OP.**'' i I 8/24/2005 TI0 = 1430/1430/340. Temp = SI. IA FL (For SL). IA FL @ 4570' (245 bbis), ~ ;142' below sta-1. No A/L. ~. ~~~._~ ~ ~a__.~ .~_._~.w~_..~.. ~~ ~~ ~~~~ 8/24/2005 LRS Tanker standby for wireline. ; ~ j~ 8/26/2005~ T/I/0= 1520/1400/ 380 , ASSIST SLICKLINE- Load IA and MIT-IA to 4000 psi.~ ; Pumped 240bb1s of inhibited 60/40 meoh. down IA. S/L set dummy valve, Pumped ; ;an additional 20 bbls to reach test pressure. MIT-IA to 4000 psi. [PASSED] Lost ~ ;20 psi in the 1st 15 min. and 10 psi. in the 2nd 15 min. for a total loss of 30 psi. ~ FBled pressure back to 1450. FWHP=2050/1400/400 3 __ __ _______ ~~ 8/26/2005!`**WELL S/I ON ARRIVAL*"* ~ ; SET 4.5" SLIP STOP CATCHER @ 4615' SLM. PULL DGLV FROM STA#1 @ ;4413' SLM. ~OAD IA W/ 245 BBLS OF INHIBITED 60/40 METH. SET DGLV IN ;STA# 1. MITIA - 4000 PSI, PASSED. PULL SLIP STOP CATCHER. ~ €'**WELL LEFT S/I''*' I .._ `~ 9/14/2005sT/I/0-2420/1420/480. Temp Cold TBG FL (for FO call-m) TBG FL @ 1140T~ s ~(173 bbls) ~~ ~ 10/4/2005; UNABLE TO TIE INTO PROVIDED LOGS DUE TO SATURATION IN TH~E ~ ~ 'GAMMA RAY AND LACK OF CURRENT TUBING STRING LOG. CORRELATED ~ =T0 BP TUBING SUMMARY DATED 22-JUL-2005. jLOGS INDICATE MAJORITY OF INJECTION GOING BELOW 12660' FT. ~ ;""NOTIFY DSO OF WELL STATUS"' ~ ~ , ___ _ _ _, _ _ .~__ ,__~ _w _ .._~. .__ _._._.~ _ . _.._ __ _ w ... _.._~_ _._.__ _ _..__ _. ~.._...__. ? 10/7/2005~TI0= 610/770/550. Well is on Inj. IA FL (pre-MITIA). IA FL @114' (7 bbls). OA ~ ;FL near surface. __ ~ _ __ _ ~--- - ---~_~~ ~ __ ....__.__.~ ~ _ ~ ___ _ ~_ _ _ _ . _ _ . _ ~ _ _____ ___ 10/8/2005~T/U0=370/740/500 MIT IA PASSED @ 4000 psi (AOGCC Witnessed by John j ~Spaulding)( Injecting)( for Swap to MI) IA pressured up w/ 14.8 bbls Meth ~ ~ pumped. IA lost 20 psi in 15 min. w/ Total loss of 20 psi in 30 min. Final ~ ~ W HP's-400/700/540 ~ _. ~ _ _ _, ._ __ . . ~. - - - ~ _ ._. ~ ~ ~ ___ _ _ _ ~_ ___._ _~.._._ .~ _ ______ __ m ~ _. __. ~ _ _ w ~_ ~` FLUIDS PUMPED BBLS 519.8 60/40 METH 6 DIESEL ,~~r 4'? I T~.,,i^`'I~ • • ~~ BP Exploration (Alaska) Inc. ~ Attn: Well Integrity Coordinator, PRB-20 "" Post Office Box 196612 ~~ Anchorage, Alaska 99519-6612 June 25, 2009 ` Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~~ ~ ~~',;~~~~ .~~~. ~; ~:'~~~~t 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) S-pad n~e fi/95M009 Well Name PTD R Initial top of cement Vol. of cement um ed Final top of cement Cement rop off date Cortasion inhibitor Corrosion inhibitod sealant date ft bb~s it na at S-O78 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 0.25 NA 025 NA 1.7 5/25/2009 S-03 1811900 1325 NA 1325 NA 92.65 5/20/2009 5-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009 5-06 7821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 S-OBB 2010520 0 NA 0 NA 0.85 5/27/2009 5-09 1821040 1.5 NA 1.5 NA 9.4 5l31/2009 S-10A 1971230 0.5 NA 0.5 NA 3.4 5/31/2009 5-11 B 1990530 0.25 MA 025 NA 1.7 5/27/2009 S-12A 1851930 025 NA 0.25 NA 1.7 6/1/2009 5-13 1821350 8 NA 8 NA 55.3 6/1/2009 5-15 1840170 0.25 NA 025 NA 3 6/712009 S-17C 2020070 025 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 5-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 0.25 NA 025 NA 7.3 5/19/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 5-228 1970570 0.75 NA 0.75 NA 3 5/19/2009 5-23 1901270 025 NA 025 NA 1.7 5/25/2009 S-24B 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 S-288 -29A~1 5-30 2030020 1960120 1900660 0.5 . 0 0.5 NA NA NA 0.5 0 0.5 NA NA NA 2.6 0.85 5.1 5/31/2009 5/27/2009 5/31/2009 S31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 S-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 5-34 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 S35 1921480 0 NA 0 NA .85in 5/31/2009 S-36 1921160 0.75 NA 0.75 NA 425 5/27/2009 S37 1920990 125 NA 125 NA 11.9 5/27/2009 S38 1921270 0.25 NA 025 NA 102 5/27/2009 S-47 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5/30/2009 5-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 S-44 1970070 0.25 NA 025 NA 1.7 5/28/2009 5-100 2000780 2 NA 2 NA 21.3 5/29l2009 S-101 2001150 125 NA 1,25 NA 11.9 5/29/2009 5-102L1 2031560 125 NA 125 NA 71.1 5/31/2009 S-103 2001680 1.5 NA 1.5 NA 11.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 5-106 2010120 1625 NA 7625 NA 774.3 6/2/2009 S-7o7 2011130 2.25 NA 225 NA 28.9 5/18/2009 S-708 2011000 3.5 NA 3.5 NA 40 5/30/2009 S-709 2022450 2 NA 2 NA 273 5/30/2009 S-110 2071290 11.75 NA 11.75 NA 98.8 5/30/2009 S-t7t 2050510 2 NA 2 NA 19.6 5/30/2009 S-712 2021350 0 NA 0 NA 0.5 5/30/2009 S-113 2021430 1.75 NA 1.75 NA 22.1 5/78/2009 5-1~4A 2021980 125 NA 125 NA 102 5/30/2009 5-715 2022300 2.5 NA 2.5 NA 272 5/29/2009 S-116 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 5-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-770 2032000 5 NA 5 NA 76.5 5/28/2009 S-11s 2041620 1 NA 1 NA 52 5/30/2009 S-120 2031980 5.5 NA 5.5 NA 67.2 5/29/2009 S-121 2060410 4.5 NA 4.5 NA 53.6 5/28!'2009 S-722 2050810 3 NA 3 NA 27.3 5/29/2009 S-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2W9 S424 2061360 1.75 NA 1.75 NA 77.s 5/26I2009 S-125 2070830 225 NA 225 NA 20.4 5/28/2009 S-126 20710970 125 NA 125 NA 15.3 6!1/2009 5-200 1972390 1.25 NA 125 NA 14.5 5/28/2009 S-201 2001840 0 NA 0 NA 0.85 6/19/2009 S413A 2042130 2 NA 2 NA 13.6 5/29/2009 S-215 2021540 2 NA 2 NA 18.7 6/1/2009 S-27s 2001970 4.75 NA 4.75 NA 51 5/29/2009 5-217 2070950 025 NA 025 NA t.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 Sd01 2060780 i6 NA 16 NA 99.5 6/2/2009 S-504 0 NA 0 NA 0.85 5/28/2009 • MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg '(eq;(, It (LD (U~ P.I. Supervisor n DATE: Tuesday, October II, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-29AL 1 PRUDHOE BAY UNIT S-29ALI Src: Inspector ~/o\~ \~ Reviewed By: -,",",:-, P.I. Suprv .:JJ52- Comm FROM: John Spaulding Petroleum Inspector NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT S-29ALI API Well Number 50-029-22082-60-00 Insp Num: mitJS051010105345 Permit Number: 196-012-0 Rei Insp Num Inspector Name: John Spaulding Inspection Date: 10/8/2005 Packer Depth Pretest Well I· S-29ALl ¡Type Inj. I II TVD i 8575 IA 740 P.T. 1960120 ITypeTest SPT I Test p~ir 2143.75 OA 500 -1!Iterval '-Iy~ P/F p Tubing I_~~ Notes 14.8 BBLS MEOH Annulus was not fluid packed to surface Initial 15 Min. 30 Min. 45 Min. 60 Min. 4000 I 3980 3980 500 600 600 370 370 400 5CÁNNEI NOV 1 7 2005 Tuesday, October II, 2005 Page I of I STATE OF ALASKA ALASKA t AND GAS CONSERVATION CO. )ISSION '"'lED REPORT OF SUNDRY WELL OPERATIONSJG.2 4 Z005' 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program G Gi1im1is5;~ 1 o Suspend 0 Operation Shutdown 0 Perforate 0 Other o Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well iii Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 68.17' 8. Property Designation: ADL 028261 11. Present well condition summary Total depth: measured 14275 true vertical 8872 Effective depth: measured 14275 true vertical 8872 Casing Length Structural Conductor 110' Surface 2790' Intermediate 11698' Production Liner 1583' Liner 1569 Perforation Depth MD (ft): Perforation Depth TVD (ft): 4. Current Well Class: iii Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 196-012 6. API Number: 50-029-22082-60-00 99519-6612 9. Well Name and Number: PBU S-29AL 1 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' 13-3/8" 2764' 2689' 5020 2270 9-5/8" 11698' 8152' 6870 4760 7" 11533' - 12681' 8050' - 8855' 8160 7020 4-1/2" 12699' - 14268' 8862' - 8872' 8430 7500 Slotted Liner: 12737' - 14245' 8875' - 8870' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 4-1/2", 12.6# x 3-1/2", L-80 9.3# 7" Baker 'S-3' packer; 7" Baker 'S-3' packer; 4-1/2" HES 'X' Nipple 12452' 12394'; 12219'; 2088' Treatment description including volumes used and final pressure: :SCi~NNEC' l\UG ~!; 0 200;5 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run iii Daily Report of Well Operations iii Well Schematic Diagram Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure TubinQ Pressure 15. Well Class after proposed work: o Explo~tory iii Development 0 Service 16. Well Status after proposed work: iii Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Paul Chan, 564-5254 N/A Printed Name Terrie Hubble Signature ~~ Hu ~ Form 10-404 Revised 04/2004 Title Technical Assistant œ ~3 I Prepared By Name/Number: Phon~.,\ i rQq4f629\ L Date /.; IOS . Terrie Hubble, 564-4628 U \-( Ib ! 1\ J-\ '~ßj)j15 ~~l1~ Only ) . S-29A Completion ~ ~ TREE = , 4" crw WB..LHEAD = FMC ÞfCTUA TOR = BAKER KB. B..EV = 63.12' BF. B..EV = 35.72' KOP = 1758' Max Angle = 91 @ 14738' Datum MD = 12713 Datum TVD = 8800' SS 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" l-i 113-3/8" CSG. 68#, NT-80. ID = 12.415" l-i 1 ~ 12353' 2764' L - ~i ì~ I TOP OF 7" LNR 1-1 11533' I TOP OF SECTION MILLED WINDOW l-i 11698' Minimum ID = 2.635" @ 12707' 3-1/2" HES XN NIPPLE 13-1/2" TBG, 9.3#, L-80. 0.0087 bpf. ID = 2.992" 1-1 12452' 1 ) 20eB I ..ai!8&' 1-i4-1/2" HES X NIP, ID = 3.813" -, 2720' 1-1 FOC I ~ I STI MD I TVDI DEVllYPE IVLVI LATCH PORTI DATE I 1 4430 3800 54 MMG þcR-1 RKP 12146' 1-14-1/2" HES X NIP, ID = 3.813"] 12219' H 7" BAKER S-3 A<R ID = 3.875" 1 12252' 1-i4-1/2" HES X NIP, ID = 3.813"1 12283' - 4-1/2" HES XN NIP, ID = 3.7" 1 12346' - UNIQUE MACHINE OVERSHOT 12382' 1-13-1/2" HES X NIP, ID = 2.75" I 12394' H 7" BAKER S-3 A<R, ID = 3.875" 1 12419' 1-13-1/2" HES X NIP, ID = 2.75" 1 12440' 1-13-1/2" HES X NIP, ID = 2.75" 1 12452' H3-1/2" W/LEG 1 I 12457' 1-1 B..MD TT LOGGED 05/02/961 ~ 12699' H BAKER SEITING SL V W/6' EXT 1 ~ ........ .... .... .... MILLOUT WINDOW ................ 12681' - 12693' ........ ........ ........ ........ "'" ~.... ........ ........ ........ ........ ........ 11---1 12495' l-i RA TAG I ................... ........ 