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196-011
Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday, April 26, 2015 6:42 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S;Wallace, Chris D (DOA); Glasheen, Brian P; Regg, James B (DOA); Munk, Corey Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R;AK, OPS FF Well Ops Comp Rep; Pettus,Whitney; Hidalgo, Ramon Subject: NOT OPERABLE:Injector S-29A (PTD #1960110) Due for AOGCC MIT-IA Attachments: image001.png;Injector S-29 (PTD #1960110)TIO Plot.docx All, Injector S-29A(PTD#1960110) is due for an AOGCC MIT-IA on May 4, 2015. The well will not be on injection for the test before the due date. The well is reclassified as Not Operable until the well is ready to be placed on injection and will be added to the quarterly Not Operable Injector Report. A copy of the TIO plot is included for reference. Thank you, Whitney Pettus SCANNED APR 2 7 2015 (Alternate•Kevin Parks) BP Alaska-WellIntegrity Coordinator 4]•t��tat: GW ��31���on"' WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 Injector S-29A(PTD# 1960110)TIO Plot 4900 I M 2roo ;OA OW OOO� 000 0124115 11242/15 020015 021115 _. _ '5 139515 011615 13:315 01X.1 041115 041025 Ii Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep [AKOPSFFWeIlOpsCompRep @bp.com] Sent: Monday, May 20, 2013 11:26 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Redmond, Randy; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 OSM; AK, D &C Well Integrity Coordinator; Bill, Michael L (ASRC); AK, OPS GC2 Field O &M TL; Starck, Jennifer L; AK, RES GPB West Wells Opt Engr Subject: RE: FYI: BPXA PBU Low PSI H2O Injector SVS Defeat - S -29A Dear Mr. Regg, As of 5/20/13 S -29A SVS has been returned to normal service. Please contact me with any questions. SCANNED MAY 31 2093 Thank you, Ryan Hayes (Alt. Lee Hulme) FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659 -5332 Cell: (907) 350 -2473 Harmony - 7187 From: AK, OPS FF Well Ops Comp Rep Sent: Sunday, May 19, 2013 8:02 AM To: Regg, James B (DOA); aogcc.inspectors(a alaska.gov Cc: Redmond, Randy; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 OSM; AK, D &C Well Integrity Coordinator; Bill, Michael L (ASRC); AK, OPS GC2 Field O &M TL; Starck, Jennifer L; AK, RES GPB West Wells Opt Engr Subject: FYI: BPXA PBU Low PSI H2O Injector SVS Defeat - S -29A Dear Mr. Regg, Per AOGCC waiver dated 3/11/13, PBU Oil Pool Low Pressure Water Injectors, BPXA is providing notification that well S- 29A (permit #1960110) in now operating with its SVS defeated as of 5/19/13. Per the wavier, BPXA has tagged and logged the defeated components, and will notify AOGCC once the SVS is returned to service. Please contact me with any questions. Thank you, Ryan Hayes (Alt. Lee Hulme) FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659 -5332 Cell: (907) 350 -2473 Harmony - 7187 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 09, 2011 TO: Jim Regg (" R& C 4 5 (i ( I( P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -29A FROM: Lou Grimaldi PRUDHOE BAY UNIT S -29A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ,.- NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT S -29A API Well Number: 50- 029 - 22082 -01 -00 Inspector Name: Lou Grimaldi Insp Num: mitLG110504162931 Permit Number: 196 -011 -0 Inspection Date: 5/4/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S -29A > I Type Inj. 1 W TVD 8575 - IA 1190 1 2260. 2240 2230 - 1960110 ° l SPT P,T,D� TypeTest II 1 Test psi 2143 -1 OA 360 1 360 360 I 360 Interyal pj' P . Tubing 250 250 250 1 250 Notes: Good test, 3 Bbl's diesel pumped 2.7 returned. ■ �;;., 1 2.011 Monday, May 09, 2011 Page 1 of 1 OPERABLE: Injector S -29A (PT,960110) POI for state witnessed MITI Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Tuesday, April 05, 2011 4:55 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: AK, D &C Well Integrity Coordinator; Schultz, Kirsten L; King, Whitney Subject: OPERABLE: Injector S -29A (PTD# 1960110) POI for state witnessed MITIA All, Injector S -29A (PTD# 1960110) was shut -in July 2009 due to nearby drilling on S -18B. The 4 -year regulatory MITIA came due while it was shut -in, thus it was classified as Not Operable. The S -18B sidetrack has been completed; therefore, S -29A may be placed on injection. The well has been reclassified as Operable and will need a state witnessed MITIA for UIC compliance when thermally stable. Please notify Well Integrity once the well is on injection so a state witnessed test can be scheduled. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator �� 6 .0 Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 4/6/2011 NOT OPERABLE: S -29AL1 (PTD 960120) Reclassified as Not Operable Due 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 S k k ( 0'0 Subject: RE: NOT OPERABLE: S -29AL1 (PTD #1960120) Reclassified as Not Operable Due to Out -of -date Compliance Testing Hi Danielle, 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 APR Zn 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 well reclassified as Not Operable. Let me know if you need any more info. Danielle Ohms GPB WWF Lead Production Engineer (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 (PTD #1960120) Reclassified as Not Operable 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 Nat 4perable Due to Out-of-date Campliance Testing c°~Y^ r, ~ Pi~~ `~~+~, ` ~ic%,t x ~ ~+~ci ~~~ ~~ .' ~.~.~ej Correct, it is S-29A. ~ ~~~ ~' Torin From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Sunday, October 11, 2Q09 9:16 AM To: NSU, ADW Welf Integrity Engirteer, Regg, ]ames B(DOA); Schwartz, Guy L(DaA); 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? Although S-29AL1 was likely the last segment drilled, the IA teehnically is in S-29A. Your tino~gntS? Tom Maunder, PE AOGCC _ _ _ __ __ __ _ _ From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sen#: Fri 10/9/2009 7:30 PM To: Regg, ]ames B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA); GPB, Area Mgr West (GCZ/WRa); 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 Gc: NSU, ADW We11 Tntegrity Engineer; Williams, Carrie Subje~k: 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 MlTIA will be required when the well has been placed on injection and thermatty stable. Please cafl with any questions or concems. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907} 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 14/12/2009 ,~. . STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS ~~4.~~1\1'~~~~~ ~ JUL 2 ~ 20~~ 1. O erations Abandon Re air Well Piu PerforaNons Stimutate p er ~ p ~ g ~ ~ A;~aS~J~~~~ . Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ ~~~k~~r ~~~` 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: rvame: De~nelopment ~ Exploratory ~ 196-0110 3. Address: P.O. Box 196612 StP8tlg1'2phIC ~ Service ~ 6. API Number: Anchorage,AK 99519-6612 50-029-22082-01-00 7. KB Elevation (ft): 9. Well Name and Number: 68.17 KB 8-29A 8. Property Designation: 10. Field/Pool(s): ADLO-028261 Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 15061 feet Plugs (measured) None true vertical 9029.95 feet Junk (measured) None Effective Depth measured 15061 feet true vertical 9030 feet Casing Length Size MD ND Burst Collapse Conductor 110 20" Surface - 110 Surface - 110 Surface 2790 13-3/8" 68# NT-80 Surface - 2764 Surface - 2689 5020 2270 Intermediate 11698 9-5/8" MN-80 Surface - 11698 Surface - 8152 6870 4760 Liner 1583 7" 29# L-80 11533 - 13116 8050 - 8979 8160 7020 Slotted Liner 2143 4-1/2" 12.6# 13-cr 12918 - 15061 8944 - 9030 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 3-1/2" 9.3# L-80 12696 - 12716 Packers and SSSV (type and measured depth) 3-1/2" Baker S-3 Packer 12394 3-1/2" Baker ISO MDL D PKR 12696 CTC Payzone Packer 13332 7" BAKER S-3 PKR 12219 12. Stimulation or cement squeeze summary: Intervals treated (measured); ` ~ t~ ~~"i!+# ~ `~ ~ ~; , ~, ~ ~~~J~i f` M• L•~+ L. M.R+~ia' ~ 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 proposed work: Copies of Logs and Surveys Run ExpIOPBtOry ~ D2~IOpfY1211t ~' Sef'VIC2 ~~ Daily Report of Well Operations X 16. Well Status after proposed wor ; Oil .- Gas ~ WAG GINJ ~ WINJ ~ WDSPL I~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. `~~ 1 Sundry Number or N/A if C.O. Exempt: ~^~~ ' ~ 305-199 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 7/29/2009 Form 10-404 Revised 04/2006 ~ ~~~%~ ~ ~_=~ _,~~ ~ ,~iy> ~~ ~~~~~ ,~ Submit Original Only Si~1ft S-29A 196-011 PFRF OTTO(_HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base S-29A 2/24/96 SL 13,470. 15,059. 8,988.93 9,029.75 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-29A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ } ~? , 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 ~ I 'DUMMY VALVE IN SAME, PULL S.S. CATCHER SUB ~ ; ;NOTIFY PAD OPER OF WELL STATUS, MAY NEED TO BE FREEZE ~ ~ ~ PROTECTED ? ~"""WELL LEFT SI, TURNED OVER TO PAD OP.""" ~ ~_, ~ __~___ ___.___.._.._~ ____ - _ _~»__ _-- ----- -- - ~ 8/24/2005°:.TIO = 1430/1430/340. Temp = SI. IA FL (For SL). IA FL @ 4570' (245 bbls), ~mm-~ `142' below sta-1. No A/L. ' ~_______~ ~.~.~.~~.a.~._~.~ _~ .___~_.~~._~.., ~.~~.~._.k. .~~.~ 8/24/2005; LRS Tanker standby for wireline. ~- _ __.._w .._____ { __ __ ,_ , . _ _ __. _ _.~.- ----- , . . ~. ~. _. _ __.,_._~__ , 8/26/20053 T/I/0= 1520/1400/ 380 , ASSIST SLICKLINE- Load IA and MIT-IA to 4000 psi. j ~ ; 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 ~ i20 psi in the 1st 15 min. and 10 psi. in the 2nd 15 min. for a total loss of 30 psi. g Bled pressure back to 1450. FW HP=2050/1400/400 ~ ~ 8/26/2005;***WELL~S/I ON ARRIVAL*** ~ ~~~~--~-~ ---~~~~ ~ ~~ ~~ ~~~~~ ~ ~ ` SET 4.5 SLIP STOP CATCHER @ 4615 SLM. PULL DGLV FROM STA#1 @ ~ ~ ~4413' SLM. LOAD IA W/ 245 BBLS OF INHIBITED 60/40 METH. SET DGLV IN ~ ?STA# 1. MITIA - 4000 PSI, PASSED. PULL SLIP STOP CATCHER. ~ ~ "*"W ELL LEFT S/I*** j 9/14/2005 % 0=2420/1420/480. Temp=Cold. TBG FL, (for FO call-in). TBG FL @ 11407' ;(173 bbls). ~ 10/4/2005 UNABLE TO TIE INTO PROVIDED LOGS DUE TO SATURATION IN THE ~~ i ;GAMMA RAY AND LACK OF CURRENT TUBING STRING LOG. CORRELATED ~ i ;TO BP TUBING SUMMARY DATED 22-JUL-2005. ; : LOGS INDICATE MAJORITY OF INJECTION GOING BELOW 12660' FT. ~ "*NOTIFY DSO OF WELL STATUS'''` ~ i~~ ~ _ _ ~ ~_----_ ___--- _ _ ____ ____ _,___ _ _ _ _ _ ____ . _~ __ _ __ _ _.._ _. _ _ i 10/7/2005~T10- 610/770/550. Well is on Inj. IA FL (pre-MITIA). IA FL @114' (7 bbls). OA i ~ FL near surface. j ' --~- ____ _. 