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182-151
Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 01/12/2023 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 4Q 2022. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through the end of 4Q 2022. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Engineer Hilcorp North Slope, LLC By Samantha Carlisle at 3:53 pm, Jan 12, 2023 Digitally signed by Oliver Sternicki (4525) DN: cn=Oliver Sternicki (4525), ou=Users Date: 2023.01.12 14:52:49 -09'00' Oliver Sternicki (4525) • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, October 03, 2015 7:53 AM To: AK, OPS GC3 Facility OIL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM; AK, OPS GC3 Field OTL; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers;AK, OPS Well Pad AB; 'chris.wallace@alaska.gov'; Glasheen, Brian P Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Regg, James B (DOA); Boman, Wade Subject: OPERABLE: Producer B-25 (PTD #1821510) TIFL Passed All, Producer B-25 (PTD#1821510) became available to place on production for diagnostics prior to the scheduled gas lift valve wellwork. A passing warm TIFL was performed on October 02, 2015, confirming two competent barriers in the wellbore. No further intervention is required. This well is reclassified as Operable. Plan forward: 1. Downhole Diagnostics: Cold TIFL—FAILED 09/25/15 2. Downhole Diagnostics: Warm TIFL—PASSED 10/02/15 3. Operations: Place well on production Please call with any questions or concerns. Thanks, Whitney Pettus %AIMED AUG 0 4 2016 (Alternate: Kevin Parrs) BP Alaska-Well Integrity Coordinator G` WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From D&Cdell Integrity Coordinator Sent: Satur a , ptember 26, 2015 1:07 PM To: AK, OPS GC3 Facility OT ; GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; AK, OPS GC3 Field OTL; Cismoski, Doug A; Daniel, Ryan ACD&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt r; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; Boman, Wade; 'chris.wallace@alaska.gov' -.. Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) (jim.regg@alaska.gov) Subject: UNDER EVALUATION: Producer B-25 (PTD #1821510) Sustained Inner Annulus Casing Pressure Above MOASP All, 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, September 26, 2015 1:07 PM To: AK, OPS GC3 Facility OIL; AK, OPS GC3 Operators; AK, OPS GC3 Wel!pad Lead; AK, OPS GC3&PCC OSM;AK, OPS GC3 Field OIL; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers; Boman, Wade;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: UNDER EVALUATION: Producer B-25 (PTD#1821510) Sustained Inner Annulus Casing Pressure Above MOASP Attachments: Producer B-25 (PTD #1821510) TIO Plot.docx All, Producer B-25 (PTD#1821510) was reported to have sustained inner annulus casing pressure above MOASP on September 23, 2015 after the well was shut in. The pressures were tubing/inner annulus/outer annulus of 2130/2140/0 psi. A cold TIFL failed on September 25, 2015. The failing TIFL indicates a lack of two competent downhole barriers. The well is reclassified as Under Evaluation and is placed on a 28 day clock. Plan forward: 1. Slickline: Dummy gas lift valves 2. Fullbore: MIT-IA 3. Well Integrity Engineer: Additional diagnostics as needed A copy of the TIO plot is included for reference. Thank you, Kevin Parks SCANNED AUG 1 7 2016 (Alternate: Whitney BP Alaska-Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com 1 • • Producer B-25(PTD#1821510)TIO Plot M M tee xx,: IMES 67.1011. *MSS N.16 W.OW m»S MINS mins onr. am! rr3 Men. mx75 ___ OPERABLE: Producer B -25 (PTD #16510) Verified tubing integrity - PassiriiIFL Page 1 $f'2' Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] T 4 Sent: Tuesday, February 01, 2011 4:23 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers Cc: Walker, Greg (D &C); Winslow, Jack L (ASRC); Derrick, Laurie R; AK, D &C Well Integrity Coordinator Subject: OPERABLE: Producer B -25 (PTD #1821510) Verified tubing integrity - Passing TIFL All, Producer B -25 (PTD #1821510) passed a TIFL on 1/31/11 after it was reported to have sustained casing pressure on the IA. The passing test ve•fies tubing integrity. The well has been reclassified as Operable and may continue on production. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 F�B 7011 WANNED Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 in From: AK, D &C Well Integrity Coordinator Sent: Sunday, January 23, 2011 5:56 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C WT -line Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; D- rick, Laurie R Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Winslo Jack L (ASRC) Subject: UNDER EVALUATION: Producer B -25 (PTD #1821510) •stained IA and OA Pressure Above MOASP All, Producer B -25 (PTD #1821510) has been found to ' ave sustained casing pressure on the IA and OA. The wellhead pressures were tubing /IA/OA equa o 190/2040/1000 psi on 01/21/11. The well has been reclassified as Under Evaluation and may be • oduced under a 28 -day clock. The plan forward is as follows: 1. DHD: Arctic pack flush on OA su ace valves 2. DHD: TIFL 3. WIE: Pending results TIFL, develop plan for testing IA if further evaluation is required 4. DHD: OA repre rization test (OART) 2/1/2011 OPERABLE: B -25 (PTD #1821510) Ting Integrity Restored • Page 1 orr Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] P I/ I It Sent: Saturday, January 01, 2011 10:59 AM 1 1 To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Derrick, Laurie R; AK, OPS Prod Controllers Cc: Janowski, Carrie Subject: OPERABLE: B -25 (PTD #1821510) Tubing Integrity Restored All, Producer B -25 (PTD #1821510) passed a TIFL on 12/31/2010 after returning the well to production confirming the gas lift valve checks have seated and the well has tubing integrity. The well has been reclassified as Operable. Please call if you have questions or concerns. Thank you, �; JAN a. 8 2O Mehreen Vazir (for the Well Integrity Coordinator Torin Roschinger /Gerald Murphy) BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @bp.com From: AK, D &C Well Integrity Coordinator Sent: Friday, December 10, 2010 5:25 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; Schwartz, Guy L (DOA)'; AK, OPS GC3 Facili. & Field OTL; AK, OPS GC3 Wellpad Lead; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Leas, Cismoski, Doug A; Engel, Harry R; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Derrick, Laurie R; AK, OPS P •d Controllers Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Quy, Tiffany Subject: UNDER EVALUATION: B -25 (PTD #1821510) Sustained IA Casing Pr: ure Above MOASP All, Producer B -25 (PTD #1821510) has confirmed s = ained casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 2270/22.0/0 on 12/09/2010. The well has been reclassified as Under Evaluation. The plan forward: 1. DHD: TIFL 2. Slickline: Set tubing tail plug • TIFL fails) 3. Fullbore: MIT -T, CMIT -T (if TIFL fails) A TIO plot and wellbor- schematic are included for reference. « File: Producer B -25 (PTD #1821510) TIO Plot.doc » 1/4/2011 UNDER EVALUAT B-25 87}5lN Sustained lA Casing Press MOASP Pa�lofl �� e��g,Ja��es �� (D����) -- t From: AK D&���U|n�ghbCoo�ina�rk��D�N�U|nb�h��oo�ina�n0bpcoml . ' ^ ~. � ^ Sent: Friday, December 1O.201O5:25PyW To: Maunder Thomas E PS [;C3 Facility & Field u|L; *K. OPb GC3 VVo||poU Lead; AK, D&C VWpe|ine Operations Team Lead; AK, O&C Well Services [}penoUonm Team Lead; Cionnoaki, Doug A; Engel Ha R; /\K. RES GPB West Wells {]pt Engr; AK, RE8 GPB East Wells [)pt Engr; Derriok, Laurie R; AK. (]PS Prod Controllers Cc: AK. O&CVVeU Integrity Coordinator; King. Whitney; Quy, Tiffany Subject: UNDER EVALUATION: B-25(PTD#1821510) Sustained |A Casing Pressure Above K8OASP Attachments: Producer B-25 (PTO#182151O) T|D P|oLdoo; Producer B'-25 (PTD#183151O) vvaUbono schematic. pdf AU. � Producer B-25 (PTD#1821510) has confirmed sustained casing pressure above K8OASP. Thevve||head pressures were tubing/|AJOAequal to 2270/2260/0 on 12/09/2010. The well has been reclassified as Under Evaluation. -----' The plan forward: 1. OHD:T|FL 2. S|ick|ine: Set tubing tail plug (ifT|FL hyi|n) ~'—~ --- 3. FuUbore: yW|T'T. CK8|T'Tx|A (if TlFLfails) ATIO plot and weUbore schematic are included for reference. <<Produoer B-25 (PTO #182151O) T|O P|oLdoo>> <<Pnoduoar B-25 (PTO #1021510)vveUbore ouhamnado.pdf>> Please call if you have questions orconcerns. Thank you, Ge»aldMurp@m (o|LTorinRoochingeh Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752'0755 Pager (907) 859-5100 Ext. 1154 l7/]]/?0l0 PBU B -25 PTD #1821510 12/10/2010 TIO Pressures Plot Well: 8 -25 4,000 ;.000 T Tbg —M - IA 2,000 - OA OOA OOOA On i i 1,000 i 09/11110 09/18/10 09125/10 10!02110 10!09 /10 10116/10 10/23/10 10130110 11/06!10 11/13110 11/20110 11127110 12/04/10 _ . ._.__._. - _ • TREE = C1W WE L LHEAD = MCEVOY � " WES WELLHEAD BUILT OFF 9-518" CSG ACTUATOR= BAKER C B -25 !�F4 1 12- OM E TBG & NIPPLES KB. R EV = 80.19 BF. ELEV = 44.69' KOP= 2000' Max Angle = 38* @ 6600' J77i�-4 HES ES CEMENTER Datum MID = 10050 F95/8" BOWEN 2065' Datum TV D= 8800' SS JCSG PATCH 9-5/8" CSG, 47#, L-80 HY D 563, ID = 8.681 2065' 221 7' 4 -1/2" HES X NIP, ID = 3.813 GAS LIFT MANDRELS 13-3/8" CSG, 72#, L-80, ID= 12.347" 2748' ST I MID I TVD DEV TYPE I VLV LATCH PORT DATE 7" LNR, 26#, L-80 TCII XO T� �-80 BTC-M 2970' 5 3409 3239 35 KBG-2 DOME BK 12 04/14/10 4 5829 5256 35 KBG-2 DOME BK 12 04/14/10 3 7073 6254 36 KBG-2 DOME BK 16 04/14/10 2 8269 7264 27 KBG-2 DOME BK 16 04/14/10 1 9304 8200 26 KBG-2 SO BK 24 1 04/14/101 Minimum ID = 3.725" @ 9604' 4-1/2" HES XN NIPPLE F -- 9 - 46 - T ---- 4-1/2" HES X NIP, ID = 3.813" 9498' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" —4 - — HES X NIP, ID = 3.813 17" LNR, 26#, L-80 BTC-M, .0383 bpf, ID = 6.276" 9584* 9584' 7 TIEBACK STEM - 1 — F 9584 --[9-5/8 GR, ID = 6.276"? 1 TOP OF 7" LNR 9584' — - 1 4-1/2" TBG, 12.6#, 13CR-80, 9616' F4- XN NIP, ID = 3.725 .0152 bpf, ID = 3.958" 9616 4 -112" WLEG, ID = 3.958 9-5/8" CSG, 47#, L-80, ID = 8.681 — -1 F — ]4ELMD TT — LOGGED 05/30/91 PERFORATION SUMMARY 9942' 1-47" MARKER JOINT REF LOG: DA-BHCA ON 10/31/82 ANGLE AT TOP PERF: 24' @ 9862' Note: Refer to Production DB for historical perf data 10023' -ASA NDBA CK FOR FRA C SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9861-9881 S 11/23/90 10095 -fT x 4-1/2" 6TIS'WU PKR, ID = 4.0" 3-3/8" 4 9862-9882 0 05/25/94 3-1/8" 4 9918-10018 S 11/23/90 — F - 1 - 0 - 10 — Y - 1+47 - 2 -- OTIS X NIP. ID = 3.813 3-1/8" 4 9970-9980 S 05/17/91 3-1/8' 4 9990-10020 S 05/17/91 F--1-07170 3-3/8' 4 9990-10020 0 05/30/91 787] 4-1/2" OTIS XN NIP, ID = 3.725" 3-1/8' 4 10030 - 10088 S 05/17/91 3-3/8' 4 10030 - 10088 0 06/11/92 10110' —14-1 3-1/8' 4 10120 - 10130 S 05117/91 F 10110' - ELM TT - LOGGED 05/30/91 4-1/2" TBG, 12.6#, L-80_0152 bpf, ID = 3.958" 10110 -F FISH - JUNK BASKET, TAPERED MILL, CEMENTED IN HOLE F 10150' 10650' E DRILL PLUG 7" LNR, 26#, L-80_0383 bpf, ID = 6,276" 4 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/05/82 AUDI ORIGINAL COMPLETION WELL: B-25 05/18/91 D16 RWO PERMIT No: 1 821510 03129/09 D16 RWO AR No: 50-029-20826-00 05/05/09 FR/JMD DRLG DRAFT CORRECTIONS SEC. 31,T11N, R14E, 1114'& 1899'FEL CJNSV GLV C/O (04/1411 BP Exploration (Alaska) BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 11, 2009 c~"~~~`~ ~l~:l~! ~ ~ Z~ tiC r~ ~- ~' r~~ i~ ~ C~l~~' Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Pad B Dear Mr. Maunder, ~-I~?I~~% >.E ha'~ .'~ mitl~. t~friiT'118S10i1 ~ga~ ~s~ ~- as Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad B that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Repoli of Sundry Operations (10-404) Date: 12/11/09 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al B-01 1700080 50029200590000 Sealed Conductor NA NA NA NA NA B-02 1961110 50029200660100 Sealed Conductor NA NA NA NA NA B-03A 1870480 50029203060100 NA 0.5 NA 3.40 8/20/2009 B-04 1700320 50029200720000 Sealed Conductor NA NA NA NA NA B-058 2010680 50029202760200 NA 1.8 NA 13.60 8/22/2009 B-O6 1770740 50029202790000 NA 1 NA 5.10 8/20/2009 B-07 1780020 50029202850000 NA 1 NA 5.10 8/20/2009 B-08 1780410 50029203140000 NA 1 NA 6.80 8/20/2009 B-09 1780490 50029203160000 NA 0.5 NA 3.40 8/20/2009 B-10A 2082050 50029203210100 Cellar liner welded to casin NA NA NA NA NA B-11 1780690 50029203310000 NA 0.5 NA 3.40 8/20/2009 B-12 1970090 50029203320100 NA 0.6 NA 3.40 8/22/2009 B-13 1990570 50029203410100 NA 0.4 NA 1.70 8/20/2009 B-14 2090590 50029203490000 NA 0.4 NA 1.70 8/20/2009 B-15 1790190 50029203600000 NA 0.1 NA 1.70 8/20/2009 6-16 1790250 50029203650000 NA 0.8 NA 5.10 8/21/2009 B-17 1790280 50029203680000 NA 0.1 NA 1.70 8/20/2009 B-18 1820020 50029207020000 NA 1.5 NA 15.30 8/21/2009 6-19 2001610 50029207030100 NA 0.1 NA 1.70 8/21/2009 B-20 1821680 50029208420000 NA 0.5 NA 3.40 8/21/2009 B-21 1821760 50029208500000 25 4.5 BBLs 0.1 11/30/2009 1.70 12/3/2009 B-22A 2001570 50029207590100 34 6.5 BBLs 0.2 11/30/2009 1.70 12/3/2009 B-23 1970590 50029207790100 12 2.2 BBLs 3.2 11/30/2009 10.20 12/4/2009 B-24 1821400 50029208150000 NA 3 NA 22.10 8/21/2009 B-25 1821510 50029208260000 NA 0.25 NA 1.70 8/13/2009 B-26 2000570 50029209760200 NA 0.3 NA 1.70 8/21/2009 B-27 1961010 50029214710100 Sealed Conductor NA NA NA NA NA B-28 1853030 50029215100000 NA 1.1 NA 6.80 8/22/2009 B-29 2002090 50029215230100 NA 0.7 NA 6.80 8/21/2009 B-30 2011050 50029215420100 NA 0.2 NA 1.70 8/21/2009 B-31 1910460 50029221520000 NA 0.3 NA 1.70. 8/20/2009 B-32 1991180 50029221650100 NA 0.3 NA 1.70 8/20/2009 B-33 1931450 50029223390100 NA 1.2 NA 8.50 8/21/2009 B-34 1930370 50029223520000 NA 1.2 NA 10.20 8/21/2009 B-35 1931460 50029224060000 NA 0.3 NA 1.70 8/20/2009 B-36 1960650 50029226670000 NA 0.3 NA 1.70 8/21/2009 B-37 2071450 50029233750000 Sealed Conductor NA NA NA NA NA STATE OF ALASKA ~" ,Y ~~®•~'~~ ALA OIL AND GAS CONSERVATION CO~SION ~~ ~ ~ ..,, .,~ ~ ~ ~~ ~~~ REPORT OF SUNDRY WELL OPERATIONS ~iaska Oil & Ua~ i>~x~. l;dmmissior 1. Operations Performed: AFlC#10~8Q@ ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing - ®Pull Tubing _ ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. -® Development ^ Exploratory 182-151 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20826-00-00 7. KB Elevation (ft): 80 2' - 9. Well Name and Number: PBU B-25 - 8. Property Designation: 10. Field /Pool(s): , ADL 028310 - Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 10706' ~ feet true vertical 9500' - feet Plugs (measured) 10023' Effective depth: measured 10150' feet Junk (measured) Yes, Below Cmt true vertical 8973' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2748' 13-3/8" 2748' 2692' 4930 2670 Intermediate 9837' 9-5/8" 9837' 8684' 6870 4760 Production Liner 1118' 7" 9583' - 10700' 8452' -9494' 7240 5410 Tieback Liner 9589' 7" 9589' 8458' 7240 5410 ~~5~`~~4~ ~~~~~ ~ 2d~ Perforation Depth MD (ft): 9862' - 10088' Perforation Depth TVD (ft): 8707' - 8916' 4-1 /2", 12.6# 13C r80 9616' ~s~ ooss' - ~ o» o'> Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker S-3 Packer 9498 ; 7" x 4-1/2" Otic'WD' Packer 10095' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 9480'. Cut and pull 9-5/8" casing from 2061'. Run 9-5/8" (47#, L-80) tieback to surtace. Cement w/ 140 bbls 'G', (yield 1.17). Run new 7", 26#, L -80 tieback casing to surtace. Cementw/80 bbls'G' w/Gas Block, (yield 1.17) and 175 bbls'G' (yield 1.16). Clean out and run new Chrome tubing. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 110 180 Subsequent to operation: 569 8599 1806 1060 250 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Welt Status after work: ® Well Schematic Diagram ®~Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ 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 Frank Roach, 564-4373 309-046 Printed Name Sondra S roman Title Drilling Technologist I ~' Prepared By Name/Numt~er: Sign ure Phone 564-4750 Date lJ ~ -~ 7" Sondra Stewman 564-4750 Form 10-404 Revised p4J2Q06 ; ~ ~~"~ ~ ~ y Submit Ori final Only ..~, t ~ TREE = 4" CM/ WELLHEAD= MCEVOY ACTUATOR= OTIS KB. ELEV - 80.19' BF. ELEV - 44.69' KOP = 2000' Max Angle = 38 @ 6600' Datum MD = 10050' Datum TV D= 8800'SS B-25 SAF~NOTES: ***4-1/2"CHROMETBG*** W D BUILT OFF OF 9-5/8" CASING 9-5/8" CSG, 47#, L-80, ID = 8.681" 13-3/8" CSG, 72#, L-80, ID = 12.347" 2065' 2748' 2217' -~ 4-1 /2" HES X NIP, ID = 3.813" FOC GAS LIFT MANDRELS Minimum ID = 3.725" @ 9603.53 4-1 /2" HALLIBURTON XN NIP 4-1/2" TBG, 12.6#, 13CR, .0152 bpf, ID = 3.958" ~-) 9616, 7" TIEBACK, 26#, L-80, .0383 bpf, ID = 6.278" 9584' TOP OF 7" LNR 9583' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9837 PERFORATION SUMMARY REF LOG: DA-BHCA ON 10/31/82 ANGLE AT TOP PERF: 24 @ 9862' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9861 - 9881 S 11/23/90 3-3/8" 4 9862 - 9882 C 05/25/94 3-1/8" 4 9918 - 10018 S 11/23/90 3-1/8" 4 9970 - 9980 S 05/17/91 3-118" 4 9990 - 10020 S 05/17/91 3-3/8" 4 9990 - 10020 C 05/30/91 3-1/8" 4 10030 - 10088 S 05/17/91 3-3/8" 4 10030 - 10088 C 06/11/92 3-1/8" 4 10120 - 10130 S 05/17/91 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 10110' PBTD 10150' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 10700' ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3409 3239 35 KGB-2 DOM BK 16 04/03/09 4 5829 5256 35 KGB-2 SO BK 20 04/03/09 3 7073 6254 36 KGB-2 DMY BK 0 03/28/09 2 8269 7264 27 KGB-2 DMY BK 0 03/28/09 1 9304 8200 26 KGB-2 DMY BK 0 03/28/09 9467' -~4-1/2" HES X NIP, ID = 3.813" 9498' 7" x 4-1/2" BAKER S-3 PKR, ID = 3.875" 9531' 4-1/2" HES X NIP, ID = 3.813" 9604' 4-1/2" HES XN NIP, ID = 3.725" 9616' 4-1/2" WLEG 9596' ELMD TT -LOGGED 05/30/91 9951' ~RKER JOINT 10023' -~SANDBACKFORFRAC~ 10095' 7" x 4-1/2" OTIS'WD' PKR, ID = 4.0" 10103' 4-1/2" OTIS X NIP, ID = 3.813" 10108' 4-1/2" OTIS XN NIP, ID = 3.725" 10110' 4-1/2" TTL WLEG 10110' ELM TT -LOGGED 05/30/91 10139' FISH -JUNK BASKET, TAPERED MILL, CEMENTED IN HOLE 10650' - EZ DRILL PLUG DATE REV BY COMMENTS DATE REV BY COMMENTS 11/05/82 ORIGINAL COMPLETION 05/18!01 RWO 03/29/09 N2ES RWO 04/05/09 DAV/SV GLV C/O PRUDHOE BAY UNff WELL: B-25 PERMfT No: 1821510 API No: 50-029-20826-00 Sec. 31, T11N, R14E BP Exploration (Alaska) BP EXPLORATION Page 1 of 17 Operations Summary Report Legal Well Name: B-25 Common Well Name: B-25 Spud Date: 10/14/1982 Event Name: WORKOVER Start: 2/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/29/2009 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT ~ Phase Description of Operations ',3/2/2009 12:00 - 00:00 12.00 MOB P PRE Blow water and steam down, disconnect interconnect to the pits, move cuttings tank, shop, camp, and sub off of B-10A and i to B-25. Spot the rig, pits, camp, and shop. Rig still not accepted. 3/3/2009 00:00 - 06:00 6.00 RIGU P PRE Move onto B-25 and rig up. 06:00 - 06:30 0.50 WHSUR P DECOMP Ri acce ted at 06:00 to begin work on B-25 RWO. 06:30 - 08:00 1.50 WHSUR P DECOMP Remove the snow from the cellar box and remove the 2nd annulus valves on tubing spool. OA, IA and tree have 0 psi. 08:00 - 09:30 1.50 WHSUR P DECOMP Rig up DSM and test the lubricator to 500 psi. Good Test. Pull ~t a and ng down DSM. 09:30 - 11:30 2.00 WHSUR P DECOMP Rig up to reverse circulate out the diesel freeze protect. 11:30 - 12:00 0.50 WHSUR P DECOMP Pre-spud meeting with Toby Bordelon's crew. 12:00 - 14:30 2.50 KILL P DECOMP Reverse circulate out 30 bbls of diesel from the tubing. -4 bpm ~ 450 psi. Switch hose and reverse circulate out diesel from OA. Verify clean from the mud engineer. Verify the well is dead. 14:30 - 16:00 1.50 KILL P DECOMP t 00 i fo minutes. Good Test. Then test the TWC from below to 1000 psi for 10 minutes. Good Test. 16:00 - 17:00 1.00 KILL P DECOMP Rig down the circulating lines and hold a PJSM to nipple down the tree. 17:00 - 19:30 2.50 BOPSU P DECOMP Nipple down the tree and verify the threads on the tubing hanger. Good. Function all LDS and prepare to nipple up the BOP stack. 19:30 - 21:30 2.00 BOPSU P DECOMP Nipple up the BOP stack, install the mousehole, turnbuckles, and riser. 21:30 - 22:30 1.00 BOPSU P DECOMP Make u TIW and dart valves to 4" test 'oint. Fill the stack and perform a body test to 250psi low / 3500psi high. Good Test. 22:30 - 00:00 1.50 BOPSU P DECOMP Witness of BOP Test waived by AOGCC rep. Jeff Jones. Test witnessed by BP WSL Chris Kobuck and NAD Tourpusher Ken Helf. -Tested the choke manifold to 250 psi low / 3500 psi high. Good Tests. All tests charted for 5 minutes low and 5 minutes high. 3/4/2009 00:00 - 03:30 3.50 BOPSU P DECOMP Continue to test BOPE. Tested the Hydril to 250 psi low / 2500 psi high with 4" test joint. Good Test. Tested the Upper Rams with 4" and 4.5" test joint to 250 psi low / 3500 psi high. Good Test. Performed a Accumulator test. Good Test. Tested the IBOP, Dart valve, and TIW valve to 250 psi low / 3500 psi high. Good Tests. All test performed were charted for 5 minutes low and 5 minutes high. 03:30 - 05:30 2.00 BOPSU P DECOMP Ri u DSM and test the lubricator to 500 si. Good Test. Pull the TWC and ri down DSM. 05:30 - 06:30 1.00 PULL P DECOMP Screw into the tubing hanger and loosen the lock down screws. P n r to the loor with 1 5k. No issues at all. 06:30 - 07:30 1.00 PULL P DECOMP Circulate a bottoms up at 450 gpm and 500psi. 07:30 - 08:30 1.00 PULL P DECOMP Lay down the tubing hanger, change out the elevators, and rig up the control line spooling unit. 08:30 - 10:00 1.50 PULL N RREP DECOMP Adjust the Koomey Pumps, start and stop was out of adjustment. 10:00 - 14:00 4.00 PULL P DECOMP Pulled 4.5" completion out of the hole from 9492' to SSSV at 7505'. Recovered: Printed: 4/73/2009 2:50:03 PM BP' EXPLORATION Operations Summary Report Legal Well Name: B-25 Common Well Name: B-25 ;Event Name: WORKOVER ~~Contractor Name: NABOBS ALASKA DRILLING I 'I Rig Name: NABOBS 2ES Date From - To Hours Task !Code NPT -- 3/4/2009 10:00 - 14:00 l 4.00 PULL P 14:00 - 14:30 0.50 PULL P 14:30 - 15:00 0.50 PULL P 15:00 - 21:30 6.50 PULL P 21:30 - 22:00 0.50 PULL P 22:00 - 22:30 I 0.501 CASE I P 22:30 - 23:00 I 0.501 BOPSUFI P 23:00 - 00:00 I 1.001 BOPSUFi P 3/5/2009 ~ 00:00 - 01:00 1.00 ~ BOPSUFj P 01:00 - 01:30 0.50 CLEAN P 01:30 - 03:30 2.00 CLEAN P 03:30 - 12:00 I 8.501 CLEAN I P 12:00 - 14:00 I 2.001 CLEAN I P 14:00 - 15:00 1.00 CLEAN N 15:00 - 16:00 1.00 CLEAN P 16:00 - 17:00 1.00 CLEAN N 17:00 - 20:30 3.50 CLEAN P 20:30 - 22:00 1.50 CLEAN P 22:00 - 00:00 2.00 EVAL P 3/6/2009 00:00 - 05:00 5.00 EVAL P 05:00 - 09:30 I 4.501 EVAL I P Start: 2/25/2009 Rig Release: 3/29/2009 Rig Number: Page 2 of 17 Spud Date: 10/14/1982 End: Phase Description of Operations DECOMP -1 SSV -51 Jts. Tubing -26 Clamps -4 SSB's Up Wt. 120k /Down Wt. 110k DECOMP Rig down the control liner spooler. DECOMP Slug the pipe and blowdown the top drive. DECOMP Continued out of the hole iwth 4.5" com letion from 7505' to surface. -Total Completion Recovered. -1 SSV -242 Full Jts. Tubing -5 GLM's -26 Clamps -4 SSB's -1 Cut Jt. which was 1.7' long DECOMP Rig down casing equipment and prepare to pressure test the 9 5/8" casing. DECOMP Pressure test 9 5/8" casing to 3000 psi for 30 minutes. Lost 90 psi in 1st 15 minutes and 30 in 2nd 15 minutes. Good Test DECOMP Pick up 4" test jt. and make up to TIW valve. Prepare rig floor for testing the bottom rams. DECOMP Pressure test the bottom rams to 250 psi low and 3500 psi high. Witness waived by AOGCC rep. Jeff Jones. Leaking by the rams, open rams and function and reattempt test. DECOMP Continue to test the bottom pipe rams to 250 psi low / 3500 psi high with a 4" test jt. Good test. Pulled test jt. and rigged down. DECOMP Install 13 3/8" x 9 1/16" wear bushing. DECOMP Make up 9 5/8" scraper run BHA to 301'. Consists of: -8.5" used bit -9 5/8" scraper -(2) 7" boot baskets -Bit Sub with float -6 1/4" bumper sub -(9) 6 1/4" Drill Collars -Cross over sub DECOMP Single in the hole from 301' to 9480' on 4" drill pipe. Tagged the 4.5" tubin slum at 9480'. DECOMP Circulate a hi-vis sweep -502 gpm @ 1792 psi -98 RPM's / TO 4-5k. SFAL DECOMP Work on top drive to get number for recalibration. DECOMP Service top drive and draw works. SFAL DECOMP Rebuid the annular regulator. DECOMP POH from 9429' to 301'. Rack back the drill pipe. DECOMP Lay down the BHA and clean and clear the floor. DECOMP Rig up to run Schlumberger USIT log. DECOMP Run in hole with Schlumberger USIT to 9400' and. log to DECOMP Run in hole with Schlumberger 3 shot string shot at 2072' and fire, which is 2 full joints above the TOC located ~ 2150' Printed: 4/13/2009 2:50:03 PM BP EXPLORATION Page 3 of 17 Operations Summary Report Legal Well Name: B-25 Common Weil Name: 8-25 Spud Date: 10/14/1982 Event Name: WORKOVER Start: 2/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/29/2009 Rig Name: NABOBS 2ES Rig Number: l Date .From - To:' Hours Task Code NPT Phase ~, Description of Operations 3/6/2009 09:30 - 13:00 3.50 DHB P DECOMP Pick up Halliburton 9 5/8" RBP and run in hole on drill aide to 2714'. -Up Wt. 67k /Down Wt. 65k. -Verify RBP tool is set 13:00 - 13:30 0.50 DHB P DECOMP Pressure test RBP to 3500 psi for 15 minutes. Good Test 13:30 - 18:00 4.50 DHB P DECOMP Dump 22001bs of 20x40 river sand on top of RBP through the drill pipe. 18:00 - 19:00 1.00 CLEAN P DECOMP Pump a drill pipe volume to clear sand out of the drill pipe and to sand C~? 2646'. -Up Wt. 68k /Down Wt. 65k 19:00 - 20:30 1.50 CLEAN P DECOMP POH from 2646' to surface and rack back the drill pipe. Laydown the the RBP running tool and clean and clear the floor. 