1E TOPOF 4-1/2" LNR l-i 12918' 1 7" LNR 29#. L-80, 0.0371 bpf, ID = 6.184" l-i 13116' 14-1/2" LNR 12.6#, L-80, 0.0152 bpf, ID = 3.953" 1-1 13319' \ TOP OF 4-1/2" SL TO LNR l-i 13470' \4-1/2" SL TO LNR 12.6#, 13-CR, 0.0152 bpf. ID = 3.958" 1-1 15059' 12696' 1-1 BKR ISO MDL D A<R, ID = 2.93" 12707' 1-13-1/2" HES XN NIP, ID = 2.635" 1 12716' 1-13-1/2" W/LEG 1 4-1/2" LNR, 13-CR, 12.6#, -I 14268' 1 .0152 bpf, ID = 3.958" 12740' I-IRA TAG 1 1 13332' IJ CTC PA YZONE A<R 1 13459' H4-1/2" XN NIP, ID = 3.725" 14-1/2" LNR 12.6#, 13-CR, 0.0152 bpf, ID = 3.958" 1-1 15061' 1 PRUDHOE BA Y UNrT W8..L: S-29A PERMrT No: 196-0120 API No: 50-029-22082-01 SEC 35, T12N, T12E BP Exploration (Alaska) DATE 11/14/90 02/23/96 01/21/99 03/15/01 03/16/01 REV BY DATE 03/02/02 REV BY COMMENTS RNITP CORRECTIONS CHH GLM SIS-MH SIS-CS COMrVlENTS ORIGINAL COMPLErION MULTI-LA TERAL COMPlETION LAST WORK OVER CONVERTED TO CANVAS FINAL ) ) -6'" Well: S-29A 1 L 1 Rig Workover Accept: 07/19/05 Field: Prudhoe Bay Unit Spud: N/A API: 50-029-22082-01-00 Release: 07/24/05 Permit: 196-011 Rig: Nabors 4ES PRE-RIG WORK 05/13/05 RIH W/ 2.70 SWEDGE TO 12,387 SLM TAG TIP POOH. RIH AT 150' PER MIN. W/ PDS CALIPER TO 12,387' SLM. POOH AT 45' PER MIN. 05/14/05 LOG UP AT 45' PER MIN FROM 12,387 TO SURF. PDS DATA GOOD. RDMO. 07/14/05 TAG PLUG AT 12,400' SLM. SET JUNK CATCHER AT 12,400' SLM, OAL 115.5 OD 2.70 ID 1.995. TUBING PUNCH, STRING SHOT, AND CHEMICAL CUT THE TUBING AT +/- 12355' IN THE MIDDLE OF THE FIRST FULL JOINT ABOVE THE S-3 PACKER. REFERENCE DEPTH TO TUBING TALLY DATED 2/22/1996. ) ) Bp·EXPLORATION Q,peratlon!;Su.mmaryFleport Page 1 of 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-29 S-29 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/18/2005 Rig Release: 7/24/2005 Rig Number: Spud Date: 8/29/1990 End: 7/24/2005 Date From - To Hours Task Code NPT Phase Descriptionof Operations 7/18/2005 15:00 - 19:00 4.00 RIGD P PRE PJSM. Scope dwon & layover derrick. Prep rig componenets for move. 19:00 - 00:00 5.00 MOB P PRE PJSM. Move rig & rig components from MP C pad to S pad. 711 9/2005 00:00 - 10:30 10.50 MOB P PRE Continue moving rig from Milne Pt C pad tp S-29, 24 mile move. 10:30 - 12:30 2.00 RIGU P PRE PJSM. Reinstall BOPE in cellar. Spot sub, pits & camp. 12:30 - 14:00 1.50 RIGU P PRE PJSM. Raise & scope up derrick. Rig accepted @ 14:00 hrs, 07/19/2005. 14:00 - 15:30 1.50 KILL P DECOMP PJSM. Rig up lines to tiger tank, take on heated seawater. 15:30 - 16:30 1.00 KILL P DECOMP PJSM. Pick up lubricator. Pull BPV. Tubing on slight vacuum. No pressure on I/A. UD lubricator. 16:30 - 17:00 0.50 KILL P DECOMP Pre job wI regard to well killing ops. Test lines @ 350 I 3500 psi, OK. 17:00 - 20:30 3.50 KILL P DECOMP Commence pumping heated seawater down tubing @ 4 bpm I 350 psi, taking returns up I/A, thru choke to tiger tank, diesel returns, no gas. Circulated & pumped total of 740 bbls. SID, well dead. 20:30 - 21 :00 0.50 WHSUR P DECOMP Monitor well. Install TWC & test same to 1000 psi. Blow down & RID kill lines.. 21 :00 - 22:30 1.50 WHSUR P DECOMP Bled off hanger void. N/D tree & adapter flange. 22:30 - 00:00 1.50 BOPSUF P DECOMP N/U BOPE. 7/20/2005 00:00 - 02:30 2.50 BOPSUP P DECOMP Con't to N/U BOPE. Install choke & kill valves. RIU scaffolding section. 02:30 - 07:30 5.00 BOPSUP P DECOMP Test BOPE as per BP/AOGCC requirements. LP 250 psi. HP 4000 psi. BOP test witnessing waived by Jeff Jones wI AOGCC. UD test joint. pull two way check valve. 07:30 - 08:30 1.00 PULL P DECOMP Rig up Schlumberger spooling unit. Prep floor for pulling completion string. 08:30 - 09:00 0.50 PULL P DECOMP PJSM. BOLDs. Pull hanger to floor, hanger free @ 45K, 122K max pull, broke back to 88K steady up wt. 09:00 - 11 :00 2.00 PULL P DECOMP PJSM. POOH w/3 1/2" completion string & control line. Retrieved 37 of 37 stainless steel bands. 11 :00 - 12:00 1.00 PULL P DECOMP Rig down Schlumberger control line spooler. 12:00 - 16:00 4.00 PULL P DECOMP Continue to POOH w/3 1/2" completion string. Holes showing up in tubing beginning at #104. 16:00 - 17:30 1.50 PULL P DECOMP 134 jts out. Flow up tubing. Circulate @ 5 1/2 BPM, 300 psi, down tubing, 100 bbls. Shut in well, close bag & PT casing & tubing plug to 2000 psi, OK. Pull 4 jts, flowing back up tubing. Pump 100 bbls @ 5 112 bpm & 10 bbls of 9 ppg dry job. 17:30 - 20:30 3.00 PULL P DECOMP Pull out of hole & UD tubing. Tubing wet. Started blowing out holes in tbg in BOP. 20:30 - 22:30 2.00 PULL P DECOMP Monitor well & allow tubing to equalize wI annulus. Flow slowly dimished. 22:30 - 23:30 1.00 PULL P DECOMP Con't to POOH & UD tubing. 23:30 - 00:00 0.50 PULL N RREP DECOMP "0" ring in control valve on pipe skate failed. Repair same. 7/21/2005 00:00 - 00:30 0.50 PULL N RREP DECOMP Finish repairing pipe skate. 00:30 - 06:30 6.00 PULL P DECOMP Con't to POOH & UD 31/2" completion. 386 jts, 6 GLMs, SSSV & cut off jt. Inspect cut, tabbed out. OD of tube below cut = 3.55". 06:30 - 07:30 1.00 PULL P DECOMP Clear I clean rig floor. Prep floor to pick up DP. Set wear bushing. 07:30 - 08:30 1.00 CLEAN P DECOMP PJSM. Finish loading pipe shed w/3 1/2" DP, tally same. Printed: 7/25/2005 7:50:28 AM ) ) BP EXPLORATION Operation~Su.mmaryReport Page 20f 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-29 S-29 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/18/2005 Rig Release: 7/24/2005 Rig Number: Spud Date: 8/29/1990 End: 7/24/2005 Date From- To Hours Task Code NPT Pha.se Description of Operations 7/21/2005 08:30 - 10:00 1.50 CLEAN P DECOMP PJSM. Pick up dress off BHA & (9) 4 3/4" drill collars. 10:00 - 19:00 9.00 CLEAN P DECOMP PJSM. RIH wI dress off BHA & 31/2" DP 1 x 1. Tag top of 7" liner 25' in on jt #354 & rotate thru, OK. Tagged up @ 12348'. 19:00 - 20:30 1.50 CLEAN P DECOMP P/U kelly. Break circulation. Wash down & dress off tubing stub 1.5'. Top of stub @ 12350'. Washed to 12361' wI Overshot shoe. Had 11' of swallow. Tubing stub against side, could not go over w/o rotating. P/U 160KI, S/O 115K, Rot 134K. 60 RPMs, Torq 6K. 4 BPM @ 1100 psi. 20:30 - 00:00 3.50 CLEAN P DECOMP Mix 40 bbls Hi-Vis sweep. Close annular & reverse circulate. Pump 40 bbls sweep & clean hole. 4 BPM @ 1100 psi. 7/22/2005 00:00 - 00:30 0.50 CLEAN P DECOMP Finish reverse circulating Hi-Vis pill. 00:30 - 01 :30 1.00 CLEAN P DECOMP R/U to LDDP. POOH to TOL. 01 :30 - 02:30 1.00 CLEAN P DECOMP Cut & slip 84' of drilling line. 02:30 - 06:00 3.50 CLEAN P DECOMP POOH & UD 31/2" DP. 06:00 - 06:30 0.50 CLEAN P DECOMP Service rig. 06:30 - 11 :00 4.50 CLEAN P DECOMP PJSM. Continue to POOH & UD DP. 11 :00 - 12:30 1.50 CLEAN P DECOMP PJSM. UD 4 3/4" DCs & dress off BHA. Wear on mill indicates over stub. Tubing stub adjusted depth = 12,348'. Pull wear bushing. 12:30 - 16:00 3.50 RUNCOtvP RUNCMP PJSM. Finish racking, tallying & drifitng completion tubing. 16:00 - 17:00 1.00 RUNCOtvP RUNCMP Rig up to run completion. Generate completion summary & double check. 17:00 - 17:30 0.50 RUNCOtvP RUNCMP Pre Job meeting wI Baker Hand, Nabors Casing & rig hands. 17:30 - 00:00 6.50 RUNCOtvP RUNCMP P/U completion tail pipe assys, Baker Lok & RIH. P/U 4 1/2" 12.6#. L-80, TCII tubing & RIH. Torque turn all connections to 4440 ft-Ibs. Ran 110 jts. 7/23/2005 00:00 - 11 :00 11.00 RUNCOtvP RUNCMP Con't to RIH w/4 1/2" 12.6#, L-80, TCII completion. Torque turn all connections to 3850 ft-Ibs. 11 :00 - 12:30 1.50 RUNCOtvP RUNCMP PJSM. 121 K up wt, 85K down wt. See tag & shear pins on Unique Overshot 19.5' in on jt # 290. Slack off to 30' in on jt # 290 to verify, OK. Lay down jt # 290, no space out pups needed, approximately 8' of tubing stub will be swallowed. 12:30 - 18:00 5.50 RUNCOtvP RUNCMP PJSM. Reverse circulate 250 bbls heated seawater followed by 600 bbls heated seawater wI corrosion inhibitor. 3 bpm I 200 psi. 18:00 - 19:00 1.00 RUNCOtvP RUNCMP Land completion. P/U Wt 121K, S/O Wt 85K. RILDS. Drop Ball/Rod. UD landing jt. Drain stack. 19:00 - 21 :30 2.50 RUNCOtvP RUNCMP RlU to set & test packer. Pressure up & set packer, increase pressure to 4000 psi on tubing. Hold & chart for 30 min. Bleed off tubing pressure to 2000 psi & SI. Pressure up on annulus to 4000 psi, Hold & chart for 30 min. Bleed off tubing & DCR valve sheared @ 1600 psi. Equalize tbg/ann & bleed to 0 psi. Pump around both ways. 2 BPM @ 110 psi, to insure good clean shear. RID test equip. 21 :30 - 22:00 0.50 RUNCOtvP RUNCMP Intall TWC & test to 1000 psi. 22:00 - 00:00 2.00 BOPSUP P RUNCMP NID BOPE. Remove lines & valves to UD stack. 7/24/2005 00:00 - 01 :30 1.50 BOPSUP P RUNCMP Con't to NID BOPE. Break out mud cross & control lines to Koomey. 01 :30 - 03:30 2.00 WHSUR P RUNCMP N/U Adapter flange & X-mas tree. Test same to 5000 psi, OK. 03:30 - 04:00 0.50 WHSUR P RUNCMP P/U lubricator & pull TWC. UD lubricator. 04:00 - 06:30 2.50 WHSUR P RUNCMP RlU hot oilers Hold PJSM & freeze protect wI 150 bbls of diesel. Pump 2 BPM @ 550 psi. 06:30 - 07:30 1.00 WHSUR P RUNCMP PJSM. Allow diesel to U-tube. Printed: 7/25/2005 7:50:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) ) BP EXPLORATION O.peratio.nsSummaryReport S-29 S-29 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/18/2005 Rig Release: 7/24/2005 Rig Number: From- To Hours Task Code NPT Phase 7/24/2005 07:30 - 09:00 Page 3 of 3 Spud Date: 8/29/1990 End: 7/24/2005 Description öfOperations 1.50 WHSUR P RUNCMP PJSM. P/U lubricator, set BPV & test wI Little Red Services to 1000 psi, OK. Release rig @ 09:00 hrs, 07-24-2005. Printed: 7/25/2005 7:50:28 AM ( if ,~'i1ù,',','" é~I' , r~\\, :.I::'"'? :¡þ' ,:,' . "~. '1 'I /"1\ :: i' " .' , 'I. : J" ': ,: , .@ 1J ÎJ~ L L6 ''ñ) r~ (,\11. "I : L., I I I 1 , 'I" !r I 'I 'u -\ '.-..iI' ' .,.,;;;;.....' /~\-I-;' (7":::;"'\;-:1 /7'~ i,\ 'I '! ! .~\ : ,I ,!-oJ! "f' id ! j \ '\ "¡: ./ ./ '\"\ \~~.~, ::' / .,J 'Ï \ \ 1/ :W \1 I i .\....J " '\ '\ :1 ;\ \ /" u .\ , :¡.\ ¡ i !:....", "~J" ! ~ ti \. ,';-'\' i' 'j'" ,-,i! :. '\'. " ) 1 :, \ '\ '{:i \:\ ~I..".J ~ ~...-y ,.-;, ~---.... ..-;.I.....-¡, !:..;JÌlrJ. FRANK H. MURKOWSKI, GOVERNOR AIJASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jim Young Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 (b~ {è. 2.Dß\,] . ,,\\¡;~ \1 \~, ~~'. (_r cl ~\~Ik\N~~~~ JUL- ~ Re: Prudhoe Bay S-29AL1 Sundry Number: 305-200 \<\VO\~ Dear Young: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day follow'q the date of this letter, or the next working day if the 23rd day falls a oliday or weekend. A person may not appeal a Commission deci on Superior Court unless rehearing has been requested. DATED this z"bday of July, 2005 Enc!. ( . bp ~, ....,:::"'.