10/8/2005~T/I/0=370/740/500 MIT IA PASSED @ 4000 psi (AOGCC Witnessed by John ~ ~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 ! ~ e W H P's=400/700/540 i , _ _ ~ ,. m ~_ ~ W_ ~ .~___~ ___ _.__ .. . ~ __ . ...____~ ~ .__ _.. _.._._._ ` ______ __ _ __E FLUIDS PUMPED BBLS 519.8 60/40 METH 6 DIESEL 525.8 Total a BP Expioration (Alaske) Inc. Attn: Well Integrity Coordinator, PRB-20 Past Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2049 Mr. Tom Maunder Ataska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 ~ ~~ ,~~ ~{' s ~,. ;~ ~~LiG! V E~ JUL 4 1 2009 Al~ska Oil & Gas Cons. Gommisxian Anchor~ge Subject: Corrosion Inhibitor Treatments of S-Pad Dear Mr. Maunder, ~~(~,-D ~~ ~- ~-~ A .. - ~„ ~,,., ~ ~ ~~ ~1 r~ Enclosed please find a spreadsheet with a list of weils 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 #he annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top af cement depth p~or to fifling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AflGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report af Sundry Operations. If you require any additional information, please contact me or my altemate, Anna Dube, a# 659-5102. Sincerely, ~~~`~~~~ JUi.. r: r: Z~~~ Torin Roschinger BPXA, Well Integrity Coordinator ~ BP ExpMoration (Alaska ) inc. Surf~e Casir~g t~r ConducWr Mnulus Cemsnt, Corrosion inhibhw, Sraimt Top~otf Report of Sundry Op~ntions t~~~) S-P~d r~. ar~snrv~o ~ WeH Name PTD R h~tai t~ ot ~ Vd. ot cement Fi~al rop W cernent Cert~t top o date Corraeion MihibHa Cortoaion inhiWtal seel~t date n ne~s n ~a i S-01B 1952020 025 NA 025 NA 2.8 5/3Q2008 SA2A 1941090 0.25 NA Q25 NA 7.7 5/252009 5-0.3 1811900 13.25 NA 1325 NA 92.85 5/20/2008 5-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-0SA 1951890 0 NA 0 NA O.e 5/28/2008 5-06 1821650 0 NA 0 NA 0.9 5J26/2008 SA]A 1920980 0 NA 0 NA 0.9 5f26/20a9 SABB 2010520 0 NA 0 NA 0.&i 5J27/2009 5-0D 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 &70A 1917230 0.5 NA 0.5 NA 3.4 513112009 5-118 1990530 025 NA 025 NA t.7 512712009 &14A 7851930 025 NA 025 NA t.T 6Nl2008 5-13 1821350 8 NA 8 NA 55.3 BI112009 5-15 1840170 0.25 NA 0.25 NA 3 6/212009 S•t7C 2020070 0.25 NA 025 MA 28 8~1/2008 &18A 2021830 0.5 NA 0.5 NA 3 B/t?I2008 5-19 186/180 0.75 NA 0.75 NA 22 5/19/2009 S20A 2010450 0.25 NA 025 NA 7.3 5/19/2008 S2t 19004~0 0.5 NA 0.5 NA 3A 5/25/2008 5-228 1970510 0.~5 NA 0.75 NA 3 5J19/2008 3-xi 1901270 025 NA 025 NA 1.7 512S~2U09 5-248 2031630 0,5 NA 0.5 NA 2.8 512512008 S-2SA 1982140 0.5 NA 0.5 NA 2.8 5125/2009 S•28 1900580 fl.75 NA 0.75 tU 3.4 5t26+2009 &278 2031$80 0.5 NA 0.5 NA 2.8 5l31/2009 S-28B 2eu> S~ 2IX~0020 >aeoa2o 7900680 0.5 a 0.5 NA w~ NA Ob o 0.5 NA nu, NA 2.s o.~ S.t 5/31t200B smrmoa 5d3t/2008 S31A /982200 0.5 NA 0.5 NA 3.4 5/26f2009 S~32 1901490 0.5 NA 0.5 NA 3.4 SB1l2009 S-3s 1921020 0.5 NA 0.5 NA a.3 5/26/2008 S~ 1921380 0.5 NA 0.5 NA 3.a 5/31/2009 S35 f923486 0 NA 0 NA .e5in 5/37/2009 S-~ 1921160 0.75 NA 0.75 NA a.25 5/2712009 3-37 1920890 1.25 NA 125 NA a7.e 5127/2009 3-38 1921270 025 NA 0.25 NA 102 5J27/2009 S-4t 196~d0 1.5 NA 1.5 NA 11 A 5r3Q12009 3-42 1960540 0 NA 0 NA 0.9 Sf30~2009 SdS 19~0630 0.5 NA 0-5 NA 17 5/2820~ 5-44 18700~0 025 NA 025 MA Y.7 5/28~2008 5100 2000780 2 NA 2 NA 21.3 5/29f200B S101 20D1150 125 NA /25 NA 11.9 529/2009 5-102Lt 2IXi756Q 125 NA 125 NA 17.1 5/31/Z008 S-tOS 20016~ 1.5 NA 1.5 NA 11.9 5/18/2009 S•104 2001960 1.75 P!A 1.75 NA 1b.3 5f20/2008 3•105 2001520 4 N11 4 NA 32.7 5/20f2008 5-108 2{f10120 1825 NA 16.Z5 NA 17A.3 B~2/2009 5107 2011130 225 NA 225 NA 28.9 5/78~2009 Sa08 ~11000 3.5 NA 8.5 NA 40 SfdO/2009 &109 2022450 2 NA 2 NA 27.3 5130Y1009 &it0 2011290 11.75 NA 11.75 NA 98.6 5J3Q12008 S•t~i 2050510 2 NA 2 NA 10.6 5/30t2008 S•712 2021350 0 NA 0 NA D.5 5/30I20D8 &113 2021430 1.75 NA 1,75 WA 72.1 5/i8t2008 SttM 2021980 i.25 NA 125 NA 102 5/30V2009 Stt6 2022300 2.5 NA 2.5 NA 27.2 Sr28/2009 S-116 2031810 1.5 NA 1.5 NA 13.8 5l28f2009 S-ltT 2030120 1. NA 1.5 NA 15.3 5/29I2008 S11B 2032000 5 NA 5 NA )8.6 5/28f200A S-I19 2W1820 1 NA t NA 52 5/30/2009 S•120 203188(Y 5.5 NR 5.5 PiA 87.2 5/29/2009 5121 20604f0 4.5 NA 4.5 NA 53.8 5/28/2009 51Y2 2050810 3 NA 3 NA 21.3 St29/2009 S72s 2041370 1.5 NA 1.5 NA 20.4 512812009 S72a 2861360 1.75 NA 1.75 NA t~.~ 5126/2009 5125 2070830 2.25 NA 225 NA 20.s St2&2009 S128 20710970 125 WA 125 NA ~ 15.3 6J1J2009 5290 1472380 125 NA 125 NA 14.5 St2812009 5-201 2001840 0 NA 0 NA 4.~ 6t1812009 S273A 2042130 2 NA 2 NA 13.6 5(29P2009 S2t5 2021540 2 NA 2 NA 18J 6l1/2008 S-258 2007970 4.~5 NA 475 NA Si 5/281'1009 S-2t7 2070950 025 NA 025 NA t.7 6/12008 S-i00 2070740 2 NA 2 NA 9.4 S/28/2009 S401 2060780 16 NA 18 NA 99.5 6/2P2008 S•604 0 NA 0 NA 0.85 5/2812a08 . ~ -a-~~ ~ ~~~ ~ C~ ~ ~, ~~ \`1.>~t~..~ \ ~ ~ ~lb '~.\ ` "~ I `t`'r ~G~ c-c,~\ ~c r t.,`R~~c~~~r -~-~.~ ~ ~~~~ ~~.~ ~ ~ ~e~,~ ~ ~~~~~~~ ~d~%~~~ ~~~~~C v ` MEMORANDUM ~ T~: Jim Regg ~k~~; I~ ~`~ ~G'~ P.I. Supervisor ~ ~~ FROM: John Spaulding Petroleum [nspector '~ State of Alaska ~ Alaska Oil aad Gas Conservation Commission DATE: Tuesday, October 11, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLURATSON (ALASKA) INC S-29A.L1 PRUDHOE BAY IJNIT S-29AL! Src; Inspector NON-CONFIDENTIAL ~ ~~~ ~~ V~ Reviewcd $y:~ P.I. Suprv ~..~.`~i~- Comm Well Name: PRUDHQE BAY UNTT S-29AL1 Insp Num: mitJSO5101o105345 Ret Insp Num ppT Well Number Permit Number: 50-029-22082-60-00 196-012-0 Inspector Name: Tohn Spautding Inspection Date: 14/8/2005 Packer Depth Pretest Initial 15 M'tn. 30 Min. 45 Min. 60 Min. Weli S-29AI.1 Type Inj. I 'j'~ ~ 8575 jA, 740 4000 3980 3980 p.T, 1960120 lTypeTest SPT Test psi 2143.75 pA soo I soo eoo soo Interval ~RY~}fL. P/~ p Tubing ~ s~o ~ s~o 3~0 ~ aoo NOtes 14.8 BBLS MEOH Annulus was not fluid paeked to surface K~, S z ~~o c-r-.o.~o t~ cc~.~ ~ \ ~ ~ ~ ~-~ S - ~-~ ~ ~ L ~ `~ ' ~ ~ ~ ~ ~~~~ ~~~E~` ~IOU ~. ~ 20fl~ ~~ "~c1 Tuesday, October 11, 2405 Page 1 of 1 n I~J MEMORANDUM To: Jim Regg '°'~ P.I. Supervisor ~~i~Of ~, ~ FROM: John Spaulding Petroleum Inspector 7~2Z~o~ ~State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, 7uly 22, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-29A PRUDHOE BAY LINIT S-29A Src: Inspector NON-CONFIDENTIAL Well Name: PRUDHOE BAY iJNIT S-29A API Well Number: 50-029-22082-01-00 Inspector Name: John Spaulding Insp Num: m~~S051010105345 Permit Number: 196-01 l-o Inspection Date 10/8/2005 Rel Insp Num: MITOP000000939 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel] S~z9A Type Inj. I 'j'~ 8575 IA 740 4000 3980 3980 P.T.D 1960110' Ty~eTCSt SPT TCSt PSl z143.75 QA 500 500 600 600 Interval In~c~ai Tesc P~j' Pass '~ Tubing 370 370 370 400 Notes• 14.8 BBLS MEOH Annulus was not fluid packed to surface , ~ ~ ~4 ~C~?~4~ ~ ~ . ,... .. E . '. ~ > .. ~} ~ - ~~~ ~~~G~,'~ ~"~J- i ~ ~t} 1pNk S ~ir~- ~,~ ~S S~v~ ~Cc~.s-~ I~r~ ~~'~t:Z ~Z_`7i~ l..l ~(~/~ l`~~i ~~ ~~ Wednesday, July 22, 2009 Page 1 of 1 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well Z-01 Y-13 L2-14B Y -08A X-36 X-30 S-29A {'I{ ... DO P2-01 os 12-08C 0.5. 09-28A P2-34 Q-05A NK-09 NK-38A BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job # 11087166 N/A 10670029 11047356 11075908 10662973 11087187 11072880 11087208 11094347 N/A 11087203 11062632 11075902 ~.ß"U\1.'Þ::t"\ 'r:" '» [, '~OOh ~~~~nI~~ \t !4f\! (. U L! ..; Log Description LDL PRODUCTION LOG PROD PROFILE MEMORY/SENSA LDL MEMORY INJECTION PROFILE GLS INJECTION PROFILE LDL SBHP SURVEY LDL INJECTION PROFILE SBHP SURVEY PROD PROFILE W/DEFT MEMORY PROD PROALE Date 08/05/05 05/01/05 08/20/04 10/15/05 08/17/05 12/02103 10/04/05 08/06105 12/24/05 12/28/05 06/02/05 11/27/05 07/01/05 07/27/05 01/04/06 NO. 3642 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD ~ -'" Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ Received be1~h Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth RECEIVED DEC 2 1 2005 Alaska on & Gas Cons. Ccmffi~k:n Anchorage Well Job# Log Description Date BL C-04A 10687728 SBHP SURVEY 01/07/05 1 L 1-15A 10715359 PROD PROFILE WIDEFT 11104/03 1 S-29A ,q~-O{I 11087187 INJECTION PROFILE 10/04/05 1 09-33 N/A PROD PROFILE WIDEFT 07/16105 1 D.S 18-03B 11057071 SBHP SURVEY 12102/05 1 M-10 11072878 LDL 08/05/05 1 D.S 18-25A 11057072 SBHP SURVEY 12/03/05 1 A-31A 11072881 LDL 08/07/05 1 K-06A 11075903 MEM PROD & INJ PROFILE 07/30/05 1 L 1-27 11058255 PROD PROFILE W/DEFT 10/25/05 1 AGI-10 11087429 LDL 09/05/05 1 S-36 11152365 LDL 11108/05 1 K-20B 11057076 SBHP SURVEY 12/06/05 1 M-18B 11072876 INJECTION PROFILE 08/02/05 1 2-18/L-16 11087185 LDL 10/01/05 1 2-62/Q-17 11084325 INJECTION PROFILE 11/21/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 8CANNElJ< JAN 2; 5 200t Date Delivered: 12121/05 NO. 3630 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne PI. Color CD ,--,,' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received bY~n , STATE OF ALASKA ALASKA' k AND GAS CONSERVATION CO,.,~ISSIOtt,:,:,:~$~,'r-,"'''',,,,, I.r,'~,','i\" E""',,,' B~V" E ' REPORT OF SUNDRY WELL OPERATIOl"Š--t,i::r¡, ,,,0 AUG 2 4 Z005 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program O 0 0 0 0 h .;.¡~ C omL C Ornmtss1on-- Suspend Operation Shutdown Perforate t er ð' i ¡.