20:30 - 22:30 2.00 FISH P DECOMP Make up 8 1/4" casing cutter and RIH and tag the sand @ 2660'. Pick up to 2050'. 22:30 - 00:00 1.50 FISH P DECOMP Locate collars C~ 2030' and 2071'. Pick up 20' and cut the 9 5/8" casin at 2051'. -89 SPM Q 614 psi /RPM 80 -Up Wt. 67k /Down Wt. 64k /ROT 58k 3/7/2009 00:00 - 03:00 3.00 FISH P DECOMP Establish circulation Q 2 bpm and 500 psi. Returns taken to the cellar, nothing to the cuttings tank. Continue to circulate and prepare to rig up LRS. While establishing circulation there was a 20 gallon leak to the herculite in the sub base with a small amount on to sub structure walls. All cleaned up. Reported to x5700. 03:00 - 05:00 2.00 FISH P DECOMP Rig up LRS to pump 50 bbl of 110 degree diesel through the drill i e and s o in a outsi e o t e casin cut. Let soak for 30 minutes. 05:00 - 08:30 3.50 FISH P DECOMP Circulate 480 bbls of hot 9.8 brine throw h the casin cut, takin returns to the cellar box. Showed signs of arctic pack for 200 bbls and then cleaned up for last 280 bbls. Varied the pumping speed from 0.5 bpm to 5 bpm in order to stir up the arctic pack around the 9 5/8" casing. 08:30 - 09:30 1.00 FISH P DECOMP Bring tools up beaver slide for casing spear run and working on strapping the 9 5/8" casing. 09:30 - 13:00 3.50 FISH P DECOMP Reverse circulate in 9.8ppg brine in order to displace the entire wellbore to 9.8 ppg brine. Monitor well and cellar and let stabilize. Put steam on the wellhead in order to free up the 9 5/8" casing head. 13:00 - 15:00 2.00 FISH P DECOMP Pull out of the hole from 2051' and lay down the casing cutter. 15:00 - 16:30 1.50 FISH P DECOMP Make up 9 5/8" spear and run in the hole and pull casing han er and acko free at 160k. Saw 1 turnbuckle on B P stack loosen, but stack did not move. 16:30 - 17:30 1.00 FISH P DECOMP Rig up 9 5/8" casing equipment and prepare to pull the 9 5/8" casing. 17:30 - 00:00 6.50 FISH P DECOMP Pull 9 5/8" casing from 2051' to 531'. Unable to get an average torque due to false bowl and tight connections. Ha to steam and hammer each connection to break free. 3/8/2009 00:00 - 05:00 5.00 FISH P DECOMP Continue to pull 9 5/8" casing out of the hole from 531' to surface. Still not able to get an average torque due to false bowl, steaming, and hammering the connections. 05:00 - 06:00 1.00 FISH P DECOMP Make up wash over BHA. Consists of: Printed: 4/13/2009 2:50:03 PM BP EXPLORATION Operations Summary Report Page 4 of 17 Legal Well Name: B-25 Common Well Name: B-25 Spud Dater 10/14/1982 Event Name: WORKOVER Start: 2/25/2009 End: Contractor Name: NABOBS ALAS KA DRILLING 1 Rig Release: 3/29/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To '~ Hours ~ Task Code ' NPT Phase Description of Operations 3/8/2009 05:00 - 06:00 . 1.00 FISH P - _ __- DECOMP -12.125" x 10.75" Drag Tooth Rotary Shoe -11.75" Wash Pipe -Wash Over Boot Basket -12.125" String Mill -XO Sub -Float Sub -6.25" Lub Bumper Sub -6.25" Oil Jar 06:00 - 09:00 3.00 FISH P DECOMP While running in the hole and making up the BHA we cont an obstruction at 7T. Rack back 1 stand of drill collars and make up the crossover and RIH with a stand of drill pipe. Hook ~i up the blower hose and try to pump on it. Still not able to get b obstruction. 09:00 - 10:30 1.50 FISH P DECOMP Couldn't get past the obstruction so we racked back the drill pipe and laid down the BHA. 10:30 - 12:00 1.50 FISH P DECOMP Pick uq new BHA and run in hole to 77' to oolish off BHA consisted of: -Drill Collars -12.125" String Mill -XO Sub -Bumper Sub -Jars -Drill pipe 12:00 - 13:00 1.00 FISH P DECOMP Work BHA through obstruction at 77' to polish off the casing. Acts like the 13 3/8" is arted and mis-ali ned at a cou lin . -SPM 5-10 /RPM 20-30 / TO 1 k Work with Dumps and rotary off 3 times without seeino any -Up Wt. 70k /Down Wt. 70k /Rot Wt. 70k 13:00 - 14:30 1.50 FISH P DECOMP POH and lay down BHA from 309'. Clean and clear the floor. 14:30 - 16:00 1.50 FISH P DECOMP Make uo wash over BHA. -12.125" x 10.75" Drag Tooth Rotary Shoe -11.75" Wash Pipe -Wash Over Boot Basket -12.125" String Mill -XO Sub -Float Sub -6.25" Lub Bumper Sub -6.25" Oil Jar -(3) stands of Drill Collars -XO Sub 16:00 - 17:30 1.50 FISH P DECOMP RIH from 348' to 1980' on drill pipe. 17:30 - 19:30 2.00 FISH P DECOMP Washdown from 1980' to 2050' @ 3 bpm and attempt to wash over the stub. Failed 19:30 - 22:00 2.50 FISH P DECOMP TOH from 2050' to 1980' where it began to pull tight with 30k overpull. Circulate a bottoms up C~ 6 bpm. Transfer fluid from pit 2 to free up more room in the pits for 9.8 ppg brine. 22:00 - 23:00 1.00 FISH P DECOMP Circulate out arctic pack at 10 bpm C~ 460 psi. Blow down the surface equipment and prepare to 23:00 - 00:00 1.00 FISH P DECOMP Trip out of the hole from 1980' to 348' with no more overpull issues. Printed: 4/13/2009 2:50:03 PM BP EXPLORATION Page 5 of 17 Operations Summary Report Legal Well Name: B-25 Common Well Name: B-25 Spud Date: 10/14/1982 Event Name: WORKOVER Start: 2/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/29/2009 Rig Name: NABOBS 2ES Rig Number: ' Date From - To Hours Task Code. NPT Phase. Description of Operations 3/9/2009 00:00 - 03:00 3.00 FISH P DECOMP POH with Washover BHA and inspect for signs of washing over the 9 5/8" stub. Showed signs off 1' of swallow on the washover shoe, junk basket full of small gravel, wear on , outside of wash pipe from what is thouoht to be obstruction at 77'. 03:00 - 04:30 1.50 FISH P DECOMP Make u wash over BHA. Chan in out the washover shoe and dro in the 12.125" strip mill. Consists of: -12.125" x 10.75" Crippled Rotary Shoe -11.75" Wash Pipe -Wash Over Boot Basket -XO Sub -Float Sub -6.25" Lub Bumper Sub -6.25" Oil Jar -(3) stands of Drill Collars -XO Sub 04:30 - 05:30 1.00 FISH P DECOMP RIH on drill pipe from 340' to 2050'. 05:30 - 08:30 3.00 FISH P DECOMP Attempt to get over the 9 5/8" stub. Unable to wash over the stub, tried rotating and pumping and still not able to wash over. -Up Wt. 75k /Down Wt. 70k /Rot Wt. 72k 08:30 - 10:00 1.50 FISH P DECOMP Circulate a hi-vis sweep Q 10 bpm / 100-150psi. Taking the returns to the cellar. 10:00 - 11:00 1.00 FISH P DECOMP Trip out of the hole from 2050' to 340' and rack back the drill pipe. 11:00 - 14:30 3.50 FISH P DECOMP Laydown the BHA and clean the handling equipment. The junk basket was full of ravel a ain. 14:30 - 15:30 1.00 FISH P DECOMP Pick up new fishing BHA to 303'. Consists of: -8.5" Smooth OD Tapered Mill -Bit Sub -Float Sub -6.25" Lub Bumper Sub -6.25" Oil Jar -(3) Stands of 6.25" Drill Collars -XO Sub 15:30 - 17:30 2.00 FISH P DECOMP Run in the hole with the BHA from 303' to 2050' on drill pipe. Rotate into the 9 5/8" casing stub with the taper mill. Continue in the 9 5/8" casin until 2648' where we tagged the sand. -Up Wt. 75k /Down Wt. 75k /Rot Wt. 70k 17:30 - 18:30 1.00 FISH P DECOMP Displace the well to 8.6 ppg Flo-Pro at 10bpm and 350 psi. Taking the returns to the cellar. 18:30 - 19:00 0.50 FISH P DECOMP rip out o the hole rom 2648' to 2050' working the BHA at the casing shoe. -Up Wt. 70k /Down Wt. 70k 19:00 - 19:30 0.50 FISH P DECOMP Circulate 80 bbls of 8.6 ppg Flo-Pro at 10 bpm and 250 psi making sure that the hole was clean. 19:30 - 20:30 1.00 FISH P DECOMP Trip out of the hole from 2050' to 303' and rack back the drill pipe. 20:30 - 21:30 1.00 FISH P DECOMP Laydown the BHA and change out the handling equipment. 21:30 - 00:00 2.50 FISH P DECOMP Make up new fishing BHA to 323'. Printed: 4/13/2009 2:50:03 PM BP EXPLORATION Page 6 of 17 Operations Summary Report Legal Well Name: B-25 Common Well Name: B-25 Spud Date: 10/14/1982 Event Name: WORKOVER Start: 2/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/29/2009 Rig Name: NABOBS 2ES Rig Number: Date _ From - To _ _ Hours Task i Code ~_ NPT ~ i Phase Description of Operations _ 3/9/2009 21:30 - 00:00 2.50 FISH P DECOMP - BHA Consists of: -Bull Nose -8.5" OD Casing Swedge -Flex Joint -XO Sub -Double pin sub -Wash over boot basket -XO Sub -Float Sub -6.25" Lub bumper sub -6.25" oil jar -(3) Stands of 6.25" Drill Collars -XO sub 3/10/2009 00:00 - 01:00 1.00 FISH P DECOMP RIH on drill pipe from 323' to 2018'. 01:00 - 04:00 3.00 FISH P DECOMP Make up to the togdrive and tap on the BHA at 2061'. 04:00 - 05:00 05:00 - 06:00 06:00 - 08:30 08:30 - 09:30 09:30 - 10:30 10:30 - 13:00 1.00 1.00 2.50 1.00 1.00 2.50 FISH FISH FISH CLEAN CLEAN CLEAN P P P P P P DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP -Up Wt. 75k /Down Wt. 75k /Rot Wt. 77k -TO on 4-6k /off 1 k Pull up to have lower "stinger" piece of the BHA inside of the 9 5/8" casing stub and circulate a bottoms up C~3 370 gpm and 125 psi, while taking the returns to the cellar. Pull out of the hole from 2064' to 323' racking back the drill pipe. LD BHA from 323'. Clean and clear rig floor. PU Millinp BHA to 344'. RIH with BHA from 344' to 2018'. Ta u at 2051'. Swallow stub to 2057' and mill to 2060', leavin the casin stub at 2053'. BHA TD and stub TD are 7' different due to the milling BHA having 7' of swallow from the external dressoff shoe to the internal dressoff mill. PU - 75k, SO - 76k, ROT - 77k. 83 gpm C~ 50 psi. TO - 4 to 10k ~ 60 RPM. TO - 1 k off bottom. Work over stub 3 times with pumps and rotary off. 13:00 - 15:00 2.00 CLEAN P DECOMP Pump hi-vis sweeps till clean Q 10 bpm, 250 psi, 50 RPM. 15:00 - 16:00 1.00 CLEAN P DECOMP POH from 2060 to 344'. 16:00 - 17:30 1.50 CLEAN P DECOMP LD Milling BHA. Clean and clear rig floor. 17:30 - 18:30 1.00 BOPSU P DECOMP ND BOPE. 18:30 - 20:00 1.50 WHSUR P DECOMP RU Wachs cutter and cut 13-3/8" wellhead off. RD Wachs cutter and remove wellhead from cellar. 20:00 - 22:30 2.50 CASE P TIEB1 RU to run 9-5/8" casing. PJSM. Perform HACL for running 9-5/8" casing with no BOP stack and thru cut wellhead. 22:30 - 00:00 1.50 CASE P TIEB1 Bakerlock casing patch to ES Cementer. RIH with 9-5/8" casing to 56'. 3/11/2009 00:00 - 02:00 2.00 CASE P TIEB1 PJSM and perform HACL with new crew coming on tour for 9-5/8" casing run. RU scaffolding, and change snub line lengths on power tongs and backup tongs due to addition of centralizers. 02:00 - 06:00 4.00 CASE P TIEB1 RIH with 9-5/8" casing from 56' to 2053'. Displacement to surface at 2:30 am. Small amount of water, -1 gal/min, flowing up the 13-3/8" x conductor annulus during connection breaks. Printed: 4/13/2009 2:50:03 PM • s BP EXPLORATION Operations Summary Report Legal Well Name: B-25 Common Well Name: B-25 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date :From - To Hours ~ Task 'Code NPT 3/11/2009 02:00 - 06:00 I 4.00 CASE P Page 7 of 17 Spud Date: 10/14/1982 Start: 2/25/2009 End: Rig Release: 3/29/2009 Rig Number: Phase I Description of Operations TIEB1 6:00 - 07:00 .00 ASE P IEB1 Around 3:45 am, Flo-Pro displacement started flowing out of the casing onto the rig floor. No flow visible out of the casing or thru the annuli on connection breaks. M/U pups and enoaoe swallow casina stub with oatch~PU 125k to confirm patch is engaged. 07:00 - 08:00 1.00 CEMT P TIEB1 MU cementing head and lines to pressure test cementer and patch. PU on casing to 300k. SO to 115k. Good pull test. Attempt to pressure pressure test. Fail, full returns coming back to cellar thru annuli. Max rate - 3 bpm C~ 120 psi. 08:00 - 09:30 1.50 CEMT N DPRB TIEB1 Wait on orders from Anchorage. 09:30 - 10:00 0.50 CEMT P TIE61 RD cementing equipment. 10:00 - 11:00 1.00 CASE P TIEB1 RU XO's & tools to back-off of stub. Rotate right 10 RPM and slowly pull off of stub - backoff successful. ' 11:00 - 11:30 0.50 CASE P TIE61 RU to LD 9-5/8" casing. 11:30 - 15:00 3.50 CASE P TIEB1 Pull casing from 2053' to 56'. 15:00 - 18:30 3.50 CASE P TIEB1 Heat baker-locked box between HES Cementer and casing patch and break connection. RD casing handling equipment and clean and clear rig floor. 18:30 - 20:00 1.50 CASE P TIEB1 Break apart XO used to rotate off of casing stub. 20:00 - 21:00 1.00 CLEAN P DECOMP MU casing cutter BHA to 7'. 21:00 - 23:00 2.00 CLEAN P DECOMP RIH from 7' to to of stub at 2053'. Attem t to et into stub f~ 1 hour - no go. PU - 55k, SO - 55k. ~ 23:00 - 00:00 1.00 CLEAN P DECOMP POH from 2053' to top of casing cutter BHA at T. 3/12/2009 00:00 - 01:00 1.00 CLEAN P DECOMP MU 4-1/2" bullnose and 1 joint of HWDP to bottom of 01:00 - 02:30 1.50 CLEAN P DECOMP RIH with BHA #12 to 2068'. Establish circulation to open cutters. SO to 2071' and tag up on 9-5/8" collar. Turn off pumps. PU 10' to 2061'. 02:30 - 03:00 0.50 CLEAN P DECOMP Establish circulation and begin rotation for cutting operation, Good indication of a cut at 2:50 am. Time -ROT -Rate -Pressure - TO 2:41 am - 60 RPM - 83 gpm - 100 psi - 1000 ft-Ibs 2:45 am-60 RPM-130 gpm-210psi- 2:47am-60RPM-168 gpm-390psi- 2:48 am - 60 RPM - 210 gpm - 630 psi - 4000 ft-Ibs 2:50 am - 60 RPM - 220 gpm - 250 psi - 2000 ft-Ibs 2:53 am - 0 RPM - 225 gpm - 240 psi - 0 ft-Ibs 03:00 - 03:30 0.50 CLEAN P DECOMP Displace well from 8.6+ppg Flo-Pro to 8.5 ppg seawater. 03:30 - 06:30 3.00 CLEAN P DECOMP POH to 2020' and cut and slip drilling line. Service top drive. 06:30 - 07:30 1.00 CLEAN P DECOMP POH with casing cutting assembly from 2020' to 43'. 07:30 - 08:30 1.00 CLEAN P DECOMP LD BHA #f2 - 8.25" Multistring casing cutter. Knives show wear several inches up the blades. 08:30 - 09:30 1.00 FISH P DECOMP PU BHA #13 to 341'. Bullnose, 1 jt. HWDP, Packoff, spear, bumper sub, jars, Sea DC's. 09:30 - 10:00 0.50 FISH P DECOMP RIH from 341' to 2036'. 10:00 - 10:30 0.50 FISH P DECOMP Tam stub at 2053' and RIH and engage fish with spear. PU - 75k. SO - 75k. 10:30 - 11:30 1.00 FISH P DECOMP POH from 2061' to 341'. 11:30 - 13:00 1.50 FISH P DECOMP LD casing spear BHA #13 from 341'. Lay down 8' 6" fish. Fish had a hole milled into it 4-8 inches wide between 4' and 6.5' from top of casing stub. 1 8" lip milled in casing at 6.5' rom Printed: 4/13/2009 2:50:03 PM i BP EXPLORATION Page 8 of 17 Operations Summary Report Legal Well Name: B-25 Common Well Name: B-25 Spud Date: 10/14/1982 Event Name: WORKOVER Start: 2/25/2009 End: Contractor Name: NABORS ALAS KA DRILLING I Rig Release: 3/29/2009 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code I NPT ', Phase Description"of Operations 3/12/2009 11:30 - 13:00 1.50 FISH P DECOMP stub -bottom of hole. 1/2" lip milled in casing at 7' from casing stub. No sign of mill wear on casing opposite hole. Casing below 1/2" lip is clean with no sign of cement. Junk basket full of metal shavings. Clean and clear rig floor. 13:00 - 15:00 2.00 CLEAN P DECOMP PU BHA #14 - 12-1/8" x 10-3/4" cripple tooth shoe, washpipe ext, 10" x 8.5" dress mill, boot basket, bumper sub, jars, Sea DC's to 341'. 15:00 - 16:00 1.00 CLEAN P DECOMP RIH from 341' to 2032'. PU - 73k. SO - 73k. 16:00 - 19:00 3.00 CLEAN P DECOMP Wash over casin stub at 2061'. Polish 6" off of stub to 2061.5' at 2 bpm, 70 psi. 10-30 rpm, 2-13k TQ. After done, slide over with no rotation and pumps on, then slide over twice with no rotation or pumps. Saw 3-5k drag while sliding over. 19:00 - 20:00 1.00 CLEAN P DECOMP Circulate hi-vis sweep at 10 bpm, 250 psi. 20:00 - 21:00 1.00 CLEAN P DECOMP POH from 2061' to 341'. 21:00 - 23:00 2.00 CLEAN P DECOMP LD BHA #14 -Dress off assembly. Clean and clear rig floor. 23:00 - 00:00 1.00 CASE P TIEB1 RU to run 9-5/8" casing. 3/13/2009 00:00 - 01:30 1.50 CASE P TIEB1 Continue to RU to run 9-5/8" casing. PJSM. 01:30 - 08:00 6.50 CASE P TIEB1 RIH with 9-5/8" casing to 2047'. Space out with pups and go over stub at 2061'. PU - 115k, SO - 115k. 08:00 - 08:30 0.50 CASE P TIEB1 Pull test casin atch to 300k - ood test. SO to 115k. PJSM. Pressure test casing patch to 1500 psi -good test. Pressure test to 2000 psi -good test. Pressure u to 2700 si too en ES cementer. 08:30 - 09:00 0.50 CASE P TIEB1 Circulate heated seawater until returns are 88 degrees F. 09:00 - 09:30 0.50 CEMT P TIE61 PJSM for cement job. Drop ball for bypass sub, load cementing head. 09:30 - 12:00 2.50 CEMT P TIEB1 Pump cement job. CIP ~ 11:37 am. No cement returns to surface. Freshwater spacer 15.8 ppg tail Class Gtail - 140 bbls; 582 sx; 1.17 ft^3/sk. Drop plug & displace with seawater at 5 bpm. 115 stks - 115 psi 2300 stks - 722 psi Reduce displacement rate to 2 bpm Lose returns -fluid level down riser 12'. Brin rate back to 3 b m. Shear ES cementer at 1500 si. Indication of shear -shook ri floor. Bleed off pressure - no flow back. 12:00 - 23:00 11.00 CEMT P TIEB1 Wait on cement to reach 500 psi compressive strength. 23:00 - 00:00 1.00 WHSUR P TIEB1 RU Wachs cutter cut 9-5/8" casin and LD 8.59' cut'oint. 3/14/2009 00:00 - 00:30 0.50 WHSUR P TIEB1 RD Wachs cutter. 00:30 - 01:30 1.00 REMCM P TIEB1 RU for remedial cement top job with 1"pipe. 01:30 - 03:00 1.50 REMCM P TIEB1 Run 1"pipe into the 13-3/8" x Conductor (OOA) and 9-5/8" x 13-3/8" (OA) annuli & verify TOC depths at different spots in each annulus. Printed: 4/13/2009 2:50:03 PM BP EXPLORATION Operations Summary Report Legal Well Name: B-25 Common Well Name: B-25 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date ~ From - To Hours ~I Task I Code NPT ~ 3/14/2009 01:30 - 03:00 1.50 ~ - REMCMT P Page 9 of 17 Spud Date: 10/14/1982 Start: 2/25/2009 End: Rig Release: 3/29/2009 Rig Number: Phase Description of Operations TIEB1 OOA - 48.5', 51' and impassable casing part at 37'. OA - 65' tag all around. 03:00 - 04:30 1.50 REMCM P TIEB1 PJSM. Pressure test lines to 500 psi. Pump cement at 1 bpm thru 1"pipe at bottom of OA. Start circulation at 4:03 am. 4:03 am -flow coming evenly out of both OA and OOA. 4:13 am - 10 bbls pumpe , no cemen ou o or A. -Annular volume of OA - 3.8 bbls, OOA - 8.5 bbls. 4:15 am - 13 bbls pumped, cement returns out of OOA. 4:18 am - 15 bbls pumped, cement returns out of both OA and OOA. 4:28 am - 24 bbls pumped, shut down pumping. Witness waived by AOGCC Rep Lou Grimaldi. Operation witnessed by NAD Toolpusher Ken Helf and BP Rep Travis Peltier. 04:30 - 05:30 1.00 REMCM P TIEB1 RD cementing equipment. 05:30 - 09:30 4.00 WHSUR P TIEB1 Install Cameron Slip-on wellhead. Pressure test packoff to 3800 psi for 30 mins. 09:30 - 15:00 5.50 BOPSU P DECOMP NU BOPE. Wellhead sunk 2" with the weight of the BOP stack on it. 15:00 - 16:00 1.00 BOPSU P DECOMP Service pipe skate. 16:00 - 17:00 1.00 BOPSU P DECOMP Continue to NU BOPE. Install test plug, fill lines and purge air. Pre-test BOP stack to 250 psi low -good test. Pressure up to 17:00 - 18:00 I 1.00 18:00 - 23:30 I 5.50 N SFAL DECOMP Troubleshoot test pump. Cleanout suction & discharge sides of pump. Change out pop-offs. N 23:30 - 00:00 0.50 BOPSU N 3/15/2009 00:00 - 04:30 4.50 BOPSU P 04:30 - 05:30 1.00 BOPSU P 05:30 - 07:00 1.50 CLEAN P 07:00 - 08:30 1.50 CLEAN P 08:30 - 10:00 1.50 CLEAN P 10:00 - 10:30 0.50 CLEAN P 10:30 - 11:00 0.50 CLEAN P 11:00 - 12:00 1.00 CLEAN P Test witness waived by AOGCC Rep Lou Grimaldi. Test witness by NAD Toolpusher Ken Helf and BP WSL Travis Peltier. DECOMP RD BOP testing equipment. Clean and clear rig floor. DECOMP MU BHA #15 cement Cleanout BHA (mill tooth bit, boot baskets, drill collars and jars), to 309'. DECOMP RIH from 309' to 2022' and tag cement. PU - 73k, SO - 73k, ROT - 75k. RPM - 60, TO - 1400 ft-Ibs off bottom. DECOMP Drill cement from 2022' to 2052'. Circulate at 404 gpm at 504 psi. DECOMP RIH from 2052' to 2603' and tag junk. DECOMP Wash and ream to 2647'. Dry drill to 2660'. PU - 80k, SO - 80k, RT - 80k. DECOMP Circulate hi-vis sweep at 402 gpm, 407 psi, 77 RPM surface to HMAN ~ DECOMP ~ Attempt to test BOPE, leaking past test plug. VR plug installed on incorrect side of wellhead. Pull VR plug with lubricator and re-install secondary annulus valve. Suck out stack and install VR plug on correct side of wellhead. Pull test plug. HMAN DECOMP Install test plug and fill up lines for pressure test. DECOMP Test BOPE to 250 psi low, 3500 psi high. Test annular preventer to 2500 psi. All tests pass. Test against test plug and test annular preventer, and upper and lower VBR's with 4" test joint. Printed: 4/13/2009 2:50:03 PM BP EXPLORATION Page 10 of 17 Operations Summary Report Legal Well Name: B-25 Common Well Name: B-25 Spud Date: 10/14/1982 Event Name: WORKOVER Start: 2/25/2009 End: Contractor Name: NABORS ALASKA DRI LLING I Rig Release: 3/29/2009 Rig Name: NABORS 2ES Rig Number: Date From - To ' Hours ' Task Code NPT Phase ' Description of Operations 3/15/2009 11:00 - 12:00 1.00 CLEAN. P DECOMP surface. 12:00 - 13:30 1.50 CLEAN P DECOMP POH from 2660' to 309'. 13:30 - 14:30 1.00 CLEAN P DECOMP LD BHA #15 from 309'. 14:30 - 15:30 1.00 CLEAN P DECOMP Pressure test casin to 3500 si - ood test. Lost 40 si in 1st 15 minutes, 15 psi in 2nd 15 minutes. ~~ 15:30 - 17:00 1.50 CLEAN P DECOMP MU BHA # 16, scraper BHA (RCJB, 9-5/8" casing scraper), to 320'. 17:00 - 18:00 1.00 CLEAN P DECOMP RIH from 320' to 2578'. 18:00 - 19:00 1.00 CLEAN P DECOMP Circulate with RCJB and cleanout wellbore to 2670'. Circulate at 169 gpm, 980 psi. RPM - 50, TO - 3k to 4k, PU - 77k, SO - 80k. 19:00 - 20:30 1.50 CLEAN P DECOMP Circulate hi-vis SS sweep at 294 gpm, 2900 psi. 20:30 - 21:00 0.50 CLEAN P DECOMP Service top drive. 21:00 - 22:00 1.00 CLEAN N RREP DECOMP Change out leaking hose on top drive. 22:00 - 23:00 1.00 CLEAN P DECOMP POH from 2670' to 320'. 23:00 - 00:00 1.00 CLEAN P DECOMP LD BHA #16 from 320' to clean out junk basket. Basket full of large metal debris pieces from float equipment and a dozen 1" to 2" diameter rocks. 3/16/2009 00:00 - 01:30 1.50 CLEAN P DECOMP MU BHA #17 to 316', same as BHA #16 but removing the 9-5/8" casing scraper. 01:30 - 03:00 1.50 CLEAN P DECOMP RIH from 316' to 2670'. PU - 80k, SO - 80k. 03:00 - 04:00 1.00 CLEAN P DECOMP Circulate with RCJB and cleanout wellbore to 2685'. Circulate at 174 gpm, 1059 psi. ROT - 20 RPM, TO - 2k. 04:00 - 04:30 0.50 CLEAN P DECOMP Circulate hi-vis SS sweep at 291 gpm, 2947 psi. 04:30 - 06:00 1.50 CLEAN P DECOMP POH from 2685' to 316'. 06:00 - 08:00 2.00 CLEAN P DECOMP LD BHA #17, RCJB. Clean and clear rig floor. 08:00 - 08:30 0.50 FISH P DECOMP MU RBP retrieval tool. 08:30 - 10:00 1.50 FISH P DECOMP RIH with RBP retrieval tool to 2682'. Establish circulation at 588 gpm, 547 psi. Wash down to RBP at 2714'. PU - 65k, SO - 65k. 10:00 - 10:30 0.50 FISH P DECOMP En a e RBP o en b ass and monitor well. PU to 95k to release plug. RIH to 2776' and set RBP. 10:30 - 11:00 0.50 FISH P DECOMP Circulate SS sweep at 585 gpm, psi. Heavy sand returns at shaker. 11:00 - 13:00 2.00 FISH P DECOMP POH from 2776' to 100'. 13:00 - 14:30 1.50 FISH P DECOMP LD RBP retrieval tool and RBP. Clean and clear rig floor. 14:30 - 16:30 2.00 CLEAN P DECOMP MU BHA #18, acker milling assembly (8-1/2" burnshoe, washpipe, bumper sub, jars & collars), to 360'. 16:30 - 20:30 4.00 CLEAN P DECOMP RIH from 360' to 8953' and tag obstruction. Overpull required to release from obstruction, see a ow. 20:30 - 22:00 1.50 CLEAN P DECOMP PU to 200k, unable to break free. SO to neutral weight & establish circulation at 100 gpm, 80 psi. to an free drillstrina. Come down on obstruction with 10k, took over 10k i slowly rotate through obstruction. ROT - 160k C~ 20 - 5k off bottom. Circulate at 110 gpm, 80 psi. Previously passed thru this section with BHA #1 (8-1/2" used oth bit 8" OD casin sera er bod with no problems. 22:00 - 23:00 1.00 CLEAN P DECOMP r t asin to 3000 si - ood test. Lost 150 si in 1st 15 minutes, 30 psi in 2nd 15 minutes. Printed: 4/13/2009 2:50:03 PM • i BP EXPLORATION Page 11 of 17 Operations Summary Report Legal Well Name: B-25 Common Well Name: B-25 Spud Date: 10/14/1982 Event Name: WORKOVER Start: 2/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/29/2009 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task I Code' NPT ' Phase Description of Operations 3/16/2009 23:00 - 00:00 1.00 CLEAN P DECOMP POH from 8953' to 8646'. 3/17/2009 00:00 - 03:00 3.00 CLEAN P DECOMP POH from 8646' to 360'. 03:00 - 05:30 2.50 CLEAN P DECOMP LD BHA #18, packer milling burnshoe, from 360'. Clean and clear rig floor. No damage visible on tools. 05:30 - 06:30 1.00 CLEAN P DECOMP MU BHA #19 swa a assembl 8-1/2" swa a DC's to 320'. 