-'~"¡J:r. ~.;[ ,~ "'<",¡ ",,)~,': ~ "," \ 1 July 18, 2005 RECE\VED JUl 42, 1 lGGS . Comffi\SS\O\1 0·\ & Gas Cons. Mas\c.a \ ~nthora\\e Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK 99501 Dear Winton: RE: Sundry Notice for S-29A & S-29AL 1 --- Conversion from Production to WAG Injection BP Exploration Alaska, Inc. proposes to convert wells S-29A & S-29AL 1 (common wellbore) to a WAG injection well. In 1996, S-29 was sidetracked from the original 9-5/8" casing and a 7" liner was cemented across the Sag & upper Ivishak reservoir prior to drilling horizontal laterals S-29A (Ivishak) and S-29AL 1 (Sag lateral). S-29A (& S-29AL 1) have been SI for high water-cut since 2001. Objective of S-29A & S-29AL 1 conversion ~. is to increase waterflood reserves in S-29A, a peripheral region between it and newly drilled wells S-278 and S-18A, capturing oil that will remain un-swept without injection support S-29AL 1 was unproductive as a Sag River producer and it is expected that this zone will not take any of the injected fluids. The S-29A scope of work is as follows: · Complete RWO to restore tubing integrity. · Convert surface facilities to water and MI injection service. · Place S-29A on injection service, confirm containment with temperature log. -' /~" S-278 is the only offset reservoir penetratiqn within % mile radius of S-29A or S- 29AL 1. S-278 penetrates 6000' of horizontal section in the Ivishak and is 600' north of S-29A at its closest approach. The cemented 7" liner from which S-278 ' was drilled is approximately 4000' from S-29A & S-29AL 1. Since no cement bond logs are available, a temperature log will be run to verify containment to the target zone upon injection startup. Questions can be referred to Jim Young at 564-5754. Thank you, Sincerely, J()~:g~~ GP8 Waterflood ¿gineer Cf'.f '7 - b~ -'o~ \AJ{¡1r 1/2. S zoo~ ( STATE OF ALASKA Or={' 7/':<6/.5 ALASKA OIL AND GAS CONSERVATION COMMISSION RECE\VED APPLICATION FOR SUNDRY APPROVA~L 21 2005 20 AAC 25.280 1. Type of Request: D D Abandon Suspend Alter Casing D Repair Well D Change Approved Program D Pull Tubing D 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 68.17 KB 8. Property Designation: ADL-028261 11. Presen1 Total Depth MD (ft): 14268 Casing Total Depth TVD (ft): 8871.7 Length CONDUCTOR SURFACE PRODUCTION LINER LINER SLOTTED LINER 83 2764 11720 1148 1569 1508 20" 91.5# H-40 13-3/8" 68# NT-80 9-5/8" 47# NT-80 7" 29# L-80 4-1/2" 12.6# L-80 4-112" 12.6# L-80 Perforation Depth MD (ft): 12737 - 14245 Perforation Depth TVD (ft): 8875 - 8870.4 Packers and SSSV Type: 3-1/2" Baker S-3 Packer 3-1/2" HES SSV Landing Nipple 12. Attachments: Description Summary of Proposal ŒI Detailed Operations Proç¡ram D BOP Sketch D 14. Estimated Date for Commencing Operation: July 29, 2005 Operation Shutdown Plug Perforations Perforate New Pool 4. Current Well Class: o D D . f.:. Cons C ommi$!Üor. -A\aska 0\\ & uas . Perforate U - w~[ije Other [!] StimulateD Time Extension D CONVERSION Re-enter Suspended Well 0 TO WAG WELL 5. Permit to Drill Number: 196-0120 /' /' Development Œ] Exploratory 0 top 27 26 25 11533 12699 12737 bottom top 110 2790 11745 12681 14268 14245 Stratigraphic 0 Service 0 9. Well Name and Number:, S-29AL 1 / 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 14268 8871.7 Size MD TVD Tubing Size: 3-112 " 27.0 26.0 25.0 8049.9 8862.2 8875.0 Packers and SSSV MD (ft): 6. API Number /' 50-029-22082-60-00 Plugs (md): None Burst Junk (md): None Collapse bottom 110.0 2710.2 8182.4 8854.5 8871.7 8870.0 1490 5020 6870 8160 8430 470 2270 4760 7020 7500 Tubing Grade: Tubing MD (ft): 9.3 # L-80 23 12452 12394 2188 13. Well Class after proposed work: ~" Exploratory D DevelopmentD 15. Well Status after proposed work: Oil D GasD PluggedD WAG IX] ./ GINJD Date: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature ~~ YO? aV\ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness BOP TestD Mechanciallntegrity Test ~ Title Phone ServiceŒ} Abandoned 0 Contact WINJD WDSPLD Prepared by DeWayne R, Schnorr 564-5174. Jim Young Petroleum Engineer 564-5754 7/15/05 Sundry Number: 3r,,5-~Dð Location Clearance D :þ,¡-...( ~t{ +'\II'-'-{ r(~.u hL d pno ~ .:þ. <} qh I~«'~:.'- · - 4D4· . '" ",' "o,.I'~ , L r', II ". ~ RDf)"~S BFl rt '1'\ ¡V ~ ~ '\i r\ m, - JUL 2 &10u5 ~ ",- BY ORDER OF THE COMMISSION Date: fi.b/ oS SUBMIT IN puchE- ,t (' I TREE = 4" CWV WELLH~D = FMC , A Cfl..LA. TOR = BAKER ~ KB. 8..EV = 63,12' BF. ELEV = 35.72' KOP = 1758' Max Ängle';"- ---'"9'f@"14738' DatLïm MD = 12713 Datum 1VD = 8800' SS S-29A SAFETY NOTES: UPPER LAT. IS AN OPEN HOLE LNR WIO LNRTOP/PKRlHGR LNRSITS ON BTM. ISOLATION PKR SET ON E-LlNEAN:> BELOW UPPER LATERAL SS:;TION. D~THS OON'T IN[]CATETHIS CUETO DIFFERENCE BETWEEN DRlLLPIPE ANDE-LlNE MEASUReJI~TS. 700@ 12879' AND 90° @ 13343' Minimum 10 = 2.635" @ 12707' 3-1/2" HES XN NIPPLE , 1 2188' H3-1/Z' I-ES SSSV LAND. NIP, ID = 2.75" -¡-i 2720' ra GAS LIFT MANDRELS ST MD lVD DEV TYPE VLV LATa; PORT DATE a 6 4880 3978 56 TGPDX RK 5 7870 5667 57 TGPDX RK 4 9470 6672 46 TGPDX RK 3 10600 7408 53 TGPDX RK .. 2 11696 8081 53 TGPDX RK 1 12321 8586 39 TGPDX RK 12382' H 3-1/2" HES X NIP, ID = 2.75" 1 12394' H 7" BAKER S-3 PKR, ID = 3.875" 12419' H3-1/2" HES X NIP, ID= 2.75" 1 12440' 1-13-1/2" HES X NIP, ID = 2.75" 1 12452' H3-1/2"WilEGI 12457' l-t ELMD TT LOGGED 05/02/96 1 ~ 12699' H BAKER SErllNG SL V W/6' EXT 1 ~ --....-.... MlLLOur WINOOW ~.... ..s"..ep ........................ 12681'-12693' --.... ~<~ -........ ................... ...................... ....- .... .....- H 12495' I-1RA TAG 1 ...................._.... L 113-3/8" CSG, 68#, NT-80, ID = 12.415" H 2720' µ 1 TOP OF 7' LNR H 11533' 11 1 9-5/8" CSG, 47#, NT-80-S NSCC, ID = 8.681" H 11745' ~ 13-1/2"TBG,9.3#, L-80, 0_0087bpf, ID=2_992" 1-1 12452' 1 )8 12696' H BKR SO MDL D PKR, ID = 2.93" 12707' 1-13-1/2" HES XN NIP, D = 2.635" 1 12716' H3-1/2" W/LEG 1 4-1/2" LNR, 13-CR, 12.6#, -i 14268' 1 .0152 bpf, ID = 3.958" TOP OF 4-1/2" LNR 1--1 12946' 1 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 1-1 13116' 14-1/2"LNR, 12.6#, L-80, 0.0152bpf, ID=3.953" 1-1 13319' ITOPOF4-1/2" SLTD LNR 1-1 13470' 1 4-1/2" SL TD LNR, 12.6#, 13-CR, 0.0152 bpf, D = 3.958" 1-1 15059' 12740' HRA TAG 1 13332' I-JCTCPAYZONEPKR I 13459' H4-1/2" XN NIP, ID = 3.725" 1 4-1/2" LNR, 12.6#, 13-CR, 0.0152 bpf, ID = 3.958" 1-1 15061' I DATE 11/14/90 02/23/96 01/21/99 03/15/01 03/16/01 CHH GLM SIS-MH SIS-CS COMMENTS ORIGINAL COrvPLErION MUL ll-LATffiAL COMR...ETlON LA ST WORK OVER CONVERTED TO CANVAS RNAL DATE 03/02/02 RBI BY COMM8'JTS RN/TP CORRECTONS FRUDHOE BA Y UNIT W8..L: S-29A ÆRMIT No: 196-0120 API No: 50-029-22082-01 SEC 35, T12N, T12E 8P Exploration (Alaska) REV BY MECHANICAL INTEGRITY REPORT' ........ :.1: G R E L E;.. S ~ : OPER & FIELD -2 P (J ¿'Ú 'W'"Eil NUMBER S ,. 2 c¡ A- L I ,- .,..,UD "'" J ~ - . .: ~ i.J _~.. ..:....:.. : .:-:..:!e::: q , )1 i ., 7" TD : [4 2&-8 Jill.. g~7 7. TVD; :? B TD : I { Z&.ç MD -f #7 2. TVD Shoe: 1/74ç HD g¡-F2 TVD i DV: 2720 till ·Tvl) Shoe: )2iPJI HD ~fS$ TVD; "... '"' T'" 115 3 ~ HD go 50 :".7"0 .:..u..t' : 7~~LL DATA Cë.si!J.g: II .. :~bi::g: '3 -/2 Packe::- J24~ 2· HD :: ole S':"z e Il ,. '/1 II anå R ,.. 'll II TVD; Set ê. t: / 2 5 c¡ 4 c-jdfe J A 2 4(--- i -..·P"e!:~··s·~ ) t 7 S 7 to l (,..~ . ~C?..ANIC;'.L INTEGRITY - P.lŒ.T ¡ 1 Annulus Press Test: ~p 15 min 3 0 min COtï:i!:lents: /Vl I'·'- 'v'1/1 C/.Æ^ I~ J I o ,,- MECHÞ_'/\1ICÞ.~ INTEGRITY - PART i 2 Cement: Volumes:· þ....mt. Liner 7 ktJ/~; Csg C¡¡¡t. -"01 to cover perf s 2, ~, DV 'Iheore tical Toe , l ~ 7 ~~ I Cement Bond Log (Yes or No) fJ In AOGCC File . CBL Evaluation, =one above perfs . i ! I i i I Production Log: Type VJ e I) 12ÆJ. .A(. ~'Yf . ç.U II'll ·~Aj¡ ." ( CONC~LUSIONS : ?arf n: ¡VtJ:T r<'~ u,/Ä.e d ? ar:: : z: "'-1 It ! I }'J!"v Cvt.-\.;t- 1;tÆJ~" ~i!)..4 \l(2 Å-P 11 J ,ß V ..../ \ -'-1-A'('}viA, M t«..d.t à , ..' I~\I, j :fr'" '-11 ) ~.:J '~,~/,. f'''' \;..../ (~~, . ·..¡i"'tÁ,... /)...'..A.....I·~ if l...) l \.r~"u:'!' ()\";,;.. Evaluation ~'~'[þ~ 1,1~ ro..I. À .. f) ,':,: (. lotk"J I ''OJ'' l 1,.11 ..,.€...'¡( /1', ¡, ,,_ V ~""-'" . ý~_ {.tl~fJV'.() / Date: To: From: Subject: t July 25, 2005 File Jane Williamson Well S-29A and S-29ALI BP is requesting approval to convert Prudhoe Ivishak Well S-29A along with its Sag lateral to a WAG injector. Production and decline plots are attached. Only the Ivishak portion of the well produced. Essentially no oil reserves remain in this producer. The reservoir pressure within the area of S Pad has been hovering at or below the minimum miscibility pressure. Increasing reservoir pressure is important and this conversion should be approved. o..m 01 ROO, M:tA 75) 400 3X) I 1&1 o - R-ase Case Nare 100 -: b : () - q ti te 8'rl Rate 100 I:iii d 10 _ RraI Råe 101.84l:iiid : Q.m ROO. 6æ.472 M:tA - Q.m D:te 1Q'31/:m2 Fè>erves 0 M:tA - 8.R 6æ.472 M:tA - Faecast 8"ded B¡ Råe Faecast D:te 07/2fi'ðJ:Jj 01 OIW:lI 1 0.1aŒ2Ae. 76.049l:iiid 12/31/2))4 Date , I I I '013' r, , I I ' ! I , ro~ I I , I r I' I I I ~r6' , I I I I r I '1'U~~' r "1" I I ~'7" r 11 [' '" ',,10' '" I 1" r I 'o~' " '! I' r "2'0 O~" r' 1'" I ~I, I '" , 02"220820100:150 - Oil Ral. (CD) (Mbblld ) Wale' Rale (CD) (t.Abblld ) Ga. Ralo (CD) ( Mt.Aclld ) W 0111 on W alar Inlecllon W oil, on G.. Injection G.. Inj Rale (CO)(Mct/d) W alor InJ Rale (CD) C Mbbl/d ) Producing Oil Well. PRUDHOE BAY, PRUDHOE OIL PBU_S PRUDHOE BAY S-29A 32 :õ ..c êÎ ~ .æ I\ a::: Ö 100:> 1 cx:ro 0.001 0.01 0,1 -: 1 -: 10 ,¡t c:~OVaX~t~a.t~c P E RM I T DATA 96-012 GR/CCL 96-012 NGP-MD ~k~( 96-012 NGP-TVD ~A'! 96-012 7906 AOGCC Individual Well Geological Materials Inventory T DATA PLUS ~EPIA . /~0 -127q3-- Q.L~ 12131-14275 ~499-8872 ~D~PERRY GR/RES Page: 1 Date: 02/25/98 RUN RECVD 1 02/26/96 FINAL 12/11/96 FINAL 12/11/96 2,5-8 02/12/97 10-407 ~-~OMPLETION DATE AI~3 Iq6l ~1 I] I ~/ DAILY WELL OPS R ~11~1~ I TO ~1~"t1~1 ~1/~ I~ I Are dry ditch samples re~ired? yes no ~d received? yes no Was the well cored? yes ~_~.Analysis & description received? ye~L___nm Are well tests required? yes Well is in compliance ,~ In~%~al COMMENTS ...~__Received? D I:! I I--I-- I I~1 G SE~I:I~I r- E S WELL LOG TRANSMITTAL To: State of Alaska February 12, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - S-29A AK-MM-960104 S-29AL1 AK-MW-60012 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning signed copy of this transmittal letter to the attention of~ Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2 LDWG formatted Discs with verification listing. API#: 50-029-22082-01 & 50-029-22082-60 respectively. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company I"1 F:t I I_1_ I IM G S El I:1~/I C I:: S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Drive Anchorage, Alaska 99501 December 9, 1996 RE: MWD Formation Evaluation Logs S-29A & S-29AL1, AK-MM-960104 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 S-.29A: ~ (.a - ~1, ~ 2" x 5" MD Gamma Ray Logs: 50-029-22082-01 2" x 5" TVD Gamma Ray Logs: 50-029-22082-01 S-29ALl: q Le-' 2"x 5" MD Gamma Ray Logs: 50-029-22082-60 2"x 5" TVD Gamma Ray Logs: 50-029-22082-60 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 F! I I--I--I IM G c:: E Fl~4 I i-- E S May 8, 1996 AOGCC Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Re: Distribution of Survey Data 17-04A Dear Mr. Grant, Enclosed are two hard copies of the above memioned file(s). od~q'l~ell 17-04APB1 MWD survey, tie in point 7,699.78', window point 7,745', interpolated depth 11,561' q.{~-Y-~Well 17-04A q{~ ,~'1 Well 17-04AL1 MWD survey, tie in point 11,310.65', interpolated depth at 12,816' MWD survey, tie in point 11,147.66', kickoff point 11,166', interpolated depth 12,894' Please call me at 563-3256 if you have any questions or concerns. Regards, SanSr~ Lufkin Dept. Specialist Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 96-12 3. Address B. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5 o- 029-22082-60 4. Location of well at surface ~ ~f:' :.~' : ~~~.'-~f 9. Unit or Lease Name 1641' SNL, 1560' EWL, SEC. 35, T12N, R12E ' ; ' ~ ~ !~2~.~. ~ Prudhoe Bay Unit ~ '~ ! 0. Well Number At Top Producing Interval ! = 0 ~/~i/~ , i! ii$~"~'"--~! S-29AL1 4010'SNL, 583'WEL, SEC. 3, T"N,R'2E !. .... '~: "')... :': !~!,~ !.~ 11. Field and Pool At Total Depth ' ' ' ' '"~ Prudhoe Bay Field/Prudhoe Bay Pool 4275' SNL, 2092' WEL, SEC. 3, T11N, R12E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 68.17' ADL 028261 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 02/13/96 02/17/96 02/23/96I N/A feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+-I-VD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 14275' MD / 8872' TVD 14275' MD / 8872' TVD YES [] ~ []I 2188feet MD 1900'(Approx.) 22. Type Electric or Other Logs Run L WD/FE, GR/SFL, ILM, ILD/Sonic/Density, RES 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Be'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Surface 110' 13-3/8" 68# NT-80 Surface 2790' 17-1/2" 2523 cuft Arctic Set II 9-5/8" 47# NT-80S Surface 11695' 12-1/4" 2842 cuft Class 'G' 7" 29# L-80 11533' 12681' 8-1/2" 388 cu ft Class 'G' 4-1/2" 12. 6# L-80 12699' 14268' 6" Uncemented Slotted Liner 24. Perforations open to Production (MD+TVD of Top and Bottom and ~5. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 3-1/2" 12452' 12394' MD 7-VD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12737' - 14245' 8875' - 8870' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Open Hole Freeze Protect w/155 Bbls Diesel 12693'- 12699' 8860'- 8862' 14268'- 14275' 8872'- 8872' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 11, 1996 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED,,~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl .(corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. "~ -~ -.- / ~ ;,.~,:~'.,.- (j' . % 7~ -; ...... t'~. ,~- r. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 12664' 8847' Shublik 12770' 8881' Shublik 12865' 8879' Shublik 14100' 8866' ORIGII'q'AL 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~,-'.'. ~ TitleSeniorDrillin~lEngin~er Date ,,'~- .~-- ~""',~''- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 / Surf Csg Dep 2958 Cum Brine ~i~'~;~;~;~':~ Cum Water ~,~;~i~i~:~i'.~;~i~:,i~;~',i~ Cum Die~FP ~Z~ t[i ~[?,~8 VOLUME (BBLS~[ Method of disp/osal=pumping down outer annulus SOURCE WELL DATE OF ...... DIESEU FRE~E ........ T_._~I COMPLICATIONS COMME~S NUMBER INJECTION MUD/CTGS BRINE w~ PROT. ua.y ~u,.. u~. I ' S-29A 1/1 8/96 160 20 100 ~[~[~[~[~ ';~=.~ 600 PSI i ' S-29A 1/21/96 950.00 35.00 ~[~ ~ ~ ~ ~:~ 600 PSI ' S-29A 1/22/96 -- 66.00 ~ ', ~?:~ ~'~! ?"::'~ ~ ?~',~ ~ S-29A 1/23/96 545 45.00 ~?;~[~;~[~ ~'8~'~8~650 PSI S-29A 1 / 24/96 1 00 26.00 (~: ~:~= ~i~ii~ ~ ;~i ~:,~ ~ S-29A 1/25/96 1000.00 -- 45.00 ~'~[~{~[~ ~; ~' ~~ ~ - S-29A 1 / 2 6 / 9 6 '-~' -- ~ ?,~i~"~[~'~i{~ :: :; ~;~[~ ~;;~ 600 PSI S-29A 1/27/96 ...... ~' .... ~; ~:~?'~:'~.8~ ~ -- S-29A 1/28/96 -- --- ~% ~'~i~[';~8;~ 750 PSI ~ S-29A 1 / 2 9 / 9 6 '~ 85.00 [~;:~ ~';~ ~[ ~;~ :;~;::~:,?:~, 800 PSI S-29A 1/30/96 359.00 --- 220 00 ~8~650 PSI 130 CBT WASH WATER S-29A 1/31/96 1072.00 51 00 ?;:::::~ ~. ~;~700PSI S-29A 2 / 1 / 9 6 604.00 ~;::;~ 600 PSI S-29A 2/2/96 60.00 ;~8;:~:'88~: 650 PSI S-29A 2 / 3 / 96 --- - ~ S-29A 2/4/96 '-- ~ ~5 ~ :.; 700 PSI S-29A 2/5/96 -- ~ 100 00 10 ~ ~ ~ S-29A 2/6/9 6 0.00 ~: ' S-29A 2 / 7 / 9 6 225.00 10.00 650 PSI I NC 125 BBL CMT WASH S-29A 2/9/96 1411.00 J 650 PSI S-29A 2/1 0/96 I 896.00 .00 I 700 PSI S-29A 2/11/96 40.00 395.00 91 PSI S-29A 2/1 2/96 743.00 25.00 PS~ S-29A 2/1 3/96 ~ 100.00 10.00 ~;;;:,;;;;~i'¥;;:;.; :i50:;:8~ 700 PSI S-29A 2/14/961 ~ 173.00 ~ :. :~'~: 173~00:700 PSI [ S-29A 2/15~ ~ 'I -~ 75.00'~ ~ S-29A [ 2/1 9/96~ 182.00l 756.00 ' 938~,00~700 PSI I S-29A 2/20/96~ ~ 1004.~ ' ' ' i00'~.0'O'~700PSl i s-29, ..... [ [ S-29A I ~-~ ~ ........ ~ %~1 ................. ~ ' 418'00~¥ S-29A ] ..... -~-3~-9-~'[ ................... 1 ....... ~' ~'[ .................. ~ ......... ~-~-~; 00 '~ ............ [?~'~ROTEOTED T~2~M.D. ! -[ .................. ....................... ! ................... ..... o,oo,. ! ....... I -- SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX/ ARCO Well Name: S-29A & Rig Name: Nabors 28E AFE: S-29AL1 Accept Date: 01/1 8/96 Spud Date: 01/25/96 Release Date: 4P0733 02/23/96 Jan 18 1996 (1) Rig moved 100 %. Rigged up High pressure lines. Retrieved BOP test plug assembly. Jan 19 1996 (2) Fill pits with Seawater. Held safety meeting. Circulated at 12300 ft. Installed BOP test plug assembly. Rigged down Surface tree. Rigged up BOP stack. Tested BOP stack. Rigged up Bell nipple. Retrieved BOP test plug assembly. Laid down Tubing to 12260 ft. Tested BOP stack. Jan 20 1996 (3) Tested BOP stack. Rigged up Tubing handling equipment. Laid down Tubing to 0 ft. Rigged down Tubing handling equipment. In- stalled Wear bushing. Ran Drillpipe to 4500 ft (5 in OD). Jan 21 1996 (4) Ran Drillpipe to 12000 ft (5 in OD). Set Bridge plug at 12000 ft with 0 psi. Pulled Drillpipe in stands to 4000 ft. Serviced Block line. Pulled Drillpipe in stands to 0 ft. Installed Seal assembly. Installed Wear bushing. Tested Casing. Made up BHA no. 1 . R.I.H. to 12000 ft. Circulated at 12000 ft. Pulled out of hole to 11695 ft. Milled Casing at 11695 ft. Jan 22 1996 (5) Milled Casing at 11745 ft. Circulated at 11745 ft. Pulled out of hole to 1000 ft. Jan 23 1996 (6) Pulled out of hole to 310 ft. Worked stuck pipe at 310 ft. Jarred stuck pipe at 310 ft. Pulled out of hole to 0 ft. Re- trieved Wear bushing. Tested BOP stack. Installed Wear bushing. Ran Drillpipe in stands to 3200 ft. Operations Summary for: ._ ~'9A & S-29AL1 Jan 24 1996 (7) Ran Drillpipe in stands to 11600 ft. Washed to 11845 ft. Circu- lated at 11845 ft. Pumped spacers - volume 14 bbl. Mixed and pumped slurry- 35 bbl. Displaced slurry - 195 bbl. Pulled Drillpipe in stands to 10717 ft. Circulated at 10717 ft. Pulled Drillpipe in stands to 0 ft. Retrieved Wear bushing. Tested BOP stack. Installed Wear bushing. Fill pits with Water based mud. Laid out 5 in drill pipe from derrick. Jan 25 1996 (8) Made up BHA no. 2. R.I.H. to 6300 ft. Circulated at 6300 ft. R.I.H. to 11457 ft. Serviced Flowline. Drilled cement to 11698 ft. Drilled to 11729 ft. Held safety meeting. Circulated at 11729 ft. Drilled to 11731 ft. Serviced Shaker discharge line. Drilled to 11746 ft. Jan 26 1996 (9) Drilled to 12046 ft. Serviced Mud shakers. Drilled to 12132 ft. Circulated at 12132 ft. Pulled out of hole to 630 ft. Pulled BHA. Jan 27 1996 (10) Held safety meeting. Made up BHA no. 3. R.I.H. to 11602 ft. Serviced Block line. R.I.H. to 12132 ft. Drilled to 12343 ft. Serviced Mud pump power end. Drilled to 12570 ft. Jan 28. 1996 (11) Drilled to 13005 ft. Jan 29 1996 (12) Drilled to 13104 ft. Worked toolstring at 13104 ft. Drilled to 13116 ft. Circulated at 13116 'ft. Pulled out of hole to 150 ft. Pulled BHA. Serviced High pressure lines. Held safety meeting. Made up BHA no. 4. R.I.H. to 3500 ft. Repaired Drillstring handling equipment. R.I.H. to 10500 ft. Page 2 Operations Summary for: ~-29A & S-29AL1 Jan 30 1996 (13) R.I.H. to 12110 ft. Reamed to 13116 ft. Circulated at 13116 ft. Laid down 990 ft of 5 in OD drill pipe. Pulled out of hole to 130 ft. Pulled BHA. Held safety meeting. Rigged up Casing han- dling equipment. Ran Casing to 1500 ft (7 in OD). Circulated at 1500 ft. Ran Casing on landing string to 6000 ft. Held safety meeting. Ran Casing on landing string to 11700 ft. Circulated at 11700 ft. Ran Casing on landing string to 12464 ft. Washed to 12464 ft. Rigged up High pressure lines. Ran Casing on land- ing string to 13116 ft. Jan 31 1996 (14) Circulated at 13116 ft. Held safety meeting. Pumped spacers - volume 90 bbl. Mixed and pumped slurry- 65 bbl. Displaced slurry- 248 bbl. Circulated at 11540 ft. Laid down Drillpipe to 3000 ft. Held safety meeting. Pulled Drillpipe in stands to 25 ft. Laid out 5 in drill pipe from derrick. Held safety meet- ing. Retrieved Bore protector. Installed BOP test plug assem- bly. Tested All functions. Retrieved BOP test plug assembly. Installed Bore protector. Made up BHA no. 5. Serviced Brake. Singled in drill pipe to 1000 ft. Held safety meeting. Serviced Block line. Held safety meeting. Singled in drill pipe to 3700 ft. R.I.H. to 10000 ft. Feb I 1996 (15) R.I.H. to 12500 ft. Logged hole with LWD: Formation evaluation (FE) from 12500 ft to 12860 ft. R.I.H. to 12920 ft. Circulated at 12920 ft. Tested Casing - Via annulus and string. Drilled cement to 13029 ft. Drilled installed equipment- Landing col- lar. Drilled cement to 13116 ft. Drilled to 13126 ft. Circu- lated at 13126 ft. Drilled to 13196 ft. Pulled out of hole to 13100 ft. Circulated at 13100 ft. Feb 2 1996 (16) Circulated at 13100 ft. Circulated at 13100 ft. Circulated at 13100 ft. R.I.H. to 13196 ft. Drilled to 13254 ft. Circulated at 13254 ft. Pulled out of hole to 12780 ft. Rest hole at 12780 ft. R.I.H. to 13254 ft. Circulated at 13254 ft. Drilled to 13413 ft. Circulated at 13413 ft. Held safety meeting. Pulled out of hole to 13100 ft. R.I.H. to 13413 ft. Drilled to 13604 ft. Pulled out of hole to 13100 ft. R.I.H. to 13604 ft. Drilled to 13667 ft. Page 3 Operations Summary for: ,~-29A & S-29AL1 Feb 3 1996 (17) Drilled to 13919 ft. Pulled out of hole to 13100 ft. R.I.H. to 13919 ft. Drilled to 13920 ft. Circulated at 13920 ft. Pulled out of hole to 11520 ft. Circulated