\m~iH)rage o Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well 181 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): 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 196-011 6. API Number: 50-029-22082-01-00 99519-6612 68.17' 9. Well Name and Number: PBU S-29A ADL 028261 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 8. Property Designation: 11. Present well condition summary Total depth: measured 15061 feet true vertical 9030 feet Plugs (measured) None Effective depth: measured 15061 feet Junk (measured) None true vertical 9030 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2790' 13-3/8" 2764' 2689' 5020 2270 Intermediate 11698' 9-5/8" 11698' 8152' 6870 4760 Production Liner 1583' 7" 11533' - 13116' 8050' - 8979' 8160 7020 Liner 2143' 4-1/2" 12918' - 15061' 8944' - 9030' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Slotted Liner: 13470' - 15059' 8989' - 9030' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2", 12.6# x 3-1/2", L-80 9.3# CTC Payzone packer; 7" Baker ISO MOL '0' packer; 7" Baker 'S-3' packer; 7" Baker 'S-3' packer; 4-1/2" HES 'X' Nipple 12452' & 12696' - 12716' 13332'; 12696'; 12394'; 12219'; 2088' 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANI'ÌED ;~UG ;] 0 2.iJC~) Treatment description including volumes used and final pressure: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl CasinQ Pressure Tubinq Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 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 ~. ~~_ Form 10-404 Revised 04/2004 Title Technical Assistant pJ.. ,,_, ,; oo.~ Prepared By Name/Number: L" '~'9~~ i_.', ~~:$~~ L ~ 0,' ate U ,QS T" e,rrie Hubble, 564-4628 J I \ U. I Jl1 'x....i3lYJIlj _ - aé~riginal Only TREE = 4" C~ WELLHEAD = FMC AqrUA TOR = BAKER KB. ELEV = 63.12' BF. ELEV = 35.72' KOP = 1758' Max Angle = 91 @ 14738' Datum MO = 12713 Datum 1VD = 8800' SS 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1-1 113-3/8" CSG, 68#, NT-80, 10 = 12.415" 1-1 ~ ) ) S-29A Completion ~ ~ 12146' 1-14-1/2" HES X NIP, 10 = 3.813"1 12219' 1-17" BAKER S-3 PKR, 10 = 3.875" 1 12252' 1-14-1/2" HES X NIP, 10 = 3.813"1 12283' - 4-1/2" HES XN NIP, 10 = 3.7" 1 12346' - UNIQUE MACHINE OVERSHOT 123821 1-13-1/2" HES X NIP, 10 = 2.75" 1 123941 H7" BAKER S-3 PKR, 10 = 3.875" 1 124191 1-13-1/2" HES X NIP, 10 = 2.75" 1 124401 1-13-1/2" HES X NIP, 10 = 2.75" 1 124521 H3-1/2" W/LEG 1 I 124571 1-1 ELMO TT LOGGED 05/02/96 1 ~ 126991 I-IBAKERSEITING SLV W/6' EXT 1 ~, ............. ........ .... .... , MILLOUT WINDOW ......... _ ", 12681' - 12693' --.......-- ...... ...... ....... ....,.... ............ ............... .......,..... '................. ......... ~ 124951 I-;RA TAG 1 ....'....,.... '.... 12353' 1 2764' ~ L I TOP OF 7" LNR 1-1 115331 '-i ì~ TOP OF SECTION MILLED WINDOW 1-1 11698' Minimum ID = 2.635" @ 12707' 3-1/2" HES XN NIPPLE 13-1/2" TBG, 9.3#, L-80, 0.0087 bpf, 10 = 2.992" 1-1 12452' 1 ~E TOPOF 4-1/2" LNR 1-1 12918' 1 7" LNR, 29#, L-80, 0.0371 bpf, 10 = 6.184" 1-; 131161 14-1/2" LNR, 12.6#, L-80, 0.0152 bpf, 10 = 3.953" l-f 133191 I TOP OF 4-1/2" SL TO LNR 1-1 13470' \4-1/2" SL TO LNR, 12.6#, 13-CR, 0.0152 bpf, 10 = 3.958" 1-1 15059' DATE 11/14/90 02/23/96 01/21/99 03/15/01 03/16/01 REV BY COMMENTS ORIGINAL COMR.EOON MUL TJ..LA TERAL COMR.ETION LAST WORK OVER CONVERTED TO CANVAS FINAL DATE 03/02102 REV BY COMMENTS RNITP CORRECTIONS CHH GLM SIS-MH SIS-CS ~' 1 - 2í!80" 1-;4-1/2" HES x NIP, 10 = 3.813" -, 27201 I~ ~ I STI MO 11V01 OEVI TYPE IVLVILATCHI PORTI DATE I 1 4430 3800 54 MMG pcR-1 RKP 126961 H BKR ISO MOL 0 PKR, 10 = 2.93" 127071 1-13-1/2" HES XN NIP, 10 = 2.635" 1 127161 1-13-1/2" W/LEG 1 4-1/2" LNR, 13-CR, 12.6#, -; 142681 1 .0152 bpf, 10 = 3.958" 12740' I-IRA TAG 1 133321 IJ CTC PA YZONE PKR 1 134591 H 4-1/2" XN NIP, 10 = 3.725" 14-1/2" LNR, 12.6#, 13-CR, 0.0152 bpf, 10 = 3.958" 1-1 15061' 1 PRUDHOE BAY UNIT WELL: S-29A PERMIT No: 196-0120 API No: 50-029-22082-01 SEC 35, T12N, T12E BP Exploration (Alaska) Well: Field: API: Perm it: ') ) 07/19/05 N/A 07/24/05 Nabors 4ES S-29A 1 L 1 Rig W orkover Prudhoe Bay Unit 50-029-22082-01-00 196-011 Accept: Spud: Release: Rig: 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. PRE-RIG WORK 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 2.70101.995. 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. ) ') BPEXPlX)RATIOJ\J :O:peratiönsS1umrnaryReport Pa.get 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 DesçriptioH of 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. 7/19/2005 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 OECOMP Pre job wI regard to well killing ops. Test lines @ 350 I 3500 psi, OK. 17:00 - 20:30 3.50 KI LL 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 OECOMP Monitor well. Install TWC & test same to 1000 psi. Blow down & RID kill lines. . 21 :00 - 22:30 1.50 WHSUR P DECaMP Bled off hanger void. N/D tree & adapter flange. 22:30 - 00:00 1.50 BOPSUF P DECOMP NIU BOPE. 7/20/2005 00:00 - 02:30 2.50 BOPSUR P OECOMP Con't to NIU BOPE. Install choke & kill valves. RIU scaffolding section. 02:30 - 07:30 5.00 BOPSUP P DECaMP 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 DECaMP 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 DECaMP 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 @ 5 112 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 ·Operati.Ql"Is.· SurnmaryReÞørt Pag~ 2013 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 NPT 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 w/ 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 PIU kelly. Break circulation. Wash down & dress off tubing stub 1.5'. Top of stub @ 12350'. Washed to 12361' w/ 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 LOOP. 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 & L/D 31/2" DP. 06:00 - 06:30 0.50 CLEAN P DECOMP Service rig. 06:30 - 11 :00 4.50 CLEAN P OECOMP PJSM. Continue to POOH & UO OP. 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 adj usted depth = 12,348'. Pull wear bushing. 12:30 - 16:00 3.50 RUNCOIVP RUNCMP PJSM. Finish racking, tallying & drifitng completion tubing. 16:00 - 17:00 1.00 RUNCOMP RUNCMP Rig up to run completion. Generate completion summary & double check. 17:00 - 17:30 0.50 RUNCOMP RUNCMP Pre Job meeting wI Baker Hand, Nabors Casing & rig hands. 17:30 - 00:00 6.50 RUNCOrvP RUNCMP PIU completion tail pipe assys, Baker Lok & RIH. PIU 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 RUNCOMP 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 RUNCOMP 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 RUNCOMP RUNCMP PJSM. Reverse circulate 250 bbls heated seawater followed by 600 bbls heated seawater w/ corrosion inhibitor, 3 bpm I 200 psi. 18:00 - 19:00 1.00 RUNCOrvP RUNCMP Land completion. P/U Wt 121 K, S/O Wt 85K. RILDS. Drop Ball/Rod. UD landing jt. Drain stack. 19:00 - 21 :30 2.50 RUNCOWP RUNCMP R/U 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 & 81. Pressure up on annulus to 4000 psi, Hold & chart for 30 min. Bleed off tubing & DCR valve sheared @ 1600 psi. Equalize tbglann & 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 RUNCOWP RUNCMP Intall TWC & test to 1000 psi. 22:00 - 00:00 2.00 BOPSUP P RUNCMP N/D BOPE. Remove lines & valves to UD stack. 7/24/2005 00:00 - 01 :30 1.50 BOPSUR P RUNCMP Con't to N/D BOPE. Break out mud cross & control lines to Koomey. 01 :30 - 03:30 2.00 WHSUR P RUNCMP NIU Adapter flange & X-mas tree. Test same to 5000 psi, OK. 03:30 - 04:00 0.50 WHSUR P RUNCMP PIU lubricator & pull TWC. UD lubricator. 04:00 - 06:30 2.50 WHSUR P RUNCMP R/U hot oilers Hold PJSM & freeze protect w/ 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: ) ) BPËXPLORATJON QþeratiQns $urnmary Rèport S-29 S-29 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Pagè3 qf3 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 Description öf.Operations 7/24/2005 07:30 - 09:00 1.50 WHSUR P RUNCMP PJSM. PIU 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 (~l F lv" ]f. !.íb '\" J! .dJ~ .; 'I \ .1:1../ " _.' ,t ~ )11 in'· ,Ui 'II ~ e-:J....J . .,' ::..~ ~ (fl"¡ r ,r ¡il :11 ! ~'-1 I ,I )'jl \~ J !I\ 11 ('1\ /~\ rV7 IT ! ; ¡\I' / .' ~ ~ I, \!- I ! / ! i \ \ f i.J Ii! ! W \ ,\ i ~ \ i .U \ '''-'\:'1 .'- j""~\ ' .,_ì l.,;' U t.':::J L: ~ .~. U \..:. L/ \ J FRANK H. MURKOWSK/, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COJDIISSION 333 W. ]TH 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 A c\ 7. t) ß'~l ....', <' t:..'f"I' \VL (, ~. ,- ,-.;;;.. fl" õ.. ct\.'~ ~~ t:. 'I-f ~'-ftC~~~ ""." Re: Prudhoe Bay S-29A Sundry Number: 305-199 , t"....~'t t , Dear Mr . 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 following the date of this letter, or the next working day if the 23rd day falls on. oliday or weekend. A person may not appeal a Commission decisi . ,. to uperior Court unless rehearing has been requested. , DATED this 1/' day of July, 2005 Encl. ö ~ ( July 18, 2005 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 RECEIVED JUL 2 1 2005 Alaska Oil & Gas Cons Comm' . . ,ss,or Anchorage 8P 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 penetration 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()~:gy; GPB Waterfl:i¡neer o ¡NAL ÚP1' 7· 2-S-a) W6A 1/1';)/lOfJÇ- ( STATE OF ALASKA 6{ ~ 7/ Z6/ S ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: 0 Abandon Suspend 0 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): 15062 Casing Total Depth TVD (ft): 9030.0 Length CONDUCTOR SURFACE PRODUCTION LINER LINER SLOTTED LINER 83 2764 11720 1583 2115 1589 Perforation Depth MD (ft): 13470 - 15059 Packers and SSSV Type: 3-1/2" Baker S-3 Packer 3-1/2" Baker ISO MDL D PKR CTC Payzone Packer 3-1/2" HES SSV Landing Nipple 12. Attachments: 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# 13Cr80 4-1/2" 12.6# 13Cr80 Perforation Depth TVD (ft): 8989 - 9029.8 Description Summary of Proposal ŒI Detailed Operations Proç¡ram D BOP Sketch D 14. Estimated Date for Commencing Operation: July 29, 2005 Date: Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: top 27 26 25 11533 12946 13470 Development [!] bottom top 110 2790 11745 13116 15061 15059 Tubing Size: 3-1/2 " 3-1/2 " PerforateD Waiver 0 Other [!] StimulateD Time Extension D CONVERSION Re-enter Suspended Well D TO WAG WELL 5. Permit to Drill Number: 196-0110 /' -É~Ploratory D 27.0 26.0 25.0 8049.9 8951.6 Packers and SSSV MD (ft): 6. API Number // 50-029-22082-01-00 Plugs (md): None Burst Junk (md): None Collapse Stratigraphic D Service D 9. Well Name and Number: S-29A / 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 15062 9030.0 Size MD TVD bottom 110.0 2710.2 8182.4 8979.4 9029.9 1490 5020 6870 8160 8430 470 2270 4760 7020 7500 9.3 # 9.3 # Tubing Grade: Tubing MD (ft): L-80 23 L-80 12696 12452 12716 12394 / 12696 13332 2188 13. Well Class after proposed work: /' Service 00 Exploratory D DevelopmentD 15. Well Status after proposed work: Oil D GasD PluggedD I WAG [X] GINJD 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 Jim ~O:9i '( Commission Use Only Conditions of approval: Notify Commission so that a representative may witness BOP TestD &Ltitu SLiJY Vt-'-{ ¡ O'~ 4 Ð 4 - Title Phone Mechanciallntegrity Test ~ Abandoned D Contact WINJD WDSPLD Prepared by DeWayne R. Schnorr 564-5174, Jim Young Petroleum Engineer 564-5754 7/15/05 Sundry Number: 30 &"- /c¡t:? Location Clearance D ~ , ~ Î - ~ 4-:" ~"¿D W t\.f (t \) hi' .o~' ~ d tt,. {.. I h,le.c,\-(,t'¡.