06:30 - 09:00 2.50 CLEAN P DECOMP RIH from 320' to 8953'. PU - 170k, SO - 145k. 09:00 - 09:30 0.50 CLEAN P DECOMP Circulate wellbore volume at 600 gpm, 350 psi. 09:30 - 13:00 3.50 CLEAN P DECOMP T of t 8954'. Be in swa in with 20k down continuing with 30k, 40k, 50k, 60k, 70k, 80k down. Jar with 90k over and break free. Work through several times, opening obstruction with 8-1/2" swage. Able to SO 25k, and PU 50k to get in and 13:00 - 15:30 2.50 CLEAN P 15:30 - 18:30 3.00 CLEAN P 18:30 - 20:30 2.00 CLEAN P 20:30 - 21:00 I 0.501 EVAL I P 21:00 - 22:30 1.50 FISH P 22:30 - 00:00 1.50 FISH P 3/18/2009 00:00 - 01:00 1.00 FISH P 01:00 - 03:00 2.00 FISH P 03:00 - 04:00 1.00 FISH P 04:00 - 07:00 3.00 FISH P 07:00 - 09:00 2.00 FISH P 09:00 - 10:30 1.50 FISH P 10:30 - 14:00 3.50 FISH P 14:00 - 16:00 2.00 FISH N 16:00 - 18:30 2.501 FISH P 18:30 - 22:00 3.50 FISH P 22:00 - 00:00 2.00 FISH P 3/19/2009 00:00 - 01:30 1.50 FISH P 01:30 - 05:30 4.00 FISH P 05:30 - 09:00 3.50 FISH P 09:00 - 09:30 I 0.501 FISH ~ P Continue to RIH to 9480' and to stum ,finding no further obstructions. POH to 8954' and work several more times until SO 15 - 20k and PU 15 - 20k over to get free of obstruction. DECOMP Slip and cut drilling line. Service top drive. Perform post jarring inspection, checking derrick and drawworks. DECOMP POH from 8954' to 320'. DECOMP LD swa a BHA #19 from 320'. Swa a is still in gauge. Clean and clear rig floor. DECOMP Pressure test casino to 3000 osi for 10 minutes. Lost 0 psi in 10 minutes- DECOMP MU k-anchor retrieval BHA (#20) to 320'. DECOMP RIH from 320' to 4556'. DECOMP Service iron roughneck and draworks. DECOMP RIH from 4556' to 9480'. PU - 175k, SO - 150k. DECOMP Ta tubin stub at 9480'. Work overshot over stub and release k-anchor. DECOMP POH from 9480' to 320' with fish. DECOMP LD k-anchor retrieval BHA (#20) and k-anchor fish. Clean and clear rig floor. DECOMP MU acker tucker BHA #21 to 330'. DECOMP RIH from 330' to 9422'. PU - 175k, SO - 140k, ROT - 165k. WAIT DECOMP Topdrive hydraulics frozen due to cold. Thaw out tube pump and get circulation system going. DECOMP Attem t to mill on packer ~ 9,493'. PU - 175k, SO - 140k, ROT - 165k. TO off - 4k, TO on - 4 - 7k. Circulate at 100 gpm, 100 psi. Unable to et more than 2 ft. inside of acker with bullnose & ra le.. DECOMP POH from 9493' to 330'. DECOMP LD acker tucker BHA (#21) from 330'. Boot baskets full of slu itts. ra le in catch osition. DECOMP MU packer milling BHA (#22) to 364'. DECOMP RIH from 364' to 9493'. DECOMP Mill over acker from 9493' to 9497'. Circulate at 200 gpm, 343 psi. PU - 175k, SO - 155k, ROT - 165k. RPM - 80, TO off - 5k, TO on - 7k to 9k. Break through and push packer down to 9501'. DECOMP CBU at 441 gpm, 1300 psi. Gas from below packer ~ surface, Printed: 4/13/2009 2:50:03 PM BP EXPLORATION Page 12 of 17 Operations Summary Report Legal Well Name: B-25 Common Well Name: B-25 Spud Date: 10/14/1982 Event Name: WORKOVER Start: 2/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/29/2009 Rig Name: NABOBS 2ES Rig Number: ~, Date I From - To 'Hours Task Code NPT Phase.. Description of Operations 3/19/2009 09:00 - 09:30 0.50 FISH P DECOMP re are to circulate throug_h_ choke & pas buster. 09:30 - 14:00 4.50 FISH P DECOMP SIDPP - 20 psi, SICP - 70 psi. CBU through choke @ 2bpm, 50 psi. CBU @ 100 gpm, 130 psi. Gas bubble circulated out. 3/20/2009 14:00 - 15:00 15:00 - 19:00 19:00 - 21:00 21:00 - 22:00 22:00 - 00:00 00:00 - 02:00 02:00 - 04:00 1.001 FISH 4.00 FISH 2.00 FISH 1.00 FISH 2.00 FISH 2.00 FISH 2.00 FISH P P P P P P P 04:00 - 07:30 3.50 FISH P 07:30 - 09:30 2.00 FISH P 09:30 - 11:00 1.50 FISH P 11:00 - 14:30 3.50 FISH P 14:30 - 16:30 2.00 FISH P 16:30 - 17:30 1.00 FISH P 17:30 - 22:00 4.50 FISH P 22:00 - 23:00 1.00 FISH P 23:00 - 00:00 1.00 FISH P 3/21/2009 100:00 - 03:30 I 3.501 FISH I P DECOMP Push acker carcass and to @ 9568'. Set 20k down. No verification of latching up with packer. PU - 175k, SO - 155k. DECOMP POH from 9568' to 364'. DECOMP LD packer millin BHA #22 from 364'. Static losses @ 40 bbls. / Hr DECOMP PU_packer fishing BHA (#23) to 319'. DECOMP RIH from 319' to 7851'. DECOMP RIH from 7851' to 9568'. PU - 172k, SO - 152k. DECOMP Establish circulation and make multiple attempts to latch onto fish. 127 pm @ 176 psi. Losses diminishing. Attempts (PU - 172k on all attempts): SO 20k & PU, SO 25k & PU, SO 25k & PU, Rotate at 5 RPM and SO 20k & PU, Rotate and SO 25k & PU, SO 25k & PU. CBU, POH 90' and SO to see if tubing tail tags 7" liner top - no indication. RIH, SO 20k & PU. No pod indications of latch up. DECOMP POH from 9568' to 319'. DECOMP LD overshot BHA (#23) from 319'. No fish. DECOMP MU spear BHA #24 to 318'. DECOMP RIH from 318' to 9258'. DECOMP Service Top Drive. Cut and slip drilling line. DECOMP RIH to 9569'. Establish parameters. PU - 175k, SO - 152k. 10 RPM, TO off - 4k. Work into fish -some obstruction. Circulate & rotate spear into packer. P/U with initial overoull of mmediate loss of returns DECOMP I POH from 9574' to 318'. Loss rate 200 to 250 bbls per hour DECOMP LD spear BHA (#24) to top of fish. DECOMP RU tubing punch and punch below connection 15' from top of fish. Tubin acked off with sand ands ittin as. Punch tubin 10' from top of fish. Packed with sand and spitting gas. Loss rate persisting at 200 to 250 bbls per hour. DECOMP Continue to punch and LD ish. LD fish from packer to bottom millout extension. Punch fish 5' and 10' from the top of tubing jt #1. Sand packed and bubbling. Punch fish above connection of pup jt below top "SWS" nipple. Sand packed and gas bubbling, portable air monitor showing 100% methane and 18 ppm H2S at punch. Ventilate rig floor until readings read 0. Punch 2 more holes at 10' and 20' above this punch, no further H2S readings. LD fish from jt #1 to pup below bottom "SWS" nipple. Printed: 4/13/2009 2:50:03 PM • BP EXPLORATION Page 13 of 17 Operations Summary Report Legal Well Name: B-25 Common Well Name: B-25 Spud Date: 10/14/1982 Event Name: WORKOVER Start: 2/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/29/2009 Rig Name: NABORS 2ES Rig Number: Date 'From - To 'Hours Task Code NPT Phase Description of Operations 3/21/2009 100:00 - 03:30 3.50 FISH P DECOMP Punch above and below bottom "SWS" nipple. Top punch sand packed with gas spitting out. No H2S. Bottom punch clean. LD fish. 03:30 - 04:30 1.00 FISH P DECOMP Clean and clear rig floor. 04:30 - 06:30 2.00 CLEAN P DECOMP MU 7" casin scra er BHA (#25) to 506'. 06:30 - 10:00 3.50 CLEAN P DECOMP RIH from 506' to 9572'. 10:00 - 11:00 1.00 CLEAN P DECOMP RIH from 9572' to 9590' with no indications of taggin 7" liner top. Establish circulation at 210 gpm, 450 psi. Wash down to 9727. 11:00 - 15:00 4.00 CLEAN P DECOMP POH from 9727' to 506'. 15:00 - 17:30 2.50 CLEAN P DECOMP LD 7" casing scraper BHA (#25) from 506'. Clean and clear rig floor. 17:30 - 18:30 1.00 DHB P DECOMP PU RBP to 53'. 18:30 - 23:00 4.50 DHB P DECOMP RIH from 53' to 9743' at 90 feet per minute, passing 7" liner top at 9586'. PU - 165k, SO - 135k. PU to 9700'. Set RBP. Slack off 15k to verif . Rack back one stand to 9651'. Losses stooped after RBP set. 23:00 - 23:30 0.50 DHB P DECOMP Pressure test RBP to 1000 psi for 10 minutes -good test. Lost 0 si in 10 minute test. 23:30 - 00:00 0.50 DHB P DECOMP POH from 9651' to 8808'. Total losses for the da - 3570 bbls. 3/22/2009 00:00 - 04:00 4.00 DHB P DECOMP POH from 8808' to 44'. LD RBP running tool. 04:00 - 05:30 1.50 BOPSU P DECOMP RU to test BOPE. 05:30 - 08:30 3.00 BOPSU N SFAL DECOMP Attempt to test BOPE to 250 psi low / 3500 psi high. Test plug leaking. Changeout test plug rubber, still leaking. Hook up cellar pump to IA and suck down test plug and seat rubber. 08:30 - 13:00 4.50 BOPSU P DECOMP Test BOPE to 250 psi low / 3500 si hi h. Test annular preventer to 250 psi low / 2500 psi high. Test VBR's with 4" test joint. All good tests. BOPE test witness waived and extra time allotted for setting RBP and POH by AOGCC Rep. John Crisp. Test witnessed by BP WSL Bill Decker and NAD Toolpusher Chris Page. 13:00 - 13:30 0.50 BOPSU P DECOMP Pull test plug and install wear ring. 13:30 - 14:00 0.50 DHB P DECOMP MU RBP and runnin tool to 53'. 14:00 - 18:30 4.50 DHB P DECOMP RIH from 53' to 9670'. PU to 9650'. PU - 165k, SO - 135k. Set RBP. Verify set by SO 15k. Good set. 7" liner to to ed a ain at 9586'. Ta oint on the RBP is 9' from the bottom of the plug, liner to is at 9577'. 18:30 - 19:00 0.50 DHB P DECOMP Release from plug and PU 60'. POH to 64' above the top of the plug, LD two singles. 19:00 - 22:00 3.00 DHB P DECOMP RU water hose and sand funnel and dump 1000# 20/40 sand. Pump 1/2 drill pipe volume at 2 bpm, 50 si. PJSM and start cut and slip drilling line while sand is falling. 22:00 - 23:30 1.50 DHB P DECOMP Finish cut and slip drilling line. Service drawworks and topdrive. 23:30 - 00:00 0.50 DHB P DECOMP RIH and to TOS at 9606'. PU to to of 7" liner at 9577'. Pump a hi-vis sweep. Printed: 4/13/2009 2:50:03 PM • i BP EXPLORATION Page 14 of 17 Operations Summary Report Legal Well Name: B-25 Common Well Name: B-25 Spud Date: 10/14/1982 Event Name: WORKOVER Start: 2/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/29/2009 Rig Name: NABOBS 2ES Rig Number: ' ~ I I h f O D i i i Date From - To Hours Task I Code NPT P ase escr pt on o perat ons 3/23/2009 00:00 - 01:30 1.50 DHB P DECOMP Continue to pump hi-vis sweep. Trace amounts of sand back to surface. Prepare to POH. ', 01:30 - 04:00 2.50 DHB N RREP DECOMP Iron roughneck leaking hydraulic fluid. ', 04:00 - 06:00 2.00 DHB P DECOMP Pump a dry job and blow down top drive. POH from 9577 to ' 3912'. 06:00 - 07:00 1.00 DHB N RREP DECOMP Change out hose and fitting on Iron Roughneck. 07:00 - 08:30 1.50 DHB P DECOMP POH from 3912' to 44'. 08:30 - 09:00 0.50 DHB P DECOMP LD RBP running tool. 09:00 - 10:00 1.00 BOPSU P TIEB2 Change top set of rams from 3-1/2" x 6" to 7". 10:00 - 10:30 0.50 BOPSU P TIEB2 MU 7" test joint. 10:30 - 11:30 1.00 BOPSU P TIEB2 Test 7" BOP rams to 250 si low, 3500 psi high. Test witnessed by NAD Toolpusher Chris Page and BP WSL Bill Decker. 11:30 - 12:00 0.50 BOPSU P TIE62 LD 7" test joint. 12:00 - 14:30 2.50 CASE P TIEB2 RU to run 7" casing. 14:30 - 15:00 0.50 CASE P TIEB2 MU 7" Tieback Stem + 2 Jts.check Float Collar. 15:00 - 23:30 8.50 CASE P TIEB2 RIH with 163 jts of 7" BTC-M casing and one BTC-M (pin) to TC-II (box) XO to 6613'. PU - 175k, SO - 150k. 23:30 - 00:00 0.50 CASE P TIEB2 RU torque turn equipment for TC-II casing. Lay BTC-M thread protectors down slide. 3/24/2009 00:00 - 06:00 6.00 CASE P TIE62 RIH from 6613' to 9577' with 7" TC-II casing. 06:00 - 07:30 1.50 CASE P TIE62 RIH from 9577' and tagged C~ 9585'. Did not witness any shears. Set down 50k to verif locator collar was bottomed out. Picked u and rotated 1/4 turn 4 times to verif no oat 9585'. Set 50k down. -Up Wt. 245k /Down Wt. 205k 07:30 - 09:30 2.00 CASE P TIEB2 Space out the casing and make up the cement head. 09:30 - 10:00 0.50 CEMT P TIEB2 Circulate heated seawater 25 gpm, psi. 10:00 - 12:30 2.50 CEMT P TIEB2 Pump 5 bbls of water to pressure test the lines to 4500 psi. Good Test. -Drop Bottom plug and pump 80 bbls (384sks) of Class "G" 15.8 Lead cement wit as o . -Follow with 175 bbls (847 sks) of Class "G" 15.8ppg Tail Cement. -Kick out the top plug with 5 bbls of water to flush the lines from SWS. -Switch over to the rig pumps and displace with 361 bbls of seawater. -Bump the plug at 6287 stks at 1.5 bpm with final circulating pressure of 3950 psi and bumped the plug at 4450 psi. -Check Floats. Held. Bleed off pressure -CIP 12:30 -20 bbls of cement back to surface. 12:30 - 13:00 0.50 CEMT P TIEB2 Pressure up to 3500 psi and hold for 30 minutes to test the 7" casin .Good Test. 13:00 - 14:00 1.00 CEMT P TIEB2 Laydown the cement head and flush out the stack. 14:00 - 15:00 1.00 WHSUR P TIEB2 Nipple down the stack and pull 165k on 7 "casing. Install the emergency slips and slack off wt. 15:00 - 16:30 1.50 WHSUR P TIE62 Rig up the Wachs cutter and cut the 7" casing and lay down the 7" cut joint (20.27' cut). Remove the riser and stand back the BOPE stack. 16:30 - 21:00 4.50 WHSUR P TIEB2 Nipple up the tubing spool and pressure test the void to 4320 psi for 30 minutes. Good Test. Install the stack, turnbuckles, Printed: 4/13/2009 2:50:03 PM BP EXPLORATION Page 15 of 17 Operations Summary Report Legal Well Name: B-25 Common Well Name: B-25 Spud Date: 10/14/1982 Event Name: WORKOVER Start: 2/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/29/2009 Rig Name: NABORS 2ES Rig Number: Date ~ From - To Hours ', Task Code', NPT I Phase Description of Operations 3/24/2009 16:30 - 21:00 4.50 WHSUR P TIEB2 riser, and mousehole. 21:00 - 22:30 1.50 BOPSU P TIEB2 Chan a out the top rams to 3 1/2" x 6" Variable rams and fill the stack. 22:30 - 00:00 1.50 BOPSU P TIEB2 Test the top rams with the 4" and 4.5" test joints to 250 psi low / 3500 psi high. Good Tests. Test witnessed by NAD Toolpusher Ken Helf and BP WSL Chris Kobuck. 3/25/2009 00:00 - 02:00 2.00 CLEAN P CLEAN Make up 7" tieback clean out BHA 02:00 - 05:30 3.50 CLEAN P 05:30 - 09:00 3.50 CLEAN P 09:00 - 10:00 I 1.001 CLEAN I P 10:00 - 13:30 3.50 CLEAN P 13:30 - 14:30 1.00 CLEAN P 14:30 - 16:00 I 1.501 CLEAN I P -6.125" ATJ-4 Mill Tooth Bit -(2) Boot Baskets -Bit Sub with ported float -(6) 4.75" Drill Collars -Fishing Jars -XO to HT40 CLEAN RIH from 206.43' to 9429' on 4" drill pipe. CLEAN Wash down from 9429' to 9480' where we tagged the cement. Drilled u the float collar and cement from 9480' to 9606'. Wash down to 9616', had trouble rotating, pumped a steel tube sweep and torque reduced from 9k to 4k. -500 gpm @ 2780 psi. -Up Wt. 175k /Down Wt. 115k /Rot 150k -60 RPM / TO 5k / WOB 15-20k CLEAN Pump Hi-Vis Sweep at 500 gpm @ 2560 psi. Pumped a dry job and prepared to TOH. CLEAN Tri out of the hole from 9616' to the top of the BHA at 206'. CLEAN Laydown the BHA and clean out the boot baskets. which were full of cement. CLEAN Make u RCJB BHA to 217'. Consists of: -RCJB -Double Pin XO -(2) Boot Baskets -7" Scraper -Bit Sub -(6) Drill Collars -Oil Jars -XO to HT40 16:00 - 20:00 ~ 4.00 ~ CLEAN ~ P 20:00 - 21:00 1.00 i CLEAN P 21:00 - 00:00 I 3.001 CLEAN I P 3/26/2009 100:00 - 02:00 I 2.00 I CLEAN I P CLEAN Run in the hole from 217' to 9534' on 4" Drill pipe. Establish circulation at 348 gpm @ 1786 psi and wash down 9623'. Dropped the RCJB ball, stopped the pumps, dry drilled to 9623'. Pick up a single, started the pumps with RCJB in reverse mode and wash down to 9640'. -250 gpm @ 1070 psi -18 RPM /Torque 5k CLEAN Circulate Hi-Vis Sweep surface to surface at 250 gpm C~ 1070 psi. Saw a significant amount of sand across the shakers, circulated until it cleaned up. Prepare to trip out of the hole. CLEAN Monitor the well, static. Trip out of the hole from 9640' to 1156'. CLEAN Pull out of the hole from 1156' with the RCJB BHA and lay down the entire BHA. RCJB and 1 boot basket were clear of any debris, 1 boot basket had some sand in it. Printed: 4/13/2009 2:50:03 PM • • BP EXPLORATION Page 16 of 17 Operations Summary Report Legal Well Name: B-25 Common Well Name: B-25 Spud Date: 10/14/1982 Event Name: WORKOVER Start: 2/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/29/2009 Rig Name: NABOBS 2ES Rig Number: Date ~~I From - To Hours , Task ,Code NPT Phase Description of Operations 3/26/2009 02:00 - 03:00 1.00 CLEAN P CLEAN Clean and clear the floor and prepare to run the RBP retrieval tool. 03:00 - 06:30 3.50 CLEAN P CLEAN Run in the hole to 9640' with RBP retrieval tool on 4" drill i e. 06:30 - 07:00 0.50 CLEAN P CLEAN Wash down to 9650' and engage the RBP. 07:00 - 07:30 0.50 CLEAN P CLEAN Pump Hi-Vis sweep. -525 gpm ~ 2250 psi 07:30 - 09:00 1.50 CLEAN P CLEAN Release the RBP, Pulling tight, so work down 10k past the setting depth. Pull 10k over C~3 9577', work up and down, rot 1/2 turn and it worked free. Pull out of the hole to 9204'. 09:00 - 09:30 0.50 CLEAN P CLEAN Service top drive and crown. 09:30 - 14:00 4.50 CLEAN P CLEAN Trip out of the hole from 9204'. Inspect the RBP, which was missin a small o-rin ,but everything else looked good. La down the RBP and prepare to run in the hole for the 2nd RBP. 14:00 - 17:30 3.50 CLEAN P CLEAN Pick up RBP retrieval BHA and run in the hole on 4" drill pipe to 9673'. BHA consists of: -RBP retrieval tool -Double Pin -(2) Boot Baskets -Bit Sub -XO to HT40 17:30 - 18:30 1.00 CLEAN P CLEAN Slip and cut 89' of drilling line, service the draw works. 18:30 - 20:00 1.50 CLEAN P CLEAN Establish up and down wt. baselines, circulate 245gpm ~ 700 psi. Slack off to engage the RBP. Pump sweep 495gpm 1676 psi. 20:00 - 21:00 1.00 CLEAN P CLEAN Slack off 105k turn right and pick up 175k to release plug. Pump a bottoms up 367 gpm C~ 910 psi. Slack off past the depth to verify the RBP has been released. 21:00 - 00:00 3.00 CLEAN P CLEAN Tri out of the hole la in down the drill pipe from 9748' to 5802'. Average loss rate of 170bph. 3/27/2009 00:00 - 05:30 5.50 CLEAN P CLEAN Continue out of the hole from 5802' with the RBP while laying down drill pipe. 05:30 - 06:00 0.50 CLEAN P CLEAN Clean and clear the floor and pull the wear ring. 06:00 - 09:00 3.00 BUNCO P RUNCMP Ri u to run 4.5" Vam To Com letion. 09:00 - 13:30 4.50 BUNCO P RUNCMP Run to 3308' with 4.5" Vam Top 12.6# 13Cr80 completion. Average torque of 4400ft/Ibs. Consists of: -W LEG -XN Nipple -X Nipple w/RHC-M Plug -Baker S3 Packer -X-Nipple -(3)GLM's 13:30 - 14:30 1.00 BUNCO RUNCMP Safet standdown with Alan Madsen, Dan Herbert,Cleve Coyne, Bill Decker, Dick Maskell, and NAD rig crews about 60 days notice of stackout. 14:30 - 16:00 1.50 BUNCO RREP RUNCMP Work on the stabbing board motor due to leaking seal. 16:00 - 00:00 8.00 BUNCO P RUNCMP Continue in the hole with 4.5" Vam Top 12.6# 13Cr80 completion from 3308' to 8081'. Average torque of 4400ft/Ibs. Consists of remainder of completion jewelery: -(2) GLM's -X-Nipple 3/28/2009 00:00 - 03:30 3.50 BUNCO P RUNCMP Continue in the hole with 4.5" Vam Top 12.6# 13Cr80 Printed: 4/13/2009 2:50:03 PM • • BP EXPLORATION Page 17 of 17 Operations Summary Report Legal Well Name: B-25 Common Well Name: B-25 Spud Date: 10/14/1982 Event Name: WORKOVER Start: 2/25/2009 End: Contractor Name: NABOBS ALASKA DRI LLING I Rig Release: 3/29/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task 'Code NPT .Phase Description of Operations 3/28!2009 00:00 - 03:30 3.50 BUNCO P RUNCMP Completion from 8081' to 9616'. Average torque of 4400 fUlbs. Land hanger and run in lock down screws. 03:30 - 05:00 1.50 BUNCO P RUNCMP Drop ball and rod, pump 150bb1s of corrision inhibited seawater down annulus followed by 75 bbls of seawater. Pressure u tubin to 4000 si to set acker. 05:00 - 06:30 1.50 BUNCO P RUNCMP Bleed pressure to 3500 psi and test the tubing for 30 minutes and chart. Bleed tubin down to 2000 si. then pressure annulus to 3500 si. and chart for 30 minutes. Bleed off all of the ressure and then ressure u on the annulus to 2800 si _ to shear the DCK shear valve. Pump 3 bbls both ways to insure the valve sheared. 06:30 - 07:30 1.00 BUNCO P RUNCMP Install the TWC and test from above to 3500 and from below to 1000 si. Both ood test. 07:30 - 12:00 4.50 BOPSU P RUNCMP Nipple down the BOPE and the double studded adaptor. 12:00 - 14:00 2.00 BOPSU P RUNCMP Nipple up the tree and pressure test the adaptor flange to 5000 psi for 30 minutes. Good test. Pressure test the tree to 5000 psi for 10 minutes. Good test. 14:00 - 15:00 1.00 BOPSU P RUNCMP Rig up DSM and pressure test the lubricator and pull the TWC. 15:00 - 00:00 9.00 BOPSU P RUNCMP Rig up LRS and pump 70 bbls of 80 degree diesel ~ 2 bpm with a pressure of 700 psi. Allow to U-tube. 3/29/2009 00:00 - 04:00 4.00 WHSUR P RUNCMP Set the BPV, secure the well and release the rig C~ 04:00. Printed: 4/13/2009 2:50:03 PM • B-25 Well History Date Summary 01/30/09 T/I/0=20/40/40 Temp=Sl MIT IA PASSED to 1000 psi. (RWO Prep) Pumped 4.5 bbls of 0'F crude down IA to reach 1000 psi for ITIA. Tbg lost 20 psi in the first 15 mins and 0 psi in the 2nd 15 mins for a total pressure loss of 20 psi in the 30 min test. Bled pressures. Verified casing valves open and tagged. Final W H P's =20/40/40. 01/31/09 T/I/0= 0/140/0 Temp=SI..CMIT TxIA PASSED to 1000 psi. (RWO Prep) Fluid packed Tbg with 18 bbls crude. Pressured up Tbg with additional 1.8 bbls crude. Communication to IA. Performed CMIT with a total of 23.8 bbls crude pumped. T/IA lost 40/50 psi in the 1st 15 mins and 0/10 psi in the 2nd 15 min for a total pressure loss of 40/60 psi in 30 min test. Bled Tbg to 0 psi, no significant communication from the IA to the Tbg, suspect one way leak. Bleed down. FWHP's=0/0/0 02/05/09 T/I/0= 110/90/0. Temp= SI. Bleed TBG, IA, OA to 0 psi pre PPPOT. AL connected, ALP= 2020 psi, SI @ casing valve. TBG & IA FL @ surface. Bled IAP from 90 psi to 0 psi in 4.5 hr, (fluid then fluid & gas, last two hr, all gas). Had grease crew service Wing & AL valve. Bled TP from 110 psi to 0 psi in 3 hr, (fluid then fluid & gas). Monitored for 30 min, TP increased 10 psi, IAP increased 5 psi. Final WHPs= 10/5/0. SV,WV,AL= C. SSV,MV= O. IA,OA= OTG. NOVP. 02/13/09 RU ELINE, 3.65" POWER JET CUTTER, CUT DEPTH = 9491.7', CCL TO CUT DEPTH = 12', CCL STOP DEPTH = 9479.7', POSITIVE SURFACE INDICATION OF CUTTER FIRE. PRESSURES UNCHANGED. MASTER OPEN, WING CLOSED, SSV CLOSED. 02/15/09 T/I/0=140/70/0. Temp=S1. Bleed WHP to 0 psi (pre PPPOT). AL connected & SI @ casing valve, ALP=2000 psi. TBG FL @ surface, IA FL @ 42', OA FL near surface. Bleed Tank showed up at change out."'* 02/16/09 T/I/0=140/70/0. Temp=Sl. Bleed WHP to 0 psi (pre PPPOT). AL blinded & SI @ casing valve, ALP=2000 psi. IA FL @ 42'. Bled IAP from 70 psi to 0 psi in 1 hr (gas/fluid). Monitored for 30 mins, IAP unchanged.TBG FL @ surface. Bled TP from 140 psi to 0 psi in 2 hrs (fluid). Monitored for 30 mins, TP unchanged. Final WHPs=O/0/0. SV, WV=Closed. SSV, MV=Open. IA & OA=OTG. NOVP. T/IA/OA= 0/0/0= Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) / PPPOT-T DHD bled WHP to 0 psi, opened SBS verified 0 psi in void, removed 1" NPT plug, removed C internal check, installed Alemite fitting. RU HP BT onto THA flushed void until clean returns achieved. Pressure void to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, RD all test equipment. Cycle and torque LDS "Standard" all were in good working and visual condition. PPPOT-IC Verified 0 psi with SBS verified 0 psi in void, removed Alemite, removed internal check, re- installed Alemite test fitting. RU HP BT onto IC test void, flushed void until clean returns achieved. Pressure for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled IC void to 0 psi, RD all test equipm~ 02/19/09 T/I/O=0/0/0 Circ-Out (RWO Prep) Pumped 5 bbls neat and 360 bbls of seawater down Tbg taking returns from IA to B-33's flowline. 02/20/09 Circ-out (Pre RWO) Pumped a total of 965 bbls seawater and 137 bbls diesel down Tbg taking returns from IA to B-33's flowline. U-tubed diesel freeze protect from Tbg to IA. Pumped 2 bbls neat an 5 ~bfs diesel down jumper line to B-33. Bled pressures to 0 psi. Final WHPs=O/0/0. SV=C, SSV=O, MV=O, WV=C, IAV=OTG, IA-ALV=C, OAV=OTG. 02/23/09 T/I/O=Vac/0/0. Set 4-1/16" CIW H BPV #111 thru tree, pre rig. 1-2' ext used, tagged @ 102". No (~~ problems. C-` S 03/03/09 T/I/O=0/0/0 Pull 4' CIW BPV#111 thru the tree for rig to move over well, 1-2' ext used, tagged @ 98 no problems. 2ES 03/28/09 T/I/0=0/0/0; Pulled 4-1/16" CIW "H" TWC #255 thru tree for 2ES Completion; 1-2' ext. 100' ; ._ Page 1 of 2 ~.J B-25 Well History U Date Summary 03/29/09 T/I/0= 100/0/0 Set 4 1/16 CIW H BPV # 138 thru tree. 1-2' ext used, tagged @ 98". For 2ES to move off well. No pro ems 03/31/09 T/I/0=750/900/0; Pulled 4-1/16" CIW "H" BPV #138 thru tree post 2ES; 1-2' ext. used, tagged @ 102"; '"Complete*" (Best/Fraker) 04/03/09 PULLED BALL & ROD @ 9516'SLM. PULLED BK-DGLV'S FROM STA #4 & #5 (DCK). SET BK-DOME STA #5 @ 3393'SLM & BK-OGLV IN STA #4 @ 5818'SLM. PULLED 4 1/2" RHC PLUG BODY @ 9520'SLM. DRIFT OUT TT W/4.5" GS -RIG HAND OVER SHOWED SECOND RHC PLUG BODY IN XN NIPPLE - NO SECOND RHC IN HOLE. DRIFTED W/3 3/8" DUMMY GUN TO TD. 10,036' CORRECTED TO MD Page 2 of 2 B-25 9-5/8 Cement Job Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, March 16, 2009 9:29 AM To: Regg, James B (DOA) Subject: RE: B-25 (182-151) 9-5/8 Cement Job Interesting; this is the first recent pipe-in-pipe cementing operation I can recall that lost returns. From: Regg, James B (DOA) Sent: Monday, March 16, 2009 9:04 AM To: Maunder, Thomas E (DOA) Subject: FW: B-25 9-5/8 Cement )ob Jim Regg AOGCC Page 1 of ~ ~1 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 _. From: Marlyn, Matthew [mailto:Matthew.Martyn@bp.com] Sent: Saturday, March 14, 2009 3:36 PM To: DOA AOGCC Prudhoe Bay Cc: Roach, Frank; NSU, ADW Drlg Field Superintendent; NSU, ADW Drlg Rig 2es Subject: B-25 9-5/8 Cement Job Mr. Grimaldi, As requested, here is a brief recap of the events that took place during cementing of the 9-5/8" tieback on B-25. As described in the workover program, the wellbore had parted 13-3/8" surface casing and 2 pressure tested barriers in the wellbore. Nabors 2ES cut and pulled the top 2050' of existing 9-5/$" intermediate casing, cut and removed the original top of 13-3/8" surface casing and wellhead. The rig installed new 9-5/8" casing with a sealing patch over the top of the original casing stub. Primary cementing took place through a stage collar to fill the 9-5/8 x 13-318" annulus to surface where a new wellhead would be built on the top of the 9-5/8" casing. 140 bbls of cement were pumped to fill a 118 bbl annulus. Good lifting pressure was seen throughout the job however approximately 10 bbls prior to plug bump retums were lost and the seawater retums that we had been taking to the cellar fell down both Conductor x 13- 3/8" and 13-3/8" x 9-5/8" annuli. Plug bumped, sheared closed. Lou Grimaldi was notified of the results and the plan for tap-off and wiaved witness of the secondary cement job. Using 1" pipe, the rig tagged up on top of cement in the 13-3/8" x 9-5/8" annulus at 65' and in the Conductor x 13- 3/8" annulus at 50'. After pumping 15 bbls of 15.8 ppg Class G through 1" pipe from the bottom of the 13-3/8" x 9-5/8" annulus, cement returns were flowing up through both annuli. Continued to pump until 24 bbls away. After rigging down and waiting 12 hours, cement has slumped down ~8 inches. After notifying Lou Grimaldi, we are continuing on with the operation. Matt Marlyn Well Site Leader -Rig 2ES GPB Rotary -Prudhoe Bay, Alaska (907) 659-4103 -Rig office ~~ ~~ ~~` ~c®~ 4121/2009 03/18/09 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth N0.5133 Company: State of Alaska Alaska Oil & Gas Cons Comm ,, , ,~ ~ p ~ Attn: Christine Mahnken ,. i ~ ~'` ~' lk ~ ~. ~Csx ~• , ' -• r 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~,. wPu _~.,ti ~ ~,~~'~ ~"~ ,. _ (~i. ~ y ~~._. .1 ~ ..,~" J-27A AY3J-00010 CBL - j 02/21!09 1 1 S-107 AWJB-26 MEM L L V ~ ~- 02/25/09 1 09-34A AZ4D-00005 _ USIT (REVISED) 02/07/09 1 1 V-210 AWJB-00025 INJECTION PROFILE 02/23!09 1 1 MPB-22A AXBD-00005 MEM SCMT & TEMP PROFILE . ., (D r 12/23/08 1 1 V-219 12103700 USIT (REVISION #2) .