at 11520 ft. Pulled out of hole to 300 ft. Pulled BHA. Retrieved Bore protector. In- stalled Bore protector. Made up BHA no. 6. R.I.H. to 8400 ft. Feb 4 1996 (18) R.I.H. to 13139 ft. Logged hole with LWD: Formation evaluation (FE) from 13139 ft to 13920 ft. Drilled to 14228 ft. Pulled out of hole to 13100 ft. Circulated at 13100 ft. R.I.H. to 14228 ft. Drilled to 14544 ft. Pulled out of hole to 13100 ft. Cir- culated at 13100 ft. R.I.H. to 14544 ft. Drilled to 14745 ft. Feb 5 1996 (19) Drilled to 14863 ft. Pulled out of hole to 13100 ft. Circulated at 13100 ft. R.I.H. to 14863 ft. Drilled to 15061 ft. Circu- lated at 15061 ft. Circulated at 15061 ft. Logged hole with LWD: Formation evaluation (FE) from 15061 ft to 13900 ft. Laid down 1900 ft of 5 in OD drill pipe. Circulated at 11530 ft. Held safety meeting. Pulled out of hole to 300 ft. Downloaded MWD tool. Pulled BHA. Feb 6 1996 (20) Held safety meeting. Made up BHA no. 7. R.I.H. to 12695 ft. Held safety meeting. Serviced Block line. Held safety meeting. Serviced Block line. Circulated at 12695 ft. Washed to 13116 ft. Reamed to 15061 ft. Circulated at 15061 ft. Pulled out of hole to 13500 ft. Feb 7 1996 (21) Pulled out of hole to 11530 ft. Circulated at 11530 ft. Pulled out of hole to 5000 ft. Held safety meeting. Pulled out of hole to 150 ft. Pulled BHA. Serviced Drillfloor/ Derrick. Rigged up Casing handling equipment. Held safety meeting. Ran Casing to 2128 ft (4.5 in OD). Held safety meeting. Ran Drillpipe on landing string to 9450 ft. Held safety meeting. Rigged up High pressure lines. Ran Casing in stands to 15061 ft. Circulated at 13470 ft. Held safety meeting. Pumped spacers - volume 70 bbl. Displaced slurry- 191 bbl. Page 4 Operations Summary for: ,.,-,,'9A & S-29AL1 Feb 8 1996 (22) Rigged down High pressure lines. Pulled Drillpipe in stands to 0 ft. Retrieved Wear bushing. Tested BOP stack. Installed Wear bushing. Made up BHA no. 8. R.I.H. to 12936 ft. Pulled out of hole to 200 ft. Pulled BHA. Made up BHA no. 9. R.I.H. to 10000 ft. Feb 9 1996 (23) R.I.H. to 12900 ft. Serviced Block line. Reamed to 12942 ft. Pulled out of hole to 240 ft. Pulled BHA. Ran Casing on landing string to 12918 ft. Circulated at 12933 ft. Set Tie back packer at 12918 ft with 3500 psi. Tested Casing - Via annulus and string. Retrieved Drillpipe landing string. Made up BHA no. 10 R.I.H. to 6000 ft. Feb 10 1996 (24) R.I.H. to 12941 ft. Drilled cement to 13100 ft. R.I.H. to 13318 ft. Drilled installed equipment - Landing collar. Circulated at 13364 ft. Reverse circulated at 13364 ft. Drilled installed equipment - Landing collar. Flow check. Pulled out of hole to 550 ft. Pulled BHA. Made up BHA no. 11 . Feb 11 1996 (25) Rigged down Drillstring handling equipment. R.I.H. to 15061 ft. Circulated at 15061 ft. Pulled out of hole to 2500 ft. Rigged down Drillstring handling equipment. Pulled BHA. Rigged up Logging/braided cable equipment. Conduct braided cable operations - 5/16 size cable. Conduct braided cable operations - 5/16 size cable. Set downhole equipment (wireline). Feb 12 1996 (2) Set downhole equipment (wireline). Conduct braided cable opera- tions - 5/16 size cable. Made up BHA no. 1. R.I.H. to 12696 ft. Set tool face. Circulated at 12681 ft. Feb 13 1996 (3) Milled Casing at 12693 ft. Circulated at 12680 ft. Serviced Block line. Pulled out of hole to 800 ft. Pulled BHA. Re- trieved Wear bushing. Made up BHA no. 2. R.I.H. to 8000 ft. Page 5 Operations Summary for: ,.. 29A & S-29AL1 Feb 14 1996 (4) R.I.H. to 12681 ft. Reamed to 12714 ft. Drilled to 12758 ft. Pulled out of hole to 10790 ft. R.I.H. to 12758 ft. Drilled to 12792 ft. Circulated at 12792 ft. Pulled out of hole to 200 ft. Pulled BHA. Made up BHA no. 3. R.I.H. to 9000 ft. Feb 15 1996 (5) R.I.H. to 12792 ft. Drilled to 13122 ft. Pulled out of hole to 11375 ft. R.I.H. to 13122 ft. Drilled to 13265 ft. Pulled out of hole to 11682 ft. R.I.H. to 13265 ft. Drilled to 13500 ft. Feb 16 1996 (6) Drilled to 13500 ft. Circulated at 13657 ft. Pulled out of hole to 200 ft. Pulled BHA. Retrieved Wear bushing. Tested BOP stack. Installed Wear bushing. Made up BHA no. 4. R.I.H. to 12518 ft. Serviced Block line. Feb 17 1996 (7) R.I.H. to 13657 ft. Drilled to 14275 ft. Circulated at 14275 ft. Feb 18 1996 (8) Circulated at 14275 ft. Pulled out of hole to 200 ft. Pulled BHA. Made up BHA no. 5. R.I.H. to 12715 ft. Reamed to 14275 ft. Circulated at 14275 ft. Feb 19 1996 (9) Circulated at 14275 ft. Pulled out of hole to 0 ft. Rigged up Casing handling equipment. Ran Casing to 1410 ft (4.5 in OD). Ran Casing on landing string to 14113 ft. Circulated at 14113 ft. Circulated at 14113 ft. Feb 20 1996 (10) Circulated at 14113 ft. Retrieved Casing landing string. Ran Casing on landing string to 14275 ft. Retrieved Casing landing string. Flow check. Serviced Block line. Retrieved Casing landing string. Laid down Casing to 1410 ft. Ran Casing to 1569 ft (4.5 in OD). Page 6 Operations Summary for: ,., ,~9A & S-29AL1 Feb 21 1996 (11) Ran Oasing to 1569 ft (4.5 in OD). Ran Casing on landing string to 14268 ft. Retrieved Drillpipe landing string. Circulated at 12681 ft. Retrieved Drillpipe landing string. Made up BHA no. 6 R.I.H. to 12681 ft. Fished at 12681 ft. Pulled out of hole to 10000 ft. Feb 22 1996 (12) Pulled out of hole to 50 ft. Pulled BHA. Serviced Drillfloor / Derrick. Made up BHA no. 7. R.I.H. to 12600 ft. Circulated at 12600 ft. Serviced Block line. Laid down 12600 ft of 5 in OD drill pipe. Pulled Bore protector. Serviced Drillfloor/Der- rick. Held safety meeting. Rigged up Tubing handling equipment. Ran Tubing to 300 ft (3.5 in OD). Feb 23 1996 (13) Ran Tubing to 10250 ft (3.5 in OD). Rigged up sub-surface equip- ment- SCSSSV nipple assembly. Ran Tubing to 12450 ft (3.5 in OD). Installed Tubing hanger. Ran Tubing on landing string to 12450 ft. Reverse circulated at 12450 ft. Rigged up sub-surface equipment - Setting tools. Held safety meeting. Set packer at 12394 ft with 4000 psi. Retrieved Tubing landing string. In- stalled Hanger plug. Held safety meeting. Rigged down All functions. Feb 24 1996 (14) Rigged down All functions. Installed All tree production valves. Removed Hanger plug. Tested Hydraulic packer. Held safety meet- ing. Circulated at 2500 ft. Held safety meeting. Rigged down Drillfloor / Derrick. Rig moved. Page ? RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/S-29AL~ 500292208261 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/27/96 DATE OF SURVEY: 021796 MWD SURVEY JOB NUMBER: AK-MW-60012 KELLY BUSHING ELEV. = 68.17 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 12663.97 8847.13 8778.96 64 11 12692.65 8859.54 8791.38 64 30 12714.58 8868.13 8799.96 69 24 12721.55 8870.51 8802.34 70 35 12728.17 8872.59 8804.42 72 54 S 58.5O W .0O S 58.30 W 1.22 S 58.66 W 22.40 S 58.78 W 17.29 S 58.88 W 34.77 7649.11S 2142.52W 7662.66S 2164.54W 7673.20S 2181.74W 7676.60S 2187.33W 7679.86S 2192.71W 7726.21 7748.75 7766.32 7772.02 7777.47 12747.85 8877.63 8809.46 77 24 12762.52 8880.34 8812.17 81 18 12788.41 8882.68 8814.51 88 18 12820.74 8882.46 8814.29 92 30 12852.96 8879.99 8811.82 96 18 S 59.18 W 22.91 S 59.40 W 26.63 S 60.20 W 27.21 S 63.10 W 15.79 S 61.10 W 13.32 7689.64S 2209.02W 7697.00S 2221.41W 7709.96S 2243.68W 7725.31S 2272.13W 7740.34S 2300.51W 7793.95 7806.41 7828.56 7855.80 7882.72 12884.59 8876.21 8808.04 97 24 12915.30 8872.05 8803.88 98 11 12943.94 8868.38 8800.21 96 30 12976.97 8865.47 8797.30 93 35 13010.39 8863.58 8795.41 92 54 S 60.10 W 4.69 S 59.00 W 4.40 S 60.80 W 8.61 S 59.10 W 10.17 S 58.70 W 2.41 7755.75S 2327.87W 7771.17S 2354.10W 7785.41S 2378.67W 7801.89S 2407.14W 7819.12S 2435.71W 7909.49 7935.72 7960.10 7988.34 8017.29 13040.03 8861.95 8793.78 93 24 13072.63 8860.22 8792.05 92 41 13104.65 8858.74 8790.57 92 35 13136.44 8857.24 8789.07 92 48 13167.17 8855.71 8787.54 92 54 S 58.20 W 2.38 S 59.40 W 4.26 S 61.30 W 5.94 S 62.50 W 3.82 S 64.40 W 6.18 7834.61S 2460.93W 7851.47S 2488.77W 7867.29S 2516.57W 7882.25S 2544.58W 7895.96S 2572.03W 8043.08 8071.35 8098.68 8125.37 8150.70 13198.66 8854.42 8786.25 91 48 13231.15 8853.65 8785.48 90 54 13262.66 8853.68 8785.51 89 0 13294.52 8854.93 8786.76 86 30 13325.18 8857.04 8788.88 85 35 S 66.90 W 8.67 S 68.00 W 4.37 S 69.00 W 6.81 S 67.50 W 9.15 S 70.70 W 10.82 7908.93S 2600.69W 7921.39S 2630.69W 7932.94S 2660.00W 7944.73S 2689.56W 7955.64S 2718.13W 8175.96 8201.43 8225.77 8250.44 8273.87 13359.32 8859.72 8791.55 85 24 13391.06 8862.27 8794.10 85 24 -- 13421.64 8864.46 8796.29 86 24 13453.19 8865.58 8797.41 89 30 13484.78 8865.23 8797.06 91 48 S 73.40 W 7.91 S 73.60 W .63 S 74.90 W 5.35 S 75.70 W 10.15 S 78.30 W 10.99 7966.13S 2750.51W 7975.12S 2780.84W 7983.39S 2810.20W 7991.39S 2840.69W 7998.50S 2871.47W 8298.77 8321.36 8342.86 8364.68 8385.84 13516.30 8864.13 8795.96 13548.15 8862.85 8794.68 13579.86 8861.27 8793.10 13611.60 8859.55 8791.38 13643.86 8858.32 8790.15 92 11 S 80.50 W 7.09 92 24 S 83.30 W 8.81 93 18 S 87.10 W 12.30 92 54 N 89.50 W 10.77 91 30 N 88.20 W 5.92 8004.29S 2902.42W 8008.78S 2933.93W 8011.43S 2965.48W 8012.09S 2997.16W 8011.44S 3029.39W 8405.95 8425.18 8442.83 8458.81 8473.91 SRRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/S-29AL~ 500292208261 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/27/96 DATE OF SURVEY: 021796 MWD SURVEY JOB NUMBER: AK-MW-60012 KELLY BUSHING ELEV. = 68.17 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 13675.63 8858.04 8789.87 89 30 N 88.20 W 6.30 8010.45S 3061.14W 13706.50 8858.82 8790.65 87 35 N 84.10 W 14.63 8008.37S 3091.92W 13737.78 8860.16 8791.99 87 30 N 82.70 W 4.48 8004.78S 3122.96W 13769.70 8861.74 8793.57 86 48 N 82.10 W 2.89 8000.57S 3154.56W 13801.53 8863.60 8795.43 86 30 N 82.60 W 1.83 7996.34S 3186.05W 8488.47 8501.62 8513.57 8525.24 8536.85 13832.15 8865.50 8797.33 86 24 N 81.20 W 4.58 7992.03S 3216.31W 13866.16 8867.01 8798.84 88 30 N 81.10 W 6.18 7986.80S 3249.87W 13897.86 8867.51 8799.34 89 41 N 80.80 W 3.90 7981.828 3281.17W 13929.55 8867.45 8799.28 90 30 N 80.60 W 2.60 7976.70S 3312.44W 13961.71 8867.15 8798.98 90 35 N 80.20 W 1.28 7971.33S 3344.15W 8547.79 8559.54 8570.40 8581.12 8591.84 13993.34 8867.06 8798.89 89 41 N 80.10 W 2.86 7965.92S 3375.32W 14023.81 8867.25 8799.08 89 35 N 80.10 W .33 7960.69S 3405.33W 14055.63 8867.14 8798.97 90 48 N 79.30 W 4.53 7955.00S 3436.64W 14087.38 8866.47 8798.30 91 35 N 79.00 W 2.69 7949.028 3467.81W 14119.24 8865.86 8797.69 