-,,- . RBDMS B.F. L .JUt 2 g'.. 20Œ 3Y ORDER OF It--Lr t / , THE COMMISSION Date: r rl "J o RIG ~ N A L SUBMIT IN DUPLICATE TREE = WELLHEAD = ACfU<\ TOR = KB, REV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD = ( ( 4"Crvv FMC BAKER 63.12' 35.72: 1758' 91 @14738' 12713 8800' SS S-29A SAFETY NOTES: UPPER LAT. IS AN OPEN OOLE LNR W/o LNRTOP/PKRlI-IGR LNRSITS ON BTM. ISOLATION PKR SET ON E-LlNEAf'Ð BELOVV UPPER LATERAL SE£TION. DEPTHS OOttT INßCATETHIS DUETO DIFFEREf\CE BETWEEN DRlLLPIPE AND E-LlNE MEASUREMENTS. 700@ 12879' AND 90° @ 13343' o 1 ~ ~ 2188' H3-1/2:' I-ES SSSV U\f'.D. NIP, 10 = 2.75" 2720' ~ 113-3/8" CSG, 68#, NT-80, 10 = 12.415" H 2720' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATa; PORT DATE 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 TOPOF7' LNR H 11533' L }I I 1 9-518" CSG, 47#, NT-80-S NSCC, 10 = 8.681" 1-1 11745' ,.t ~ Minimum 10 = 2.635" @ 12707' 3-1/2" HES XN NIPPLE 12382' H3-1/2"HES XNIP,ID= 2.75" 1 12394' H7" BAKERS-3 PKR.ID = 3,875" 12419' H3-1/2"HESXNIP,ID=2.75" 1 12440' H3-1/2"HESXNIP,ID=2.75" 1 12452' 'H3-1/2" WilEG 1 1 12457' 1-1 ELMO TT LOGGED 05/02/96 1 ~ 12699' H BAKER SETllNG SL V W/6' EXT 1 '1.. -- --.... MLLOUT WINDOW ~ _ .$,~ -....-_ 12681'- 12693' ~............. 11IIII(;9 --- -- "'9< -- .............. ....... .........t' ........ ...................... -..... --- ~ 12495' I-1RA TAG 1 ---__ 13-1/2"TBG,9,3#, L-80, 0.0087bpf, 10=2,992" 1-1 12452' 1 DATE 11/14/90 02/23/96 01/21/99 03/15/01 03/16/01 18 12696' H BKR ISO MOL 0 PKR 10 = 2.93" 12707' H3-1/2" 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. 10 = 3.958" 12740' H R,A. TAG 1 1 TOP OF 4-1/2" LNR 1-1 12946' 1 7" LNR 29#, L-80, 0,0371 bpf ,10 = 6,184" 1-1 13116' 1 4-1/2"LNR. 12,6#, L-80, O,0152bpf, 10=3.953" l-i 13319' ITOPOF 4-1/2" SLTD LNR l-i 13470' 14-1/2" SLTD LNR 12,6#, 13-CR 0,0152 bpf. D = 3.958" 1-1 15059' 13332' I~CTC PA YZONEPKR 1 13459' H4-1/2"XNNIP,ID= 3,725" 14-1/2:' LNR, 12.6#, 13-CR, 0,0152 bpf, 10 = 3.958" l-i 15061' I REV BY COMtvENTS ORIGINAL CONPLErION tvUL ll-LA TffiAL COMA..EllON u\STWORK OVER CO NV ERfED TO CANVAS RNAL DATE 03/02/02 ReJ BY COrv1MENTS RN/TP CORRECTONS ffiUDHOE BA Y UNIT W8...L: S-29A ÆRMIT No: 196-0120 API No: 50-029-22082-01 SEC 35, T12N, T12E BP Exploration (Alaska) CI--I1 GLM SIS-MH SIS-CS :~ MECHANICAL INTEGRITY REPORT· '.. :. ~ G R E L :S;._ S.:: : OPER & FIELD g? p f~ U w'"ELL NUMEER s: - 2 q It- ~?UD I:ì.~.~:::: 7~~LL DATA TD: I(O&c..,illJ. qo 30 TVD; ?BTD: jCofp2 HJ? ~CSO TVD CasiDg: f_S/g'f 7 II 7 ') l " :~Di.::g: ~ Packe:!:' 12.452. till '" 'I o·'lz'I :: ole S iz e I (.. - 4" anå ð" Shoe: J/ 74 5 HD .¡ I ~ L TVD j DV : 2- 1 20 MD -. ·Tvu ~=-:ïe~: Shoe: 1311tr-. HD ¡Q7C¡ TVD; :OP: 115~) HD .g (!J 'S 0 -:~¡D T'VD i sio ~¿ á rcr£.:J Set ê. t ) 2 3q4 )'5470 to /50S t¡ ::-:EC?,..ANIC;'..L INTEGRITY - PART ¡ 1 Annulus Press Test: ~p ; 15 m~n 30 min Co=ents: MIT 'rIÖu1~Jd, ",.- ~CH.tÜiICÞ.~ INTEGRITY - PART /2 Cement Volumes:" þ...mt. Liner 7 bh/Ç., ; Csg DV ~b@~¿ f Ci:ü t 70 1 ~o covc~ p er= s 4 hl.)! '" t- S; 00 {J 5 t? (t-~J ./2.')( ~ ç; \. I Theore tical Toe J'2~· 7-g· Cement Bond Log (Yes or No) ¡0ö In AOGCC File ' CEL ~valuation, =one a.bove perfs Proåuction Log: Type . .. VJä! bv/"Z f-~?, ç,u,Y\J¿, CONC~LUSIONS : EV,aluatian r-t Þ ¡M\ r'~,d'., . '. ? art fl: JI¡. ¡.:, T ~'';) IAAI ~I J · ? arc:. : 2: (f tv<.. ~ ") JI't.f:,O .' J<;. I ~d/ Clt '& )riA1Ü 1M...) 1"1<.1 Ar'fÞIl1/~1 ~},;"',·'.J~'\.RAA, dl J, Þ "" i') ~.... .,~ 1'" ("' ) '1..? . .oj 'lJ (\, i,·\,tA. ")\,1.,;",,,,];\ I i l ' ,I l' /,,{~,t, ~, \,' ), I~ . '.'/":. .J ~ ),l 'µZ,ø¡ ¿~..f' f(~~/) I (/ tf (~ . -. -- Date: To: From: Subject: 1, 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. Qm 01 A"OO, tvW 700 ax> :m 1&> o 01 01W:i1 1 0.1ŒŒ2 Ae. 76. 049 bI:iId 12/31/2»4 R-ase Cæe Nare 100 -: b :., [) - Q ti te B-d Rate 100 bI:iId 10 _ Fire! Råe 101.84 bI:iId : . Qm A'a:I. 6æ.472 tvW Qm D::te 1<Y31/2Xl2 - Rssaves 0 tvW - EiR 6æ.472 tvW Faecast 8'ded ~ Råe Faecast D::te 07/2fJ'XXß 32 ::ë .a 5 ~ .Jg III 0::: ð 1CXX> - . 100XJ Date 0.001 " ! ';O~~' r I I I' I I I ~17' r , I , I' " , 'g~' r " I [ 1 I I' rg~' , r r I I' , I '2'O~~' I I I' I '~11' , r I 'I' 1 I 1 ,O~' , ' , I r r " 'o~' r 1 " 1" I I 'o~" I , I I' I I "016' " r 0.01 0,1 -: 1 -: 02g220820100:150 - 011 R.,. (CD) (Mbblld I WelorRele (CD)(MÞbl/d) G.. Rale (CD)( MMclld ) Wells on W el.r Injection Wells on G.. InJecllon Ge. Inj R.t. (CD)( t.4cf/d ) W alOf Inj Rate (CD) ( Mbbl/d ) Producing QIIWella 10 PRUDHOE BAY, PRUDHOE OIL PBU_S PRUDHOE BAY S-29A . # PERMIT 96-011 96-011 96-011 96-011 AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 02/25/98 DATA T DATA PLUS RUN RECVD GR/CCL/JEWELRY ~/~EPIA /4 ~ P NGP/RES-MD ~L~ 12132-15062 NGP/DGR/RES-TVD ~t8499_9030 7905 1 05/21/96 FINAL 12/11/96 FINAL 12/11/96 /SPERRY GR/RES /4 />~ - I~'~ 2-4 02/12/97 10-407 ~COMPLETION DATE ~_/;2 ~ / qL/ DAILY WELL OPS Are dry ditch sampl'es re~ired? yes ~_ ~d received? Was the well cored? yes ~.~_.Analysis & description received? n~ Received? Are well tests required? ~)es Well is in compliance Initial COMMENTS O I::1 I I_1-- I I~] G S EI::tWI r' G S · WELL LOG TRANSMITTAL To: State of Alaska February 12, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 .- RE: MWD Formation Evaluation Logs - S-29A AK-MM-960104 ~'(o - © ~ \ :~ -'lc} o ~ S-29AL1 AK-MW-60012 ~ko- o1'2.__ 'Ix- -7ol o 6~ 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 2 LDWG formatted Discs with verification listing. APl#: 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 c;l ?--,I$1_IFI O !:t I I__1__ I I~ Oi S El I:t ~/I I-- 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: q ~ - ~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 t.e-' O{ 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 LARRY GRANT Attn. ALAS}LA OIL + GAS CONSERVATION 3001=~,~"~INE~ = DRI%~E ANCHOP~_GE AK, 99501. Date: 9 May 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: ECC No. 1 PLS FINAL BL+RF Run # 1 1130.08 1 PLS FINAL BL+RF ! CN FINAL BL+RF 1 PLS FINAL BL+RF 1 CN FINAL BL+RF Run # 1 2413.02 Run # 1 2452.06 Run # 1 3385.03 Run # 1 4112.05 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 CN FINAL BL+RF i CN FINAL BL+RF Run ¢ 1 4468.06 Run # 1 5609.04 Run # 1 5627.13 Run # 1 5665.11 Run # 1 6090.05 1 PLS FINAL BL+RF 1 D~ ~~S FINAL BL+RF 1 PLS FINAL BL+RF i PFC/PERF FINAL BL+RF 1 GR/CCL FINAL BL+RF Run ~ 1 6103.05 Run # 1 6234.05 Run # 1 6624.03 Run # i 6667.00 Run # 1 6670.00 Cont/ 1996 Received by: Please sign and return to: Attn. Rcdney D. Pau!son w~~ ~+]~ Lcc~in~ S~v 5600 B Streen Suite 201 Anchorage, AK Gas Cons. ~chor~e 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 96-11 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 . :.' -: ::~ .. ~ 5o-029-22082-01 4. Location of well at surface '. 9. Unit or Lease Name 1641' SNL, 1560' EWL, SEC. 35, T12N, R12E ~ . ~;~112~.~ . ' .... ' Prudhoe Bay Unit At Top Producing Interval 10. Well Number i' '~ ~' ' '. S-29A 4164'SNL, 885' WEL, SEC. 3, T11N, R12E ~' '" !! 'i 11. Field and Pool At Total Depth ,,..~,~;~ ..... ~_:~, Prudhoe Bay Field/Prudhoe Bay Pool 4104'SNL, 2906' 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. 15. Water Depth, if offshore 116. No. of Completions 01/25/96 02/04/96 02/23/96 N/A feet MSLI One !17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDI 19. Directional Survey J20. Depth where SSSV set 21. Thickness of Permafrost 15061'MD/9030'TVD 15061'MD/9030'TVD YES [] NO []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 SE'FFING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BO'FI'OM 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 cu fl Class 'G' 7" 29# L -80 11533' 13116' 8-1/2" 388 cu ft Class 'G' 4-1/2" 12.6# L-80 12918' 15061' 6" 72 cu ft Class 'G' 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) 3-1/2" 12452' 12394' 4-1/2" Slotted Liner 3-1/2" 12696' - 12716' 12696' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13470'- 15059' 8989'- 9030' Freeze Protect w/155 Bbls Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 11, 1996 Gas Lift Date of Test Hours Tested TESTPRODUCTIONpERIOD FORii~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 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. RECEIVED 'A1as1<a Oil & Gas Cons, C~m,,~,o~,~ 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 12742' 8880' Sadlerochit 13028' 8969' ORIGINAL 31. LIST OF A-I-I'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Senior Drilling Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". R E C ~.iV ~ D Form 10-407 APR 1 i !,996 u::S SUMMARY OF DAILY 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: S-29~ & 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 2~ 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: S-29A & S-29AL1 Jan 30 1996 (13) R.I.H. to 12110 ft. Reamedto 13116ft. Circulated at 13116ft. 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 Driilpipe 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 13196ft. 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 Operations Summary for: S-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: S-2~, & 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 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: S-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 13122ft. 