- ~ ( 11/21/08 1 1 11-18 BOCV-00006 PRODUCTION LOG / E/ - 03/02/09 1 1 B-25 AVYS-00023 USIT - /t /~ 03/OW09 1 1 N-18A AYKP-00013 PRODUCTION LOG '~- ('~ S l ~ 03/11/09 1 1 F-18 AVY5-00022 USIT j ,- ~%^ _ ''3- 03/04/09 1 1 3-19/R-28 AZ4D-00009 LDL ~/ - ( 03/06/09 1 1 V-117 BOOR-00003 MEM PRODUCTION PROFILE ~p - ( ~ 03/12/09 1 1 V-211 AY3J-00014 (PROF/RST WFL - ~ 03/16/09 1 1 V-214 AY3J-00013 IPROF/RST WFL - 03/15/09 1 1 K-06B AWJ!-00017 MCNL ~ 01/28/09 1 1 L5-15 12113027 RST - /O '~} / - 12/09/08 1 1 07-18 12071915 RST ~j 12/01/08 1 1 15-15C AWJI-00015 MCNL ~ ( 01/02/09 1 1 W-218 40018337 OH MWD/LWD EDIT / 12/07/08 2 1 R-41 40018496 OH MWD/I.WD EDIT ~ j / 01/04/09 2 1 H-18 11999064 RST / - I ~- .12/03/08 1 1 `_ - . __..__ .._.-..-.. ~~~...~ ..-.. ~.. .........................~.. vn..u.aa v.~c a.vr ~ cna.n ~ v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: FPa~ ~ -a l'~ ' v ~ w Q- o ~-- a wt ~ l >a/cX~ ' ~ 3~l dl- i ~ r~ Co~~ re.Gf ~u ec~1 3 ~2l off` Alaska Data & Consulting Services 2525 Gambell Sirectt ,. 0 .-~ . Anchorage, AK`,96~Q3+0 ~ ii ~ ~` ATTN: Beth "'" _ Received bY: - k'~L"~_ ft~ ra ?ll~ al.d A~, B-25 9-5/8 Cement Job • • Page 1 of 1 Regg, James B (DOA) (STD ~ Sz- 151 From: Martyn, Matthew [Matthew.Martyn@bp.com] Sent: Saturday, March 14, 2009 3:36 PM To: DOA AOGCC Prudhoe Bay Cc: Roach, Frank; NSU, ADW Drlg Field Superintendent; NSU, ADW Drlg Rig 2es Subject: B-25 9-5/8 Cement Job Mr. Grimaldi, As requested, here is a brief recap of the events that took place during cementing of the 9-5/8" tieback on B-25. As described in the workover program, the wellbore had parted 13-3/8" surface casing and 2 pressure tested barriers in the wellbore. Nabors 2ES cut and pulled the top 2050' of existing 9-5/8" intermediate casing, cut and removed the original top of 13-3/8" surface casing and wellhead. The rig installed new 9-5/8" casing with a sealing patch over the top of the original casing stub. Primary cementing took place through a stage collar to fill the 9-5/8 x 13-3/8" annulus to surface where a new wellhead would be built on the top of the 9-5/8" casing. 140 bbls of cement were pumped to fill a 118 bbl annulus. Good lifting pressure was seen throughout the job however approximately 10 bbls prior to plug bump returns were lost and the seawater returns that we had been taking to the cellar fell down both Conductor x 13- 3/8" and 13-3/8" x 9-5/8" annuli. Plug bumped, sheared closed. Lou Grimaldi was notified of the results and the plan for top-off and wiaved witness of the secondary cement job. Using 1" pipe, the rig tagged up on top of cement in the 13-3/8" x 9-5/8" annulus at 65' and in the Conductor x 13- 3/8" annulus at 50'. After pumping 15 bbls of 15.8 ppg Class G through 1" pipe from the bottom of the 13-3/8" x 9-5/8" annulus, cement returns were flowing up through both annuli. Continued to pump until 24 bbls away. After rigging down and waiting 12 hours, cement has slumped down ~8 inches. After notifying Lou Grimaldi, we are continuing on with the operation. Matt Martyn Well Site Leader -Rig 2ES GPB Rotary -Prudhoe Bay, Alaska ~ ~. ~A~ ~ `~ ~~~ (907) 659-4103 -Rig office (907) 632-3862 -Work cell (907) 230-8732 -Personal cell 3/16/2009 B-25 (PTD 309-046) BOP test ~ Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, March 10, 2009 4:31 PM To: 'Hobbs, Greg S (ANC)' Cc: NSU, ADW Drlg Rig 2es; Roach, Frank Subject: RE: B-25 (PTD 182-151) BOP test Greg and Frank, I missed, the PTD is 182-151. The sundry is 309-046. Tom From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs@bp.com] Sent: Tuesday, March 10, 2009 4:25 PM To: Maunder, Thomas E (DOA) Cc: NSU, ADW Drlg Rig 2es; Roach, Frank Subject: RE: B-25 (PTD 309-046) BOP test Thank you Tom- I will cc the rig with this mail to allow them to forward it to Jeff. Have a great evening and thanks for the quick response- Greg ~~~~~~~~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, March 10, 2009 4:20 PM To: Roach, Frank Cc: Hobbs, Greg S (ANC) Subject: RE: B-25 (PTD 309-046) BOP test Greg and Frank, I would agree that looking at your forward operations and since there are multiple barriers between "you" and the reservoir, it is not necessary to test the BOP prior to running your tieback. You are correct that a full test will be necessary are NU on the new wellhead. Thanks for asking the questions in advance. Call or message with any questions. Tom Maunder, PE AOGCC From: Roach, Frank [mailto:Frank.Roach@bp.com] Sent: Tuesday, March 10, 2009 3:54 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: B-25 (PTD 309-046) BOP test Mr. Maunder, On B-25 (PTD: 309-046), we are currently in the process of preparing to run 9-5/8" casing to tieback to surface. There are two tested barriers to the producing formation in the hole. Plan forward is to nipple down BOPE, cut 3/11 /2009 B-25 (PTD 309-046) BOP test • Page 2 of 2 and remove wellhead, run 9-5/8" casing to tieback and cement to surface. Once 500 psi compressive strengths has been reached, the casing will be cut at the needed working height, a new wellhead installed and tested, and the BOPE nippled back up and tested. Current test schedule has our 7-day BOPE test due at midnight, March 11 (tomorrow). With the BOP stack off and wellhead removed prior to the test due date, our plan is to test the BOPE after nippling upon the new wellhead. Matt Martyn has made Jeff Jones aware of this situation, and he recommended that we a-mail you on the issue. If there are any concerns or comments, feel free to contact me at 854-2321. Regards, -Frank Roach 3/11/2009 • • d 0 ~ ~ ~ SARAH PAL1N, GOVERNOR ALA58A OIL A1QD GcA-S 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA7'IO1~T COMIrII55I011T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 ~~," ~ ~~ ~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU B-25 Sundry Number: 309 046 {~'~ Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~c~~~~ Daniel T. Seamount, Jr. Chair DATED this ~ ~ day of February, 2009 Encl. ~b. ~~ b~~°I STATE OF ALASKA ~~ ;; ~~ ALf~ OIL AND GAS CONSERVATION COMeSION `~ ~'' ~ APPLICATION FOR SUNDRY APPROVAL ,'~'~~~. ~~~ ~~ '~'' 20 AAC 25.280 l ~ ~ ~~'~ ~ `~ ~' ,, "°' li',~r 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension !/}} ® After Casing - -® Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspend'II~ .y ~ , , ^ Change Approved Program ,® Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other t~~a 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ ®Development ^ Exploratory 182-151 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20826-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 8-25 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): , ADL 028310 80.2' Prudhoe Bay Field / Prudhoe Bay Oil Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10706' - 9500' 10150' 8973' 9576' & 10023' Yes, Below Cmt i L n th i TV Bu t olla Stru ural 11 11 Surfa 748' 1 - /8" 2748' 49 7 In rm is a 37' / " 7' 8684' 87 4760 P in in r 1118' 7" ' - 1 7 452' - 94 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below PIuA: 9862' - 10088' 8707 - 8916' 4-1/2", 12.6# 13Cr80 9589' ~a~ooss-~o~,a> Packers and SSSV Type: 9-5/8" x 4-1/2" TIW 'HBBP' packer; Packers and SSSV MD (ft): 9506 ; 7" x 4-1/2" Otis'WD' packer 10095' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: March 1, 2009 , ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the f egoing is true and correct to the best of my knowledge. Contact Frank Roach, 564-4373 Printed Name Gr ~ bs Title Engineering Team Leader Prepared By Name/Number Signature Phone 564-4191 Date ~ y Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: g , ~~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~OP Test ^ Mechanical Integrity Test ^ Location Clearance Other: 35®4 ~,`~ t~.~~~~ i t~~~ ~5 < <`~`w~"~ v~.,~o~ ~`~- Q.~1~~,J ~,G.~ ~c-,~' ~~~y~~ ~.~~--t ~ S c-~ ~ ~ 1~ Z G,ccs~.Q k-G~J ~ F ~ ,~c7 ~ p, Cam, S -_ ~-~S'C~~ Subsequent Form Required: '~`® APPROVED BY 7 h' A rwe~ 8 : C~MMISSI~NER THE C~MMISSI~N Date [..~ Form 10-403 Fte~dY06/2006 Submit In Duplicate • B-25 Expense Rig Workover • Scope of Work: Pull 4-'/z" completion, cut and pull 9 5/" casing, remove wellhead, run 9 5/8" casing and cement to surface, install new wellhead, mill and recover packer and tailpipe, run 7" tieback and cement to surface, run 4-~h" 13Cr-80 premium thread completion. y Other Requests: ~~-`~~~ ~ ~~ Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. MASP: 2300 psi Well Type: Producer Estimated Start Date: March 1, 2009 Production Engineer: AI Schmoyer Intervention Engineer: Frank Roach Pre-Rig Work: F 1 CMIT TxIA to 1000 psi to confirm PX plug barrier. If test fails, attempt at 500 psi. If still failing, establish LLR and notif town ODE. S 2 Drift w/DMY 'et cutter --9492' E 3 If CMIT passes, Power Jet Cut tubing ~ 9492' MD (jet cut desired to be in the top 2' of the 9.91' u 'oint above the to SWS ni le F 4 Circulate well to seawater. FP with diesel to 2000' W 5 Check the tubing hanger lock down screws for free movement. Completely back out and .check each lock down screw for breaka a check one at a time . PPPOT-T & IC. V 6 Set BPV in tubing hanger. Remove the well house & flow line. Level the pad as needed for the ri . D 7 Line the Cellar around the wellhead with im ermeable, s ra -sealed Herculite. Proposed Procedure Summary: 1. MIRU. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. ND tree. NU BOPE and pressure test to 250 psi low / 3500 psi high. 3. Pull and LD 4-'/z" tubing string to the cut. 4. Set RBP C 9400' MD. 5. Run USIT log to determine top of cement in 9-5/a" x 13-3/8" annulus. 6. Set retrievable bridge plug 600' below the top of cement. 7 8. 9. 10 11 12 13 14 15 16 17 18 19 20 21 22 C~ • Cut and pull 9 5/8" casing from above the top of cement. Plan is to take returns to lined cellar. Note: / Pipe rams will not be changed to 9-5/a" as the well has two tested barriers (Two RBPs) to the v reservoir. ND BOPs, Cut 13 3/8" casing just below casing spool, remove casing spool. Run and fully cement new 9 5/8" casing to surface. Install new wellhead on 9 5/8" casing. NU and test BOPs to 3500 psi. Pressure test new casing and drill out shoetrack. Clean out to retrievable bridge plug(s) and retrieve same. Mill and retrieve packer and tbg tail. Set RBP below existing 7" liner hanger C«? 9600' MD. ~ ~~ ~.~ ~..r~p c~~ ~ C~~S Run new 7" casing from 7" tieback sleeve to surface a furlfJ Ily cement slime. ~.~?~ Pressure test new casing and drill out shoetrack. ~~~ ~~~ Clean out to retrievable bridge plug and retrieve same. Run 4-~/z" 13Cr-80 completion with Baker S-3 packer. Displace the IA to completion fluid and set the packer. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = 4" CNV WELLHEAD= MCEVOY ACTUATOR= OTIS KB: ELEV = 80.19' BF. ELEV = 44.69' KOP = 2000' Max Angle = 38 @ 6600' Datum MD = 10050' DatumTVD= 8800'SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 2748' Minimum ID = 3.831" @ 1988 4-1/2" OTIS SSSV LANDING NIP 4-1/2" TBG, 12.6#, 13CR, .0152 bpf, ID = 3.958" ~ 9587' TOP OF 7" LNR 95$3' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9837' PERFORAT~N SUMMARY REF LOG: DA-BHCA ON 10/31/82 ANGLE AT TOP PERF: 24 @ 9862' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9861 - 9881 S 11 /23/90 3-3/8" 4 9862 - 9882 C 05/25/94 3-1 i8" 4 9918 - 10018 S 11 /23/90 3-1/8" 4 9970 - 9980 S 05/17/91 3-1/8" 4 9990 - 10020 S 05/17/91 3-3/8" 4 9990 - 10020 C 05/30/91 3-1/8" 4 10030-10088 S 05/17/91 3-3/8" 4 10030- 10088 C 06/11/92 3-118" 4 10120 - 10130 S 05/17/91 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 10110' PBTD 10150' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~-{ 10700' SAFETY 1~'JT~ *"' 4112' CI'f~VIETBG'""' 1988' 4-1/2" OTIS SSSV Landing NIP, ID = 3.813" FOC GAS LIFE MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3179 2970 22 MMG DMY RK 0 11 /29/03 4 6102 5397 24 MMG DMY RK 0 11 /29/03 3 8153 7081 14 MMG DMY RK 0 11 /29/03 2 9366 8175 11 MMG DMY RK 0 1 9471 8270 10 MMG 'DMY RK 0 05/28/06 - t~ i trvutu rH~-urv~ 9$00' 4-1 /2" PKR SWS Nom, ID = 3.813" 9506' 9-5/8" x 4-1l2" TNV HBBP, ID = 4.750" 9554' 4-1/2" PKR SWS NIP, ID = 3.813" 9rj76' 4-1/2" PKR SWS NIP, ID = 3.813" 9576' 4-1/2" PX PLUG (06-14-06) 9587' 4-1 /2" TTL WLEG 9596' ELMD TT - LOGG®05130/91 9951' I- j MA RKER JOlnfr I 10023' SANDBACK FOR FRAC 10095' 7" x 4-1/2" OTIS 'WD' PKR ID = 4.0" 10103' 4-1 /2" OTIS X NIP, ID = 3.813" 10108' 4-1 /2" OTIS XN NIP, ID = 3.725" 10110' 4-1/2" TTL WLEG 10110' ELM TT -LOGGED 05/30/91 10139' FISH -JUNK BASKET, TAPER® MILL, CEMEiVTED IN HOLE 10650' ¢ DRILL PLUG DATE REV BY COMMENTS DATE REV BY COMMENTS 11/05/82 ORIGINAL COMPLETION 02/21/06 RPH/TLH WAIVERSFIY NOTEDELET® 05/18/01 RWO 05/28/06 TEL/PJC GLV GO 01/06/05 RDJ/PAG WAVER SAFETY NOTE 06/14/06 TEUPJC SET PX PLUG @ 9576' 07/06/05 HS/TLH TBG L-80 TO CHROME 01/25/06 TEL/TLH PX PLUG SET 02/05/06 DTR/PJC PULL PX PLUG @ 9576' PRUDHOE BAY UNff WELL: B-25 PERMfT No: 1821510 API No: 50-029-20826-00 Sec. 31, T11N, R14E BP 6cploration (Alaska) TREE = 4" CNV 'I KB. ELEV = 80.19' BF. ELEV = 44.69' KOP = ~ 2000' Max Angle = 38 @ 6600' Datum MD = 10050' Datum TV D= 8800'SS 9-5/8" CSG, 47#, L-80, ID = 8.681" 13-3/8" CSG, 72#, L-80, ID = 12.347" ~4-1/2" HES X NIP, ID = 3.813" I FOC I GAS LIFT MANDRELS B ~Z 5 SAF NOTES: ""' 4-1/2" CHROM E TBG ""* W D BUILT OFF OF 9-5/8" CASING PROPOSED Minimum ID = 3.725" @ XXXX 4-112" HALLIBURTON XN NIP ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 4 3 2 1 4-1/2" HES X NIP, ID = 3.813" I 7" x 4-1/2" BAKER S-3 PKR, ID = 3.875" 4-1/2" HES X NIP, ID = 3.813" 4-1/2" HES XN NIP, ID = 3.725" 4-1/2" TBG, 12.6#, 13CR, .0152 bpf, ID = 3.958" I- 7" TIEBACK, 26#, L-80, .0383 bpf, ID = 6.276" TOP OF 7" LNR 9583' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9837' PERFORATION SUMMARY REF LOG: DA-BHCA ON 10/31/82 ANGLE AT TOP PERF: 24 @ 9862' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9861 - 9881 S 11 /23/90 3-318" 4 9862 - 9882 C 05/25/94 3-118" 4 9918 - 10018 S 11/23/90 3-1/8" 4 9970 - 9980 S 05/17/91 3-1/8" 4 9990 - 10020 S 05/17/91 3-318" 4 9990 - 10020 C 05/30/91 3-1/8" 4 10030 - 10088 S 05/17/91 3-3/8" 4 10030 - 10088 C 06/11/92 3-1/8" 4 10120 - 10130 S 05/17/91 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10110' PBTD -{ 10150' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I-i 10700' 4-1l2" WLEG 9596' ELMD TT -LOGGED 05/30/91 9951' ~ MA RKER JOINT 10023' SANDBACK FOR FRAC 10095' 7" x 4-1 /2" OTIS 'WD' PKR ID = 4.0" 10103' -(4-1/2" OTIS X NIP, ID = 3.813" 10108' 4-1/2" OTIS XN NIP, ID = 3.725" 10110' Ma-v2° TTL WLEG ~ 10110' ELM TT -LOGGED 05/30/91 10139' FISH -JUNK BASKET, TAPERED MILL, CEMENTED IN HOLE 10650' H ¢ DR~L PLUG DATE REV BY COMMENTS DATE REV BY COMMENTS 11/05/82 ORIGINALCOMPLETION 02/21/06 RPH/TLH WANERSFTYNOTEDELET® 05/18/01 RWO 05!28/06 TEVPJC GLV GO 01/06/05 RDJ/PAG WAVER SAFETY NOTE 06/14/06 TEUPJC SET PX PLUG @ 9576' 07/06!05 HS/TLH TBG L-80 TO CHROME 02/02/09 FVR RWO DRAFT 01/25/06 TELlRH PX PLUG SET 02/05/06 DTR/PJC PULL PX PLUG @ 9576' PRUDHOE BAY UNfT WELL: B-25 PERMfT No: 1821510 API No: 50-029-20826-00 Sec. 31, T11 N, R14E BP Exploration (Alaska) Well Job# Lo!! Description Date BL Color CD C-11A 11225983 LDL 07/02106 1 B-25 11217247 LDL 05/11/06 1 F-06A 11258688 PROD PROFILE W/DEFT 03/20/06 1 G-18A 11209612 MEM INJECTION PROFILE 07/19/06 1 P-24 11216206 MEM INJECTION PROFILE 07/06/06 1 B-28 11221590 LDL 07/04/06 1 B-01 11211508 PROD LOG W/DEFT 06/23/06 1 W-39A 11216197 MEM PROD PROFILE OS/29/06 1 Z-02A 11212856 INJECTION PROFILE 05/02/06 1 G-03A 11211493 LDL OS/24/06 1 C-26A 11225979 LDL 06/07/06 1 F-26B N/A MEM PROD & INJECTION 06/06/06 1 F-26B N/A MEM BORAX LOG 06/06/06 1 W-39A 11216197 MEM BORAX LOG OS/29/06 1 F-04A 11221602 SCMT 08/18/06 1 Y -08A 11221604 SCMT 08/20/06 1 C-06B 11212883 USIT 08/15/06 1 X-27 11217274 USIT 08/26/06 1 K-07D 10942217 MEMORY SCMT 06/15/05 1 Y-1OA 11209611 MEM INJECTION PROFILE 07/18/06 1 F-12 11225984 LDL 07/02/06 1 K-07D 11058256 SBHP SURVEY 11/28/05 1 X-04 10919925 PROD PROFILE W/DEFT 12/15/04 1 A-30A 11054295 CH EDIT OF PDC LOG W/GR 04/06/05 1 17-o4B 40010183 OH EDIT OF MWD/LWD (REDO OF TVD DATA) 03/09/04 1 1 Z-30A 40010092 OH EDIT OF MWD/LWD (REDO OF TVD DATA) 01/27/04 1 1 17-04B PB1 40010183 OH EDIT OF MWD/LWD 03/08/04 2 1 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SCANNED SEP 14 2005 liSd- IS-I Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 R· .; -,- ~.. - \. :" ;.::. ,; ;':. .J 08/28/06 .:; lor 1 ... ':;'v(Jò NO. 3941 ~()if & Gas Cons, Co~ ."nd1crage State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Company: Field: Prudhoe Bay . . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth B-25 (PTD #1821510) Internal Waiver Cancellation - Trouble Well e e Subject:~-25 (PTD # 1821510) .Interna~ Waiver Cal1ccllatio~l - Troub.le We',' _ \Zt:rl Z(?1{C6 From: "NSU, ADW Welllntegnty Engmeer" <NSUADWWelllntegntyEngmecr@BP.com> . Hate: Tue, 21 Fcb 2006 14: 13:55 -0900 To: "AOGCC - Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. jim_regg@admin.state.ak.us, "NSU, ADW Well Operations Supervisor" <I\SlJADWWellOperatiol1sSupervisor@BP.com>. "Ross berg, R Steven" <Steven.Rossberg@BP.com>, "GPB, GC3 Area Mgr" <GPBGC3TL@BP.com>, "Kurz, John" <john.kurz@BP,com>, "GPB, GC3 Wellpad Lead" <GPBGC3WellpadLcad@HP.com> CC: "NSU, ADW Well [ntcgrity Engineer" <NSUADW\VelllntcgrityEngineer@BP.com>, "NSU, ADW WI Tech" <NSUAD\VWITech@BP.com>, "Subckti, Hcny" <Herry.Suhckti@ßP.com>, "\Vinslow, Jack L." <Lyons\v@BP.com> All, An internal waiver was issued for a Surface Casing leak on well 8-25 (PTO #1821510) on 01/06/05. The well no longer meets waiver requirements and therefore the waiver is cancelled. The well is currently shut-in with plans evaluate options to repair the tubing. If successful, the well will again be evaluated for SC leak waiver. The well is reclassified as a Trouble well. Please remove all waivered well signs and the laminated copy of the waiver from the well house. Thank you, }t.nna (j)u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 K'sf *\N;:"'\'F\\ ~_}V!j- \;J \~-<~..:.-¡'~ 1 of 1 2/27/2006 12:07 PM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, ~? Commissioner Tom Maunder, P. I. Supervisor ox/\c,,- E~\ FROM: Jeff Jones, SUBJECT: Petroleum Inspector DATE: January 18, 2001 Safety Valve Tests Prudhoe Bay Unit B Pad Thursday, JanUary. 18, 2001' I traveled.to BPXs B Pad and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report shows I witnessed the testing of 17 wells and 34 components with 2 failures. The Pilot on well B-18 tripped below the required set point and the pilot on well B-21 was frozen. Both failures were repaired and-sucessfully retested before I departed location. Th'e new style pilot insulation box fabricated using pipeline insulation installed on most wells on this pad should be installed on .the remaining SVS pilots to eliminate the freeze up problems evident on this pad. I also inspected the well houses on this pad'while witnessing SVS testing. All the well houses inspected were clean and the equipment appeared to be in good condition. Summary: I witnessed the SVS testing at BPXs PBU B Pad PBU B Pad, 17 wells 34 components 2 failures 5.8% failure rate 22 well house inspections Attachment: SVS PBU B Pad 1-18-01 JJ X Unclassified Confidential confidential (Unclassified if doc. removed ) SVS PBU B Pad 1-18-01 JJ.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX · Operator ReP: Merv Liddelow AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Unit/Pad: PBF /PBU /B Pad, Separatorpsi: LPS 174 Date: 1/18/01 HPS 658 Well Permit Separ Set . L/P Test Test Test Date Oil, WAG, G~J, Number Number PSI PSI T~p Code Code Code Passed CAS or CYCLE B.01 1700080 174 125 1.20 P, P OIL B-02A - 1961110658/174 550/125 500/120 P P OIL B-03B 1870480 B-04 1700320 B-05A 1960.990 B-06 1770740 174 125 120 P P OIL B-07 1780020 658 550 520 .P P OILi B-08 1780410!658/174 550/125 510/110 P P OIL B-09 1780490 B-10 1780540 174 125 1'10 P P OIL B-Il . 1780690! B-12A i 1970090 658 550 530 ' P P OIL B-13A ' 1990570 B-14' 1780930 B-15 1790190 B-16 1790250 B-17 1'790280 B-18 1820020 658 550 0 3 P 1/18/01 OIL B-19 1820030 174 125 120 P P OIL B-20 1821680 174 ' 125 120 P P OIL B-21 1821760 '658 550 510 2 P 1/18/01 OIL! B-22 1820890 B-23A 1970590658/174 550/125 550/120 p p OIL B-24 1821400 B-25 1821510 174 ' 125 115 P P OIL B-26B 200057.0 '174 125 125 P P OIL B-27A 1961010 658/174 550/125 520/1'25 P P OIL B-28 1853030 B-29 1860140 B-30 1860310 B-31 1910460 B-32A 1991180 B-33A 1931450 174i 125 115 P P OIL B-34 1930370 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed (;AS or CYCLE B-35 ' 1931460 B-36 1960650658/174550/125 540/120 P P OIL · J-05B 2000180 Wells: 17 Components: 34 Failures: 2 Failure Rate: 5.8% []9o oar Remarks: The 2 failures were corrected and passed a retest. Pad 1-1R-fl1 _Il ~rl.~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 25 April 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL 7 ~ ' ~5 ~-~ ~-~.-~-~ ~ l- ~7~-0~~ qO~ 13~ ~-~ ~ DESCRIPTION 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 GR/CCL FINAL BL+RF ECC No. Run # 1 1506.04 Run # i 3448.03 Run # I 4041.05 Run # i 5098.01 Run # i 5604.05 Run # 1 5806.05 Run # i 5808.07 Run # i 6651.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Received by: Anchorage, AK 99518 . to (90?) 663-7803 ~n~orage z . LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 20 December 1994 Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PLS-GLS FINAL BL+RF i PLS P PROF FNL BL+RF 1 FSPL FINAL BL+RF 1PLS P PROF FNL BL+RF 1 PLS P PROF FNL BL+RF ECC No. Run # 1 1506.02 Run # 1 1506.03 Run # i 3924.03 Run # 1 5656.03 Run # 1 6333.00 Please sign and return to: A~. Rodney~ Atl~ Services / Anchorage, AK 99518 ~ Or.to (907) 563-7803 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 20 December 1994 Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PLS-GLS FINAL BL+RF Run # 1 i PLS P PROF FNL BL+RF Run # i 1 FSPL FINAL BL+RF ECC No. 1506.02 1506.03 Run # i 3924.03 i PLS P PROF FNL BL+RF Run # I 1 PLS P PROF FNL BL+RF Run # i 5656.03 6333.00 Please sign and return to: A~n. Rodney~ Atl~e Services / Anchorage, AK 99518 STATE OF ALASKA ALAs~-'"~,IL AND GAS CONSERVATION COMMISSIO"'"" REPORT SUNDRY WELL OPE ,ATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Sewice 4. Location of well at surface 1114' SNL, 1899' WEL, SEC. 31, T11N, R14E, UPM At top of productive interval 356' NSL, 3103' WEL, SEC. 31, T11N, R14E, UPM At effective depth 226' NSL, 3303' WEL, SEC. 31, T11N, R14E, UPM At total depth 194' NSL, 3346' WEL, SEC. 31, T11N, R14E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Perforate 3( Other 6. Datum elevation (DF or KB) KBE = 80.19 AMSL 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-25 (24-31-11-14) PBU 9. Permit number/approval number 82-151 / 10. APl number 50- 029-20826 11. Field/Pool Prudhoe Oil Pool 10706 feet Plugs (measured) EZ Drill @ 10650' BKB 9499 feet 10517 feet Junk (measured) BKB 9318 feet fill at 10517' WLM (05/88) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth .. 110 20x30 8 c,y. 146 2712 13 3/8 3720 c.f. 2748 9800 9 5/8 1488 c.f. 9837 measured -. 1120 7 432 c.f. 9582-10702 9862'-9882' (Sag R) Sqzd 9970'-9980; 9990'-10020', 10030'-10088', Sqzd 10120'-10130' True vertical depth BKB 146 2692 8684 8451-9495 true vertical subsea feet Tubing (size, grade, and measured depth) 4 1/2" 12.6#, NT13CR-80, TDS tubing to 9587' Packers and SSSV (type and measured depth) 9 5/8" TIW gCR 'HB-BP' Packer @9506', 7" Otis 'WD' Packer@ 10095', 4-1/2" Otis 'HXO' BVN @ 1988' 13. Stimulation or cement squeeze summary See Attachment R ~ ~ ~' i V ~ b 14. Intervals treated (measured) 0CT 1 4 1994 Treatment description including volumes used and final pressure Alaska OJJ & GaS C011~. COItlllt~loI1 Representative Daily Average Production or Injection Data ~m~,,~ Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations OiI-Bbl Gas-Md W~er-Bbl Casing Pressure Tubing Pressure 1382 1134 1894 1313 232 1408x/'' 1965 2070 1268 201 16. St~us of wellclassEication as: Oil X Gas Suspended Service 17. I hereby c~rtify that the foregoing is true and correct to the best of my knowledge. Signed '~-~A ~,v,~~ ~~ Title SeniorTechnicalAssistantl Form 10-404 Rev 06/15/88 ! Date SUBMIT IN DUP'LIC~ATE 5125194 WELL B-25(24-31-11-14) The following interval were reperforated using 3 3/8" guns, 4 SPF, random orientation and 60° phasing. 9862' - 9882' MD Sag Reperf RECEIVED OCT 1 4 1994 Oil & Gas Con~. Commission Anchom,e ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 1 June 1994 Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~-%%\ B-25 (24-31-11-1'4) q%~\q~ x-35 (~1-~2-10-13) ~~ B-17 (43-25-11-13) DESCRIPTION PFC/CEMENT FINAL BL PFC/CEMENT RF SEPIA / 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA /'1 PL PROFILE FINAL BL 1 PL PROFILE RF SEPIA jl PLS FINAL BL 1 PLS FINAL RF SEPIA ECC No. Run # 1 5783.04 Run # 1 Run # 1 1506~01 Run # 1 Run # 1 6168.02 Run # 1 Run # i 992.09 Run # 1 Please sign and return to: Atlas Wireline Services Received by: 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Please sign and return to: Petroteehnical Data Center BP Exploration (Alaska) Inc 900 East Benson Boulevard Anchorage, Alaska 99508 Received by STATE Of ALASKA AL, ._,KA OIL AND GAS CONSERVATION COMMIS,.. _,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown . Stimulate Plugging . Pull tubing Alter casing Repair well measured 10706 feet true vertical BI~B 9499 feet 5. Type of Well: Development Exploratory Stratigraphic Service Plugs (measured) 2. Name of Operator BP Exploration (Alaska). Inc. . ,. . 