90 35 N 78.80 W 3.20 7942.89S 3499.07W 8602.26 8612.27 8622.51 8632.44 8642.28 14149.15 8865.94 8797.77 89 5 N 78.20 W 5.40 7936.93S 3528.37W 14180.90 8866.91 8798.74 87 24 N 78.70 W 5.58 7930.57S 3559.46W 14212.23 8868.52 8800.35 86 41 N 79.40 W 3.16 7924.63S 3590.18W 14220.01 8868.97 8800.80 86 41 N 79.90 W 6.42 7923.23S 3597.82W 14275.00 8872.13 8803.96 86 41 N 79.90 W .00 7913.61S 3651.87W 8651.31 8660.87 8670.60 8673.10 8690.95 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 8715.58 FEET AT SOUTH 24 DEG. 46 MIN. WEST AT MD = 14275 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 209.08 DEG. TIE IN POINT 12663.97' KICKOFF POINT 12692.6' INTERPOLATED DEPTH 14275' .,'RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING PBU/S-29AL~ 500292208261 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/27/96 DATE OF SURVEY: 021796 JOB NUMBER: AK-MW-60012 KELLY BUSHING ELEV. = 68.17 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 12663.97 8847.13 8778.96 7649.11 S 2142.52 W 3816.84 13663.97 8857.94 8789.77 8010.81 S 3049.48 W 4806.03 989.19 14275.00 8872.13 8803.96 7913.61 S 3651.87 W 5402.87 596.83 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ERRY-SUN DRILLING SERVICE& ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING PBU/S-29ALt 500292208261 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/27/96 DATE OF SURVEY: 021796 JOB NUMBER: AK-MW-60012 KELLY BUSHING ELEV. = 68.17 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 12663.97 8847.13 8778.96 12715.14 8868.17 8800.00 12743.97 8876.75 8808.58 7649.11 S 2142.52 W 3816.84 7673.49 S 2182.24 W 3846.97 30.13 7687.70 S 2205.77 W 3867.22 20.25 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 16 February 1996 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ~7 M-07 1 PLS FINAL BL+RF 1PDK FINAL BL+RF 1 TEMP LOG FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1PFC/PERF FINAL BL+RF 1 CN FINAL BL+RF i GR/CCL FINAL BL+RF 1 GR/CCL FINAL BL+RF ECC No. Run # 1 604.06 Run ~ 1 3561.04 Run ~ 1 Run # 1 3986.05 Run ~ 1 5062.01 Run ~ 1 5653.07 Run # 1 '6054"06 Run ~ 1 6299.04 Run ~ 1-- 6454.01 Run # 1 6592.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services .. 5600 B Street ..... .. Suite 201 Or FA~-~/(90.7) 563-7803 Received by: Date: ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Januaw 16, 1996 Dan Slollz, Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit S-29AL1 BP Exploration (Alaska); Inc. Permit No 96-012 Surf Loc 164i'SNL, 1560'EWL, Sec. 35, T12N, R12E, UM Btmhole Loc 1068'NSL, 2462'EWL, Sec. 03, T11N, R12E,UM Dear Mr Stoltz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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. The permit is for a new segment from existing well S-29A, Permit No. 96-011, APl No. 50-029- 22082-01. Production should continue to be reported as a function of the odginal well identifier. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before ddlling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be ield inspector on the North Slope pager at 659-3607. · David W. JoI~ns-~F0-n~---- ~._ ~ Chairman ~..........~ ) -- BY ORDER OF TH MMISSION lencl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation -w/o encl Joan Miller - AOGCC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] RedrillFIIlb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration Plan RTE= 69.52 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028261 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1641' SNL, 1560' EWL, SEC. 35, T12N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1225'NSL, 633' WEL, SEC. 3, T11N, R12E S-29AL1 2S100302630-277 At total depth 9. Approximate spud date Amount 1068' NSL, 2462' EWL, SEC. 3, T11N, R12E 02/01/96 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD andTVU) property line ADL 028260 2818 feet No Close Approach feet 2560 15060' MD/8988' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~2z2o feet Maximum hole angle 9o o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# L-80 BTC-M 1571' 11550' 8058' 13121' 8977' 370 Class 'G' 6" 4-1/2" 12.6# L-80 BTC-M 2261' 12730' 8870' 14991' 8846' Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface ?~ i~.;~ ~.~,,¢ ~ i'~ ~;, ~ Intermediate Production Liner JAN 't 2 '1396 Perforation depth: measured true vertical AJask8 0ii & Oas Co,~s. 20. Attachments Filing fee [] Property plat [] BOP Sketc~ra.~iverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby~thatt.~~gistrueandcorrecttothebestofmyknowledge Signed J( .,-/~,,~ . Title Senior Drilling Engineer Date/_/-z. .... ~ Commission Use Only Permit Number IAPI number IApprgval date See cover letter /~"~_//_~__ 15 0- ~...,~-~_...~_..O ~.,~-~'~(::::7 /' -'-/~,,, ~-~, for other requirements Condibons of approval Samples required [] Yes J~ No Mud Icg required []Yes J~ No Hydrogen sulfide measures ~ Yes [] No Directional survey required ~ Yes [] No Required working pressure for BOPE []2M; i-13M; ~5M; 1-110M; ~15M; Other: ,3avJd'~'iginalw,Signed By by order of // Approved by Johnston Commissioner [ne comm,ssion Date/~(,,//~ Form 10-401 Rev. 12-1-85 Submit I Well Name: I S-29A / S-29ALiI Sidetrack/Multi-Lateral Plan Summary I Type of Well (producer or injector): [ Producer Surface Location: } 1,641' FNL, 1,560' FWL Sec 35 T12N R12E I Sadlerochit - Zone 4 Lateral (S-29A) 1st Lateral Target Location: 1,080' FSL, 907' FEL Sec 3 T11N R12E (start of horz - 1st lateral) Bottom Hole Location: 1,174' FSL, 2,368' FWL Sec 3 T 11N R 12E (end of horz - 1 st lateral) Sag River Lateral (S-29AL1) 2nd Lateral Target Location: 1,225' FSL, 633' FEL Sec 3 T11N R12E (start of horz - 2nd lateral) Bottom Hole Location: 1,068' FSL, 2,462' FWL Sec 3 T11N R12E (end of horz - 2nd lateral) ]AFE Number: ]4P0733.0 I ]Rig: I Nabors 28-E I Estimated Start Date: 12-01-96 I Operating days to complete: I 32 I RT'GL133.8' IMD: I 15,060' I IT VD: 18,988' I I KBE-MSL 69.5' I Well Design (conventional,slimhole,etc.) I Horizontal Sidetrack (Multi-lateral) I I Formation Markers: Formation Tops MD TVD (SS) CM-3 (K- 10) Behind Pipe HRZ Behind Pipe LCU Behind Pipe Kingak 10,721' 7,498' KOP in Kingak @ 11,700' MD Sag River 12,684' 8,782' Shublik 12,768' 8,813' Sadlerochit 13,045' 8,900' TD (Zone 4 Lateral) 15,060' 8,920' Sag River 12,720' 8,799' TD (Sag River Lateral) 14,991' 8,777' Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD / TVD 8-1/2" 7" 29# L-80 BTC-M 1,571' +_11,550'/8,058' +13,121'/8,977' 6" 4-1/2" 12.6# L-80 BTC-M 2,089' 12,971'/8,950' +15,060'/8,989' (1 st Lateral) 6" 4-1/2" 12.6# L-80 BTC-M 2,261' __+12,730'/8,870' __+14,99178,846' (2nd Lateral) Tubing 3-1/2" 9.7# L-80 NSCT 9,717' 33'/33' +12,300'/8,660' Cementing Program: Lead Cement Tail Cement Casing/Liner Sx / Wt / Yield Sx / Wt / Yield Comments Class G, FW=0, FL=<50 cc 7" None 370 / 15.7 / 1.17 Pump time=4+ hrs; TOC = 11,550' MD 4-1/2" None None Slotted liner (1 st Lateral) 4-1/2" None None Slotted liner (2nd Lateral) Volume assumptions: Gauge hole + 50% excess; 80' shoe joint; TOC at liner top. Logging Program: Open Hole Logs: 8-1/2" Hole 6" Hole Cased Hole Logs: 9-5/8" Casing GR/SFL, ILM, ILD/sonic/density; RFT's contingent upon hole conditions MWD' Resistivity/GR in both horizontal intervals ,~. ~ -h - None Planned Mud Program: Intermediate Mud Properties: 18-1/2" hole sec~ti~j¢~¢~,.-i~l~ LSND Depth Density Marsh Yield 10 s~~' ll~'f~~' pH Fluid (PPG) Viscosity Point gel gel Loss 11,700' 9.8+ 50-60 20-30 10-12 12-16 9-10 <6 HTHP-15.0 13,121' 9.8-10.1 50-60 20-30 10-12 12-16 9-10 <6 Csg Point HTHP- 15.0 Hazards/Concerns Utilize alternating lo / hi vis sweeps to assist hole cleaning Treat with 2 ppb each of Boreplate, Barotrol, & Baranex while drilling Kingak. Monitor YP and increase if problems occur trying to clean the hole. Potential high torque could require lubricant use. Lost circulation is probable due to anticipated faulting in Kingak. Reduce API fluid loss to <6 cc in Kingak Section. Production Mud Prol~erties: 1 6" hole sections: Xanvis KCL Depth I Density Marsh Yield 10 sec 10 rain Fluid (MD)I (PPG) Viscosity Point gel gel pH Loss Sadlerochit Zone 4 Lateral 13,121' 8.8-9.0 50-60 30-40 15-20 18-24 9.5-10.5 <6 15,060' 8.8-9.0 50-60 30-40 15-20 18-24 9.5-10.5 <6 Sag River Lateral 12,720' I 8.8-9.0 50-60 30-40 15-20 18-24 9.5-10.5 <6 14,991'I 8.8-9.0 50-60 30-40 15-20 18-24 9.5-10.5 <6 Hazards/Concerns Lost Circulation a possibility due to possible faulting in Sadlerochit in 1st lateral; Faults may also be encountered in the Sag River in 2nd lateral. Differential sticking possible (overbalance) - both laterals. Perform/report daily checks on KC1 concentrations in Xanvis KC1 system. High torque may be experienced and should be treated with Lubtex additions. Directional'. I KOP: I +11,700' MD (lst lateral); +12,720' MD (2nd lateral) Maximum Hole Angle: +90° Tangent Angle +65° across Sag River in 1st lateral Close Approach Well: None. The above listed wells will be secured during the close approach. Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Disposal'. Cuttings Handling: Fluid Handling: Annular Injection: CC2A Annular injection. As the S-29A annulus is available for injection, approval is hereby requested for annular injection into the S-29A with the S-33 well as a contingency. The S-29 well was previously approved for annular injection by ADEC in 1990. The S-33 well was approved for annular injection by AOGCC on Dec. 18, 1995 for the S-01B well (still drilling). Cumulative total limitations will remain in effect. PREV. VOLUME MAX. PERMI'I-rED MAX. PERMITTED PERMITTED AREA WELL INJECTED VOLUME FLUID DENSITY DATES (aBES) (aBES) (PPG) WQA S-29 980 35,000 17.0 Pending Approval S-33 4,904 35,000 17.0 12/18/95-12/18/96 , . , . , Aquifers in the Prudhoe Bay Field Western Operating Area have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #1 as referenced in Area Injection Order #3. There are no domestic or industrial use water wells located within one mile of the project area. The following design criteria were utilized in determination of maximum annular injection pressures (the attached pressure nomograph provides injection pressure vs. fluid density data): S-29 13-5/8", 68#, L-80 set and cemented at 2,720' MD (2,720' TVD) Burst (80%) = 2,760 psi 9-5/8", 47#, L-80 set and cemented at 12,843' MD Collapse (80%) = 3,800 psi S-33 10-3/4", 45.5#, NT-80 set and cemented at 2,958' MD (2,958' TVD) Burst (80%) = 2,864 psi 7-5/8", 29.7#, NT-95HS set and cemented at 9,018' MD Collapse (80%) = 4,096 psi A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 10/30/95 which demonstrates the confining layers, porosity and permeability of the injection zone. The cement design for these wells (and the subject S-29A well) ensures that annular pumping into hydrocarbon zones will not occur. Worse case scenario calculations assume 17.0 ppg maximum fluid density and gas-filled inner casing (see attached nomograph for ppg equivalent mud weights vs. injection pressure profiles). Breakdown pressure of the Ugnu is 13.5 ppg equivalent mud weight. DO NOT EXCEED 35,000 BBLS IN ANY GIVEN ANNULUS. Ann. Inj. Nomograph PPG vs PSI S-29A Well Hydrostatic Pressure 13-3/8" Casing Burst 9-5/8" Casing Collapse Maximum Allowable Fluid Density at 2,720' TVD at 80% at 80% Injection Pressure (ppg) (psi) (psi) (psi) (psi) 8.00 1132 2,760 3,800 1,628 9.00 1273 2,760 3,800 1,487 10.00 1414 2,760 3,800 1,346 11.00 1556 2,760 3,800 1,204 12.00 1697 2,760 3,800 1,063 13.00 1839 2,760 3,800 921 14.00 1980 2,760 3,800 780 15.00 2122 2,760 3,800 638 16.00 2263 2,760 3,800 497 17.00 2404 2,760 3,800 356 S-33 Well Hydrostatic Pressure 10-3/4" Casing Burst 7-5/8" Casing Collapse Maximum Allowable Fluid Density at 2,958' TVD at 80% at 80% Injection Pressure (ppg) (psi) (psi) (psi) (psi) 8.00 1231 2,864 4,096 1,633 9.00 1384 2,864 4,096 1,480 10.00 1538 2,864 4,096 1,326 11.00 1 692 2,864 4,096 1,172 12.00 1846 2,864 4,096 1,018 13.00 2000 2,864 4,096 864 14.00 2153 2,864 4,096 71 1 15.00 2307 2,864 4,096 557 16.00 2461 2,864 4,096 403 17.00 2615 2,864 4,096 249 Hydrostatic Pressure = TVD (casing shoe) * 0.052 * Fluid Density (ppg) Maximum Allowable Injection Pressure = Lesser of (Outer Csg Burst or Inner Csg Collapse) - Hydrostatic Pressure Operational $-29A Horizontal Sidetrack Summary · i , . · . . . . 10. 11. 12. P&A well. Test cement to 1,500 psi. Tag cement minimum of 100' above top perforation @ 12,989' MD. Cut the 4-1/2" tubing @ +12,400' MD. MIRU Nabors 28-E drilling rig. Pull 4-1/2" tubing. Test 9-5/8" casing to 3,500 psi for 10 minutes· RIH and set EZSV at +_11,995' MD (250' below proposed 9-5/8" section). PU section mill, TIH and spot 18.3 bbl (+_250') of 18·0 ppg milling fluid from EZSV (11,995' MD) to 11,745' MD. Space out and mill section from 11,695' MD to 11,745' MD. POOH. TIH with open-ended drillpipe. Mix and spot a 17.0 ppg cement kick-off plug (per recommended practices) from 11,495' to 11,845' MD. POOH a minimum of 12 stands. Perform a hesitation squeeze. Do not exceed a final squeeze pressure of 2,000 PSI and do not displace cement any closer than 100' above section top. NOTE: Final cement volume should insure slurry placement 100' below milled section, 50' across milled section and 200' inside casing above milled section. PU directional BHA and TIH. Tag TOC. MINIMUM WOC TIME IS 12 HOURS. Dress off cement plug to 11,700' MD (5' below top of section), kick-off and directionally drill to +_13,121' MD (8,979' TVD). Final inclination is planned for 88.5° along an azimuth of 268°. POOH. Make a hole opener run to +_13,121' MD prior to running 7" liner. RU and run 7" liner from 13,121' MD and tie back into 9-5/8" casing at +_11,550' MD. POOH and LD liner running tools. PU directional BHA and drill 6" horizontal hole to 15,060' MD (final inclination at +_90°) at an azimuth of 274°. Maximum lateral interval is _+1,939'. POOH. NOTE: Inclination, azimuth and overall lateral length may be shortened by onsite geologist. A wiper trip may be made prior to running production liner. JAN 12 1~96 ~-~'-';~ Oil & Gn, r,:,,,~ Commission Anchorage .. S-29A Sidetrack Operations Summary Page 2/2 13. Run and set a 4-1/2", L-80 slotted liner @ Total Depth. Top of liner will be at _+12,971' MD. 14. Set 7"x 3-1/2" permanent production packer (with 3-1/2" tubing tail) at _+12,680' MD (near the end of the 65° tangent). 15. Set oriented, retrievable whipstock above permanent packer to promote casing exit at _+12,695' MD (8,857' TVD; 5' TVD below the top of the Sag River). 16. Mill window off whipstock at _+12,695' MD and drill +25' new hole. POOH. 17. PU directional BHA, kick-off and directionally drill a 6" hole in the Sag River to · +14,991' MD (final inclination at +89°; final azimuth at -+277°). Maximum lateral interval is _2,296. POOH NOTE: Inclination, azimuth and overall lateral length may be shortened by onsite geologist. 18. A wiper trip may be made prior to running production liner. 19. Run and set a 4-1/2", L-80 slotted liner @ Total Depth. Top of liner will be at · +12,705' MD (_+10' below casing exit). 20. RIH and pull retrievable whipstock. 21. RU and run 3-1/2", L-80, production tubing. 22. 23. 24. Drilling Set two way check and test to 1,000 psi. ND BOPE. NU tree and test to 5,000 psi. Freeze protect well and release rig. Hazards Sadlerochit interval has a pore pressure of +8.1 ppg EMW. Lost circulation may occur due to overbalance conditions. Small faults are expected in the lower portion of the build interval with larger (50-100' throw) faults anticipated in the horizontal section for the Sadlerochit lateral. Similar faulting can be expected in the horizontal section of the Sag River lateral. There are no known drilling close approaches. No other known drilling hazards are expected. ng elLplan ' $-~A'W'p9 L1 J HALL[ BU~TOM K(I:) / liE. 1~ / INgEI~i"[]L.~TED PiStil' / g]AR'f UF CURVE "E ILOO'/tO0 F'L 21~T~ MD :' e IlS0n ND R~ ~ r O! CURVE - _ 8ol ~ eose? =-'BE,fa' IL-~I - 71,73' e 7 in rmo, e )::]l~p MD, e979 TVD i~ I,~B~4 MD Tc~ ~'Gd / Zone e. 13J~LfiD' F_~D ~ EURV£ CRITICAL i::~lll'i~' DA~'A HO l'nc Azi. 'i'¥D N/X E/W I~ ,~'lil~k I§TBI 54.35' 2'03.66' 7SG7 G4~2. SI43B' I!~ / ]I7G~ 51,$3:' c"OS. SD' 8153 7IG'J S 1760 [NTEItPIILAIED POINT / STAR! ~ ~URV£ 8 8, 00'/!1~ Pt I~- CURVE IP_/Y3P- BS.(M)' ~O~L:~' 8411 734G S li~7 E~ DF C~ l~O 65.~' 230.~0' ~801 7630 S 2~73 Sag River ~268,l 65.E~' 23Q,~' 8853 7673 S 816C ~hubtlk 12772 6~0' 830.0B' 88~0 7724 S 2280 S}~ OF I~? 65. Qb' 230.0~' 8905 7~44 ~B84~ CURVE ~ T~ ~d / 13054 ~.33' 260. B7' ~74 78:39 g ~4SB Z~ 4 /~) 4.~/1~ F~ lom:je'L J~,,~e ]'VD lit: LC'l/ ~Gr'id }C Grid TD ~37 ~B5 S 4546 M 6153~ 5~7800o CA~I~ F O]~I ~ATA 7 )n (31~Z' Bg. 54)' L>~B. G8· 8~79 7845 S 25~5 W 4 I/~ in [5OG! gO. O0' ~74.00' 6989 7744 S A4GO V PROPOSED BHL MD I61:H;ngB 4460-50 S-29AWpg LL ~7,00' e 1:~56[ iN1) END I]r CURVE 88.50' e }34~1 Hi) START DF CURV£ B 4,0O'/1OO 4 I/2 i~ OIL e 1543G1, HD, 8989 ~VO -"- 9~.00' e [506~ KD 7400 B~O0 84011~ 8G~ I I ! 8~0 ~eal ~(an ', §-EgA~p9 L1 7~.,q30 JNIE~A~D 0~/1~ ~t END ~ ~ [~ ~.~ ~ ~lt ~6 S J~ L? KI~I ~ i~ 6~ ~ ~ 7744 S ~,15 ~ L4~l~ rt ~/t~ Ct TVD HS E~ Cr~ X Gr';d Y · f~79 7'335 S 45~0 ~;;9'9 78~ S ~ g 617:]07 597lC~::~ c)~37 7785 S 4..9~G 8936,04 7144.135 S , Halliburton Energy Services - Drilling Systems PSL C~:~la~e~ ~aF, ~r M'mlznum Curvature Melhod BPX~ated ~rvi~ Ddl~tg Ales~ ~ $~tt~ ?rant: Zene-4 P~U: WOA: ~t: S-29A A.~-bulll Wc[lp~n: S-29AWp9 Me. asm~ Ind Dzfft Subsca TVD Ceun~ TOTAL OP,.LDCoord~nalr. s (~) (~) (~ , (~) (~) (~ (~) ~ (~) 1l~0~ ~,~ 2~ ~ ~1,~9 20.50 7~Z,~8 S I?0LSIW 5~.10 61813~ 7~19k~ [1523.15 ~,47 2~3 7975~ 1~,36 20.50 7037.10S t~08.7~ 5~~ 6181~ ~[~19~.~ 050.75 [J543~5 ~,30 ~30 7P~1~4 a~6,Sl 20,40 705[.70S 171S.~ 59~7 618119~ ~57.4~193~7 115~.95 5L~ 205.18 ~.~ 8~9,29 20.40 70~30S 17~.5~ 5932762,87 6J811~9 1158435 5Lg~ 205,88 8Ol~ 808Lgl 2~40 708~88S. [729.~ 59~748,~8 61gt~28 11~.65 51~7 2~.!2 ~5.03 B~4.30 2030 ~095.37S ~73~1~ ~9~733,58 61~.72 73~.7~t9335 9014.~ 11~5.05 ~1~ 20521 8~7.61 810~ ~O 7I~.91S 1943.~ 59~718,94 618~3A2 73~.4~t93,77 ~,~ 11~5,45 51.78 ~2L 9050,2f BliP.48 ~.40 7~24A25 1749.8~ 597270432 618~5[ LI6~,95 5L.63 205~ 8062,91 .gl3LL8 ~30 713B.98S 17~.TJW 59~6B9.~ 618~9,~ Cioaorc ¥crttceI Bu'dd Walk Dig Ctun. Expr-~a~' ToLa! Man Hot Agin Ho: Dh-. D]~L Dh. ~r. c6oa Ra~r Ra~ Dogleg lbxrtangular Ceor& F. rrm' Ener Max (n) (~e~.) (R) (~r/mon) (~/~ooa) (~loon) (~ (~) (~) (~) (a) (~) LI666.35 51.52 205.3~ 8075.59 8144,85 20,40 7153.OS 17~ KOP/~ ~ / ~~~ PO~l ST~T ~ ~RV~ 11700~ 5!,52 205~ 8~9 81~,35 [3,65 71~38S 1768. l~V 5~39 618~.84 ~780~193.~ ~_~ ilE~0 ~3.5~ 205.~ 8[51.56 ~23 l~O ~9~5S J~.9~V 5~9B.43 61gO3i.O6 7~02~J93.98 71~ 1190~.(]0 35.53 205.63 /:22&63 8297.90 IO~.OO T286J];3S Jg27.57W 59725~.72 61801135 7512,52~i96.08 7226.45 1200~.00 27.52 206.09 8513.79 83~.05 10030 7133.82S 1850.43W 59724~39 6[7988,23 7553,65~!94.16 727L$7 ISqD OF CURVE ;2031.62 25.0[3 206.2~ ~42.14 g4lJ.41 31.62 7346,~$ 1858.5~V 597248C.74 6[79E5,26 7577,35.~!96.fg 72~2._~3 START OF CURVE ~. i0.00 dc~10,0 ft ~2t31.67 25.00 20&20 g¢3L?7 gSZL04 [g0.00 7384.30,5 i;75.~V 5972~ 61~96526 76tC.6~1~.~ ~3~.70 [~21~2 33,~3 215~6 85[~.85 85~.12 [O0.~ 7425.9~S t~ 597~1 617940.[5 7~53~i9~.36 [~1~2 43,13 221.~ g~ ~667.34 [O0.~ 7474.08S ~.I~V 597~1.74 6179~f.~ ~2L.~i~.55 7~,90 .. -0-29 0,34 ,,0.73 0..20 -0,34 .4}39 -0,78 -,0.49 -0,49 0_20 -0.25 -0.69 0.00 -0.73 0.05 ~-~--,,,.. 124.al.62 52,64 225,96 1668.07 173.4.34 [00,0l} 752731S 199[.66W 5972297.72 617851.ff3 T}rgG,34~194.SZ 7516,73 ~ .~,. 1253L62 62,27 229,20 1718.31 17B8,08 100,DO 7583.99S 2053.gL'W' 5972.240.0q 617789.56 7857.J~198.18 T596'.91 · L,' ; ~ END OF CURVE ._.~ 12559.85 68.00 230.0~ 873[34 8800,51 2~.22 7600..178 20~.[5W 5972223.39 6i77~.fi6 ~878.04~195.26 7620.71 0.40 123.6 7822,38 ~' 1701.81W [71.1~6 38.07 :Z84.18 0.?'~ 123.8 7~7,10 g 1~7~ 172.~ 38,~ 0.84 i~.9 7~1,7D S 1715~ 1~.61 O,S~ J~.O 7~05 1~,5~ 17Z9~ 38.47 2~ 0,87 124,2 7080.8~ S J729.4~ 173,35 3E.62 2~ g,52 ]~,3 7~37S ]736. l~ 173,72 3E.74 2~ OA3 ~.4 71~.9~ S 1743.0~ 174.08 ~.85 2~1 0~9 124.6 7~,42S 1749,8~ 174.45 39.~ 2~3 0.73 I~.7 713~.98 S 17~6,7[~ 174.82 39.15 -~.$4 0,78 ~L82 17A.9 '~i53.438 1763,5q,¥ 175.17 3930 284'.38 LOg (}.85 125.0 7163.~ S' [768.13W ~75.4L ~9..~ 2~t4.40 g.~ 133.0 7'230.~3 g 179P..85W 176,32 43.87 2~433 -8.00 0. t7 -8,00 O.Z6 E,00 I;4f,0 7287.77 5' 1825.63~V :77.13 ~7.~ 28~.25 E.OO 149,0 7335.00 S 1§47.9P~' :77.8[ 5i.49 284,17 ~.0O ~.36 LOP t51,5 73~7.63 S 1~.54.{]O~' ;7~.DL 52.46 284.15 9.30 9,.51 '9.63 9,67 C.O0 0.~'b 151.5 73~-$.76 $ I872.23W LTE.62 52.80 2FA.t9 9.66 I0.~ 161.5 7~g.04 S lgPT.~V t79. I3 50,~ ~,~ 5.95 10.~ 17l.$ 7477.4~ S 1934,g~ I~,~ 4E.25 285,~ 4,17 10.00 18l~ 7532.69 $ 1984.3~',r tgO.2[ 4,5,99 Zs$.gB 3.22 t0.00 t91.5 7592.11S 2044.2E'8' [80,92 4tl.25 286.74 2.~ 10.00 194.3 760933 S 2~62.