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 RECEi\/ED APR 1 1 1.996 Alsska 0il ~, 6r:s C,:;;~. 6ommission Operations Summary for: S-29A & S-29AL1 Feb 21 1996 (11) Ran Casing 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 ? _,~ ..... Sud Csg Dep 2958 .... VOLUME (BBLS) Method of displosalcumping Cwn outer annulus SOURCE WELL DATE OF DIESEU FRE~E MUD/CTGS BRINE WATER Dally Cum. Total COMPLICATIONS, COMME~S NUMBER INJECTION PROT. S-29A 1/18/96 160 20 100 ~ [ [~[~ 600PSI S-29A -- 1/21/96 950.00 35.00 i~i ~i~8 600 PSI - S-29A 1/22/96 66.00 ~ ~ ~'?'i~:,~[i~',8 ~8-~[ -- S-29A 1/23/96 545 45.00 __ ~ ~8 650 PSI S-29A 1/24/96 1 00 26.00 :~ ~' ;~t~[~[~ 650 PSI S-29A 1/25/96 1000.00 45.00 ;i~ [: i[8~i~8 600PSI 's-~, ~/~6/96 ~0.00 ~[ [ [?'i~i8 eoo,s~ _ S-29A 1/27/96 63.00 ~[~[~ 750 PSI S-29A 1/28/96 29.00 ~ [~;~:~?;~ 750 PSI S-29A 1/29/96-- 85.00 ~ ~ ~?'~ 800 PSI __. S-29A 1/30/96 359.00 -- 220.00 - ~ ~ :~:.~ ~ - 130 ~MT WASH WATER S-29A 1/31/96 1072.00_ - 51.00 ~ ~ ~:~ 700 PSI .... S-29A 2/1/96 604.0~ ~ ?:~:;~:,~ ~0 PSI S-29A -- 2/2/96 -- 60.00 :.~[ ~( ~ ;~::~;~:~::~';~~ PSI S-29A 2 / 3 / 96 0.00 - S-29A 2/4/96 128.00 ........... S-29A 2/5/9 6 .......... 100.00 ~ ......... S-29A 2 / 6 / 96 0.00 - ~ ~' S-29A 2/7/9 6 - 225.00 10.00 INC 125 BBL CMT WASH S-29A 2/9/96 ~ 1411'00[ .... PSi ~ - S_29A -- 2/11/96[ ~- 395.00[ 91.00 15.00; .:: .~50!,00 650 PSI I . S-29A 2/12/96i q 743.00t 25.~_ 15.00 783;00650 PSI S-29A ~ 2/13/96[ ~-{ 100.00~ 10.00 150,;00 700 PSI ~, , s-~e, I ~/~4/96~ [ , 1~3.00~ : ~.00 ~oo~s~ S-29A I 2/15/961 I ~ 75,00' 75.00700 PSI , S-29A [ 2/1 7/96[ ~ 60.00 60.00 700 PSI S-29A ~ 2~1 9/96~ 182.00~ 756.00 ~. 938,00.700 PSI 1 S-29A ~_ 2/20/96~ I, 1004.00 { 1004,00 700 PSI S-29A 2/21/9611 ~ 924.00 25.00 ' · 949~00' 650 PSI [ S-29A 2/22/96/ 418.00~ : 4i8.00 650 PSI S-29A 2 / 2 3 / 9~ 171.00 120.00 '; ':~. ~:': ':;;~: ::::2:91:~ 00 :; 650 PSIi~EEZE PRO~CTED T~2~M.D. ! ~'~:.~.~ ~';?~. I SPERRY-SUN DRILLING SERVICES · ANCHORAGE ALASKA ~HARED SERVICES DRILLING PBU/S-29AI 500292208260 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/27/96 DATE OF SURVEY: 020596 MWD SURVEY JOB NUMBER: AK-MM-960104 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. 11685.25 8143.76 8075.59 11700.00 8152.94 8084.77 11710.54 8159.62 8091.45 11742.56 8180.77 8112.60 11774.51 8202.85 8134.68 51 31 S 25.38 W .00 51 31 S 25.54 W .86 49 42 S 25.38 W 17.40 47 35 S 24.87 W 6.67 45 0 S 24.33 W 8.23 7153.43S 1763.54W 7078.96 7163.86S 1768.50W 7090.48 7171.21S 1772.01-W 7098.60 7192.97S 1782.21W 7122.54 7213.97S 1791.83W 7145.54 11806.40 8225.63 8157.46 11838.76 8249.49 8181.32 11868.47 8272.21 8204.04 11899.64 8296.82 8228.65 11931.59 8322.74 8254.57 43 47 S 23.74 W 3.98 41 12 S 23.10 W 8.14 39 0 S 22.40 W 7.56 36 42 S 21.20 W 7.75 34 47 S 20.40 W 6.12 7234.34S 1800.92W 7254.40S 1809.61W 7272.05S 1817.01W 7289.80S 1824.11W 7307.24S 1830.75W 7167.74 7189.45 7208.44 7227.37 7245.79 11963.67 8349.43 8281.26 11995.44 8376.54 8308.37 12028.26 8405.22 8337.05 12058.50 8432.21 8364.04 12082.10 8453.59 8385.42 32 35 S 19.20 W 7.16 30 12 S 17.60 W 8.00 27 53 S 18.20 W 7.06 25 42 S 17.30 W 7.40 24 23 S 18.90 W 6.21 7323.98S 1836.78W 7339.68S 1842.01W 7354.85S 1846.90W 7367.83S 1851.06W 7377.33S 1854.16W 7263.31 7279.53 7295.11 7308.43 7318.21 12103.13 8472.77 8404.60 12133.98 8500.84 8432.67 12165.04 8528.67 8460.50 12196.63 8556.18 8488.01 12228.08 8582.63 8514.46 24 0 S 17.40 W 3.49 25 0 S 20.20 W 4.97 27 42 S 23.10 W 9.63 31 12 S 26.20 W 12.08 34 17 S 31.00 W 12.85 7385.52S 1856.85W 7397.62S 1860.98W 7410.42S 1866.08W 7424.52S 1872.57W 7439.44S 1880.74W 7326.65 7339.20 7352.84 7368.30 7385.29 12258.97 8607.67 8539.50 12290.62 8632.30 8564.13 12323.16 8656.56 8588.39 12355.50 8679.70 8611.53 12387.71 8701.77 8633.60 37 24 S 34.90 W 12.46 40 24 S 37.70 W 10.98 43 12 S 41.20 W 11.20 45 24 S 43.00 W 7.83 48 5 S 46.60 W 11.68 7454.60S 1890.59W 7470.60S 1902.36W 7487.33S 1916.15W 7504.08S 1931.30W 7520.71S 1947.83W 7403.35 7423.09 7444.47 7466.54 7489.21 12418.00 8721.44 8653.27 12447.32 8739~60 8671.43 12477.33 8757.30 8689.13 12509.80 8775.20 8707.03 12539.30 8790.15 8721.98 12572.69 8805.87 8737.70 12603.68 8820.06 8751.89 12632.71 8833.24 8765.07 12663.97 8847.09 8778.92 12692.65 8859.51 8791.34 50 54 S 49.90 W 12.41 52 35 S 52.90 W 9.91 55 5 S 56.40 W 12.57 58 0 S 58.10 W 9.94 61 5 S 59.60 W 11.39 62 42 S 59.90 W 4.86 62 47 S 58.90 W 2.89 63 12 S 58.60 W 1.66 64 11 S 58.50 W 3.21 64 30 S 58.30 W 1.22 7536.03S 1965.02W 7550.38S 1983.02W 7564.39S 2002.78W 7579.04S 2025.56W 7592.19S 2047.33W 7607.02S 2072.77W 7621.04S 2096.48W 7634.46S 2118.60W 7649.08S 2142.50W 7662.63S 2164.52W 7511.06 7532.48 7554.48 7578.55 7600.80 %626.36 7650.34 7673.01 7697.61 7720.34 o te _, OI ' 0:3- OI SPERRY-SUN DRILLING SERVICES · ANCHORAGE ALAS RA PAGE ~HARED SERVICES DRILLING PBU/S-29A~ 500292208260 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/27/96 DATE OF SURVEY: 020596 MWD SURVEY JOB NUMBER: AK-MM-960104 KELLY BUSHING ELEV. = 68.17 OPERATOR: BP EXPLORATION FT. 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. 12723.56 8872.67 8804.50 12754.41 8885.41 8817.24 12785.03 8897.70 8829.53 12815.87 8909.89 8841.72 12847.18 8921.77 8853.60 65 5 66 5 66 35 66 48 68 35 S 58.30 W 1.94 7677.33S 2188.32W S 58.30 W 3.24 7692.09S 2212.22W S 57.60 W 2.66 7706.978 2235.99W S 58.10 W 1.62 7722.05S 2259.97W S 59.30 W 6.75 7737.09S 2284.72W 7744.95 7769.67 7794.44 7819.46 7844.85 12879.23 8932.76 8864.59 12908.50 8941.61 8873.44 12940.32 8950.12 8881.95 12970.87 8957.54 8889.37 13002.06 8964.31 8896.14 71 18 73 30 75 30 76 24 78 30 13032.89 8969.91 8901.74 80 35 13064.26 8974.52 8906.35 82 30 13087.82 8977.09 8908.92 84 57 13119.83 8979.66 8911.49 85 49 13151.25 8981.99 8913.82 85 40 13182.71 8984.35 8916.18 13215.02 8986.35 8918.18 13246.91 8987.74 8919.57 13278.96 8988.99 8920.82 13311.21 8989.80 8921.63 13343.12 8989.70 8921.53 13374.55 8989.34 8921.17 13406.33 8989.13 8920.96 13437.86 8989.01 8920.84 13469.76 8988.88 8920.71 85 43 87 9 87 50 87 41 89 26 90 54 90 25 90 18 90 9 90 18 13501.67 8988.69 8920.52 90 22 13534.06 8988~41 8920.24 90 37 13563.93 8988.25 8920.08 89 58 13595.51 8988.42 8920.25 89 26 13627.09 8989.05 8920.88 88 16 13658.82 8990.05 8921.88 13690.99 8991.20 8923.03 13722.90 8992.36 8924.19 13754.32 8993.43 8925.26 13783.51 8994.47 8926.30 88 7 87 46 88 3 88 1 87 52 S 61.70 W 10.97 7751.91S 2310.93W S 64.30 W 11.32 7764.578 2335.78W S 67.10 W 10.55 7777.18S 2363.72W S 70.60 W 11.50 7787.87S 2391.36W S 74.00 W 12.59 7797.12S 2420.36W S 77.80 W 13.90 7804.50S 2449.76W S 80.40 W 10.19 7810.37S 2480.22W S 80.96 W 10.71 7814.16S 2503.33W S 81.72 W 3.58 7818.97S 2534.87W S 82.47 W 2.42 7823.278 2565.90W S 82.56 W .33 7827.36S 2597.01W S 84.04 W 6.36 7831.12S 2629.03W S 84.22 W 2.21 7834.388 2660.72W S 84.31 W .55 7837.58S 2692.59W S 86.06 W 7.67 7840.29S 2724.71W S 84.84 W 5.96 7842.82S 2756.51W S 85.28 W 2.05 7845.52S 2787.82W S 84.39 W 2.83 7848.38S 2819.47W S 85.08 W 2.25 7851.28S 2850.87W S 86.87 W 5.63 7853.528 2882.68W S 86.98 W .39 7855.23S 2914.55W S 86.40 W 1.95 7857.10S 2946.88W S 87.78 W 5.11 7858.61S 2976.71W S 89.16 W 4.68 7859.46S 3008.28W S 88.29 W 4.62 7860.16S 3039.84W S 89.31 W 3.25 7860.82S 3071.55W S 89.49 W 1.20 7861.16S 3103.69W N 89.85 W 2.25 7861.26S 3135.58W N 88.07 W 5.66 7860.69S 3166.97W N 88.73 W 2.33 7859.888 3196.13W 7870.77 7894.15 7919.03 7942.08 7964.57 7985.64 8005.93 8020.74 8040.65 8059.87 8078.94 8098.18 8116.82 8135.50. 8153.87 8171.94 8189.91 8208.18 8226.36 8244.18 8261.57 8279.32 8295.53 8312.01 8328.37 8344.77 8361.11 8377.11 8392.29 8406.13 SPERRY-SUN DRILLING SERVICES ANC~IORJlGE ALASKA PAGE oHARED SERVICES DRILLING PBU/S-29A~ 500292208260 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/27/96 DATE OF SURVEY: 020596 MWD SURVEY JOB NUMBER: AK-MM-960104 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. 13817.14 8995.82 8927.65 13849.22 8997.25 8929.08 13883.29 8998.84 8930.67 13913.84 9000.00 8931.83 13945.22 9000.89 8932.72 87 31 N 89.31 W 2.00 7859.30S 3229.73W 87 20 N 87.92 W 4.36 7858.53S 3261.77W 87 19 N 86.53 W 4.08 7856.88S 3295.76W 88 18 N 86.40 W 3.24 7855.00S 3326.23W 88 27 N 86.05 W 1.23 7852.93S 3357.53W 8422.40 8437.72 8453.26 8466.83 8480.67 13977.54 9001.83 8933.66 14008.96 9002.80 8934.63 14041.36 9003.85 8935.68 14072.94 9004.94 8936.77 14105.29 9005.84 8937.67 88 12 N 85.93 W .86 7850.67S 3389.75W 88 16 N 85.09 W 2.68 7848.22S 3421.06W 88 0 N 84.65 W 1.59 7845.32S 3453.31W 88 3 N 83.76 W 2.82 7842.13S 3484.71W 88 44 N 83.18 W 2.76 7838.46S 3516.84W 8494.79 8508.29 8521.88 8534.79 8547.63 14135.97 9006.14 8937.97 14168.21 9006.09 8937.92 14199.03 9006.05 8937.88 14229.46 9005.95 8937.78 14261.96 9005.85 8937.68 90 9 N 81.77 W 6.50 7834.44S 3547.25W 90 0 N 82.03 W .93 7829.90S 3579.17W 90 9 N 81.39 W 2.13 7825.45S 3609.67W 90 15 N 81.10 W 1.01 7820.82S 3639.74W 90 5 N 80.68 W 1.38 7815.68S 3671.83W 8559.33 8571.32 8582.69 8593.69 8605.25 14293.91 9005.88 8937.71 14326.02 9006.35 8938.18 14356.78 9007.13 8938.96 14389.11 9008.10 8939.93 14420.14 9009.32 8941.15 89 49 N 80.69 W .84 7810.50S 3703.36W 88 29 N 80.81 W 4.16 7805.34S 3735.05W 88 36 N 80.98 W .67 7800.48S 3765.41W 87 57 N 83.50 W 8.05 7796.11S 3797.43W 87 31 N 85.05 W 5.18 7793.02S 3828.27W 8616.50 8627.84 8638.78 8650.98 8663.70 14450.92 9010.62 8942.45 14482.48 9011.95 8943.78 14514.72 9013.30 8945.13 14546.47 9014.76 8946.59 14578.36 9016.51 8948.34 87 37 N 84.48 W 1.88 7790.22S 3858.90W 87 32 N 84.93 W 1.45 7787.31S 3890.29W 87 39 N 87.35 W 7.51 7785.14S 3922.43W 87 2 N 89.11 W 5.87 7784.16S 3954.12W 86 41 N 89.17 W 1.08 7783.68S 3985.96W 8676.55 8689.70 8703.85 8718.83 8734.30 14610.09 9018.37 8950.20 14641.78 9020.11 8951.94 -- 14673.90 9021.30 8953.13 14706.18 9021.53 8953.36 14738.40 9021.07 8952.90 86 34 N 88.24 W 2.95 7782.96S 4017.63W 87 5 N 87.89 W 1.98 7781.90S 4049.25W 88 40 N 87.39 W 5.13 