3. Address P. 0. Box 196612, Anchorag...e, Alaska 99519-6612 4. Locai'i°n of well at surface .... 1114' SNL, 1899' WEL, SEC. 31, T11N, R14E, UPM At top of productive interval 356' NSL, 3103' WEL, SEC. 31, T11N, R14E, UPM At effective depth 226' NSL, 3303' WEL, SEC. 31, T11N, R14E, UPM At total depth 194' NSL, 334E' WEL, SEC. 31, T11N, R14E, UPM 12. P'resent well conc~iiion summary Total depth: Perforate Other_ x ' ~ [,,, 6. DatUm el~vatio~ (DF (~r"kB) ' .KBE = 8.0.19 ,.AMSL feet] 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-25 (24-31.11-14) PBU 9. Permit number/appr°~/al number 82-151 / 10.APl number 50- 029-20826 11. Fi~'i'd/P(~ol ' ' Prudhoe Oil Pool EZ Drill @ 10650' Effective depth: measured 10517 feet true vertical BKB 9318 feet Junk (measured) fill at 10517' WLM (05/88) Casing Length Size Cemented Measured depth True vertical depth Structural -- BKB Conductor 110 20x30 8 c. y. 148 146 Surface 2712 13 3/8 3720 c.f. 2748 2692 Intermediate 9800 9 5/8 1488 c.f. 9837 8684 Production - Liner 1120 7 432 c.f. 9582-10702 8451-9495 Perforation depth: measured 9862'-9882' (Sag R) 9970'-9980', 9990'- 10020', 10030'- 10088', 10120'- 10130' true vertical subsea Tubing (size, grade, and measured depth) 4 1/2' 12.6#, NT13CR-80, TDS tubing to 9587' Packers and SSSV (type and measured depth) 13. Stimulation Or Cement"squeeze summary 'S~;e Attacl~ment' 9 5/8' TIW 9CR 'HB-BP' Packer @9506', 7' Otis 'WD' Packer@ 10095', 4-1/2' Otis 'HXO' BVN @ 1988' RECEIVED 14. Intervals treated (measured) Treatment description including volumes used and final pressure AU G 2 ,~ 199 .~.!~_~k-_. 0!! ~_ c,~.~ cons. i;;0.m~ss~ot~ ReDreS~ntatiye Daily Avera'ge Production or In!ecti°n Data ~,n_chprage_ OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure /uoing Pressure Prior to well operation Subsequent to operation 2010 2192 349 958 182 4510 ~ 7189 861 1245 255 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil × Gas Suspended Service 17. I hereby c, ertify that the foregoing is true and correct to the best of my knowledge. Signed(~,/,~3~i~(2..,.. ~D~ ~ Title Senior Technical Ass/stant l Form lO-4o4'Rev o6/15/88 / ...... Date ,,, SUBMIT IN DdPLI~ATE 6/16/92 WELL B-25(24-31-11-14) Hydraulic Fracturing A Hydraulic Fracture (Ivishak) was performed using the following fluids: Pumped 124,000# 16/20 CL. 80,000# behind pipe. 44,000# in Liner. Fluids Pumped: 30 bbls 50# Gel Prepad 188 bbls Pad w/9% ESL 55 bbls Dirty 1 PPG 13 bbls 2 PPG 16 bbls 3 PPG 22 bbls 4 PPG 26 bbls 5 PPG 27 bbls 6 PPG 31 bbls 7 PPG 32 bbls 8 PPG 33 bbls 9 PPG 254 bbls 10 PPG 22 bbls 50#-20# Gel Flush fjh 3/11/93 RECEIVF. D AU G 2 ~ 199~ Nas]~ Oil & Gas Oons. Gomm'~ss'~oD ,Anchorage f'~" STATE OF ALASKA ~-'-'"' ~ /L...,.,KA OIL AND GAS CONSERVATION COMMIE .... ,JN nI ~. I N REPORT OF SUNDRY WELL OPERAT'i'dN s ' 1. Operations performed: Operation ShUtdoWn Pull tubing . 2. Name of Operator BP Exploration (Alaska)/nc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 Stimulate Plugging AItercasing ... Repairwell 5. Type of Well: Development ..~ Exploratory Stratigraphlc Service 4. Location of well at surface 1114'SNL, 1899' WEL, SEC. 31, T11N, R14E, UPM At top of productive interval 356' NSL, 3103' WEL, SEC. 31, T11N, R14E, UPM At effective depth 226' NSL, 3303' WEL, SEC. 31, T11N, R14E, UPM At total depth 194' NSL, 3346' WEL, SEC. 31, T11N, R14E, UPM 12. Present well condition summary Total depth: measured 10706feet true vertical BKB 9499feet Perforate X Other__ 6. Datum elevation (DF or KB) KBE = 80.19 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-25 (24-31-11-14) PBU 9. Permit number/approval number 82.151/ 10. APl number 50- 029-20826 11. Field/Pool Prudhoe Oil Pool Plugs (measured) EZ Drill @ 10650' Effective depth: measured 10517 feet true vertical BKB 9318feet Junk (measured) fill at 10517' WLM (05/88) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth True vertical depth .. BKB 110 20x30 8 c.y. 146 146 2712 13 3/8 3720 c.f. 2748 2692 9800 9 5/8 1488 c.f. 9837 8684 .. 1120 7 432 c.f. 9582-10702 8451-9495 9862'-9882' (Sag R) 9970'-9980',9990'-10020',10030'-10088',10120'-10130' J 'ECEIVED true vertical subsea S E P - 8 1992 Tubing (size, grade, and measured depth) 4 1/2" 12.6#, NT13CR-80, TDS tubing to 95~$J(a 0il & Gas Cons, Commiss|ot~ ;Anchorage Packers and SSSV (type and measured depth) g 5/8" TIW gCR 'HB-BP' Packer @9506', 7" Otis 'WD' Packer@ 10095', 4-1/2" Otis 'HXO' BVN @1988' 13. stimulation or cement squeeze summary 5/30/91 The intervals be/ow was reperforated using 3 3/8 gun diameter, 6 SPF and 4 $PF random orientation and 60 to 120 degree phasing. Intervals treated (measured) 9990'- 10020' 6SPF, 60° 10030' - 10088' 4SPF, 120° Treatment description including volumes used and final pressure 14. Represerltative Daily Average Produ~iorl or 113jection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation "15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 1280 3643 2363~. 741 208 1770 2039 490 1101 206 '1 16. Stmus of wellclassificmion as: I Oil X Gas . Suspended Service 17. I hereby ced!fy that the forego, j~g Form 10-404 F~ev 06/15/88 · is tr~?~ to the best of my knowledge. Title Senior Technical Assistant l SUBMIT IN DOPLIOATE · 0 I G IN A L ALA~. ~^ OIL AND OAS CONSERVATION COMMISSar... ~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing X Alter casing Repair well 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory Stratigraphic Service Perforate Other x Fish 6. Datum elevation (DF or KB) KBE = 80.19 feet 7. Unit or Property name Prudhoe Bay Unit 4. Location of well at surface 1114'SNL, 1899'WEL, SEC. 31, T11N, R14E, UPM At top of productive interval 356'NSL, 3103' WEL, SEC. 31, T11N, R14E, UPM At effective depth 294'NSL, 3198' WEL, SEC. 31, T11N, R14E, UPM At total depth 194' NSL, 3346' WEL, SEC. 31, T11N, R14E, UPM 12. Present well condition summary Total depth: 8. Well number B-25(24-31-11-14) 9. Permit number/approval number 82-151/Conservation order 258 10. APl number 50- 029-20826 11. Field/Pool Prudhoe Bay Field/Oil Pool measured true vertical 10706 feet 9499 feet Plugs(measured) EZ Drill plug @10650'MD Effective depth: measured true vertical 10150' feet 8973 feet Junk (measured) Junk basket, tapered mill cemented in hole top @ 10150' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length true vertical Tubing (size, grade, and meaSured depth) Size Cemented Measured depth True vertical depth REeE, IVED MAY - ,5 1~92 Alaska 0ti & (]as Cons. C0mmlsSi0~ Anchorage 4-1/2" 12.6#, NT13CR-80, TDS tubing to 9587' Packers and SSS V (type and measured depth) 9-5/8" TIW 9CR 'HB-BP' Packer @ 9506', 7" Otis 'WD' Packer @ 10095', 4-1/2" Otis 'HXO' BVN @ 1988' 13. Stimulation or cement squeeze summary Squeeze perforations, see attached Activity Summary Intervals treated (measured) 9970'-9980', 10120'-10130' Treatment description including volumes used and final pressure 155 cu fl Class "G" final pressure = 2200 psi 14. Prior to well operation Subsequent to operation Representative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby ~ertify that the foregoing is true and correct to t.13]~best of my knowledge. Sicjned ;r~,~7~/~'~ (~')'x//'~'~I Title WorkovorEngineorSuporvisor Form 10-404 Rev 06/15/88 Date ~//~-~,,/~,L SUBMIT IN DUPLICATE BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Monday, May 6. 1991 WELL: B-25 (24-31-11 14), PRI. IDHOE BAY UNIT Rig: Doyon Rig #16 Day: 3 Expense AFE Number: Expense AFE Amount = 145O52 $770,00.0.. Current Field Costs = Estimated Final Cost = Current Operation: RIH with washover shoe and washpipe. Summary. of Last 72 Hours Accept rig at 2100 hours on 5/3/91. Circulate diesel from well. ND tree, NU BOP's and test. Pull and lay down 4-1/2" tubing. Replace 9-5/8" packoff and test. RIH with overshot to slick stick at 9518'. Rotate to release, PC)H, no recovery. Change grapple and RIH to slick stick. Rotate to release, POH, no recovery. RIH with washover shoe and washpipe. Reviewed By:¢~ R[ EIVED MAY - ,5 199~ Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Tuesday, May 7, 1901 WELL: B-25 (24-31-11-14), pRUDHQE BAY UNIT Rig: Doy0n Rig #,!6 Day: 4_ Expense AFE Number: Expense AFE Amount = 145052 Current Field Costs = Estimated Final Cost = Current Operation: RIH to recover packer. Summary. of Last 24 Hours RIH with shoe and washpipe. Tag packer at 9536', washover to 9541'. Circulate and POH. with overshot and recover slick stick. POH. RIH with spear to recover packer. RIH Reviewed By:'~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PR, UDHOE BAY UNIT As of 0600 Hrs. Wednesday, May 8, 199.1. WELL: B-,,.25 (24-31-11-14) Rig: Doyon Rig #16 Day: 5 Expense AFE Number: Expense AFE Amount -- 145052 Current Field Costs = . Estimated Final Cost = Current Operation: RIH with mill. Summary_ of Last 24 Hours ' RIH and spear packer. POH and lay down. RIH with bit to 10,142', bit torquing. Circulate and POH. RIH with tapered mill. Reviewed By' BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Thursday, May 9, 1991 WELL: B-25 (24-31-11-14) PRI. IDHOE BAY UNIT Rig: Doy0n Rig #16 Day: 6_ Expense AFE Number: Expense AFE Amount = 145052 Current Field Costs = Estimated Final Cost = Current Operation: POH. Summary of Last 24 Hours RIH with tapered mill. Wash thrOugh perfs to 10,143'- would not drill off. POH. Left mill and junk basket in hole. RIH with overshot. Work over junk basket, PC)H, no recovery. RIH with redressed overshot. Attempt to washover fish. POH. BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Friday, May 10, 1991 WELL: B-25 (24-31-11-14), PRUDHOE BAY UNIT Rig: Doy0n Rig #16 Day: 7 Expense AFE Number: Expense AFE Amount = 145052 Current Field Costs = Estimated Final Cost = Current Operation' RIH-with short catch overshot. Summary_ of Last 2--4 Hours POH with overshot. RIH with.shoe and washover boot basket. fish. POH. RIH with short catch overshot. POH. RIH with impression block, tag Reviewed By: c~~..... BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Monday, May 13, 1991 WELL: B-25 (24-31-11-14) PRUDHOE BAY UNIT Rig: Doyon Rig #16 Day: 1 0 Expense AFE Number: Expense AFE' Amount = ..1. 45052 Current Field Costs = Estimated Final Cost = Current Operation: P©H with overshot and hollow mill guide. Summary_ of Last 72Hour8 RIH with short catch overshot. Work onto fish and POH with boot basket and tapered mill. RIH with tapered mill and boot baskets, ream through perfs to 10,149', mill stopped. POH, parted at same spot, left mill and junk basket in hole. Make two attempts to fish with overshot, no recovery. RIH with shoe and wash over junk basket. POH. Make three attempts to fish with overhshot, no recovery. PU modified hollow mill guide and overshot. RIH and attempt to cut over junk basket. POH. Reviewed By' ~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Tuesday, May 14, 1991. WELL: B-25 (24-31-11-14) PRUDHOE BAY UNIT Rig' Doyon Rig #16 Day: 11 Expense AFE Number: Expense AFE Amount = 145052 Current Field Costs = Estimated Final Cost = Current Operation: POH with box tap. St~mmary of Last 24 Hours POH, service rig. RIH with modified shoe, cut over junk basket. Pump high vis sweep. shoe. RIH with box tap, fish on junk basket. POH, L/D Reviewed By' ,~~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHQE BAY UNIT As of 0600 Hrs. Wednesday, May 15, 1991 WELL: B-25 (24-31-11-14~ Rig: D0yon Rig #16 Day: 1 2 Expense AFE Number: Expense AFE Amount - 145052 Current Field Costs = Estimated Final Cost = Current Operation: Hold 2500 psi squeeze pressure. Summary of Last 2_~4 Hours P©H with taper tap. RIH with 6" bit and 7" scraper to 10,139'. Reverse circulate and POH. RIH and set cement retainer at 10,100'. Acidize and squeeze perfs with 11 bbls below the retainer and 17 bbls above. Hesitate squeeze to 3000 psi. Circulate thru choke holding 2500 psi squeeze pressure. BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Thursday, May 16. 1991 WELL: B-25 (24-31-11-14), PRI. IDHOE, BAY UNIT Rig: Doyon Rig #16 Day: 1 3 Expense AFE Number: Expense AFE Amount = 145052 Current Field Costs = Estimated Final Cost = Current Operation: Clean out cement at 10,016'. Summary of Last 24 Hours POH. RIH with 8-1/2" bit and 9-5/8" scraper to liner top, reverse circulate, green cement returns. POH. RIH with 6" bit, tag cement at 9738'. Pressure test casing and liner lap to 3000 psi. OK. Clear out firm cement from 9800' to 10016'. Reviewed BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Friday, May 17, 1991 WELL: B-25 (24-31-11-14). PRUDHOE BAY UNIT Rig' Doyon Rig #16 Day: 14 Expense AFE Number: Expense AFE Amount = 145052 Current Field Costs = Estimated Final Cost = Current Operation: POH and lay down drillpipe. Summary of Last 24, Hours Drill cement to top of retainer. Test perfs to 3000 psi, OK. Drill retainer and cement to 10,140'. Test perfs 2500 psi, bled 200 psi in 15 minutes. POH. RIH with 7" scraper to 10,140'. Reverse circulate and change over to filtered inhibited brine. P©H and lay down ddil pipe. · Reviewed By: ~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Monday,. May 20, 1991 WELL: B-25 (2,4-31-!.1-14), PRUDHOE, BAY UNIT Rig' Doyon Rig #16 Day: .16 Expense AFE Number: Expense AFE AmOunt = 145052 Current Field Costs = Estimated Final Cost = Current Operation: Released rig at 1900 hours on 5/18/91. Summary_ of Last 72~ L/D drillpipe. Run gauge ring to 10,150'. Set WD packer at 10,095'. Run 4-1/2" chrome completion. N/U and test tree to 5000 psi, ok. Set packer at 3000 psi. Test annulus 2500 psi, 30 minutes. Displace well with 135 bbis diesel freeze protection. Release rig at 1900 hours on 5/18/91. BP EXPLORATION BP Ext31oration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION D ate :07/15/91 T#:82584 FROM: Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Enclosed is your copy of the material listed below, if you have any questions, please contact BP Well Records at (907) 564-~.~.~.5. A-06 B-05 B-25 /~ B-25 ~1~. ,/,,~,Z F,26 G-26 M-09 M-09 M-09 ~/'/,,~ P-12 R-06 R-06 R-21 R-21 /Y-32 Jewelry Log 05/24/91 #1 9300-9500 HLS 5" CL 05/06/91 #1 10489-10788 HLS 5" Jewelry Log 05/30/91 #1 9700-10113 HLS 5" Peal 05/30/91 #1 9700-10113 HLS 5" CL Baker Packer 06/28/91 #1 9900-10560 HLS 5" Perf 03/15/91 #1 10362-10580 HLS 5" Production Log 06105/91 #1 9900-10289 HLS 5" Gas Lift Survey 06/05/91 #1 9900-10289 HLS 5" Production Log 06105/91 #1 9900-1~0289 , HLS 5" Perf 06/06/91 #1 8930-9'550 HLS 5" Production Log 06/15/91 #1 9700-10080 HLS 5" Production Log 06/15/91 #1 9700-10080 HLS 5" Production Log 06/14/91 #1 10100-10380 HLS 5" Production Log 06/14191 #1 10100-10380 HLS 5" Production Log 06/15/91 #1 12200-12760 HLS 5" Production Log 06/15/91 #1 12200-12760 HLS 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES BP EXPLORATION TO: DISTRIBUTION BP Exploration (Alaska) Inc. 900 East Benson Boulevard i~,~ ~"F~°x 196612 g~,C~ ~,~lel~orage, Alaska 99519-6612(907) 561-5111 ' ~.1 ~/~~ ~as ~,o~s. : 0~% & Nto~a~ Date :05/21/91 i991 1#:82415 FROM' Aic. '.. .-' ~ '-- InformatiOn Control . ~t~lt°[Etittt Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. -, B-25 Packer Set 05/17/91 #1 0-10098 Sch 5" D-15 CNL 05/16/91 #5 9795-10587 Sch 5" D-20 CNL/GR 05/16/91 #1 9600-10293 Atlas 5" C-12 CNL' 05/17/91 #5 11095-11955 Sch 5" H-06 CNL/GR 05/15/91 #1 9450-9753 Atlas 5" H-08 CNL ' 05/14/91 #2 8850-9426 Sch 5" H-14 CNL/GR 05/16/91 #1 9950-10745 Atlas 5" H'30 CNL/GR 05/17/91 #1 10700-11548 Atlas 5" H-20 CNL 05/17/91 #1 9395-19238 Sch 5" J-17 CNL 05/18/91 #1 9995-10930 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES TO: THRU: MEMORANDUM State of Alaska ALASKA OiL ~D GAS CONSERVATION COMMISSION Commis s ioner ( -- FILE NO: ~516-1 TELEPHONE NO: SUBJECT: RIG/BOPE Inspection BPX PBU Pad B-25 Prudhoe Oil Pool FROM: Harold R. Hawkins Petrole~ Inspector Sunday May 12, 1991: I performed a BOPE walk-thru inspection on BPX PBU pad B-25, Doyon Rig #16. Anchor on BOPE stack was in compliance. The blowdown line and flare line are both in compliance that were completed on 5/3/91. Everything else on the RIG seems to be in compliance. I filled out an AOGCC BOPE Walk-thru inspection Report attached. In s~ar¥: ~e Doyon rig #16 for BPX PBU B-25 was in compliance With~o infraction I could find. The RIG/BOPE inspection was satisfactory. Attachment. 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 OPERATION: yrlg. Wkvr Locati on T Drlg contr '~ ~ Locati on (gen' 1 ) C'~./f'~/ I N COMPL I ANCE; I N COMPL lANCE; yes no n/a A. DIVERTER yes~ ~ n/a 1. (*~ (~) ~) line sz & length 11. ('~ ( ) ( ) 2 (~x~. (J) /(]) line corm & anchored 12. ( ,~ ( ) ( ) 3 (~ '~ (I) bifurcated & dwn wind 13. ('~ ( ) ( ) 5 Cl)/ Cl)~' (I) vlvs: auto& simultaneous 1. ) 76 ~ ~ X~I))~.c°ndiei°nannular pack-offgOp SI~CK ~32 ~ ~ ) ~ / ) 1. (~ ( ) ( ) wellhead flg wkg press 5 (~ ) 2. (~ ( ) ( ) stack wkg press 6.(~ ) ~. (~ ( ) ( ) annular preventer 7. (~. ( ) 8.(~ () 5. ~~( )(~, ()blind rams '~__ 6. { ) ( ) stack anchored i. ( ( ) 7..,~ ( ) ( ) chke/kill line sz , 2. ~ C } 8. I'~, ( ) ( ) 90~ turns targeted (chke & kill ln) 3.~ ( ) 9.(t~ ( ) ( ) HCR vlvs (chke & kill) ~. ( ) 10. (I~() ( ) manual vlvs (chke & kill) )il.(~, ( ) ( ) connections (flgd, whd, clmpd) i2. (~ ( ) ( ) dr l spool 5. ( ) ~ ( ) 13. (~ ( ) ( ) flow nipple 6. (~ ( ) iq. (~ ( ) ( ) flow monitor 15. {~ (){ )control lines fire protected 7. (f~() C. CLOSING UNITS 8. (~( ) 1. (~ ( ) ( ) wkg press 2. (f ( ) ( ) fluid level ~. (~() 3. (~ ( ) ( ) oprtg press 2 (~() 5 ( ( ) ( ) sufficient vlvs 3. ( ) 6. (~ ( ) ( ) regulator bypass g. ( ) 7. (~ ( ) ( ) q-way vlvs (actuators) 5.. ( ) 8. () b]indh ndl oo 9. (~ ( ) ( ) driller control panel 6. (~; ) lO. (~ ( ) ( ) remote control panel ~_. 7 ( ) STATE OF ALASKA ALASKA 01L AND GAS CONSERVAT I ON COMM I S~ I ON BOPE Walk-Thru Inspection Report Permit # R M Rig# Represe-nt~ti ve Well name E Representative firewall nitrogen power source (back-up) condition (leaks, hoses, etc) D. MUD SYSTEM { ) pit level floats installed ( ) flow rate sensors ( ) mud gas separator ( ) degasser ( ) separator bypass ( ) gas sensor ( ) chke In conn ( ) trip tank E. RIG FLOOR ( ) kelly cocks (upper,lower,IBOP) ( ) floor vlvs (dart vlv, ball vlv) ( ) kelly & floor vlv wrenches ( ) driller's console (flow monitor, flow rate indicator, pit level indicators, gauges) kill sheet up-to-date gas ~etection monitors (H S & methane) ( ) hydr chke panel ( ) chke manifold F. MISC EOUIPMENT ( ) flare/vent line ( ) 90° turns targeted (dwn strm choke lns) ( ) reserve pit tankage ( ) personnel protective equip avail ( ) all drl site suprvs trained 2for procedures ( ) H S probes ( ) rig housekeeping Kill sheet current? Date of last BOP inspection: Date of last BOP test: Resulting non-compliance: L~O ~iT~j~F/~ Non-compliances not corrected & why:. ~~~~~ Date corrections will be completed: j~ ~ BOP test & results properly entered on daily record? ~ Inspector C.0013 (rev 03/29/91) ~ ~ STATE OF ALASKA : ALA,..,,A OIL AND GAS CONSERVATION COMMISS,,.,i~I APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Alter casing ~ Repair well Change approved program ~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface · 1114'SNL, 1899'WEL, SEC. 31, T11N, R14E, UPM At top of productive interval 356'NSL, 3103'WEL, SEC. 31, T11N, R14E, UPM At effective depth 226' NSL, 3303' WEL, SEC. 31, T11N, R14E, UPM At total depth 194' NSL, 3346' WEL, SEC. 31, T11N, R14E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10706 feet BKB 9499 feet 10517 feet BKB 9318 feet Operation Shutdown ~ Plugging ~ Time extension Pull tubing ~ Vadance ;K Perforate 5. Type of Well: 6. Development X Exploratory ~ Stratigraphic Service Re-enter suspended well Stimulate Other Datum elevation (DF or KB) KBE - 80.19 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-25 (24-31-11-14) PBU 9. Permit number 82-151 10. APl number 50- 029-20826 11. Field/Pool Prudhoe 011 Pool Plugs (measured) Junk (measured) EZ Drill ~ 10650' oil w~t. ~o+ p~.~,~v~.~ /, fill at 10517' WLM (05/88) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth . - BKB 110 20x30 8 c.y. 146 146 2712 13 3/8 3720 c.f. 2748 2692 9800 9 5/8 1488 c.f. 9837 8684 -. 1120 7 432 c.f. 9582-10702 measured 9862'-9882' (Sag R) 9970'-9980', 9990'-10020', 10030'-10088', 10120'-10130' true vertical subsea 8627'-8645' (Sag R) 8726' - 8874' (four lvishak intervals) 8451-9495 RECEIVED JAN 28 Tubing (size, grade, and measured depth) 4 1/2" L-80 to 9557' with 4 1/2" tailpipe to 9694' · Packers and SSSV (type and measured depth) 9 5/8" B~er packer at 9557'; 4 1/2" SSSV at 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation March 1991 16. If proposal was verbally approved Name of approver Lonnie Smith 01/14/91 Date approved 15. StatUs of well classification as: Oi~'- ~'~. '~as ~ Suspended Service__ j' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSiON USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Mechanical Integrity Test Approved by order of the Commission Form 10-403 Rev 06/15/88 Date 1/15"'/~/ I J Approval No. ~ / ... 0,~' Location clearance Subsequentf°rm required 10' ~:~/'/ORIGINAL SIGNED BY 'AP~'~neC(~t3Y~-~ ~ ~/ [ LO,NIE C. SMITH Com~ate ~- ~--- ¢/ SUBMIT IN TRIPLICATE Request for WELL B-25 PBU Variance to Produce with tubing leak A tubing leak~has been detected in waterflood producer B-25. A variance is being requested to allow production until a rig workover can be performed. The workover is currently scheduled for the first quarter, 1991. A full scoP~A of work to be~__ dormed on B-25 is outlined below. B-25 is/cl~rentlvon,.__.,__ --- -- gaslift.~ B-25 well wgrk 1. CTU Pre-rig cement squeeze, 2, RWO to change out tubing. 3, Hydraulic Fracture treatment. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date:01/15/91 T#:82045 FROM' information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS EncloSed is your copy of the material listed below. If you have any questions, please Contact BP Well Records at (907) 564-4445. A-30 ,~A-34A B-25 ',C-15 "E-02 ~'E-27 ~G-07 "'P-13 -28 "-S-32 -,,,S-29 "WV-40 ~Y-14 "Y-14 Y-19 Prod-F 1 2/15/90 PITS 12/28/90 Prod-F/Jewelry 1 2/11/90 Prod-F 12/24/90 - Prod-F/Jewelry ..... 12/20/90 Prod-F CCI_/Temp Prod-F IN J/PITS Prod-F Prod-F Prod-F Prod-f/PITS Jewelry Log Jewelry Log 1 2/13/90 1 2/13/90 12/27/90 1 2/16/90 12/27~90 1 2/21/90 12/14/90 12/23/90 12/23/90 12/22/90 #1 10650-11080 Camco 5" #1 8900-9190 Camco 5" #1 9800-10164 Camco 5" #1 9350-9757 Camco 5" ..... #1 -. 9675-9981 ............. Camco ........ 5" ............. -#1 9450-9720 Camco 5" #1 11150-11396 Camco 5" #1 9000-9380 Camco 5" #1 8750-8925 Camco 5" #1 10100-10540 Camco 5" #1 12850-13190 Camco 5" #1 10200-10510 Camco 5" #1 9900-10401 Camco 5" #1 9600-10300 Camco 5" #1 8900-9701 Camco 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES RECEIVED JAN 1991 · Alaska 0il & Gas Cons. Commission Anchorage BP EXPLORATION May 8, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well B-25 (24-31'11'14) 'PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, ~;n~;e~r;~duction Engineering JAB:JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File o Alaska Oil & ~ Con.% A~Chorago C°m,7~iss/o~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1, Operations performed: Operation shutdown , Pull tubing Alter casing 2, Name of Operator BP Exploration (Alaska) Inc, 3, Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1114' SNL, 1899' WEL, SEC,. 31, T11N, R14E, UPM At top of productive interval 356' NSL, 3103' WEL, SEC. 31, T11N, R14E, UPM At effective depth 226' NSL, 3303' WEL, SEC. 31, T11N, R14E, UPM At total depth 194'NS1., 3346' WEL, SEC. 31, T11N, R14E, UPM 12. Present well condition summary Total depth: measured 10706feet true vertical BKB 9499feet Stimulate X Plugging Perforate. Repair well . 5, Type of Well: Development X Exploratory , Stratigraphio . Service , Plugs (measured) Other. 6, Datum elevation (DF or KB) KBE = 80,19 AMSL feet 7, Unit or Property name Prudhoe Bay Unit 8, Well number " B-25 (24-31-11-14) PBU 9. Permit number/approval number 82-151 / 9-188 10. APl number 50- 029-20826 11. Field/Pool Prudhoe Oil Pool EZ Drill ~ 10650' Effective depth: measUred 10517feet true vertical BKB 9318feet Junk (measured) fill at 10517' WLM (05/88) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 110 20x30 8 c.y. 146 2712 13 3/8 3720 c.f. 2748 9800 9 5/8 1488 c. fo 9837 measured true vertical .. 1120 7 432 c.f. 9582-10702 Tubing (size, grade, and measured depth) 9862'-9882' (Sag R) 9970'-9980', 9990'-10020', 10030'-10088', 10120'-10130' subsea 8627'-8645' (Sag R) 8726'. 