[r2W 1Bt. J4 43.91 286.95 Halliburton Energy Services - Drilling ~stems P~L ~ Propo~al Report C;l',IDC_~ordimI~ Ck~u, Vgtli~a~ Ituiid Walk I~LS Cnm. gxpoacdTeta~' tVatx Hot Min Hot Dir. Vcr~ HoathJng ~tn~ D~I. Dir. .-%~en ~: Ra~¢ DcrgT~g ~c~:~gul~C~rds F.n~r ~r M~ E~ Sag Rive~' 12684,a4 65.0~ L~.eO 8784,~ B~3~ t~,6t 7672.96S 2{fi9.~' 59~149.46 6t761~,28 ~ql.l~lgS.?~ ?~.B0 0.~ 0,00 0.~ 19~3 76~.~0S 2146.2~V KsLg~ ~4.ag ~7AI 56At Shublik 12771.99 ~.~ ~.~o 882t,~ g~7 87.55 77~97S ~A~ S~.~! 6t7625.2~ 8~63~[~ ;801~ 0.~ 030 0,~0 I~3 7~9.]71 22~,~V 184.~ ~5.67 2~.76 56,b~ ST~T OF ~R~ ~ 14.~ ~e~t00 a t2~06.84 ~.~ ~0.OO ~5,73 g~0 34,85 77~7~ ~3~ ~2&~ 617601A0 8~I~16 7~t.O0 0.~ 0.~ 0.~ 1~ ~.50S ~2IW 114~ 4631 28730 57.~, L29~6.84 71.73 243.22 8172,72 8941.99 10~.00 7795.045 ~L~ ~720~.B5 6[7~4.69 8133,S~19~9 7913.6B 6,73 t~ 14.~ ~ 7815.~8 ~03.4~ I~.M 5~.~ ~8~ ~g.C . T~gMIZ~ 414B !~75 ~.~ ~O. B7 8905.00 ~2427 46.91 7~31~ ~~ 5~1~9.27 61~3L 8214. B~197~! ~19.08 7.94 L1.67 14.01 ~.9 3867_4OS ~37~ l~.O0 6[.08 ~.00 62.~ 131116J01 82.32 266.96 1~909.47 19/834 53,09 7844.105 251OA2Wr 5971972.86 612337.12 E236.03~197,75 eOSg. 17 $.05 11.48 14.gO 2~6.3 7876.22S 2A89.T2W 18'3.81 64.39 29(3. J9 END OF CUR¥S £312136 88.50 2~1L62 ilgl0.O0 tT/9,27 1432 7844.665 25~ 5971972.07 61'/322.63 E24Q.99~197,8~ ~05T.~8 B.13 11.4] 14.00 238,4 7877.675 250~.15q~/ 183.79 65.2~ 29~3.23 CAGING POrNT OD = 7 in, ID:= 6.tg i~Vcigh~ =2g,om lb/IL t3[21.86 BB.$O 268.62 a910.01 ~979,2a O. Sa 7844.6?$ 2525.4~r~. $971972.0~617322.13 1241.15~197.84 g058.]4 O.00 0.0O O. OO 231.4 7144.675 2525.42W 0.00 0.0O O. O0 START OF CURVE ~ 4.00 dcg~t Oi) I~ 12421.36 8B.50 26~L62 11917.~5 1~987.12 299.$a 7~lJl~g 2124.73W 597t960_16617022.a3 1344.5~i99.79 B2[3.79 O.00 0.00 O_0O 238A 79~)3.195 280:L~6W [87.23 75.16 293.611 65.1~. 13521.36 89.5T 27247 8919.53 11988.80 t00.O0 7850.93S 2924.6~W 5971959.f~616922.113 azT&O0~200.43 BT.6LS5 t.07 3.8~ 4.00 2q2A 79O8335 290'J.7~V t87.98 80.01 294.70 [3560.98 91L0~ 274.00 8919.68 898855 39.62 7848.69S 2964.24W $971%1.18 616883.23 8389.'/9~2011.69 $2gO.65 1.08 3,1t5 4.00 264.0 7~B.50S. 2943,5~V 188,2B 81.94 295.12 66.1, CAStHOlxOIHI' OD=4 f/2 [~L 10=3.95 ln, We~t= 12.60 b/IL 1306(L50 9OJlo 274.00 8919.69 a91~8.96 L499.52 7'/4~.e9S 4460.I1W 597204Z39615365.~ 8936~.94 8936.63 0.gO 0,00 0.t20 244.0 T'/44.09S 4460.1TW 0.00 O.OO 0.0O 0.O 1~'060.911 ~030 274.00 8919.69 11988.96 0.48 T'/44.05~ 4460.51~' 5972042.62 615384.76 89:~6.84~1209.gul 8936.84 0.00 0.0O 0.O~ 24,4.O 7tL95,05S 4446,22W 226.69 135.41 324,44 773' WELL PERMIT CHECKLIST PROGRAM: exp [] dev O. redrll [] serv [] UNi~# //~~ o~/oFF SHORE__ ADMINISTRATION ENGINEERING REMARKS 2. Lease number appropriate ............... N /~,~. j ~/O/2 3. Unique well name and number .............. ~.,' ~ N _~ ,.~.~ X~, 'r..~~'~ /~/~,.~ 4. Well located in a defined pool ............. N '%'-- ~-/~- . v 5. Well located proper distance from drl9 unit boundary. ~ '~,w' 6. Well located proper distance from other wells ..... ~ ~ 7. Sufficient acreage available in drilling unit ..... ~ 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ........ ~3 N APPR D~TE 14. Conductor string provided ................ Y N/ 15. Surface casing protects all known USDWs ......... Y ~ 16. CMT vol adequate to circulate on conductor & surf csg.. Y 17. CMT vol adequate to tie-in long string to surf csg . . ~% N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N~ 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. Y~ N 22. Adequate wellbore separation proposed ......... ~ N 23. If diverter required, is it adequate ........... ~ 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to _~OC.FO psig.~ N 27. Choke manifold complies w/API RP-53 (M~M 84) ...... ~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N / 31. / ~; ~ Data presented on potential overpressure zones ..... Y N-' . 32. Seismic analysis of shallow gas zones .......... ~/N /~ , 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . .~-f.. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/ljb- A:~FORMS~cheklist rev 11/95 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. '£ape Subfile 2 is type: TAPE HEADER PRUDHOE BAY UNIT M D/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPAN~Y: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW- 60012 R. JACKSON K. WHITE S-29AL1 500292208260 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 03-FEB-97 MWD RUN 5 R. JACKSON KIRK WHITE MWD RUN 6 R. JACKSON C. DIXON MWD RUN 7 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD R. JACKSON C. DIXON MWD RUN 8 R. JACKSON C. DIXON 35 12N 12E 3638 3719 68.17 66.67 33.37 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 8.500 7.000 12684.0 PRODUCTION STRING 6.000 14275.0 REMARKS: MWD - GR/EWR4. ALL DEPTHS ARE MEASURED BIT DEPTHS. THIS WELL, S-29AL1, IS REPRESENTED BY RUNS 1, 2, 5, 6, 7, AND 8. THIS WELL WAS KICKED OFF FROM S-29A AT 12693', PART WAY THROUGH MWD RUN 2. MWD RUN 1 WAS DIRECTIONAL ONLY AND NO DATA IS PRESENTED. MWD RUNS 2, 5, 6, 7, & 8 WERE DIRECTIONAL WITH GAMMA RAY. ALL GAMMA RAY DATA WAS ACQUIRED WITH NATURAL GAMMA PROBE, SCINTILLATION TYPE DETECTORS (NGP/SGRD). THIS WELL WAS DRILLED TO TD AT 14275'. NO DEPTH SHIFTING WAS APPLIED, PER STEVE JONES OF BP EXPLORATION (02-DEC-96). FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 12075.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: STOP DEPTH 14216.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 12132.0 12693.0 5 12693.0 12713.0 6 12713.0 12793.0 7 12793.0 13659.0 8 13659.0 14275.0 MERGED MAIN PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : S-29AL1 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Lo9 Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 53 Tape File Start Depi = 14275.000000 Tape File End Depth = 12075.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13204 datums Tape Subfile: 2 146 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes 0 0' 000 ' 00' . O' 0 'APT O' 000 ' 000 ' 000 ' 000 ' OOP 6'8 08'6 O' ~69~'E 00S'8 99 ~DM ~N_rlN ~00~ S'E8 O'PE 0 0 · SIIEI 0 ' ~£IEI 0'SII£I I0'S ~ES / I50'¢ II'g DSI / EE'I DSN 96-N--~£-8E : (~I) NOILOZH~OO ZqOH :X~ISM~ XI~IrN :XI~LIrN qOOL NO~JXI~N : (£Z) HZdHG ONISWD : (MI) HZIS lie HqOH ~£~G DNIS~D ~Ntf ~OH~OE (NO,T,.I,OE O.L dO.L) DMI%tJ, S ~IO0,T. O' 8S0£I H£dZG EO.T,S SI~ :sd_Kq sT C SIT~qns sd~i CN WN FN COUN STAT DATA BELOW [E KICK-OFF-POINT OF 12693 ~S FROM THE S-29A WELLBORE. $ : BP EXPLORATION (ALASKA) : S-29AL1 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units GR MWD 68 1 AAPI 4 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 26 Tape File Start Depth = 13125.000000 Tape File End Depth = 12075.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6304 datums Tape Subfile: 3 91 records... Minimum record length: 18 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LiS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log 'header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12559.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12587.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 5. 12-FEB-96 MSC 1.32 / ISC 2.11 DEP 2.041 / SP4 5.01 MEMORY 12713.0 12693.0 12713.0 0 64.5 64.5 TOOL NUMBER NGP 235 6.000 12684.0 SEAWATER/FLO PRO 9.00 64.0 9.5 45000 5.0 .000 .0 .000 74.1 .000 .0 .000 .0 .00 .000 .0 0 s@~Xq s@~Xq ~9 :q~Bu~I pxoo~ mnmix~M :q~BusI p~oo~x mnm!uiM · ''sp~oo@x L9 5 :~I!~qns ~dPL smn~p L06£I 89 :apoD :A~mmns 6uypoosp ~pom uoy~uss~dsx SIq 00000S'0 = 5u!D~dS I~A~ ~IYZ 000000'0SSEI = q~d~G pu~ ~IYg 000000'SE£EI = q~d~G ~x~S ~IY~ ~d~z ~ SZLA~ EEOI (0 #ZdAi) GHODZH ~L~G . I 66 566 06 P P pox sIO clAL clK~ q~Bu~ ~zTS A~D A~D 5o~ HHd~ I 89 GMM dO~ s~Iu~ seIdm~S spoo IOOi :SsA~nD I ~ :~I q~d~p Z60~IS H.I,HON : Xlf~ ZOHCK1H~t : i~lRf6 E- S : (tf~Sk~Ilf) MOIik~/OqdX.q d~ : 'N/1H SIHL HO~ ZqR~f~II~A~ N/IOO NM ' 9 N/IH ~MN : SHH~q4,~H 0 0' : (RI) 000 ' 00' :(NI) NOIID~HHOD ~OH :A~ISN~ XIH~kn~ :XIH~tfN qOOi . 0' 0'III 0' 000 ' 000 ' 000 ' 000 ' O'S O00CjV cj'6 O'V9 00'6 OHcI 0~ 0'V89EI 000'9 : (&~) H&daQ DNISVD S,H~qqlHQ : (MI) aZIS &I~ ~qOH V&~Q DMIS~D ~N-~ SEE dDM (NO.LI.O~ 03. dO.L) DMIH.I.S ~IOOJ. £'I8 V'69 0 0' £6LET 0' £TLEI 0' C6LEI To's vas / zvo'g daQ I~'~ OSZ / ~£'I DSN 0'9fiLET STq :~ctKq sT ~ ~IT~qns ~d~& CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : S-29AL1 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 FPHR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 12800.000000 Tape File End Depth = 12650.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7208 datums Tape Subfile: 5 67 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12741.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13607.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 7. 15-FEB-96 MSC 1.32 / ISC 2.11 DEP 2.041 / SP4 5.01 MEMORY 13659.0 12793.0 13659.0 0 85.4 92.9 TOOL NUMBER NGP 235 6.000 12684.0 FLO PRO 9.OO 7O.0 8.2 39000 5.2 .000 .000 .000 .000 .0 137.5 .0 .0 .00 .000 .0 0 ss~Aq 5IOI :q~Bu~I p~oo~ mnmyxe~ ss~Aq E9 :q~Bu~I p~oos~ mnm!uyx · ''sp~oo~ £8 9 :~I7~qns ~d~L smn~p II661 89 :~poD d~ 00000S'0 = BuyoedS I~A~q ~I7~ 000000'00LEI = q~d~ pu~ sI7~ ~d~i 000000'00££I = q~d~G ~S ~I7~ ~d~ :sp~oo~ ~G Im~OL 66 ~66 06 ~ IO 0I£ 06 ~ P HHd~ I 89 ~MI4 dOH P Idtflf I 89' ~MM MD poM sIO clAi clAi q~Bu~% szys s~Iug s~Idm~s ~poD IOOi ~m~M :s~A~no g ~ :~I qqdap (~9 #ZdXL) ~ODZM i~O~ ~ tf~S~ : ZdO~S HLHON : X~ ZOHQ/IH6 : Iq~f6E-S : (tf~S~) NOIitf%IO%dXZ d~ : N/IOD MM NM ND 0 0' 000 ' 00' . O' I'OSI O' 000 ' 000 ' 000 ' 000 ' 9'9 000L£ I'6 0'6S 00'6 OHd O~I.~ 0'~89EI 000'9 99 dDN ~Wi1N ~OOi 9'I6 0 0'S£E~I 0'6S9£I 0'SLEgI I0'S ~dS / I~0'E d~G II'~ DSI / ~£'1 DSH 96-~H~-LI ' 8 N/1H ~M/4 : SHHk~.~H :(iH) : (RI) : (NI) NOIID~HHOD ~OH :XIHi~q~ qOOi NOHJ~qZN : (MI) MZIS IlK H~OH NMdO VlVG ©~ISVD GN-V H~OHZ~O~ ,~6X.l. ~OOi ,~GOD ~O0,1. HOfINZA 0'9IE~I · s~i!~ s~dss uI unx ~Iq qs~s ~o~ ~p ~p~q BoI pu~ s~A~no (IM~ MtfH 9 : H.w~J~RqN .wqI~ HZGVZH Z~II.4' SIq :sctX~ s! t aIl~qns sdei CN WN FN COUN STAT : BP EXPLORATION (AIJISKA) : S-29AL1 : PRUDHOE BAY : NORTH SLOPE * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 17 Tape File Start Depth = 14275.000000 Tape File End Depth = 13590.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11322 datums Tape Subfile: 7 80 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 8 is type: LIS 97/ 2/ 3 01 **** REEL TRAILER **** 9?/ 2/ 3 01 Tape Subfile: 8 2 records... MinimUm record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 3 FEB 97 ll:06a Elapsed execution time = 1.92 seconds. SYSTEM RETURN CODE = 0