7780.57S 4081.32W 90 29 N 87.04 W 5.74 7779.01S 4113.56W 91 10 N 86.16 W 3.45 7777.10S 4145.71W 8749.49 8764.34 8779.20 8793.93 8808.33 14769.96 9020.48 8952.31 14801.27 9019.96 8951.79 14832.69 9019.58 8951.41 14864.90 9019.50 8951.33 14897.60 9020.20 8952.03 90 57 N 86.03 W .78 7774.95S 4177.20W 90 55 N 85.55 W 1.54 7772.65S 4208.42W 90 27 N 84.42 W 3.89 7769.90S 4239.71W 89 50 N 84.06 W 2.20 7766.67S 4271.76W 87 40 N 83.52 W 6.84 7763.13S 4304.25W 8822.18 8835.77 8849.01 8862.20 8875.35 SPERRY-SUN DRILLING SERVICES ° ANCHORAGE ALASKA PAGE 4 ~HARED SERVICES DRILLING PBU/S-29A~ 500292208260 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/27/96 DATE OF SURVEY: 020596 MWD SURVEY JOB NUMBER: AK-MM-960104 KELLY BUSHING ELEV. = 68.17 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 14930.36 9021.73 8953.56 86 58 N 83.45 W 2.15 14959.94 9023.30 8955.13 86 55 N 82.96 W 1.67 15000.71 9025.77 8957.60 86 8 N 82.68 W 2.03 15061.00 9029.83 8961.66 86 8 N 82.68 W .03 15062.00 9029.90 8961.73 86 8 N 82.68 W 1.98 7759.42S 4336.77W 8888.36 7755.93S 4366.10W 8899.97 7750.84S 4406.47W 8915.72 7743.18S 4466.13W 8938.85 7743.05S 4467.12W 8939.24 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 8939.24 FEET AT SOUTH 29 DEG. 58 MIN. WEST AT MD = 15062 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 209.94 DEG. TIE IN POINT 11685.25 KICKOFF POINT 11700' INTERPOLATED DEPTH 15062' SPERRY-SUN DRILLING SERVICES ~ ANCHORAGE ALASKA PAGE oHARED SERVICES DRILLING PBU/S-29A~ 500292208260 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/27/96 DATE OF SURVEY: 020596 JOB NUMBER: AK-MM-960104 KELLY BUSHING ELEV. = 68.17 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 11685.25 8143.76 8075.59 7153.43 S 12685.25 8856.32 8788.15 7659.12 S 13685.25 8990.98 8922.81 7861.11 S 14685.25 9021.56 8953.39 7780.06 S 15062.00 9029.90 8961.73 7743.05 S 1763.54 W 3541.49 2158.84 W 3828.93 287.44 3097.96 W 4694.27 865.35 4092.65 W 5663.69 969.41 4467.12 W 6032.10 368.42 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ~HARED SERVICES DRILLING PBU/S-29A~ 500292208260 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/27/96 DATE OF SURVEY: 020596 JOB NUMBER: AK-MM-960104 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 NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 11685.25 8143.76 8075.59 7153.43 S 1763.54 W 3541.49 11723.75 8168.17 8100.00 7180.32 S 1776.32 W 3555.58 14.09 11863.25 8268.17 8200.00 7268.99 S 1815.74 W 3595.08 39.49 11985.76 8368.17 8300.00 7335.04 S 1840.54 W 3617.59 22.51 12098.09 8468.17 8400.00 7383.55 S 1856.20 W 3629.92 12.33 12210.80 8568.17 8500.00 7431.19 S 1876.09 W 3642.63 12.71 12339.24 8668.17 8600.00 7495.63 S 1923.55 W 3671.07 28.44 12496.86 8768.17 8700.00 7573.22 S 2016.40 W 3728.69 57.62 12712.92 8868.17 8800.00 7672.26 S 2180.11 W 3844.75 116.05 13022.78 8968.17 8900.00 7802.25 S 2440.05 W 4054.61 209.86 15062.00 9029.90 8961.73 7743.05 S 4467.12 W 6032.10 1977.50 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS MEMORANI dM TO: THRU: David J~ Chairm~i~ Blair Wondzeil, ~J~,~ P. I. Supervisor o ate of Alaska Alaska Oil and Gas Conservation Commission DATE: January 30, 1996 FILE NO: airka4dd.doc FROM: Jerry Herring,.~.~ SUBJECT: Petroleum Inspector BOPE Test- Nabors 28E BPX, PBU S-29A PTD # 96-0011 Tuesday, January 30, 1996: I traveled to BPX's S-Pad and witnessed a B.O.P.E. test on Nabors 28E. The B.O.P.E. Test Report is attached. The B.O.P.E. test lasted for (4.0) hours and there were (3) failures. Two choke manifold valves leaked through the equalizing port. These valves were repaired and retested good. The dart valve leaked, was repaired and retested good. I found the rig and location in good condition and crew in good spirits. Summary: I witnessed a B.O.P.E. test on Nabors 28E drilling PBU S-29A. The test lasted for (4) hours and there were (3) failures. Attachment: airka4dd.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial X Workover: NABORS BPX PBU S-29A Set @ Weekly Rig No. 28E PTD # Rep.: Rig Rep.: 13,116' Location: Sec. X Other DATE: 1/30/96 96-0011 Rig Ph.# 659-4863 Kirk White Dave Rhodes 35 T. 12N R. 12E Meridian UM TEST DATA MISC. INSPECTIONS: Location Gen.' OK Housekeeping: OK (Gen) PTD # OK Standing Orders Posted 0/4 BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign OK Drl. Rig OK Hazard Sec. OK Test Quan. Pressure P/F 250 / 3,500 P I 250 / 5,000 P I 250 / 5,000 P I 250 / 5,000 P I 25015,000 P 2 250 / 5,000 P I 250 / 5,000 P n/a n/a n/a MUD SYSTEM: Visual Alarm ' Trip Tank OK OK 'Pit Level Indicators OK OK Flow Indicator OK OK Methane Gas DeL OK OK H2S Detectors OK OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 250 / 5,000 P I 250 / 5,000 P 1 250 / 5,000 P 1 250 / 5, 000 F/P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 18 Test Pressure 250 / 5,000 48 250 / 5,000 2 P Functioned Functioned P/F F/P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: (8) Bottles 2,950 P 1,700 P minutes 28 sec. minutes 50 sec. OK Remote: OK 2,000 (Ave.) Psig. TEST RESULTS Number of Failures 3 Test Time 4.0 Hours Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within n/a days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Choke manifold valves #2 & #18 leaked through equalizing port. These valves were repaired. Dart valve failed, was repaired and retested good. I found the rig in good shape and crew in good spirits. Distribution: orig-Well File c- Oper./Rig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: AHPKICCD.XLS ' A~LASI~A OIL AND GAS CONSERVATION COMMISSION Janua~ 16,1996 · t' TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Stoltz, Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Al~ct~orage, AK 99519-6612 Re: Prudhoe Bay Unit S-29A BP Exploration (Alaska), Inc. Permit No 96o011 Surf Loc i641'SNL, 1560'EWL, Sec. 35, T12N, R12E, UM Btmhole Loc 1174'NSL, 2368'EWL, Sec. 03, T11N, R12E,UM Dear Mr Stoltz: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested'in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed pdor to ddiling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dlf/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill Flllb. 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 2o AAC 25.025) 1641' SNL, 1560' EWL, SEC. 35, T12N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1080' NSL, 907' WEL, SEC. 3, T11N, R12E S-29A 2S100302630-277 At total depth 9. Approximate spud date Amount 1174' NSL, 2368' 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 property15. Proposed depth (MD and TVU) property line ADL 028260 2912 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 ~zoo 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' 350 sx Class 'G' 6" 4-1/2" 12. 6# L-80 BTC-M 2089' 12971' 8950' 15060' 8989' 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 i"~i~ ~ ~¢, ~ -~ V ~ D Surface Intermediate JAN 't 2 1996 Production Lin e r At-~s,,a Gl & Ga8 Cons. 0omrc. issian Perforation depth: measured ~,ri~'lora,~e true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed reportl-I 20 AAC 25.050 requirements[] 21.1 hereby c/e~ti~ that th~ f~r/e~l/oing is true and correct to the best of my knowledge / / Y/l/Il Signed ~z~,,~ ,,::~,r¢-"~=¢~ Title Senior Drilling Engineer Date /-/z -~/6 Commission Use Only Permit Number APl number tApproval date See cover letter /~'_/'// 50-~-2.. ~-..~_. :2_ 0 ~'.2_-"~,/I / '-//~, .-'" ¢'~' for other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required []Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required li~ Yes [] No Other:Required working pressure~riglrla/~l(jrleafOr BE)~E [] ~V; 1-13M; ,~5M; I--I10M; I--I15M-, by order of //(~ j~ Approved by David W. Johnston Commissioner zne commission Date ~ Form 10-401 Rev. 12-1-85 Submit ir cate I Wen Name: I S-29A / S-29AL~1 Sidetrack/Multi-Lateral Plan Summary Type of Well (producer or injector): I Producer I 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 T11N R12E (end of horz - 1st 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) I AFENumber: 14P0733.0 I I Rig: INab°rs 28-E I Estimated Start Date: 12-01-96 I I Operating days to complete: I 32 I RT-GL 133.8' IMD: I 15,060' I ITvD: 18,988' I I.KBE-MSL 69.5' Well Design (conventional,slimhole,etc.) 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' 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' ~aska Oi.i & Gas Cons. Casing/Tubing Program: ~or~ 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' _+13,12178,977' 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' +_14,991'/8,846' (2nd Lateral) Tubing 3-1/2" 9.7# L-80 NSCT 9,717' 33'/33' + 12,300'/8,660' ementing 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-U2" Hole 6" Hole I 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 ---~'~ None Planned ~U:~*~ ~'~ - Mud Program: Intermediate Mud Properties: [ 8-1/2" hole ~q~,~ ffo,'~~tal: LSND Depth Density Marsh Yield 10 sec "I0 min 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 AP1 fluid loss to <6 cc in Kingak Section. Production Mud Properties: 16" hole sections: Xanvis KCL Depth I Density ! Marsh Yield 10 sec 10 min 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 ih Sadlerochit in 1 st lateral; Faults may also be encountered in the Sag River in 2 'rd lateral. Differential sticking possible (overbalance) - both la erals. Perform/report daily checks on KC1 concentrations in Xanvis KC1 system. High torque may be experienced and should be treated with Lubtex additions. Directional'. [ KOP: [ kl 1,700' MD (lst lateral); k12,720' MD (2nd lateral) Maximum Hole Angle: kg0° Tangent Angle k65° 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. . isposal: 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. PERMITTED MAX. PERMITTED PERMITTED AREA WELL INJECTED VOLUME FLUID DENSITY DATES (aBES) (aBES) (PPG) WOA S-29 980 35,000 17.0 Pending Approval S-33 4,904 35,000 17.0 12/18/95-12/18/96 o , . . . 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): $-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. Wor;se case scenario calculations assume 17.0 ppg maximum fluid density and gas-filled i qner casi!