8874' (four IviShak intervais) 4 1/2" L-80 to 9557' with 4 I/2" tailpipe to 9694' Packers and SSSV (type and measured depth) True vertical depth BKB 146 2692 8684 8~I-94~ 95/8"Bakerpacker at 9557'; 4 1/2"SSSV at 20g E C E IV E D 13. Stimulation or cement squeeze summary see attachment InterVals treated (measured) Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Commission Anchorage 14. Reoresentative Daily Averaoe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1590 1997 1048 0 237 Subsequent to operation 1880 2265 1596 0 234 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well OperatiOns X Oil X Gas Suspended. Service 17, I here~/~rtify that the ~ is true and correct to the best of my knowledge. Signed '~:~'~ / ~T ¢ "~"~~ Rev 06/15/88 TEleManagerProductionEngineering Date F,,rm 10~4 SUBMIT IN DUPLICATE WELL B-25 (24-31.11-14~ PBU STIMULATION OPERATIONS A half-strength mud acid wash and scale inhibition treatment was performed on the following perforated intervals in Well B-25. 9970' - 9980' MD BKB 9990' - 10020' MD BKB 10030' - 10088' MD BKB The treated intervals were isolated from thc lower interval by setting an inflatable bridge plug at 10104' MD. Thc mud acid treatment was pumped 3/26/89 via coiled tubing as follows: a) b) c) d) e) f) g) h) i) J) k) l) m) n) o) P) q) 1000 gal. 15% HC1 1000 gal. 6% HC1 - 1.5% HF 2000 gal. 2% NH4C1 8 bbls. diverter 1000 gal. 15% HC1 1000 gal. 6% HCI - 1.5% HF 2000 gal. 2% NH4CI 8 bbls. diverter 1500 gal. 15% HC1 1500 gal. 6% HCI - 1.5% I-IF 3000 gal. 2% NH4CI 8 bbls. diverter 2000 gal. 15% HC1 2000 gal. 6% HC1 - 1.5% I-IF 4000 gal. 2% NH4CI 2000 gal. Arctic diesel w/10% mutual solvent Displaced to perfs with 1000 gal. produced water The packer was released and the well returned immediately to production, then tested. The following scale inhibition treatment was performed 4/3/89 via coiled tubing: a) b) d) e) 10 bbls. diesel preflush w/mutual solvent 30 bbls. EDTA w/OSR diverter 99 bbls. scale inhibitor solution w/OSR diverter 75 bbls. seawater overflush After a 12-hour shut-in period, the well was returned to production and tested. jm 4/25/89 RECEIVED MAY 1 0 1985 Alaska Oil & G~S Cons. EO~,7~ission Anchorage BP EXPLORATION March 7, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well B-25 (24-31-11-14) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, ~ ' v Manager Production Engineering JAB:JAM Enclosures (9) cc: L. Burke (MB12-1) Well File · ...... ,.,o~v~,Oil & fi;as Cons. ' ~~ ~rtchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend , Alter casing ~ Repair well Change approved program 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1114' SNL, 1899' WEL, SEC. 31, TllN, R14E, UPM At top of productive interval 356' NSL, 3103' WEL, SEC. 31, T11N, R14E, UPM At effective depth 226' NSL, 3303' WEL, SEC. 31, T11N, R14E, UPM At total depth 194' NSL, 3346' WEL, SEC. 31, T11N, R14E, UPM 12. Present well condition summary Total depth: measured true vertical BKB Effective depth: measured true vertical BKB operation Shutdown .. Plugging Time extension . Pull tubing Variance Perforate 5. Type of Well: 6. Development x Exploratory Stratigraphic 7. Service Re-enter suspended well Stimulate X.. Other Datum elevation (DF or KB) KBE , 80.19 AMSL feet Unit or Property name Prudhoe Bay Unit 8, Well number B-25 (24-31-11-14) PBU 9, Permit number 82-151 10, APl number 50- 029-20826 11. Field/Pool Prudhoe 011 Pool 10706 feet 9499 feet 10517 feet 9318 feet Plugs (measured) EZ Drill~ 10650' Junk (measured) fill at 10517' WLM (05/88) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented .. measured true vertical Measured depth True vertical depth BKB 146 146 2748 2692 9837 8684 110 20x30 8 c.y. 2712 13 3/8 3720 C. fo 9800 9 5/8 1488 c.f. .. 1120 7 432 c.f. 9582-10702 9862'-9882' (Sag R) 9970'-9980', 9990'-10020', 10030'-10088', 10120'-10130' subsea 8627'-8645' (Sag R) 8726'- 8874' (four Ivishak intervals) Tubing (size, grade, and measured depth) 4 1/2" L.80 to 9557' with 4 1/2" tailpipe to 9694' Packers and SSSV (type and measured depth) 9 5/8" Baker packer at 9557; 4 1/2" SSSV at 2097' 13. Attachments Description summary of proposal x Detailed operations program 8451-9495 14. Estimated date for commencing operation I 15. Status of well classification as: March 1989 '16. If proposal was Verbally approved Oil X Gas ~ Suspended ~ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Signed ~//f.,w~...'"~.-- Title Mana~lerProductionEr~lineerin~l Date .,/.,/ ~' O' FOR COMMISSION USE ONLY Cond(~i~ns of aPProval: NOtify commiSSion s° rePresentative may witness I Approval No. ~ _/ Plug integrity BOP Test Location clearance .__ Mechanical Int-~gr'~ Test Subsequent form required 10- /--/-o~ _. i~,Pproved Copy . . ORIGINAL SIGNED BY Returi~ed Approved by order of the Comm,ss,on LC;,'.%'~E C. SMITH ~ .;~_~ ~4~ ? Commissioner Date '-~ -"/~ "~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE B-25 MUD ACID TREATMENT ABOVE CTU BP 1. RIH with slicktine and run a drift to ensure no obstruction exists in wellbore and to tag PBTD. Do not perform acid job unless 50' of rathole exists. 2. Obtain wellhead sample. Test for~emulsion tendencies using API RP 42 testing procedure with spent and unspent acid. Acid system to contain 5000 ppm ferric iron. Adjust additives as required. 3. Obtain maximum rate test. 4. Pull SSSV and isolate SSS. MIRU CTU. RIH and set a Lynes inflatable BP in the 32' blank between 10088 and 10120 ft. Preference is to set the BP as close as possible to the upper set of perfs without setting in them. Do not flow well after setting bridge plug. 6. Rig up stimulation company. Sample acids to insure acceptable concentration and that iron count is less than 350 ppm. Lay lines and pressure test to 4000 psi. 7. RIH with a nozzle on CT and tie into tubing tail for depth control. Fluid pack well with CT at 9950'. 9. Acidize 108'(424 holes) of Zone 4 perfs with half strength mud acid. Maximum pressure is 4000 psi. Reciprocate CT across perfs from 9990 to 10088 ft. while acidizing. A strip chart of surface wellhead pressure (CT by 4-1/2" annulus) vs rate should be recorded and sent into town. Filter fluids to 3 microns. Pump as follows: 1) 1000g 15% HC1 2) 1000g 6%HCL-1.5% HF 3) 2000g 2% NH4CL 4) 1/3 diverter stage (300 lbs. = 0.7 ppp) 5) 1000g. 15% HCl 6) 1000g 6%HCL-1.5% HF 7) 2000g 2% NH4CL 8) 1/3 dlverter stage (300 lbs. = 0.7 ppp) 9) 1500g 15% HCl 10) t500g 6%HCL-1.5% HF 11) 3000g 2% NH4CL 12) 1/3 diverter stage (300 lbs. = 0.7 ppp) 13) 2000g 15% HCl 14) 2000g 6%HCL-1.5% HF 15) 4000g 2% NH4CL 16) 2000g arctic diesel with 10% mutual solvent. 17) Displace to perfs with sea or produced water. 10. POOH while pumping diesel. 11. Immediately after CT is rigged down, rig up wireline and RIH to retrieve BP. Try to have well on production 12 hrs after last flush is pumped. 12. Return well to production and obtain maximum rate test. mat/February 28, 1989 Coiled Tubing Blow-Out-Preventers Coiled Tubing · , Pack-Of'i' Blind Rams Cutter Rams Chick:san (Ki[! Line) Slips 'Pipe Rams .Pump-ln Sub (Clrcula te/R e turn s) W ell Head -~L..--' Swab Valve Sla,do~d Alu~ka Produclion Compa, 900 Ecs! Benson Bo~ ,,d P.O. Bo,~ 19661? DALLAS ARCO CHEVRON EXXON TEXACO TO: HO B I L PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR REFERENCE: ARCHIVES SAPC CASED HOLE FINAL LOGS I NDEXEO STANDARD ALASKA PRODUCTION Dote: 06/24/88 TI: 79008 The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this offlce: B-25 G-12 M-3 ~~-16 ~Y-24 CCL/Perf 05/29/88 #1 8700-9200 GO 5" CCL/Perf 05/24/88 #1 10800-11154 GO 5" CCL/Perf 05/25/88 #1 9550-10100 GO 5" CCL/Perf 05/29/88 #1 8100-9600 GO 5" CCL/Perf 05/08/88 #1-4 2900-5250 GO 5" Temp/Survey 05/20/88 #1 10150-10500 GO 5" CCL 05/21/88 #1 10430-10500 GO 5" CCL/Perf 05/25/88 #1 8700-9400 GO 5" CCL/Pref 05/11/88 #1 12910-13330 GO 5" 9 Alaska 0ii & Gas Cons. Commission Anchorage Race i red Da te A un;! of the o,;9;nol $'ondo,d (~1 Co,,irmnv founded ~ Cle-elond. O~.o..n 1870 Jennifer Dietz I NFORHAT I ON CONTROL Wel I Records LR2-1 Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ~/~ ALASKA PRODUCTION June 22, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well B-25 (24-31-11-14) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of perforating the well. BJP:JAM~ Enclosures (4) J. L. Haas (MB12-1) Well Records (LR2-1) w/10 B-25 Well File Yours very truly, wB~teJ~flPo~o~[&kY,MisS~i~b~:i~orod RECEIVED JUN 2 4 1988 Alaska 011 & C~-~s Cm,s. Commission ~nchorage A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation performed: Operation shutdown [] Stimulate [] Plugging [] Perforate r~ Pull tubing [] Alter casing I'-! Other [] 2. Name of Operator Standard Alaska Production Company 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1114' SNL, 1899' WEL, SEC. 31, T11N, R14E, UPM At top of productive interval 356' NSL, 3103' WEL, SEC. 31, T11N, R14E, UPM At effective depth 203' NSL, 3332' WEL, SEC. 31, T11N, R14E, UPM At total depth 194' NSL, 3346' WEL, SEC. 31, T11N, R14E, UPM 5. Datum elevation (DF or KB) KBE-80.19 AMSL feet 6. Unit or Property name " Prudhoe Bay Unit 7. Well number B-25 (24-31.11-14) PBU 8. Approval number 8-149 9. APl number 5 0 - O29-20826 10. Pool Prudhoe Oil Pool 1. Present well condition summary Total depth: measured true vertical 10706 feet BKB 9499 feet Plugs (measured) EZ Driil @ 10650' Effective depth: measured 10650 feet true vertical BKB 9495 feet Junk (measured) Casing Length Size Cemented Measured depth Structural -- Conductor 110 20x30 8 c.y. 146 S u rface 2712 13 3/8 3720 c.f. 2748 Intermediate 9800 9 5/8 1488 c.f. 9837 Production -- Liner 1120 7 432 c.f. 9582-1O702 Perforation depth: measured 9862'-9882' (Sag R) 9970'-9980', 9990'- 10020', 10030'- 10088', 10120'-10130' true vertical subsea 8627,-8645'(SagR) 8726' - 8874' (four IviShak intervals) Tubing (size, grade and measured depth) 4 1/2" L-80 to 9557' with 4 1/2" tailpipe to 9694' True Vertical depth BKB 146 2692 8684 8451-9495 Packers and SSSV (type and measured depth) ~. 9 5/8" Bakerpacker at 9557';41/2" SSSVg~ ~ t '~J ~ [~ 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure , Prior to well operation Subsequent to operation ReDresentative Daily Average Production gr In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2170 2425 513 0 2010 2569 725 0 Tubing Pressure 215 220 4. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 5. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,~/~ Title Supervisor Waterflood/Miscible Flood Form 10-404 Rev. ;I-2-1-85 ~'~ ,~ubmit in Duplicate Well B-25 (24-31-11-14) PBU Additional Perforating Operations The following Sag River interval was perforated May 25, 1988 using Gearhart 3 3/8" HSC guns at 6 spf: 9862' - 9882' MD BKB (8627' - 8645' TVDss) Depths are referenced to BHCS, 10/31/82. A lubricator was installed and tested to 3500 psi for all well work. The well was returned to production immediately following perforating operations. jam 6/06/88 0800Z Production Company P.O. ~. !~1~ Anc ho¢oge. Alos~ o ~519-~ 12 DALLAS INDEXED ARCO CHEVRON EXXON TEXACO Date: 06/03/88 TO: MOBIL TI: 78905 STANDARD ALASKA PRODUCTION PHILLIPS GEOSCIENCES ARCHIVES .', REFERENCE: . SA]PC CASED HOLE FINAL LOGS o. The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returnlng It to this office: A-25 B-25 C-30 C-31 C-34 D-16 G-2 M-10 R-'2 R-5 R-21 Production Profile Il 11 F].,owmet er/Temp Flowmeter/Temp Flowmet er/T emp Flowmeter/Temp Spinner/Temp Leak Detection Spinner (Fullbore) Leak Detection PITS 05/22/88 t/1 12300-12682 Camco 5" 05/13/88 #1 8950-10563 " " 05/11/88 #1 9300-9700 Camco 5" 05/12/88 #1 11450-11659 Camco 5" 05/12/88 #1 9360-9605 Camco 5" 05/24/88 #1 9650-10000 Camco 5" 05/18/88 #1 9900-10225 Camco 5" 05/21/88 #1 Surf-6150 Camco 2" 05/24/88. #1 9400-9641 Sch 5" 05/21/88 ttl 10-8600 Camco 2" 05/19/88 #1 5500-10514 Camco 5" Rel Naska uni! al the o~;g;nol S"ondo,d O;I C~pony found,d ;, Cle*tlond. C~.o. m 11~70 Victoria Aldridge I NFORMAT ~ ON CONTROL Wel~ Records LR2-1 Standard Alaska P~odu¢ I~a,n Comp, on? 900 £o'. 1907) DALLAS ~RCO CHEVRON EXL~ON INDEXED _ ~-rJ~NDARD ALASKA PRODUCTION Oate: 05/19/88 TEXACO TO: 'ri: 78850 MOBIL PHILLIPS ARCHIVES REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material ls being submlfted herewith. Please acknowledge recelpt by slgnlng a copy of thls let¢er and returning It to this office: A-1 Static Gradient A-15 " " A-19 " " B-25 Flowing Gradient 05/07/88 Otis 05/07/88 Otis 05/07/88 Otis 05/13/88 Camco Recel v INFO, blAT ION CONYRO~ Date Wel I Records LR2-1 DALLAS ARCO cn~.v~oN STANDARD EXXoN /",,[ ASK/"-,~ PRODU[ ]'ION TEXACO Date: 03 / 17 / 88 lO: MOBIL T#: 78668 PHILLIPS ~S~TATE OF ALAS-~'K~./ CEOSCIENCES REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: - B~28, C-21 C-29 H-7 N-8 N-15 N-18 N-19 W-40 W-40 Y-22 B-13 Miscible Gas Injection Profile CH/CNL 03/12/88 #1 FM/Temp 03/10/88 CH/CNL 03/13/88 #1 Production Profile 03/11/88 #1 Injection Profile 03/11/88 #1 PITS 03/09/88 #1 PIT 03/12/88 #1 PIT 03/13/88 #1 CBT 03/13/88 #1 TCP Gun Positioning Log 03/14/88 #1 Temp/Gas Lift Survey 03/09/88 #1 03/1A/88 #1 10400-10826 10450-i1341 Sch 5" 8900-9229 Camco 5" 10900-11930 Sch 5" 10550-10890 Camco 5" 9600-9840 Camco 5" 9600-10200 Camco 5" 9700-10035 Camco 5" 9700-10115 Camco 5" 9302-10564 Sch 5" 9973-1035I Sch 5" 3440-10585 Camco 5" Sch 5" Rece i ved Date A ur,,~ ol ,he o,,9,,~,1 S,o,~do,d 0,1 ~:ov,,('J~-d ,n (le.el~,~(t. C)~,o ,,, 18.70 Victoria Aldridge INFORMAIION CONIROL Well Records LR2-1 ARCO EXXON STANDARD ALASKA PRODUCTION Date: 03/15/88 PHILLIPS /O: T~: 78664 X~S~TATE OF AK PDBY Systems (Transmittal Only) SYSTEMS .(Transmittal & Tape) ARCHIVES SAPC MAGNETIC LIS TAPES & LISTINGS The following material is being sut]nitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: C-29 CH/CNL tape 03/12/88 f/1 10447.5-11367.91 Tape Pos. ~?'05649 Sch f/72634 1600bpi CH/CNL tape- 03/13/88 f/1 10896.5-11955.91 Tape Pos. Sch f/72633 1600bpi #05650 ARCHIVES ONLY- B-28 CH/CNL field C-29 CH/CNL field Tape Pos #05652 Tape Pos #05651 * EXXON' An Asterisk (*) next to a listing above means you should have received the Tape(s) and Listing(s) directly from the respective Please! ,. ~!~~ service company, confirm this. Received ~ INFfRMATIoNVict°ria AldridgeoDNTROL Date ..i.'i .... Well Records I/t2-1 i;;,-% Standard Alaska Production Company 900 East Benson Bouleva~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 3, 1988 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well B-25 (24-31-11-14) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. BJP:JAM Enclosures (9) cc: J. L. Haas (MB12-1) B-25 Well File A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Yours very truly, ~ 3. B~icky, ~upervfsor/ Waterflood & Miscible Flood RECEIVED Mf~p 0 z, !,988 Alaska Oil & Gas Cons. Commission1 Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS · Type of Request: Abandon I'1 Suspend I-I Operation Shutdown ri Time extension [] Change approved program [] Plugging [] Stimulate [] 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1114'SNL, 1899'WEL, SEC. 31, T11N, R14E, UPM At top of productive interval 356'NS!., 3103' WEL, SEC. 31, T11N, R14E, UPM At effective depth 203' NSI., 3332' WEL, SEC. 31, T11N, R14E, UPM At total depth 194' NSL 3346'WE1., SEC. 31, T11N, R14E, UPM Effective depth: 1. Present well condition summary Total depth: measured true vertical measured true vertical Casing Length Structural -- Conductor 110 Surface 2712 Intermediate 9800 Production -- Liner 1120 Perforation depth: measured 10706 feet BKB 9499 feet 10650 feet Re-enter suspended well [] Alter casing [] Pull tubing [] Amend order I'1 Perforate 13 Other [] 5. Datum elevation (DF or KB) KBE,, 80.19 AMSL feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number B-25 (24-31-11.14) PBU 8. Permit number 82.151 9. APl number 5 0 - 02~-20826 O. Pool Prudhoe Oil Pool Plugs (measured) EZ Dri# @ 10650' Junk (measured) BKB 9495 feet Size 20x30 13 3/8 9 5/8 Cemented Measured depth True Vertical depth BKB 8 c.y. 146 146 3720 c. fo 2748 2692 1488 c.f. 9837 8684 7 432 c.f. 9582-10702 9970'-9980', 9990'-10020', 10030'-10088', 10120'-10130' 8451-9495 true vertical subsea 8726'- 8874' (four inte~a/s) R E C E I Y E D Tubing (size, grade and measured depth) 4 1/2" L-80 to 9557' with 4 1/2" tailpipe to 9694' ~AR 0 z, !.q~8 Packers and SSSV (type and measured depth) 9 5/8" Baker packer at 95577 4 1/2" SSSV,t~I~{~,~'Oil & Gas Cons. Commissl0n Anchorage 12. Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 3. Estimated date for commencing operation Februa~ 1988 Su]:;=cq::,;~,t ~7_J. ~ ....... _~ 14. If proposal was venally approved ~o~ No.~' ~/~4/, Dat~~~ Name of approve( 15. the~~~e and correct to the ~st of my knowledge I hereby cen~at Signed ~~~~~~~~ Title Supe~isorWatedl~d/Miscible F~ I ~ ~ ~ Commission Use Only Conditions of approval Notify commission so representative may witness IApproval No. ~ Plug integrity ~ BOP Test ~ Location clearance I Date approved Date Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 12-1-85 Approved Copy Retu.~nedf~ ~: Oommissioner by order of the commission Date Submit in triplicate~ apl: the fOllowing Sag ~iver interval during ?ebruary 9862, -. 9882, IHD ~K~ (8627, nepths A l~ricator Will be - 8645, ~ss) are referenced to BHCS' 10/31/82 FOllowing Per installed aa and tested, f°ratiag Operati~ d testes uas. the Wel~ to 3SO0 Psi for all Well work. Will be returned to Production RECEIVED Alaska Oil & Gas Cons. Commissior~ Anchorage 0833Z 02/08/88 FLOW'TUBES & PACKOFF BOWEN PACKOFF HAND GREASE SEAL FLOWTUBE PUMP FLOWL! N E GREASE LINE RISER GREASE MANIFOLD GREASE PUMP ~- GREASE RESERVOIR BOP Standard Alaska ,~. Production Coml~ ~ 900 East Benson I~, ,ard P.©. Box 196612 Anchoroge, Alasko 99519-6612 (907) 561-5111 December 12, 1986 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Well B-25 (24-31-11-14) PBU Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LRZ-1) w/10 B-25 Well File A. Bragg ~/~/ ervisor Production Operations A unit of the or,ginal Standard Oil Company Founded in Cleveland Ohio in 1870 ~ STATE OF ALASKA ~ ALAS[ *DIL AND GAS CONSERVATION COMr,' SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate i~ Plugging [] Perforate [] Pull tubing Alter Casing ~ Other ~' 2. Name of Operator .~mA~nA~n AT,A.q~A P~ODT]C. TTON COMPANY 3. Address P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 4. Location of well at surface 1114' SNL, 1899' WEL, Sec. 31, TllN, R14E, UPM At top of productive interval 332' NSL, 3140' WEL, Sec. 31, TllN, R14E, UPM At effective depth 203' NSL, 3332' WEL, Sec. 31, TllN, R14E, UPM At total depth 194' NSL, 3346' WEL, Sec. 31, TllN, R14E, UPM 5. Datum elevation (DF or KB) KBE = 80.19 Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number B-25 {24-31-11-14) PBU 8. Approval number 606 9. APl number 50--029-20826 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 10706 feet Plugs (measured) 9499 feet BKB Effective depth: measured true vertical 10650 feet Junk (measured) 9495 feet BKB Casing Length Structural -- Conductor 65 ' Surface 2?03 ' Intermediate 9?92 ' Production -- Liner 1120' Perforation depth: measured 9970' - 10130 ' Size Cemented Measured depth True Vertical depth BKB 20"x30" 8 cu.yds. 110' 110' 13 3/8" 3720 c.f. 2748' 2692' 9 5/8" 1488 c.f. 9837' 8684' 7" 432 c.f. 9582'-10702' 8451.' -9495' (four interVals ) true vertical (subsea) 8726' - 8874' Tubing (size, grade and measured depth) 4 1/2" L-80 t° 9557' with 4 1/2" tailpipe to 9694' Packers and SSSV (type and measured depth) 9 5/8" Baker packer..at 9557'; 4 1/2" SSSV at 2097' Stimulation or cement squeeze summary See attachment Intervals treated (measured) Treatment deScription including Volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well-operation 2140 1533 68 0 309 Subsequent to operation 2260 1384 90 0 199 14. Attachments Daily Report of Well Operations [] Copies of LOgs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge~.,- .- ,~,//-~. ~":'"',~,'~"j Form 10-¢ Rev. 12-1-85 ~/ U' Title Supervisor Production Operations Date/'2.,/).'/~ Submit in Duplicate Well B-25 (24-31-11-14) PBU STIMULATION OPERATIONS A combination 2000-gal. EDTA/80-bbl. scale inhibitor matrix squeeze via coiled tubing was performed on the following perforated intervals in Well B-25 on December 5, 1986. 9970' - 9980' MD BKB 9990' - 10020' MD BKB 10030' - 10088' MD BKB 10120' - 10130' MD BKB Following the treatment, the well was left shut in for 24 hours, then put back on production and tested, jm 12/9/86 Standard Alaska Production C~m ~'~ 900 East Benson 8~. ~ard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 25, 1986 STANDARD ALASKA PRODUCTION Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Well B-25 (24-31-11-14) PBU Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB: JAM ~m Enclosures (9) cc: J. L. Haas (MB12-1) B-25 Well File · A..Bragg V (J upervisor Production Operations A unit of the or,ginal Standard Oil Company Founded in Cleveland Ohio in 1870 STATE OF ALASKA ALAS/'"'"OIL AND GAS CONSERVATION COM?'-'~SION APPLIO I'ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon F~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing E2 Time extension ~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing ~' Amend order .~ Perforate r'_~ Other 2. Name of Operator STANDARD ALASKA PRODUCTION COMPANY 3. Address P. O. BOX 196612, ANCH©RAGE, ALASKA 99519-6612 4. Location of well at surface 1114' SNL, 1899' WEL Sec. 31 TllN R14E, UPM At top of productive interval' ' ' 332' NSL, 3140' WEL, Sec. 31, TllN, R14E, UPM At effective depth 203' NSL, 3332' WEL, Sec. 31, TllN, R14E, UPM At total depth 194' NSL, 3346' WEL, Sec. 31, TllN, R14E, UPM 11. Present well condition summary Total depth: measured 10706 feet Plugs (measured) true vertical 9499 feet BKB 5. Datum elevation (DF or KB) KBE = 80,19 6. Unit or Property name Prudhoe Ba~; Unit 7. Well number B-25 (24-31-11-14) PBU feet 8. Permit number 82-151 9. APl number 50--029-20826 10. Pool P~udhg¢ Oil PQgl EZ Drill @ 10650' Effective depth: measured 10650 feet Junk (measured) true vertical 9495 feet BKB Casing Length Size Cemented Measured depth True Vertical depth Structural -- BKB Conductor. 65' 20"x30" 8 cu..yds. 110' 110' Surface 2703' 13 3/8" 3720 c.f. 2748' 2692' Intermediate 9792' 9 5/8" 1488 c.f. ' 9837' 8684' Production -- Liner 1120' 7" 432 c.f. 9582 '-10702' 8451'-9495' Perforation depth: measured 9970' - 10130' (four intervals) true Vertical (subsea) 8726' - 8874' Tubing (size, grade and measured depth) 4 1/2" L-80 to 9557' with 4 1/2"' tailpipe to 9694' :'.~-r:: '. .. '~.~ Packers and SSSV (type and measured depth) 9 5/8" Baker packer at 9557'; 4 1/2" SSSV at 2097' 12.Attachments Description summary of proposal .~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation December 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Si~eed /~~ Title. Suloervisor Production O~erations Date /_' A. Bragg /'(.,/ Commission Use Only Condit3ons of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance ApprOved by Form 10-403 Rev 12-1-85 Commissioner Dy oraer oT _l the commission Date j/-~. Submit in triplicate Well B-25 (24-31-11-14) PBU STIMULATION PROPOSAL A combination 2000-gal. EDTA/80-bbl. scale inhibitor matrix squeeze via coiled tubing is proposed for the following perforated intervals in Well B-25. 9970' - 9980' MD BKB 9990' - 10020' MD BKB 10030' - 10088' MD BKB 10120' - 10130' MD BKB Following the treatment, the well will be left shut in 24 hours; then put back on production and tested, jm 11/24/86 Coiled Tubing Blow*Out-Preventers Coiled Tubing Pack-Off Blind Rams ! Cutter Rams I (~)-~~2' Chicksan (Kill Line) Slips Pipe Rams Pump-In Sub (C ircula te/R e turns) --~ W ell Head Swab Valve P,oducl~on Compon~ 900 [:o$1 I~en~,on ~ui~-~,d P.O ~. 