~lg (see attached nomograph for ppg equivalent mud weights vs. injection pressure prof:les). 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 @0% 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 1692 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 =5-29A Horizontal Sidetrack Summary , , , . , , . , , 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 m~y be made prior to running production liner. -29A Sidetrack Operations Summary Page 2/2 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Run and set a 4-1/2", L-80 slotted liner @ Total Depth. Top of liner will be at _+12,971' MD. 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). 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). Mill window off whipstock at _+12,695' MD and drill +_25' new hole. POOH. 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 Jr- ~ · lateral interval is _2,296. 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. 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). RIH and pull retrievable whipstock. RU and run 3-1/2", L-80, production tubing. 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. Drilling 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 horizontai section of the Sag River lateral. There are no known drilling close approaches. No other known drilling hazards are expected. BPX- Shared Services Drilling Alaska SLate Plane: Zone4 PBU · ~OA: S-Pad Slo~ · S-29A As-buH~ ~e~]p[an ' S-29A %~p§ L2 I/I;/% CRII'JCAL Pi]Jllf BAIA TIE IN KOP I START ElF CURVE ~ . ZO,,OO' Il O0 Ft , Nl,~ubii k i EHB nF CURYE r & &O'/I/]i] Ft END 13~ CLIRV~' Mb Inc P,2i. IZGgS 65.86' PZ7 ~-~] 65, Q0' iZ791 7& 4i~' lZ87B 9~. I)~' 10::310 9~. (M~ E57. OD° 8800 I eG68 - 688R -- BBgl 8895 -- sgon -- 8950 8EB~ OSCO 770~ 7 75~ G. O0'/l~ ct END ~ c~vc .... - -- . - 79~3 ---%----~-----~ .................... 7800 71350 7~ 7950 uae0 casa mOO 9~50 eaU0 ~ tO0 ~L / ~ 9~.~6' e 137~.~ l. ll] END ~ CtIRVL CLI:RVL ?. 6. UO"/]O0 Ft 46' ~ 14991 M Halliburton Energy Services - Drilling Systems PSL Proposal Repor~ Survey ~~: W'EM.,HEAD Ref,~rcac~ Wo~d Coc)~[~,a(c~:t. st '/Q.2LI3 N - L~n~ i49,01. A0 W Eel'ormlx GRtDCoordinams', (PO: S~?.9S5~'.0,0 N 61.gT23,OD £ Nozth AiYgncd 'fo: 1RUE NORTH ',/~i~ $c~tion R~-~'mo~: WELLHEAD Closure R~ fer~-:. WF..LLI~=AD Vcsilcal Sr, ctk~ Pl~: 209.~ deg. Bt'X-Skmed .~:nri~.s Ddllin~ Aln.~e Sttt~ Nme: PBU: WOA: $4~a~ Slot: S-29A As-&n~h Wall.olin: $-29A Wp8 L2 Mc~urc~ ]a~ I~ Svb~a ~ Com'~c T 0 T A L GP, ID Coonrautcs Naah~ ~-t~ (a) (a) · C,k~u~ Vcrticnl BuLtd Walk DL~ Cum. E~p~'~edTolal Max H~r Min~r D~, t2~0.00 S~.O0 236, S3 8~5,66 8894,93 28.94 7750,8t S 2261.32W 5~720'/0.03 617584.82. g~3~t~.2G 7872.68 19.~ ~DOF~ 12877.68 95,0D ~0~O 8~6.16 6895.43 57.~ 7781.09S ~10~ 5~7~ 6t7536~l -8116,~1~,54 ~22.~5 19.~ 13~.68 95,00 2~gO S813.~ 8882.36 150.~ i3117.68 95.05 2~2 8~.32 R8~ 13~7.6B 01.~ ~ RS1 88g_~ 1O0.~ ~D OF~ 13309~ 95.~ ~7.~ ~1 8~7~ 8225 ~58.47g 2700~V 59718~5.54 617148.94 ~.1~[~.74 8~2.~ -0,06 O.O0 0.00 194_~ 7679.11 8 2166.9~Y9/ 0.00 O,0O e_~ 0.~ 1~3 8~.1~ S tB71.7~V ~0.~ 55.41 6,14 ~.00 214.3 g1273Og 1945.9~, ~S6 M.~ 3~-~ 6,0[ 20.0~ ~5.9 g160.21 S ]~3.4~V ~0.1t ~29 O,0O 0.~ 2~.9 ~L74~ Zll8.~ ~9~7 54.49 320.~ 6.02 6,~ 231.9 8291~9S 2~5,4~ ~55.59 55.~ 320.~ 6.0Z 6,~ 2~.9 83~.10 S 2296,6~ 66t.74 5LB7 320.67 6.02 6.~ 2~.8 ~59.69 S Z374A~' ~.69 56~ Sag River t:~5~,~O ~S.O0 257.0O 1~'/84.2~ S~$L52 ~.S? 9968.9~g 274~,~ 5~7L~.~9 6171~ S4~.~t~.01 ~2~8,~7 ~,~ 0.~ 13516~8 ~.~3 ~J fi771.~ 8640.95 [gO,~ ~.7g~ 290t.TlW 5971811.f~61694~.[~ ~.7~1~ g40t. S5 -l.~ 5,82 0.0o 242.g ~37LB! S 2419.039' 669.52 5639 321.01 0.00 2~2.g :389.64 S 247&2c'W 6'/3.17 56.76 32Li7 (~3o '2AE,g g4L3.10 S ~7'3.64Rr 6'78,97 57,73 321.48 6.00 2.~4.E g426.5~ S 2673.0e'~ 6fi4.44 5~,79 321.84 &.~ 26~.B ~30. I"/S 2773.(33V 699.4T $9.1~9 Y222.4 6.00 263.5 g{283g S zBIg.31W 69t.6B 6~A2 322A2 g.00 0.~3 263.$ g352.20 S 4048.2L~¥ 7M37 61.79 327.00 _C 28 ~95 BP EXPLORATION To:, Bixby/Farris PB C-1 K, Whil:e/C. Dixon Nabors 28E From: T, Burns BPX - HB 8-1 ARCO Alaska, In¢, A Date: December 4, 199S Subjec=: _S-2gA Pre-Rig Work $-29A is a potential multi-lateral horizontal sidetrack well targeting Zone 4 and Sag River reserves. Estimated lateral lengths are :1=~.,000' for bot~l zones. $-Z9A is currently shut-in due to Iow productivity and a high TGOR. Nabors -~eE should move on and spud the well on or near January 30, 1996. Contact the Coml3any Representa~ive o~ Nabobs ~BE at 659-4863 for the most a¢curate moving schedule update, PRE-RIg WORK SUMMARY (odor to MIRU Ns.bo. rs 28E_3 The objective of the P&A is to effectively squeeze and isolate the existing perforations from 12,g89'-13,17g' MD and cut the 4-1/?." tubing. Placement of al=13roximately ZO.0 bbl cement slurry should include a ~8 bbl sclueeze into perforations, leaving +I 2.0 bbl inside the 7" liner (:1=313') above the tot) perforation. Critical Well Information 4-1/2% 12.6#, L-80, TDS, Non-IPC Tubing I.D. -- 3,gs8" Capacity = 0,0152 bbl/ft SSSV Landing Nipple: ?.,091' MD XN-Nipple ($.7;~5" I.D.): 1Z,553' MD End of Tubing (WU[G): 12,565' MD 7", 26#, L-80, BTC Liner I.D. = 6.Z76" Capacity = 0.0383 bbVft PBTD (7"): 1~,310' MD Perforations:1Z,989'-13,179' MD Desired TOC: +12,676' ,MD The tubing has five Otis GU~'s (1-1/?." RA latch) as shown In the schematic. The 4-1/Z" t. ubing is secured to the production packer via a Baker tubing anchor at 1 2,474' MD. Maximum documented hole angle is $8' at +_7,g00' MD. Average hole inclination below '~3,$00' MD is greater than $0', Pr e_,_R ia Prooeelu£e _ 1, Notify an AOGCC representative prior to commencing plug-back ol3erations. Z. R~ and establish injection using seawater. Bulll~ead seawater down tubing to kill well. Mix and pump the following: 5 bbl fresh water, g0.O bbl (84.~ f1:3) Class G cement, 5 bbl fresh water, 151.9 bbl seawater, 30.$ bbl diesel (Calculate~l displacement of cement to reach top perforation = ~-~.07,4 bbl). Continue pumping (with diesel) and down squeeze :!=8 bbls cement into perforations from 12,989'- 13,179' MD leaving ~1 2.0 bbls (:I:313') cement above top perforation. Insure cement wash-u0 water is properly disposed. NOTE: If Injection cannot be established, a coil tubing unit will be requi~ed to compile the P&A, Circulate ZO.0 bbl (11 g.3 it3) above too perfor~ion (1 Z,989' MD), PU coil, clear tools and POOH. RU sJIckline unit and make dummy run (3.$~S" O.D.) to end of tubing to confirm clear. If required by oneite AOGCC rel~reaentative, procure tee, cement plug to I~SO0 lOCi. RIH and tag TOC e~.e~ble TOC i~ l l30',a~ove the te~ ~erf = · Nave AOQCC representative an location during te~Jng ~ tagging S-29A Pre-Rig Work Memorandum Page 212 . 1 1 . 1. 2. l 1 RU electric line unit. PJH and jet cut the 4-1/2" tubing at 1~,400' ~ID, NOTE: Due to possible clirecticnal plan scope change, recommend deep cut, RU and reverse circulate the weilbore through the tubing cut wi[h seawater until returns are clear, Freeze protect well with diesel to Z,O00'. Test 9-,~/8" pack off to 5,000 psi (rece~:is indicate 9-$/8" on mandrel hanger) and service lock down studs. Notify Rig Representative immediately of any pressure test or wellhead conclition problems. Bleed any pressure from the tubing, inner anti outer annuli to zero Install a BPV and test same to 1,000 psi against the cement plug. Remove the well house and flowlinas, NOTE', Pad Engineer notes that S-29 flowtines currently being utllizeci by S-38 well and may have to be relocated prior to mobilizing the drilling rig, Prel=are for the arrival of the rig. Level pad. Dig out cellar. Prgcedure MIRU Nabors ZS-E. Puli 4-1/2" tubing. Set an EZSV plug at 12,050' MD. Mill sectio~ in 9-5/8" casing from ±11,7~)5'- 11,545' MD. Set slde13'ack I<ick-off I~lug from 11 ,$95'-11,94S' UD (SSD recommended practices). Kick off (~11,800' HO) and directionally drill an 8-1/?." hole building angle to +88.6' in Zone 4. Set 7", L-80 liner at :~88.6'. Drill a .-I:Z,O00' horizontal leg (6' hole) in Zone 4 along a planned azimuth of Z?2:°. Contingency I~lans a[ this I~oint include setting packer, whi~tock and sidetracking out of the 7" liner and drilling a ±2,000' horizonta~ leg (6" hole) along a I~lanned azimuth of 272° in' the Sag River, NOTE; Dire;ional plan ha~ not been finali;ed, Completion operations entail 4-1/Z", L-80 slotted liner in both laterals. 3-1/2", L-80 tubing will be run with a permanent packer sat above tile Sag River. In adclition to the current well status reDorts normally provided to the' Rig Supervisor, pleaae suUmlt a complete coat breakclown for all charges to this AFE for pre-rig work. This should Include all service company charges, allocations, direct and indirect expenses. If you haVe any questions, please contact Tim Burns ~ (W) 564-4315 or (H) 345-9515. Thanks fo? your help, Prepared by:. _ Drilhng Engineer A~roved by: ~'1~/_ ~ ---sen{or I~!~ Enginair LINER NANI3ER "~ 2,B36~ NT-60S, NSCC J.~.I~J3J~,A~ON SUMMARY REF LDG:$WB- BHOa MAIN 9/17/90 INTERVAL OPEN/SQZ'D 12,98g- 13,020' OPENI12-24-g0 12,989 · 13.019' Reperf 12-28-.~4 15,030 - 13,140' OPEN/I 1.15.90 15,152.13,17'9' OPEN/Il-15.90 : PBTD ?", 26 #/ft, L-I~0, BTR~, I DATE g-P-.3-g0 ~.1.gl etl0/~ 1~:-26,Q4 REV. BY A, TEEL RK8 JDBII - II OOMMENT$ ml i II NEW COMPLETION REVISED ii i , REVISED -- i i PRE-FRAO PERF8 9/01' 12,054' 12,43B' 6853' 8312' 8553' 4 1/2' "BWS' NIPPLE (PARKER) (3,815' ID) BAKER TUBING ANCHOR I~ 5t8" PACKER (BAKER) (4,75' ID) 4 ~/2', 12.8 it/fi, L-BO TAILPIPE 4 1/2' "SWB" NIPPLE 4 1~' "XN" NIPPLE (OTIS)(3,725" ID) 4 1/2' WLEG / -' FISH: iBP rubDer lost NOTim: 3" FLOWLINE IN 8KID PORTIONS OF THI8 WELL'S FLOWLINE ARE :3" AND gU~IJEOT · ! {l l~l~ql~Wm~ mm NOTIFIED OF ANY WELL OPERATION WHtCH COULD INCREASE THE FLOW OR ERO$IOI~ ~A?~S, ,, , _ I I II . I PRUDHOE B~Y UNIT WEI,,L: S-2_9 (43-0a-11-_12) APl NO: $0-029-220_82 .SEC 35: T12N! RG12E _ BP EXPLORATION ! I. P~posed Jet Cut 12,400' MD 3 97O 1' 2 12,054.' 1 12,438' 6853' 8112' 8553' ! 4-1/2", 12,8#,% L-80, TDS 1 NON-,;'C TUBING TUE-ING ID: 3,988" , CAPACITY: 0,0152 BBLq='r' 1 i i KOP: 1545' MAX ANGLE; _ TOP OF LIND$EY t12~35' 1 LINER HANGER , --' . ropo=.cl TO-eL 12,676' MD ,~",-,,,~ . e/e', I!2'784' i--' NT-808, NSC, C , PERFORATION 8UMMARY REF LQO:SW$- BHC$ dAIN 9/17/90 · ~PFt_ IN~..ERV^L ' OP_E N/E~,,,Z'D 6 i 12,989 - 13,019' 4 J 13,~0 ' 13,140' 4 ~13.1~-1~1~' SQZ'D !-g6 $OZ'D 1-g6 SQZ'D 1.96 4 1/2" "9WS" NIPPLE (PARKER) (3.813" ID) BAKER TUBING ANCHOR g 618' PACKER (BAKER} (4.76" ID) f12,,47S't (PARKER) (3.e13' ID) 4 1/2 .... XN' NIPPLE 4 1/2" WLEG ~^~:.. JO,~T 112,678'I i Cement Squeezed to Perf'; PgTD 7', 26 #/ft, L-80, BTRS DATE _ 8-01,91 ..... I--' REV. BY II A. I'EEL ~<e" JDBII i · I.!3.31o'] COMMENTS ! REVISED __ REVISED I~RE-FRAC PERF8 -__ i PROPQBEO P&A .! F~H: IBP rubber i~t 3/24/~1 - _ NOTE: 3" ,FLOWLINE IN SKID PORTIONS OF THIS WELL'S I FLOWLINE'ARE 3" AND 9UBJECT TO EROSION, THE GC SHOULD BE NOTIFIED Ol:: ANY WELL OPERATION WHICH COULD INCREASE THE FLOW OR ERO$1OI~ .~TES, __ PRUDHOE BAY UNIT WEL~.: S-2~ APl_NO= ,~0-029-220{12 $12C_3~.' T12N,' RG12B BP EXPLORATION ._. CHECKLIST ~s~ON ..... 1. Permit fee attached ................... ~ N PROGRAM: exp [] dev FI, redrll~ serv [] wellbore seg [] REMARKS ENGINEERING 4. Well located in a defined pool ............. N ~/~. ,,, .~. ~Q/~ / ,,~ 5. Well located proper distance from drlg unit boundary.. N.~ ~ -' -- ~ ~ ......... / ' ' -' 6. Well located proper distance from other wells ..... 7. Suffteiont a~reage available tn drillin~ unit ..... 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party ............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... ~ N 12. Pe~it can be issued without administrative approval..~ N 13. Can pe~it be approved before 15-day wait ....... N APPR DATE GEOLOGY 14. Conductor string provided ................ y Nt ~~ '~ 15. Surface casing protects all known USDWs ......... y N ~ 16. CMT vol adequate to circulate on conductor & surf csg.. Y N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 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. ~ N 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... .-T---N- ~R 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to .~OOC~ psig. Y N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/_ 31. Data presented on potential overpressure zones ..... Y~ 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ /y N 34. Contact name/phone for weekly progress reports .... ~/. Y N [explorator~ only] GEOLOGY: ENGIB,:,:aING: COMMISSION: Comments/Instructions: m HOW/Ijb - A:tFORMS~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. .pe Subfi!e 2 is .type: LIS TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 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 MWD RUN 2 AK-MM- 960104 R. JACKSON K. WHITE S-29A ff~- O~ 500292208201 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 03 -FEB-97 MWD RUN 3 ERIC CRIBBS KIRK WHITE 35 12N 12E I~D RUN 4 ERIC CRIBBS KIRK WHITE 3638 3719 68.17 66.67 33.37 OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 7.000 13115.0 6.000 15062.0 Mk~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~SHIFTING WAS APPLIED, PER STk ~ JONES OF BP EXPLOI~TION (02-DEC-96). FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMA~RY PBU TOOL CODE GR RP $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH 12075.0 12437.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 15016.0 15023.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 12132.0 13115.0 3 13115.0 13924.0 4 13924.0 15062.0 MERGED MAIN PASS. CN WN FN COLIN STAT : BP EXPLORATION (ALASKA) : S-29A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OFIMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 90 640 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 193 Tape File Start Depth = ~15062.000000 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 47801 datums Tape Subfile: 2 290 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: CN WN FN COUN STAT START DEPTH 13101.0 13108.0 STOP DEPTH 15016.0 15023.0 MAD RUN NO. MAD PASS NO. MERGE TOP 4 1 13144.0 4 2 13908.0 MERGE BASE 13908.0 15062.0 MERGED MAD PASSES. $ : BP EXPLORATION (ALASKA) : S-29A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAD 68 1 AAPI 4 2 RPX MAD 68 1 OHMM 4 3 RPS MAD 68 1 OHMM 4 4 RPM MAD 68 1 OHMM 4 5 RPD MAD 68 1 OHMM 4 6 FET MAD 68 1 HR 4 7 RATE MAD 68 1 FPHR 4 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 127 Tape File Start Depth = 15062.000000 Tape File End Depth = 13100.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 31401 datums Tape Subfile: 3 152 records... Minimum record length: 62 bytes Maximum record length: 998 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12075.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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 13058.0 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 TEMPEP~ATURE (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 2. 28-JAN-96 MSC 1.32 / ISC 2.11 DEP 2.041 / SP4 5.01 MEMORY 13115.0 12132.0 13115.0 0 24.0 82.5 TOOL NUMBER NGP 66 8.500 11700.0 LSND 9.80 45.0 8.9 400 4.8 .000 .000 .000 .000 .0 147.0 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : S-29A : 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 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 54105 datums Tape Subfile: 4 89 records... Minimum record length: 18 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12430.0 EWR4 12437.0 $ 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 13868.0 13875.0 03-FEB-96 MSC 1.32 / ISC 2.11 DEP 2.041 / SP4 5.01 MEMORY 13924.0 13115.0 13924.0 0 85.0 90.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0388SP4 P0388SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 6.000 13115.0 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: MI/D CAKE AT MT: FLO PRO/SEAWATER 8.50 42.0 8.4 22000 11.8 .320 60.0 .110 161.0 .250 60.0 .410 60.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 3. $ : BP EXPLORATION (ALASKA) : S-29A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 90 220 09 1 4 90 995 99 1 4 90 220 10 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 104 Tape File Start Depth = 14000.000000 Tape File End Depth = 12400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 57010 datums Tape Subfile: 5 169 records... Minimum record length: 62 bytes Maximum record length: 998 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: 4 DEPTH iNCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13862.0 EWR4 13869.0 $ 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) MINIM UMANGLE: MAXIMUM ANGLE: STOP DEPTH 15016.0 15023.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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) : 05-FEB-96 MSC 1.32 / ISC 2.11 DEP 2.041 / SP4 5.01 MEMORY 15062.0 13924.0 15062.0 0 86.6 91.2 TOOL NUMBER P0388SP4 P0388SP4 6.000 13115.0 XANVI S / SEAWATER 8.60 43.0 8.9 23000 9.2 .300 60.0 .120 162.0 .240 60.0 .390 60.0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : S-29A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod t GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 90 220 09 1 4 90 995 99 1 4 90 220 10 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 79 Tape File Start Depth = 15062.000000 Tape File End Depth = 13850.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 73506 datums Tape Subfile: 6 144 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 4 I~j~D PASS IVuI~BER: i DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13101.0 EWR4 13108.0 $ 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 13862.0 13869.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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: Fu~TRIX DENSITY: HOLE CORRECTION (IN): 05-FEB-96 MSC 1.32 / ISC 2.11 DEP 2.041 / SP4 5.01 MEMORY 13924.0 13101.0 13908.0 0 85.0 90.9 TOOL NUMBER P0388SP4 P0388SP4 6.000 13115.0 XANVIS/SEAWATER 8.60 43.0 8.9 23000 9.2 .300 60.0 .120 162.0 .240 60.0 .390 60.0 .00 .000 TOOL STANDOFF (IN) : .0 EWR FREQUENCY (HZ): REMARKS: CN WN FN COUN STAT MAD PASS LOGGED WHILE TRIPPING IN THE HOLE FOR MWD RUN 4. $ : BP EXPLORATION (ALASKA) : S-29A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAD 68 1 AAPI 4 2 RPX MAD 68 1 OHMM 4 3 RPS MAD 68 1 OHMM 4 4 RPM MAD 68 1 OHMM 4 5 RPD MAD 68 1 OHMM 4 6 FET MAD 68 1 HR 4 7 SRAT MAD 68 1 FPHR 4 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 54 Tape File Start Depth = 13925.000000 Tape File End Depth = 13100.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 70219 datums Tape Subfile: 7 121 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 8 is type~ LIS FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: M_AD PASS N~BER: DEPTH INCREMENT: FILE SUMMARY 4 2 .5000 VENDOR TOOL CODE START DEPTH GR 13857.0 EWR4 13864.0 $ 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: MAXIM UMANGLE: STOP DEPTH 15016.0 15023.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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: MOLE CORRECTION (IN): 05-FEB-96 MSC 1.32 / ISC 2.11 DEP 2.041 / SP4 5.01 MEMORY 15062.0 13857.0 15062.0 0 86.6 91.2 TOOL NLTMBER P0388SP4 P0388SP4 6.000 13115.0 XANVI S /SEAWATER 8.60 43.0 8.9 23000 9.2 .300 60.0 .120 162.0 .240 60.0 .390 60.0 .00 .000 TOOL STANDOFF (IN) : .0 EWR FREQUENCY (StZ) : ~ REMARKS: CN WN FN COUN STAT MAD PASS LOGGED WHILE TRIPPING OUT OF THE HOLE AFTER MWD RUN 4. $ : BP EXPLORATION (ALASKA) : S-29A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAD 68 1 AAPI 4 2 RPX MAD 68 1 OHMM 4 3 RPS MAD 68 1 OHMM 4 4 RPM MAD 68 1 OHMM 4 5 RPD MAD 68 1 OHMM 4 6 FET -MAD 68 1 HR 4 7 SRAT MAD 68 1 FPHR 4 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 82 Tape File Start Depth = 15062.000000 Tape File End Depth = 13800.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 93707 datums Tape Subfile: 8 149 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 9 is type:'' LIS 9?/ 2/ 3 01 **** REEL TRAILER **** 97/ 2/ 3 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 3 FEB 97 10:03a Elapsed execution time = 3.68 seconds. SYSTEM RETURN CODE = 0