19~12 Anchorage, Alaska 99519.6612 (~71 564-51 I I TO: DALLAS ARCO CHEVRON EX_XON TEXACO MOBIL PHILLIPS STATE" OF ALASKA GEOSCIENCES INDEXED STANDARD ALASF./-x PRODs. JC Date: 10/09/86 TI: 77393 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signlng a copy of this letter and returning it to this office: - CET 03/02/86 #2 11000-11986 Sch 5" CET 03/18/86 #1 9000-9786 Sch 5" CET 03/20/86 #1 9100-9875 Sch 5" CET 03/19/86 #1 10200-11180 Sch 5" CCL/Perf. 09/17/86 #1 9700-10250 GO 5" CCL/Perf~ 09/27/86 #1 9700-9940 GO 5" CBT 03/08/86 #1 ~700-9648 Sch 5" CCL/Perf. 09/21/86 #1 7900-9217 GO 5" GCT 06/12/86 #1 32-6711 Sch 5' CCL/Perf. 09/22/86 #1 9402-10657 GO 5" EPL 03/15/86 #3 9350-9850 Sch 5" CBT 03/07/86 #1 8900-9629 Sch 5" CBT 06/24/86 #1 8600-9780 Sch 5" CCL/Perf. 09/23/86 #1-4 10500-10950 GO 5" GCT 04/18/86 ~#1 0-10510 Sch 5" founded ,n Clevelo,sd C~-o ,n IRTO Standard Alaska Production Company /--'x. 900 East Benson Boulev P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 September 26, 1986 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well B-25 (24-31-11-14) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Operations, for the above-named well. This contains our subsequent report of perforating the well. As discussed in a telephone conversation 9/18/86 between Lonnie Smith and Barry Chapman, the Application for Sundry Approval was not forwarded through an oversight on our part prior to the work being performed. Enclosures (4) cc: J. L. Haas, MB12-1 Well Records, LR2-1 B-25 Well File A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Yours very truly, P. F. Barth, Supervisor Re servoir/Production Surveillance Unit I STATE OF ALASKA ALASF"-~IL AND GAS CONSERVATION COMrv'"'";ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate F' Plugging [] Perforate [] Pull tubing Alter Casing ~ Other [] 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 80.19 Feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 1114' SNL, 1899' WEL, Sec. 31, TllN, R14E, UPM At top of productive interval 332' NSL, 3140' W-EL, Sec. 31, TllN, R14E, UPM At effective depth 203' NSL, 3332' WEL, Sec. 31, TllN, R14E, UPM At total depth 194' NSL, 3346' WEL, Sec. 31, TllN, R14E, UPM 7. Well number B-25 (24-31-11-14) PBU 8. Approval number 9. APl number 50--029-20826 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 10706 feet 94 99 feetBKB Plugs (measured) EZ Drill @ 10650' Effective depth: measured 10650 feet Junk (measured) true vertical 9495 feetBKB Casing Length Size Cemented Structural -- Conductor 65' 20"x30" 8 cu.yds. Surface 2703' 13 3/8" 3?20 c.f. Intermediate 9792" 9 5/8" 1488 c.f. Production -- Liner 1120' 7" 432 c.f. Perforation depth: measured 9970' - 10130' (four intervals) Measured depth 110' 2748' 9837' 9582'-10702' True Vertical depth BKB 110' 2692' 8684' 8451'-9495' true vertical (subsea) 8726' - 8874' Tubing (size, grade and measured depth) 4 1/2" L-80 to 9557' with 4 1/2" tailpipe to 9694' Packers and SSSV(type and measured depth) 9 5/8" Baker packer at 9557'~ 4 1/2" SSSV at 2097' Stimulation orcementsqueeze summary Intervals treated (measured) 1986 'Alaska 0il & Gas Cons. Commission Anchorage Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2480 2082 52 0 199 434:0` 4360 28© 1429 242 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed, , /. ~- Title Supvr. Res/Prod. Surveillance I Form 10-404 Rev. 12-1-85 Submit in Duplicate PERFORATING DATA - Well B-25 (24-31-11-14) PBU The following additional intervals were perforated September 17, 1986 using Gearhart 3 1/8" carrier guns at 4 spf: 9970' - 9980' MD (8726' - 8735' TVDss) 10120' - 10130' MD (8865' - 8874' TVDss) All depths are referenced to BHCS/GR, 10/31/82. A lubricator was installed and tested to 3500 psi for all well work. The well was put back on production and tested. jm 9/18/86 SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 February 26, 1986 Alaska Oil & Gas ConserVation Commission 3001 PorCupine Drive Anchorage, Alaska' 99501 Attn: Mr. C. V o Chatterton Well B-25' (24-31-11-14) PBU Gentlemen: Enclosed, in duplicate, is FoTM 10-403, Sundry Notices and Reports on Wells, for'the'above-named well. This contains our subseqUent repOrt of stimulating the well. Yours very truly, JAB: J~ S~ervisor Production Operations Enclosures (2) cc: Drilling Well Files (MB12-1) Well Records (LR2-1) B-25 Well File RECEIVED FEB 2 8 ]986 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7, Permit No. SOHIO ALASKA PETROLEUM COMPANY 82-151 3. Address 8, APl Number P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 50-029-20826 4. Location of Well At surface: 9. Unit or Lease Name Prudhoe Bay Unit 1114' SNL, 1899' WEL, Sec. 31, TllN, R14E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 80.19' AMSL I6. Lease Designation and Serial No. ADL 28310 10. Well Number B-25 (24-31-11-14) PBU 1 1. Field and Pool Prudhoe Bay Prudhoe Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Welt [] Change Plans [] Repairs Made Pull Tubing [] Other E] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations. (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work. for Abandonment see 20 AAC 25.105-170). A 40-bbl. EDTA acid wash was performed on the following perforated intervals on February 19, 1986, via coiled'tubing. 9990' - 10020' BKB 10030' - 10088' BKB The SSSV was. removed prior'to the stimulation and reset after the job at 2097'. RECEIVED FEB 2 8 ]986 Alaska 011 & Gas Cons. Comml~lon Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (-,~/~ /~~'I~. Til,eSupvr. ProdUction Qperations The space b/~47~ for Commission use U(~. A. Bragg Con-----J;, ions o(9/Approval: ;~' ;-n~ ~ By O,de, of Approved by COMMISSIONER the Commission Dale Form 10-403 Subm,! "Intentions" ,n Triplicate R~,u 7.1.nn ,'~nfl ".q,,h<.auent R~_nOri~" in [3uohcale SOHIO ALASKA PETROLEUM COMPANY FebrUary 12 ,' 1986 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well B-25 (24-31-11-14) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB: JAM~ //. A-- .Bragg USupervisor Production Operations Enclosures (3) cc: Drilling Well File (MB12-1) Well RecOrds (LR2-1) B-25 Well File RECEIVED Alaska Oil & Gas Corls. CommJss/or~ Anchorage STATE OF ALASKA ALASKA G,~. AND GAS CONSERVATION CO,.,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL r-I COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. Permit No. SOHIO ALASKA PETROLEUM COMPANY 82-151 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20826 4. Location of Well At surface: 1114' SNL, 1899' WEL, Sec. 31, TllN, R14E, UPM 5. Elevation in feet (indicate KB, DF, etc.) ERR= 80.19' AMSL J 6 . Lease Designation and Serial No. ADL 28310 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number B-25 (24-31-11-14) PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Propos~ or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposedwork, forAbandonmentsee20AAC25.105-170). A 2000 gal. EDTA acid wash is proposed for the following perforated intervals in Well B-25. 9990' - 10020' BKB 10030' - 10088' BKB The SSSV will be removed prior to the stimulation and reset after the job at 2097'. This work is scheduled to commence in February/March 1986. RECEIVED F' ~!i!;;t 1 4 1986 A!aska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title...S. upvr. Production Operations L_T_~e sp//elow for Commission use ~J. A. Bragg Condi iof~'s of Approval, if any: Approved Copy Returrte~ ~Y LBNNI[ C~ SlJ~ By Orderof Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate soHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON 31 I 1 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 GETTY TO: SFO/UNIT/STATE' (-Marathon) MOBIL PHILLIPS BPAE (TranSmittal Only) CENTRAL FILES (CC#' s-Transmittal Only) Date: 3-7-84 CC#: 75105 //~NCE: ocs ~.!~owing material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- ~25 TDT-M 12-1-83 #1 9950-10634 Sch 5" D-17 TDT-M 12-3-83 #1 9500-10413 Sch 5" (4/82) RECEIVED DATE Carolyn Bishop Development Geology Well Records SOHIO ALASKA PETROLEUM COMPANY SFO ARCO TO: EXXON PHILLIPS CENTRAL FlLES(CC#'s-Transmittal Only 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 2-27-84 CC#: 75066 REFERENCE: //~Hio MAGNETIC LIS TAPES & LISTINGS ' .,,,,,'The following material is being submitted herewith. Please acknowledge receipt by signing a /_.// copy of this letter and returning it to this office:-- SFO/UNIT/STATE: '~B-6 ~-,B-25 *H-7 2-3'84 #6 C/ff/OqLw/Listing Sch #68983 C.H. 12-1-83 #1 TOT-MLISw/Listing Sch #68867 C.H. 11-11-83 #- CH/~NLw/ Listing Sch #68787 C.H. _T_ape Pos. 02883 02884 02881 (4/89 *SFO & EXXON: An Asterisk.(*) next to a listing abouve means you should have received the TaM(s) and Listing(~$~ diy~ectlpTm from the respective service company. Please conf i~,h'i s. ~ ~/L ..... / ~ .... -- ;, - - - - ~_-~_ ~o1~ Bishop Development Geology D~E ~ Well Records SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO - CHEVRON 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE 1907! 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 ~o~ SFO/UNIT/STATE: (-Marathon) EXXON GETTY MOBIL PHILLIPS STATE ~: BPAE (Transmittal Only) CENTRAL FILES (CC#'s - Transmittal Only) Date: 12/12/83 Trans.f~ - 74881 CC#: REFERENCE: (4182) SOHIO FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- PBU Pressure Prin~ut Formats for wells ~fD-22(8/24/83), D-1 B-2 10/03/83 Pressure Survey & BHPD B_25~ " ,, ,, ,, C- 2 ~" BHPD C-24 /Pressure Su~,ey" " D-16 ~ BHPD D_22~-'~ ,, E-1 ~ Static Gradient E-4 j BHPD E-4 ~ Pressure Survey & BHPD E-9~'~ Static Gradient F-4 ~-~ Pressure Survey & BHPD F-6 ~' " " " " F-16/ " " " " F-16 ~ Flowing Gradient F-17 z~' Pressure Survey, & BHPD F-17 ~- Static F-18/ H-6 / Pressure Survey & BHPD j_6 ~-'~ ,, ,, ,, ,, M-6 ~ Static Gradient N-2~ " N-16'~ Pressure Survey & BHPD N-16-~ Static Gradient N_17~ ,, ,, N-18 / Pressure SurVey & BHPD N-18 ~ Static Gradient N_19~- ,, ,, Q-3 ~ 6(8/26-28/83), C-2(8/30-9/1/83) & GO E-4 (9/2-3/83). 09/30/83 08/31/83 09/23/83 08/27/83 08/23/83 10/03/83 09/02/83 11/13/83 11/25/83 10/07/83 10/06/83 11/~2/83 10/29/83 11/27/83 10/30/83 11/04/83 10/09/83 11/02/83 11/24/83 11/26/83 12/02/83 11/07/83 11/09/83 12/04/83 11/17/83 11/16/83 12/05/83 Otis Johnston Macco Otis Johnston Macco Johnston Macco Camco Johnston Macco Camco GO GO Otis Otis Camco Camco Otis Camco Otis Otis GO GO Camco Otis Camco Otis Otis Camco Camco ABOVE BY JOHNSTON-MACCO Victoria Aldridge TP1-5 Development Geology Well Records SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE {907! 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 TO: SFO/UNIT/STATE: GETTY (-Mar a tho n) MOBIL PHILLIPS ~ STATE OF AK BPAE (Transmittal Only) CENTRAL FILES (CC#' s-Transmit tal Only) Date: 10/12/83 CC#: 74765 REFERENCE: S~~ CASED HOLE FINAL LOGS /The following material is being submitted herewith. Please acknowledge receipt by signing a /~ copy of this letter and returning it to this office:-- B-25 C-24 Spinner 9/30/83 #1 9800-10150 Otis 5" Spinner 9/24/83 #1 10100-10464 Otis '5" (4/82) RECEIVED DATE , Victoria Aldridge TP1-5 ~s ___ Well Records Alaska 0il & G~s Cons~ Commissior~ Anchorage SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 September 28, 1983 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Well B-25 (24-31-11-14) PBU Enclosed, in duplicate, are the following forms for the above-named well. 1. Form 10-407, Completion Report; 2. Form 10-403, Sundry Notice and Reports on Wells; 3. Form 10-404, Monthly Report of Drilling and Workovers. Gjp/J~"H~/pjw Enclosures cc: J. D. Hartz Geology Well File #17 Yours very truly, ' ' troleum Engineer SEP 3 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ~ , ' ALAS~)IL AND GAS CONSERVATION'-%~MMISSION WELL COMPLE% .JN OR RECOMPLETIO.. REPORT AND LOG 1. Status of Well Classification of Service Well OIL:3~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7, Permit Number Sohio Alaska Petroleum Company 82-151 3. Address 8. APl Number Pouch 6-612, Ancho[age, Alaska 99502 50- 029-20826 · ,,. 4. Location of well at surface 9. Unit or Lease Name 1114' SNL, 1899' WEL, Sec. 31, TllN, R14E, UPM Prudhoe Bay Unit At Top Producing Interval top of Sag R. Sst. ~0. Well Number 356' NSL, 3103' WEL, Sec. 31, TllN, R14E, UPM B-25 (24-31-11-14) PBU _ At Total Depth i 1. Field and Pool 194' NSL, 3346' WEL, Sec. 31, TllN, R14E, UPM Prudhoe Bay _ , , 5. Elevation in feet (indicate KB, DF, etc.} } 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 80.19' AMSLI ADL 28310 , 12. 10-14--82Date Spudded 13. Date10_31_82T.D. Reached 14. Date 11-5-82C°mp" Susp. or Aband.II 15. Water Depth, iffeetOffshoreMSL.1116' NO.oneOf Completions ' 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+-rVD) 19. Directional Survey 20. Depth where ssSv set 21. Thickness of Permafrost .0706 'MD 9499 'TVD 10650 'MD 9445 'TVD YES [] NO [] 2097 feet MD 2095 ' 22. Type Electric or Other Logs Run DIL/SP/GR, DIL/BHCS/SP/GR, FDC/CNL/CAL GR, Gyroscopic Survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORDIAMOUNTPULLED , '20"x 30" £nsulated:onductor Surface 110' 36" 8 cu. ft. concrete' - '~3 3/8" 72~ L-80 Surface 2748' 17 1~2" 3720 cu. ft. Permafrost II 9 5/8" 47~ L-80 Surface 9837 12 1/4" 1355 cu. ft. Class G; ,,, 133 cu. ft. Permafrcst C , 7" 26~ L-8.0 9582' 10700' 8 1/2" 432 c.u...ft. Class G ~/18% salt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. IUBING RECORD interval, size and number) MD TVDss SIZE DEPTH SET (MD) PACKER SET (MD)' Prudhoe Oil Pool Top: 9990' 8744' 4 1/2" 9557' 9557' Bottom: 10088' 8835' w/4 1/2" ta .1pipe 9694' 26. ACID, FRACTURE, CEMENT SQuEEzE, ETC. 9990'-10020 ' BKB (8744'-8772' TVDss) DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED 10030'-10088' BKB (8781'-8835' TVDss) 10650' EZ Drill Plug , ,, _ ,., 27. PRODUCTION TEST Date First Production I Method of Operatfon (Flowing, gas lift, etc.) August 31, 1983I Flowing " Date of Test Hours Tested P"RODUCTION FOR OIL-BBL GAS-MCF wATER-BBL CHOKESIZE iGAS-OILRATIO TEST PERIOD I Flow Tubing Casing Pressure (~ALcuLATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co'r) Press. 24-HOUR RATE I~ · ..... 28. CORE DATA .... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None .~,,~ Ala¢~ Oil & Gas Cons,, Commis:;lo~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. (GEOLOGIC MARKERS FORMATION TESTS -- ., NAME Include interval tested, pressure data, all fluids recovered and gravily0 MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ..... BKB Subsea Sag. R. Sst. 9856' 8621' Shublik 9881' 8644' Ivishak 9964' 8720' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~~~ ~~ District Petroleum En. ineer S~gned T~[e INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA ALASKA ~L AND GAS CONSERVATION CO,,,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 82-151 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50_029-20826 4. Location of Well At Surface: 1114' SNL, 1899' W-EL, Sec. 31, TllN, R14E, UPM 5. Elevation in feet (ir~dicate KB DF etc.) KBE = 80.19 AMSL' ' 12. 6. ~]i,e [~e~i~r~on and Serial No. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number B-25 (24-31-11-14) PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals were perforated August 31, 1983, using Dresser Atlas 3 1/8" Carrier guns at 4 s.p.f. A lubricator was installed and tested to 3500 psi on all well work. 9990'-10020' BKB (Ref. BHCA/GR, 10-31-82) 10030 '-10088' BKB ( " ) An SSSV was set and tested in the ball valve nipple at 2097' Alaska Oil & Gas Cons. Commissior~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed.././- . . . ~/ F T hesp)~c~elowfor Co mission use CondltiCns of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate PERFORATING DATA - Well B-25 (24-31-11-14) PBU August 29, 1983: Pressure tested tubing and inner annulus. August 31, 1983: September 5, 1983: Rigged up Dresser Atlas and perforated the following interval using 3 1/8" Carrier guns at 4 spf: 9990'-10020' BKB (Ref. BHCA/GR, 10/31/82) 10030'-10088' BKB ( " ) Put weal on production. Shut well in to prepare for static pressure survey. September 7, 1983: Ran static pressure/temperature survey at 8800' TVDss. September 8, 1983: Set and tested SSSV in ball valve nipple at 2097' Well on production. -~_' '-' .~, , STATE OF ALASKA -~- ALASKA ('~'~ AND GAS CONSERVATION CC'"'?vllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] I 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company 82-151 3. Address 8. APl Number Pouch 6-612, Ancborage,,Alaska 99502 50-029-20826 4. Location of Well at surface 1114' SNL, 1899' WEL, Sec. 31, TllN, R14E, OPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 80.19' AMSL 6. Lease Desiqnation and Serial N°. ADL 28310 9. Unit or Lease Name Pr,_,ah~e Bay Unit 10. Well No. B-25 (24-31-11-14) PBU 11.FieldandPool Prudhoe Bay Unit Prudhoe Oil Pool For the Month of September ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run · 16. DST data, perforating data, shows of H2S, miscellaneous data See Attached Ai,~s~a 0it & Gas C~rl,~; Ancnor~,cje 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~~m District Petroleum Engineer SIGNED -,~ ,,, TITLE DATE NOTE--R t on this form is required .__ _ach ndar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and G~onservation Commission by the 15th'of the succeedin, g month, unless otherwise directed. Form 10-404 Submit in duplicate SOHIO ALASKA PETROLEUM COMPANY ,,,, SFO ARCO - CHEVRON 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 EXXON TO' SFO/UNIT/STATE: (-Marathon) GETTY MOBIL PHILLIPS ~iSTATE BPAE (Transmittal Only) _ CENTRAL FILES (CC#'s - Transmittal Only) Date: 9/22/83 Trans.#: - 74726 CC#: REFERENCE: S~ FINAL DATA- PRESSURE SURVEY DATA .~,.~The submitted herewith. Please acknowledge receipt by signing a following material is being copy of this letter and returning it to this office:-- B-25 '"-~- Static Gradient 9/7/83 Otis C-18 ~'~ " 8/18/83 Otis C-19 ~' " 8/20/83 Camco C-20f' " 8/21 / 83 Camco C-21/ " 8/23/83 Otis C-22 J " 8/25/83 Camco C-23--~ " 8/31/83 Camco C-24 ~ " 9/3/83 GO C- 28-"'"'"' " 9/5/83 Otis D-3~' BH Pressure Report & BHPD 8/9/83 GO D-17 Static 8/13/83 Camco D_18u~' " 8/19/83 Otis D_20--~ " 8/17/83 Camco H-8 ~' Transient Pressure Survey & BHPD Sperry Sun H-8~' Pressure BU 8/11 & 12/83 Sperry Sun M-2.~- Static Gradient 9/7/83 Camco N-9 j~ Initial Well Transient Pressure & Spinner 9/5/83 GO Pressure BU 9/4/83 GO Static Gradient 9/8/83 Camco N-9 R_l 8/11/83 8/11/83 '4/82) RECEIVEO _ DATE Aiaska 0il & Gas Cons, Commission Anchorage Victoria Aldridge TP1-5 Development Geology Well Records SOHIO ALASKA PETROLEUM COMPANY May 9, 1983 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska .99501 Attention: Mr. C. V. Chatterton Wells B-18 through B-23 and~25' C-18 through C-28, and D-16 through D-23 (excluding D-19) Gentlemen :~ 'EnClosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named Wells. This contains our proposal to perforate these wells. ~._ Distr_i~ Petroleum Engineer GJP:JLH:pjw Enclosures CC: J. D. Hartz Geology Well File #17 STATE OF ALASKA ALASKA C"-"AN D GAS CONSERVATION CO"'-'"~ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator 7, Permit No. Sohio Alaska Petroleum Company 82-151 8. APl Number 3'Add~Such 6-612, Anchorage, Alaska 99502 50- 029-20826 OTHER [] 4, Location of Well At Surface: 1114' SNL, 1899' WEL, Sec. 31, TllN, R14E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 80.19' AMSL 12. I 6. Lease Designation and Serial No. ADL 28310 9. Unit or Lease Name Prudhoe Bay Unit 10, Well Number B-25 (24-31-11-14) PBU 11. Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] . Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other r'-I Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals will be PerfOrated during June/July, 1983, using 3 1/8" carrier guns at 4 spf. A lubricator will be installed and tested to 3500 psi for all well work. *9990' - 10020' BKB (Ref. BHCA/GR, 10-31-82) 10030' - 10088' BKB ( " ) An SSSV will be set and tested in the ball valve nipple at 2097'. *Contingent interval, to be perforated if well will not sustain flow. Subsequeat Wo~k~_ z/x~ .~// ~ ~t j~R. eportea ' -,- 14. I hereb tif that the f lng is true and Correct to the best of my knowledge. Sign ~. TitleDis~riC~ ~e~Fo~eum SngineeF · u,e d Conditions of ApprOval, ~ any: Approved by 0~l~'l~[ SIGNED BY [()N;~!E C. SMITH Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY TO: SFO ARCO EXXON PHILLIPS CENTRAL FILES(CC#'s-Transmittal Only 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 1-4-83 Da te: Trans. # :2979 CC#: 55979 REFERENCE: 'NETIc LIS, TAPES & LISTINGS ollowing material is being submitted herewith. ,Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- ,~B-25~ 10-26-82 Magnetic Open Hole Tape Tape Pos # 02029 D/A *C-24~ 9-20-82 - ,, ,, ,, ' *C-23/~ 8-31-82 ,, ,, ,, 02028 D/A " 02027 D/A Replacement tape; bad data on DIFLrun #1 *B-22/ 8-22-82 Magnetic OpenHole Tape 02026 D/A *B-23/ 9-11-82 ,, ,, ,, ,, *C-27-- 11-28-82 ,, ,, ,, 02025 D/A " 02024 D/A *C-25~ 10-9-82 ,, ,, ,, ,, *B-24~ 10-4-82 . ,, . 02023 D/A " 02022 D/A (4/89 *SFO & EXXON: An Asterisk:(*) next to a listing abouve means you should have received the Tape(s) and L~r__~(s)~~~~~~tive service company. Please confirm this. ' 0 - 1983 Geology .: DATE ~9 Well Records Alaska Oil & 6as Cons. Commission Anchorage SOHIO ALASKA PETROLEUM CO;~,'~PANY 1'0: SFO/UNIT/ STATE: SFO i CHEVR(~N ' ' EXXON '. GETTY' .: NARATHON MOBIL PHILLIPS OF AK BPAE (Transmittal Only) 3111 "C" 51R£ET ANCHORAGE. ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date:~ 11~23~82 Trans.~: 2880 CC#: ,55880 * Da C"~" to" :'$ ta Ce Via Drilling: · · 11r~.3,-,82 REFER~:ENTRAL FILES (CC#' s-Transmi, t.,t. al Only) SOHIO OPEN HOLE FINAL LOGS -.. ., ' ~ , . · · The following material is being Submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- SFO/UNIT/STATE: B-25 Dres~ DtFL #1 1Q~26.~82 Z748~9.842 #2 10~3t~82 .~454~10705 '5" & 2" B-25 Dres. B-25 Dress. B~25 Dres. BHC CDL CDL/CNLog #1 10~31~82 9.453~10677 #1 10~31~82. '9800'"1(1708 #1 10-'31~82 '9.800r,t(1708 5" & 2" 5'' & 2u 5''~' & 2" STATE ONLY: DIRECTIONAL SURVEYS: Magnetic Single Shot Directional Survey Gyroscopic Directional Survey Date: Date: RECEIVED DATE 10~14v82 Job#: A~1082~014 11~10~82 Job#: Boss~16127 Karen t~es-t a s- Well Reco~s: Uept? ~s ~ . ~Development Geology Alaska 0ii & Gas-C-5-n~. uommls~,~on, . Anchorage SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 December 1, 1982 Alaska Oil & Gas Conservation C~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton 'WRT'.T'. 'B'25 .' (24~-31~11~14)' 'PBU Enclosed, in duplicate, is Form 10-407, Well Completion Report, for the' above-n~ well together with the Well History, Well Logs and Directional Surveys. This well has been completed as a non-perforated oil well. Very truly yours, encs cc: Well File #17 Geology R. H. Reiley District Drilling Engineer ....... ?"'" STATE OF ALASKA WELL C 0 M ~tA~'~'~ Classification of Service Well 1. Status of Well · OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Sohio Alaska Petroleum Company 82-151 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20826 4. Location of well at surface 9. Unit or Lease Name 1114' SNL, 1899' WEL, Sec. 31, TllN, R14E, UPM ~--~'H'a Prudhoe Bay Unit At Top Producing Interval top of Sag, R. Sst, I ~'-'J~nSI 10. Well Number B-25 (24-31-'11-14) PBU 356' NSL, 3103' WEL, Scc. 31, TllN, R14E, UPM At Total Depthi SNOii. V301 !~ 11. Field and Pool 194' NSL, 3346' WEL, Sec. 31, TllN, R14E, UPM ' Prudhoe Bay 5. E~evation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 80.19' AMSLI ADL 28310 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 10--14--82 10--31--82 11--5--'82I feet MSLI One 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey i 20. Depth where SSSV set 21. Thickness of Permafrost 10706'MD-9499'TVD 10650'MD-9445'TVD YES~ NO []I 2097 feet MD 2095l 22. Type Electric or Other Logs Run DIFL/SP/GR, DIL/BHCS/SP/GR, FDC/CNL/CAL/GR, Gyroscopic survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20'x 30 Znsulated Conductc,r Surfac~~. 110 36 8 cu.yds, concrete 13 3/8 ~729 L-80 Surface 2748 17 1/2 3720 cu.ft. Pe~maf~,st II 9 5/8 479 L-80 Surface ·9837 12 1/4 1355 cu. ft. Class G; 133 cu. ft. Permafr~.st C 7 26# L-80 9582 10700 8 1/2 432 cu. ft. Class G w/18% salt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD ihter'val'TSize and number) : I SIZE DEPTH SET (MD) PACKER SET (MD) 4 1/2" 9557' 9557' w/4. 1/2" taJ.lpipe 9694' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. None . ..... ':, . .~ DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 10650' EZ Drill Pluq . · 27. PRODUCI~ON TEST Date FirsfR~oduction - ~ ' ' "I Method of Operation.(F~owing, gas Hft, etc..) Date of Test Hours Tested PRODUCTION FOR O~L-BBL GAS-MCF WATER-aBL CHOKE S~ZE IGAS-O~L RATIO ... : .- ,'- . TEST PERIOD I~: . Flow Tubing ' Casidg Press.ure '. CALCULATED OIL-BB.L GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. ' ' ~ _, .-, 24:HOUR RATE. ~ .' ' 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None , - .. REC. EIVED -' " DEC021982 Alaska 0il & Gas Cons. CcmmmsJ0~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. · GEOLOGIC MARKERS FORMATION TESTS . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTF GOR, and time of each phase. BKB SLlt~F_~ :. , Sag. R. Sst. 9856' 8621' Shublik 9881 ' 8644 ' Ivishak 9964 ' 8720 ' 3! LIST OF ATTACHMENTS Well History, Well Logs and Directional SurveyS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Distr~ct Drilling Engineer Signed L~*~ ~,,~ ~'~~~ '~ ~)~/Title 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 productio.n 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, Hvdraulic Pump, Submersible, Water Ir~- WELL B-2'5 ('24-31'i1'14~)' PBU WELL HISTORY Spudded well at 0900 hours October 14, 1982. Drilled 17 1/2" hole to 2750'. Ran 71 jts. 13 3/8" 72# L-80 Buttress casing to 2748'. Cemented with 3720 cu. ft. Permafrost II ~t. Installed and tested BOPE. Cleaned out to 2708', tested casing to 3000 psi, okay. Drilled out to 2790', ran leak-off test to 0.74 psi/ft. gradient. Directionally drilled 12 1/4" hole to 9860'. Ran 241 jts. 9 5/8" 47# L-80 Buttress casing to 9837'. ~ted in tw~ stages: First stage with 1355 cu. ft. Class G cement; second stage through D.V. packer at 2652' with 133 cu. ft. Permafrost C cement preceded by Arctic Pack. Cleaned out D.V., tested casing to 3000 psi, okay. Cleaned out float equiument and directionally drilled 8 1/2" hole to 10706'. Ran open hole logs. Ran 29 jts. 7" 26# L-80 IJ4S liner to 10700'. Cen~_nted with 432 cu. ft. Class G cement with 18% salt. -. Cleaned out to 10658'; no cement. Tested liner lap to 3000 psi, okay. Changed well over to NaCl. Ran CBL. RIH with EZ Drill, set by wireline at 10650' MD. Ran 243 jts. 4 1/2" 12.6# A/B ~d Buttress IPC tubing with 4 1/2" tailpipe assembly to 9694'. Landed tubing with ball ~ralve at 2097'. Installed and test~ tree. Displaced tubing to diesel, set packer at 9557'. Tested tubing to 3500 psi, okay. Released rig at 2400 hours, November 5, 1982. Ran gyroscopic survey, tested and secured well November 10, 1982. RE£EIVED DEC 0 2 J982 Alaska Oil & Gas Cons. Ccmmlssior~ Anchorage CONTROLL,., DRILLING · . i ::'~ ':. '.:. i':.-::'- ...:7668.HiShla ncier 'DriX;e-?: ! ' :.' · !". '.-:. -Anch0r~age, Alaska . . .- . :.'-.-:'::. :....i:-.' '...'-(90'7) 349:31 . - ,. ., . . · , . Mr.. Brian Rose Sohio Alaska. Petroleum 'Company' Pouch 6-612' ..", ~' Anchorage, .AK 99502 RE: Magnetic Single Shot Survey, · . --'' Job:No. A~1~82-014 ' ~ ~:'.'. WelI B-25 prUdhoe BaY.FField North .Slope:'~ Alaska ~'.:"'~'-'.:-..' Dar0 of Survey: 10-14-82 Dear Mr.' Rose: ' ' _?'.,,.':, ' Please find".enclosed th~-"'!')0rigin~1'' and six (6) copies of'.our Magnetic si~gie.'shot SurVey on the ab0ve'well. The method used in calculating-this surVeY'was Radius of Curvature. The depth of the survey..was 91,743," Thank you for'..giVing us this opportunity to be of service. ' . Yours very truly, ... Controlled Drilling .Consultants, Inc'. C'. W~.. Harrin'gton .. · . ,. :i~ Dir.ect ional'.:; Supervisor RRD[US*'OF CURVRTURE HETHOD OF 'coH~UTRTZOH : COHPUTED FlOR *CDC BY OCE~HTECH CFH L]:NDSEY &*-I~$S,OC. ) R~CORD OF SURVEY D N ~0 0 0 ,99 · '-80.19 DEG. , S , ,0.0 $ , ,00 U t5,' 1650 3 0 !649,96 t?4t 5 45 1740,68 ~81 $ ,00kl t569.77 S12,00# 1660,49 $ ?.OOki 2204 17 30 2195,$2 2295 18 0 2262.29 25[44 2~ 45 2~13,13 2115,43 S12, OOW 2202.10 $15, OOki 24:32.94 $t2' 2:634 28 15: 2592.96 2512;77 $12,0:0# 3432 34 45 3262,28 3192,09 Sll,OOM 38G3 33 45 3&18.54 4'~5~ 33 ..... 0 4030'24 4822 32 45 -4421.61 5297 33 dS 4816,64 ~'60S 33' 4'5 S'e?4 , 93 6007 36 0 5404,71 2,36 $ .25 9,21 $ 1.39 86.89 G 17,01 113.87 ~ 23,49 153'20 S 203,91 $ 45.37 244,56 8 54,01 407.04 G 64,12 671.40 S t30.74 3538.35 $10.OOkt 909.90 S 174,94 OS 1 224, 4341.42 813,00g 1423.97 $ 276,95 4738.65 ' 815. OOki 1676,66 $ 339, ~ 4994' 7~ ~t 4';'~dO~ 1942, 32 S 3~2 ' 80 5324.52 S16,00~ 2064.32 S 442.28 , O0 S90 ', 00' 2.38 $ 9,31 $ 8 36 25 W ? :7' 49 '49 88.s4 s 11 4 43 116,26 2 08,90 250,45 684.01 926.57 1450.65 1710.?? 2111,17 2320,67 0 0 ki .000 , · o'ki , 3,297 2,33 3,022 9,20 8:06 17 2 230 4,$:16 42, 3; 533 62,49 3; 226 88. O0 ,633 , 115,68 2.6U 156.26 4. 309 208,', ) , 667 249,52 ;738 413.57 .250 679.77 .243 920.5;' ,164 11:89.81 ,137 t441,62 · 247 1701 , , 180 I$72.48 · 586 2102. t 1 .212 2311.99 '25 8INGLE 8HOT 2'9 OCT. 2 RECORD OF SURV£Y TRUE DOG LEG 4EAS, DRIFT VERTICAL SUB DRIFT TOTAL COORDINATEG C L O S U R E S SEYERITY )EPTH AHGLE DEPTH SEA DIREC DISTANCE ANGLE DEG/100FT D N 'O;~.' D . s' SECTION DISTANCE 7339 34 45 6476.93 6396'~,'74 $15.00W 3 $ 662',63 W 2999. 7591 33 0 6686.15 6605,96 816.0.0W 2958,47 $ 700,16 W 3040,20 $ 13 18. 53 W ,?04 3032.46 7920 31 15 6964.76 6884,57 $14,008 3t27.45 $ 745,44 W 3215.06 9 13 24 23 ~ .557 3207.25 ; ?'91::",'53 W 33:$$ 1.493 820:..94 W 3424,.23:. t.304 3417,74. ,o0 's37.oou 35:51.i4 S 955.&& u 9466 24 30 8356.02 8275.83 $50.00W 3693.56 $ !090,82'U )OTTON HOLE CLOSURE S 17 24 9. ~ 3851.27 $ 16 27 12 W 3944,94 $ 17 24 8 W .466 .487 ,254 3850.74 3944.94 D£F',H ~HO ,~E:V£RV £V£, 0o ;££T OF DE:P?." · r, TRUE V£RT!C~L CORRECT!OH: E O, -80 t 81O 180. 1 O0 : 590 580, 500 790 ?80, 700 t 380 18;)I 1992 2084 2293 2507 2620 2734 2e5 0 2970 30go 32 t 1 3332 3454 3575 36~6 1 lglo. 11.00 0 1280, 1200 0 1380, 1300 0 0 0 0 0 0 1 4 9 14 17 19 2O 22 1600. 17g O, i700 0 18'8o. 1800 o 1980, 1900 1 a:Oee. 20~0 3 2t80. 21 O0 7 2280, 2208 12 2380. 2~00 2480. 2400 27 2580. 2500 39 268 e, 26 OG 53 2780. 2700 70 2ee O. 2000 89 ~9e0. 3oeo. 3000 3 eo. z oo 3280. 3200 i73 3380. 3300 3480, 3400 216 .00 S ,00 $ 4. 9.2'1 22.35 35.29 55,46 92.21 113,21 147,23 189,26 237.88 292.17 351.17 415.08 491,41 549.28 615.67' 683,59 751.24 818.25 3,11 W 5.79 td 10.3'1:: W 16,0:2 U 23.31 W 32.t6 W 41.94 bi 52,59 bi 74,69 bl 95.40 bi 9&,28 U 107.86 bi 120.13 bi 133,10U 146,02 td t59.47 W TRUE YER 381 ? 393;' 441 6 4535 4654 5131 5251 5371 56ti. 5?32 5954 5977 6100 6349 64?4 6599 6724 6849 6974 7098 7221 7343 ?464 75~4 7703 7821 358'0. ,3500 236 8884,62 $ 170,46 bi 36880. 360'0 256 950.37 $ 182,13 Y 4080, 4009 335 4188.0, 4100 354 1271,885 4280, 4200 373 1335,06 1 146 4( 47880. 4889e. 5290, 53880. 5460. 5580. 5688O. 5;'80. 5880. 5990 ~ 6090, 6teo, 628~. 6 38 O. 6480. 6580. 6680. 6790. 6880. 6990. 4600 450 4700 470 333,33. Y 488800 490 350,48 bi 5'200 5?3 5300 596 5400 620 5!500 :644 ~00 6688 57 O0 693 5800 ;;'188 5900 743 6000 ;'688 61 O0 793 62 O0 lt.1 ? 6300 840 6500 883 6600 903 6700 922 68809 940 6900 957 20 20. ~4 ~4 25 25 24 18 1651,75 t?'16,27 1645.73 19t: :I 197;) ,56 2047.24 2 064,32 2064,32 ~ 2064,32 2331,09 2402.97 2474.92 2546.96 2688.7? 2757,70 2025,29 2891. t3 2954.75 30t6,61 3077,20 3136.48 437.42 bi 442,288 W 44:2 ;' 2:88 Y 442. 288 ~ 5188.9t bi 540, 00 Y 561.44 'W 583,24 Y 62s,3e ~ 644,83 ~ 663,21 Y 681.t6 ~ 699.1 0 ~ 732.65 e 747.74 M ;OH..[.O .W:E~L :2-5 SIHGLE SHOT GUll. VEY 29 OCT. ;HTERPOLATED VALUES FOR 'EVEH I000 FEET OF HEASURED DEPTH. DEPTH TOTAL C00RDiZ. HI~tTES 0 O. -gO. .:00 S ! 000 ! 000, 920. ,.00 S 39.33 ~. ~5 O00 4571 . 4491 · 6000 5399, 5319, 7'000 6201 , 6121 . 1 8.13 2060,3'7 2633,36 3?6.4 .00 W 6,46~J gO ', W 441, ]5 W 609.24 14 ~W. -HORIZONTAL vIEW--:'~: ........ :- SOHIO ALASKA PETROLEUM i wELL B -25~ ( 24; 3i .- 11_i"14.).'..:-:/i' -. ................. RADIUS OF-CURVATURE----i MAGNETIC_ SINGLE~ 8HOT ~ _~ ..... ~x_! , OC~' ~9+ 1982 _ ...... : i .... i ' ............. ......... .... i- -; ........ ~, ' . . ; TVD = 8609 ............................................... TMD = 9745 ' . _ ,, , ALL' DEPTH ARE TVD : ....... DEPTH ~,HD '~OTHER. T~ FOR 'EV£RY EYEH t O0 FEET OF SUB DEPTH. TRUE TOT.~IL CiOORD.{H:~TE $ OCT. 8054 7080. 7000 973 3192.40 8168 7180. 7100 987 3243,76 961 2 ?580. 7500 1 032 8?22 7680, .7600 1041 8832 7780. 7700 1 051 : 927'3 8180. 9383 8280. 9493 8380. 971! 2 8580. 9743 8609. 8100 1092 ~8200 1102 8300 t112 16 14 t3 11 10 11 9 10 I 0 10 10 10 I0 9 3 3456,28 8 3494. tl4 S 3659,05 $ 3670,80 S 3700,60 ~ 3729,17 ~ 3?56.72 $ 764,42 bi # 891.85: bi 916.04 bi I 1 064.72 W 1099.25 bi 'I 134: ;"~ 'W sun November 15, 1982 Mr. Gary Plisqa Sohio Alaska Petroleum Conpany Pouch 6-612 Anchorage, Alaska 99502 Re: Our Boss Gyroscopic Survey Job No. Boss-16127 (AK-BO-26127) Well: B-25 (SEC31 TllN R14E) Prudhoe Bay Field North Slope, Alaska Survey Date: November 10, 1982 Operator: Ton McGuire Mr. Plisqa: Please find enclosed the "Original" and sixteen -(16) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRYLSUN, INC. Kirk Affierbach District Supervisor Enclosures · ....?-..: ~..-~NCHOR~:.-~,~S~.- ..... . .. :.,:..: ......... . ...... :.-..-....:.--.,.:-:-., .:-... .... .... -. . ... :.x.'... ':' ':?:.-:.:'::::'ii:?--.:.::: ' [i~TE NOVEMBER (YP, :i. 9:32 ,_IOL:: IxlL.IME4ER BOSS-14,127 KELLY ?US;FIZ~fO ELEV, = LIP'gN¢~ t LiN- I .. -. ..:.. ... .. F.:E:C:T.-.I: CtN C.:AVC:ULATE~D.. ALONG L.L,_ oL RI::: - :?:...:.... :. :: .--: V E: R T I C:r~ L V E R T .T. C ~!. .T. N C: L .T. Ix: A "r T 0 h,I 0 :: F;; S C: T .T. 0 i,,I S: EVE R I 'T Y ?' "' t ' ", - -.1-, .~.. t:: F'TH T~ ~iz"l'~--l...? ..... , T, EL: ?I ....................... ]' N [ rE~ ,r~I-. ~-.._-, i'~ ~::' :--~ ,/', 0(.1 ?r--q.:SC I FT. Iq fEI R Ti"i./'.{i::CI:._!TI.'! E~:~':-: 7' ,: [,.-/E S'T VERT I C:PL S:SC: T i ON 0 O. O0 J, O0 100 ~'00 ::.:.",~.:!~ 0 :7:: 00., 00 q.:".~ () ,-1. 00, 00 Sa-.fi-I ! 0 A!_/-~:Sk]A F'ETR'OLEUI'q COMPANY P':;: L. IFJ H Ct~ BAV Al. A :.--:l<'f'~ VERTIC:AL. SE:K:TTON "A: P' ~-,.-.,Tcr~ AL,-,F~:--. ;71 OF:URE' NOVEMBER 0'.::',', 19,'_--,':2: JOB NLIMBER BOSS-16127 KELLY BUSHING ELEV. = OPERATOR- T. NCGLII~E L: EI Li i e::, i: -. DO C:~-i._'EC~ TOTAL D I RECT ! ON SEVER I TY REL-..'TANC';UI._A R COORD I NATES.'; VERT I E:AL DEGRE;--_S 'F..'.EG/! O0 IqOITTH/SOUTH EAS;I-/WEST SECT I ON 80, i 'P FT. zt :::: 0 ri 4:5:98 ,, :3 8 49()0 4'4.82.35 ~ .... .' 52C)0 477::..5:. !!5400 45?00 ,, 0'2 ,:'." =',.h_ .4. 9 83, ," '.7. ·., ...~ ,,.. ('3 ,4-. -~ ...... ,:. 44. o 1 ":' 50 W 0 ":":' 14.23 c,o :~ .........· ..., :. ......... . . . . ..... .. 275 . :[ 0 W 14:3:3 .11 4ztc~';..'..,. 't 6 ':"7' :_:.: :i.:.; 13 (] W 0 41 1476 '- = '-' 2':'7 ,')'-' ......................... .'.' .... .:, ..,-,, . ,. ,:, N " ~' ':*"" ' ' ~':~ '~15" ~':""Z''~:-' ........ '-'~: ' ~ % I'":" ................ !'~ ..... --r,.~, ............. - ...... .~'-.*CI' ~!~:=~ ,~' ................ : ............. .~i ~'. .... :..''., -. 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MCGUIRE ' : :,.. : . : . . · :: - · ' ' II',iTE.m(F'u,.,~-:: .... E~.,'"" VAL.UE:.~: FC,'R EVEN 100 FEET;i;i;OF,;'SUB~S:E~:i DEPTH;:: :i:: .:;. ::::i '::::i: . ~,,.., , T F;,' U E F:; Li B.- S E ;'::~ T Q T A L )":: ;'~:::.;i_i F;::: T~ VEF;,' T Z I.-_:A! .... VERT l C:aL. ' R EC:TA NCC.IL AF.'.I C:00F,' Fi i NATES.'; MD- TVD VERT I ~-~~-~ .............. L'D:~PTH E.'~.: f'i.-.~.NuR f' H/~:C,'UTH .-E~.:::, I ,, W~.:,T DIFFERENCE C:ORRECTi ON :~8:.:-.-:'7' 7780 ,, t ? 7700~. O0 ?,....:,L].,.-.:, 7:-::¥-.:()..I.. 'P 7':F.;O0 ,, O0 ....... , ~"~-(::',.') ....... 79'~ 0'7:[? .......... ,-7'F,'~O';-O0 ':.:;' 171 ',::c] ::: 0 1 '.-.]' '..-.',';,", ~3 ('t ~.'~ ':;' 2~:: :::': ,c:_ 180.,, I :--~.. · ,_,o ,..~ :,.q,-],~. 00._.... ':::'"'";'" ": 8 3:L::O ,, .I. '..'.:~ :E~:3 0,'.'..'. ,, ':? ,'.:, :t. :';i: ,...,'::' s., ::,.., ¢',,.., .... 'f ':;'. :E: 4 L].O , ................... --~....-T'?~./ ............ "~ ~7-F ~,T',,'C"T-- ..... .-m~., ~ .'~',, 7-f I .,: c',-: ', '::' c,"" 6' ,,:,':-" t."~ '[ ? :::: ~:, f! 0 ,, - 9'i:,'4.2 .,S:780, '~ ';'"'.: 8700 ,, :.-: . ... . (~k, ::Y, .. ,:'s,: ,~ [.) ~ L ':' ,'.: ,"" t ~(...'..~ 10 :f..., =: c,c' ;~:?.. 'ii:' :3. 0 . 19 C"'. 9 ..... C,', Q ~ :3442, 6,4 S :::51 :::-:: / ~ '-' ~ .%; ...,I ""'fi ~:;~: '7,$ f:'.; · .::, .~.._ .,: 1 O, 2:-'-.: :[0'; O_i 'P, 75 I0;75 SF'ERRY-SLi?4 iCELi_' E;i. Ji~¢i:: ~.' iNU' L.-'~='~'~~,~ ,P-'ANY' Sohio Alaska Pe%roleum Company Our Boss Gyroscopic Survey Job No. Boss-16127 Well: B-25 (SEC31 TllN R14E) Prudhoe Bay Field North Slope, Alaska Survey Date: November 10, 1982 Operator: Tom McGuire Scale: 1" = 1000' TRUE. NORTH Surface Location (lll4SNL 1899WEL) 000.00 fO, 00_ O0 10706 4000. 00 HORIZONTRL PROJECTION L'OCATED IN THE APPENDIX UI WFL UI IPR LOG UI CALIPER SURVEY UI VOLAN · CURVE DATA [21STRATIGRAPHIC HIGH RESOLUTION DIPMETER [21 OTHER: Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. - ' - r, W a~d Number Reports and Materials to be received by: Date Required Date Received Remarks Ccal0 l etio n Rsport Yes / Well History Yes /~i~ ~ ~, ~-~:~ ~7. 0~/' · _Samples //~_ /~/ . · , ~. , , Mud r,c~j .C°re, Chips ~~e~ ~ O'/f" ' , , , Core Description /~ '/~e-- Registered Survey Plat y~.~ m,,, , Inclination Survey ~/~ Directional. Survey ~ :--' P / /~--Oa- ~ ~.~ ~ ''/~/ .. Drill Stun Test Reports MEMORANDUM Sta[-e of Alaska ~n_:_ Thru ~ Lonnie C. Smi th ~ Commissioner ~o~-~o~ ~os~r ~'~ Petroleum ~spector FILE NO: 10 8/G TELEPHONE NO: SUBJECT: Witness BOPE Test on Sohio's B-25 Sec. 31, TlJ_N, R13E, UM Permit #82-151 SP_nday, 0c~t~_o~--~.::i. 17, !9,~ - The BOPE test began at 7:30 a.m. and %~S~'~onciude~ at 10:30 a.m. As the attached BOPE test report shows, there was one failure. This %~a s repaired and tested. In s'ummary, I witnessed the BOPE test on Sohio's B-25. 02-00IA(Rev.10/79) AL' A ST^TS OF' ;doASKA OIL & GAS CO;;SERVATIOll B.O.P.E. Inst:ection Report .... ~ r .... -----------,--- ............... __7--___: Repr es e n ta t iv e E~ Z/g~/a~ Drillin9 Contracto~'~~-' ~/~ Rig # Z Representativ-O~ ~,l/',,z"/,/L"~ __ O Z" ~i ACCU,'IULATO R SYSTEM · FUll Pres sure ~)D ;9 ps ig - , z Location, General Well Sign General Housekeeping Reserve- pit Rig % . Pres sure BOPE Stack Test Annular Preventer / Pipe Rams Blind Rams Choke Line ValVes Kill Line Valves Check Valve /I Charge ,,Pressure After :.200 psig Above i!Full Charge Closu=e/ © psig Precharge Attained: -- min~--: Pressure Attained:____~_z__min ~-~: 'I .. Controls: Master ~~ Remote~~~ Blinds switch Kelly and Floor Safety Valves Upper Kelly ..... / Test Lower Kelly / Test Ball Type / Test Inside BOP / Test Pressure Pressure Pressure Choke Flanifoldg~_~ Test Pressure ~o. Valves /O Adjustable Chokes ~. Hydrauically. operated choke. Test Failures / Repair or'Replacement of failed eqUipment to be Inspect°r/C°mmiS~si°n °ffice n°tified' ~ Z~ ,.: ; ~.:. ,t ' . / Results Test Time ~ hrs made wi thin .... days and .. _ z, Distribution orig" - A0&GCC cc - OperatOr cc - Supervisor September 8, 1982 Mr. R. H. Reiley District Drilling Engineer Sohio Alaska Petroletm C~any Pouch 6.-612 Anchorage, Alaska 99502 Prudhoe Bay Unit B-25 Sohio Alaska-Petroleum Company Permit No. 82-151 Sur. Loc. lll4'$NL, 1899'%~L, Sec. 31, TllN, R14E, UPM. Btmhole LOc.. 27'NSL, 1725'EWL, Sec. 31, TllN, R14E, UPM. Dear Mr. Reiley~ Enclosed is the approved application for permit to drill the above referenced ~ii. Well samples and a nd log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a ,tape containing the digitized log information shall be .sub~tted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been claSsifiedas important for the spawning or migration of anadromous fish. operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to comm~encin$ operations you may ~ contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the. Federal Water Pollution Control Act, as amended. Prior to commencing operations .you may be contacted by a representative of the Department of ~vtronmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout preve~tion equip~n~ so ~hat a representative of the CommissiOn may be present 'to witness testing of the equipment before the Mr, R. H. Re£1ey Prudhoe Bay Unit B-25 -2- September 8, 1982 surface cas!ntt shoe is drll'led. Where a diverter system is required, please also notify this office 24 hours prior to c~ncin~ equipment installation so th.at the Commission may witness t~st~n§ before drillir~ below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very.:~.truly C. V. Chatterto~¥ ORDER OF THE COMMISSION Chairman of Alaska 0il and Gas Conservation Commission Enclosure cc~ Department of Fish & Game, Hah:[tat Section w/o encl. Depar~men~ of Environmental Conservation w/o enCl. CVC ~ be SOHIO ALASKA PETROLEUM COMPANY 3111 'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 September 3, 1982 Alaska Oil & Gas Conservation Conlnission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: . 'WRT'.I; 'B'25 · (24'31'11'14) 'PBU Enclosed are the follOWing documents, in triplicate, along with our cheCk for $100 to cover the permit filing fee. 1. Application for Pennit to Drill; · 2. Proposed drilling program outline; 3. Proposed Blo~Dut Prevention Diagram; 4. Surveyor' s plat showing well' location; 5. Directional map. If you have any questions, please call R. H. Reiley at 263-5183 or K. W. Kolthoff at 263-5176. Yours very truly, District Drilling Engineer cc: Well File #17 SEP 0 ? [s 2 Gao Cons. Cc mm ..... :~ STATE OF ALASKA ~ ALASKA ~.,LAND GAS CONSERVATION CC,.,MlSSlON PERMIT TO DRILL 2O AAC 25.0O5 ,,. la. Type of work. DRILL EX lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator Sohio Alaska Petroleum ~y 3. Address Pouch 6-612, Anchorage, Alaska 99502 z~'. Location of well at surface 9. Unit or lease name 1114 ' SNL, 1899 ' WEL, Sec. 31, TllN, R14E, UPM P~_dhoe Bay Unit At top of proposed producing interval (target) 10. Well nu'mber 400' NSL, 1850' EWL, Sec. 31, TllN, R14E, -UPM B-25 (24-31-11-14) PBU At total depth 11. Field and pool 27' NSL, 1725' EWL, Sec. 31, TllN, R14E, UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF etc.) ] 6. Lease designation and serial no. Prix:]hoe Oil Pool Est. KBE = 75' ~4SLI ADL 28310 12. Bond information (see ~20 AAC 25.025) Type Blanket Surety and/or number Safeco Ins. Co. 2975387Amount $200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or'completed' NW of Deadhorse 10 mi,es North of ADL 28313 400 feet well B-9 1450 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 10708'MD - 9533' TVD feet ' 2491 October 15, 1982 19. If deviated (see-20 AAC 25.050) 120. Anticipated pressures 3330 psig@ ... Surface KICK OFF POINT 1600' feet. MAXIMUM HOLE ANGLE 31 oI (see 20 AAC 25.035 (c) (2) 4390 psig@ 8800 ft.~ (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMF'NT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 36 20x30 Insulat~ Cond~lctor 80 Surface 110 110 8 cu. yds. concrete Surf ce 2700 3720 cu. ft. Permafros~ 17 1/2 13 3/~ 72~ L-80 Butt. 2747 !~ 2747 12 1/4 9 5/$ 47# L-80 Butt. 9680 Surface 9680 8651 1350 cu. ft. Class G; ~ I 130 cu. ft. Permafros~ 8 1/2 7 26# L-80 IJ4S 1278 9430~, 8436 10708 II 9533 345 cu. ft. Class G 22. Describe proposed program: W/18% salt See attached proposed drilling and completion program. As shown on the attached d~rectional plat, we are aware of the potential intersection problems which can result from the drilling of this well. If during actual drilling operations, one of these intersections is approached within hazardous proximity, the well to be intersected will be shut-in. SEP 0 ? 1 82 23. I hereby.certify that the foregoing is true and correct to the best of my knowledgt ~ ~/' ~ District ur~±±~ng" SIGNED TITLE ' DATE The space below for Commi CONDITIONS OF APPROVAL Sarqiples required Mud Icg required Directional Survey required I APl number []~ES ~NO []YES ~NO ~YES ~NO Per,nit number ApJA~Qval date , ( AI~PROVED BY ,COMMISSIONER DATE , September 8, 1982 ~ %~ /" "-"~ -?- / by order of the Commission .... ~S 01 Submit in triplicate W~LT. B-25 (24-31-11-14) PBU PROPOSED D~ AND COMPLETION PROGRAM Dry bucket 36" hole to 80' below ground level and cement 30" x 20" insulated conductor to surface using 8 cu. yds. concrete. Drill 17 1/2" hole to 2700' and cement 13 3/8" 725 L-80 Buttress casing to surface using 3720 cu. ft. Permafrost I cement. Blowout prevention program consists of 5000 psi W.P. pipe rams, blind rams and annular preventer from 13 3/8" casing point to T.D. Maximum possible bottc~hole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface frcm 8600' TVDss and an oil colun~ to 8800' TVDss. Directionally drill 12 1/4" hole to 8655' TVD. Run 9 5/8" 475 L-80 Buttress casing to 8651 ' TVD and ce~t first stage with 1350 cu. ft. c~nent. Cement second stage through D.V. packer collar at 2600' with 130 cu. ft. Permafrost C cement. The 9 5/8" casing will be hung at surface, the 9 5/8" x 13 3/8" annulus will be Arctic Packed. Directionally drill 8 1/2" hole to T.D. at 9533' TVD. Cement 7" liner to 250'' inside 9 5/8" casing shoe with 345 cu. ft. Class G cement with 18% salt. Run 4 1/2" 12.6# L-80 A/B Fbd Buttress IPCtubing with a production packer assembly at 8393 ' TVD. A subsurface safety valve with dual control lines will be placed at 2135 '. Displace tubing to diesel. Install and test Xmas tree. Suspend well for perforating subsequent to rig release. Details of proposed perforations to be suhnitted on Sundry Notice to follow. SEP 0 7 Oil & Gas Cons. B.O.P. ,~S TACK ,CO N F IGU R.~T ION 1:5 5/8" TRIPLE RAM STACK 5000 .... PSI w,p DRILLING ANNULAR PREVENTER PIPE RAMS BLIND RAMS 2" KILL LINE DRILLING SPOOL CHECK GATE GATE GATE PIPE RAMS 4" CHOKE LINE HYDR. ASST. GATE ~ECE!VE~ SEP 0 ? Oil & Gas Cons. OI 3O 4o r,; ~io oa 20 30 40 lO 20 30 40 30.' 29 03 04 36 I 'o B-18 I B-20 B-19 - ~o (Proposed) t ,'Proposed) (P'°"°"d'~°~w~, f ' } 0 0 S-18(Pro'posed) T LAT. '- 70° 16' 14.08" L. ONG. = 148° X : 663,371 _~ ~1§0' Y 5,9,50,300 B-22 B-23 (Proposed) (Proposed) 32 04 02 B-25 ( Proposed ) PORTION OF T II N, R 14 E, U.M. SCALE 1"=1/2 MILE CERTIFICATE OF SURVEYOR PIT T. ION. SUMP 14- $0- II- 14] I'/4 - $0- II- 14~ -II- 14/ ' 32. - Sg-/I-/4! PAD DETAIL. SCALE I"= 300' I hereby certify that I am properly registered to practice land surveying in the State of Alaska and that this plat represents a location survey of the wellpad shown and the wells thereon. This survey was made by me or under my supervision and oll dimensions and other details are correct. Bottom hole locations are furnished by others. Date -SORVEyOR Sheet 3 of 3 Add Proposed 8HL e-zI,2Z,23,24,B25 Revill 8-18 surface location,add proposed bottom hole IocotBofl B - 20 REVISE fl-18 8 fi- 19 BHL. il I (~1'~ 5/27/82 $/4/8z (;L~ I / 5 /8Z PAD "B" EXTENSION Located in NE I/4 IMiAT MERIDIAN Surveyed for SOHIO ALASKA PETROLEUM CO. Surveyed by F.M. LINDSEY I~ ASSOC. LAND ~ HYDROGRAPHIC SURVEYORS 250:>West Northern Lights Boulevard Box 4-081 Anchorage' AIosko . ~,,, ...:i,./,~. ," ........................... ,,,,, -/- · .............. ., ,/ ..... ~:..:-- - ........ : · · t ./ , :::: .... :::.:.: ,","..'..:.: .... :~':~ -: :~ /~' :: .... 7 ' " __. .. --'7--'. i ........ ':.: ............. / , ! ..... i .... ................. ~ ' V"-' ' -: ..... ' ..... - ' .... ........ .......... 11 Pit'1 1~ .~--.. · , ..... '~ ',~ C - ! "i" ,- ~ ~. ~ ~'~ ': : , , . ~'l'l~ . '' · ..... _, · _, · , _. ,=,_: z. __, , , · / , , ¢ _ _ ., . , , :: ..... /................. /,. _ __ : - _~ : : : : :: : , , . .... / , ....... ~,, ml,~ ,~ , IMMIL~ VOU L%KE fi FULL REPORT ~EFIT 'M THE PRINTER LO~TlOtl · Id-E S-..fl TurD(gB9 ) TQP ro3744.04i r, g4~. to JOTTOfg 66;~446,,~ =J945366. t?,i g4El,i9 NOTE - &LL lJEPTH~: IN ~ BELOt/ KELLY CLOI;EGTI~Pm:M4~ tdELL %oEl~r /PROPO'3£}~ i5i5.3 e.e 14~.9 i~.e e.e ~,6 3346,8 919J l~.i 8,0 I~.S 3,6 t~.e 8,~ tS~,4 3.4 337i.0 680.6 4993.3 1~,7 4~E,3 11~,7 ~ · i ~ · i ~4 24~,B i~.? ~48i.S CLO6EST 3L~,3 47e,9 388,9 4698°0 · 6E~.4 649,7 724.t GS2.6 348.5 3860.0 4~4.E 44~.5 ,,PROPO6ED% ,'HE~RBV% ~ER'rIC6L WELL B-25 .(24-31-11-14) MOULD VOU [,[gE f~ FULl, Rk'PORT GEHT TO THE PI~XNTER UF.R$ ;Oft 5,,3 Iq FOR PROPOSE3) bELL ~--~( U[RTIC~L Ih'TER~CTION CL0~£97 ,,'PROPOSED% /~lY% DIGT~ ~ ~P~ T~D ~ DIGT~ ~,5 ~1.3 ~G,G ~11 ,~ 440,4 ~744.G ~.3 478.9 ~.4 648,7 ~4.~ S6e.d 5~3,4 tOtg.9 49~.6 t~.? ~4,0 4~.2 ~9,8 ~45,4 ~,4 4241,0 ~.~ ~O.~ ~e.3 4330.8 ~.~ ~.? ~.G . 9Wv THE UELL MHZCH COl'ES ~ TO THE PROPOSED flO PRIflTI~D REP~ UOULD YOU LIKE ~ PRINTOIN ~F 1~ ~ ]~; INUaLID RESPQflS~,. U~LID P~SPONSE-q ~ - YES ? ZI~i~ILID RE~E, ~LID RE~ ~ - N SEP 0 ? ~;~ :: '.;f(~ Oil &. Gas Cons. WELL B-25 (24-31-11-14) - 7° LEAD LINE CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. f~. ~ /3'~%J~ ITEM APPROVE DATE (1) Fe___~e ~ ~ ~~ (2) Loc ~(2 thru 8) le YES _ Is the permit fee attached ......................................... 2. Is well to be located in 'a defined pool ..... . ....................... 3. Is well located proper distance from property line ................. ~ 4. Is well located proper distance from other wells ............ ~ ...... ~ 5. Is sufficient undedicated acreage available in this pool ........... ~? 6. Is well to be deviated and is well bore plat included , .............. ~ 7. Is operator the only affected party ................................. ~ 8. Can permit be approved before ten-day wait ........................... (3) Admin (~z.~-,, 9~P~~- 9. -(.9/thru il) 10. 11. (4) Casg ~(12 thru 12¸, 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. (21 thru 24) (6) Add:. NO R~2~ARKS Does operator haVe a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used t~ circulate on conductor and surface ....... Will cement tie in surface and intermediate or 'production strings ~. Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... ~/~ ~,'~II/~-D Are necessary diagrams of diverter and BOP equipment attached ....... ~--~ Does BOPE have sufficient pressure rating -Test to ~-~-~ psig .. Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. .. Additional requirements .............................................. ~ . Additional Remarks: Geology: Engineering: _K ev: 08/19/82 " INITIAL GEO. UNIT ON/OF POOL CLASS STATUS AREA NO. SHORE , ,, Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No Special'effort has been made to chronologically organize this category of information. ,o LIBRARY TAPE CURVE SPECIFICATIONS Company SOHIO ALASKA PETROLEUM COMPANY Well D.S. B-25 Field PRUDHOE BAY County, State N. SLOPE, AI~SKA Date 10-26-82 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale RFC1 I Re.sist..ivity. Focused .... DIFL RUN 1 .. .2 -..20.00.. RLM1 " Me d ium " " RLD1 " Deep " " GR2 Gamma Ray 2 " 0-100, 100-200 ·SP1 Spontaneous Potential 1 " -100-0, 0-100 RFOC Resistivity Focused DIFL RUN 2 .2 - 2000 RILM " Medium " " RILD "' Deep " " GR3 Gamma Ray 3 " 0-100, 100-2'00 SP2 Spontaneous Potential 2 " -100-0, 0-100 AC Acoustic BHC/AL 150 - 50 GR1 Gamma Ray 1 " 0-100, 100-200 SP Spontaneous Potential " -100-0, 0-100 CN Compensated Neutron CD/CN 60 - 0 DENP Density Porosity " " DEN ,. Density ~EC~~D CDL. .... 2 - ~ .... ~_ " ..... ].5 - .5 ..CORR Correction J~N. 0 5 ~ GR G. amma ...Ray -~lSska0il& 8asC,O~o t,~_ CD/CN-CDL 0-100, 100-200 , ................. ~ ,, , ,, LIBRARY TAPE CURVE SPECIFICATIONS CompanX SOHIO ALASKA PETROLEUM COMPANY Well D.S. B-25 Field PRUDHOE BAY County, State N. SLOPE, ALASKA Date 10-26-82 Curve Name (Abbrev.) 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PAGE 15 PAGE VERIFIC~.TiON LISTING LVP 0!.0.H02 VERIFICAq'IOb! !,ISTING PAGE 1 ** TAPE HEADER ** SERVICE NAME :EDIT DATF :m4/O2/10 ORI~TN :68~6 TAPE NAME CONTINUATION CO~MFNTS :I,I~RARY TAPE ~$ FILE HEADER SERVICE NA~ : VERSID~ # : DATE t ~AXIM~!~ LKNGTH : 1024 FILE TYPE PRE¥IOIIS FILM : ** INFORMATION R~CORDS ** CN : SOHIO ALASKA PETROLEu~ COHPANY WN : ~-25 FN ~ PRUDHOE BAY ?0~ 11~ SECTS COUN: NORTH SLOP~ STAT: ALASKA CTRY: lISA ** COMNENTS ** UNIT TYPE CATE SIZE COD~ 000 000 O30 O65 000 000 004 065 000 000 012 065 000 000 003 065 000 000 003 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 004 065 bVP 010,H02 VERIF.]C~TION I.,TST!MG PAGE 2 ****************************************************************************** * SCHbUMBERGER * * ~L~SKA CO~PUTINC, CENTER * ****************************************************************************** CO~PANY = S~HIO AI.,ASK.~ PETR~LF[i~ COMPANY ~IEbD = P~U~HOE BAY COUNTY c NORTH SLOPE ~OROUGH ST~TF = JOB ~II3~-~BER AT ACC: 68867 RUN #!o DATE LnGGED: DFC LOP: RICK KRI. tWELL CASING TUBING TYPE FI,UID 13,375" SURFACE TO 2750 FT, 9,625" SURFACE TO 9837 FT, 7,000" 9583 FT. 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