The URL can be used to link to this page

Home My WebLink About190-058 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, March 18, 2016 9:02 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Bergene, Matthew; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; AK, D&C Well Integrity Coordinator; Sayers,Jessica; Dickerman, Eric; Glasheen, Brian P; Morrison, Spencer; Munk, Corey; Odom, Kristine; Regg,James B (DOA) Subject: OPERABLE: Producer S-26 (PTD #1900580) MIT-IA Passed post Gas lift Valve Work All, Producer S-26 (PTD#1900580) passed a MIT-IA on March 17, 2016 following slick line work. The passing test confirms two competent barriers in the well. The well is reclassified as Operable. • Well status is Operable • Annuli are fluid packed Please use caution while placing well on production due to fluid packed annuli and the potential for annular fluid expansion. Thank you, Kevin Parks Alt�rnnte Whitney P'ttu, BP Alaska-Well Integrity Coordinator SCANNED APR 2016 GWGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Friday, March 04, 2016 1:34 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismosk Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AKRES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Bergene, Matthew; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; AK, D&C Well Integrity Coordinator; Sayers, Jessica; Dickerman, Eric; Glasheen, Brian P; Morrison, Spencer; Munk, Corey; Odom, Kristine; 'Regg, James ti-(DOA) (iim.regg@lalaska.gov)' Subject: UNDER EVALUATION: Producer S-26 (PTD #1900580) Sustained Inner Annulus Casing Pressure over MOASP All, Producer S-26 (PTD#1900580) was reported to have sustained inner annulus casing pressure over MOASP on March 01, 2016. The pressures were confirmed to be TBG/IA/OA= 2010/2010/640 psi. A subsequent cold.31FL performed on 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Friday, March 04, 2016 1:34 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD S; Bergene, Matthew;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; AK, D&C Well Integrity Coordinator; Sayers,Jessica; Dickerman, Eric; Glasheen, Brian P; Morrison, Spencer; Munk, Corey; Odom, Kristine; Regg, James B (DOA) Subject: UNDER EVALUATION: Producer S-26 (PTD #1900580) Sustained Inner Annulus Casing Pressure over MOASP All, Producer S-26 (PTD#1900580)was reported to have sustained inner annulus casing pressure over MOASP on March 01, 2016. The pressures were confirmed to be TBG/IA/OA= 2010/2010/640 psi. A subsequent cold TIFL performed on March 02, 2016 failed indicating a potential lack of two competent barriers in the wellbore. At this time,the well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Downhole Diagnostics: Cold TIFL—FAILED 03/02/16 2. Operations: Place on Production—DONE 03/03/16 3. Downhole Diagnostics: Warm TIFL 4. Well Integrity Engineer: Additional diagnostics as needed Please call with any questions or concerns. Thank you, J�NNED mAR Whitney Pettus 2p'6� (Alternate:Kevin Parks) BP Allaska-Well Integrity Coordinator GINc: WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator@BP.com 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. i ~'0-" 0~,~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED /~ Logs of various kinds [] Other Complete COMMENTS: Scanned by:~Bren Vincent Nathan Lowell [] TO RE-SCAN Date:5¢q¢0~ Is, ~ Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: /si NOTScanned.wpd • UNSCANNED, OVERSIZED MATERIALS AVAILABLE: i ~~o ~ ~ FILE # 'U~~ ~ .~~ ~~~~ ~ dl'I,~~ ~ To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission +333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 }Fax (907) 276-7542 S -26 Commingled Producer Geochem sampling Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, November 24, 2010 2:00 PM To: 'Derrick, George (Mackie) M' 7—D Subject: RE: S -26 Commingled Producer Geochem sampling Mackie, The conservation order ( CO 457B.003 Rule 13 (b) ) actually gives a 7 month max for the sampling date ( or twice a year) . I don't know if you were giving the 12/3/10 date based on a 6 month time window. It looks like you are POPing the well very soon and should get a sample in the next couple of weeks once the well stabilizes. A couple of extra weeks to stabilize the well and get a representative sample is a reasonable request, Guy Schwartz Senior Petroleum Engineer AOGCC NOV 3 0 ZU18 793 -1226 (office) 444 -3433 (cell) From: Derrick, George (Mackie) M [mailto:derrgm @BP.com] Sent: Wednesday, November 24, 2010 10:08 AM To: Schwartz, Guy L (DOA) Cc: Vandergon, Mark A; Schultz, Kirsten L; Engel, Harry R; AK, D &C Well Integrity Coordinator; gpblabtl @bp.com Subject: S -26 Commingled Producer Geochem sampling Guy, As per our conversation I am emailing you to update the status on S -26 . S -26 has been shut in since 10106/10 due to proximity to 7es drilling a new well. The geo chem sample is due by 12/03/10. 7es has been able to move off the location and now we are in the process of POPing S -26. This well is a high priority for the slope to get back on production. Once the well is online we want to get -7 days of production to clean up and stabilize production from both zones to get an accurate geochem sample. Because of drilling and being unable to produce the well we are notifying and requesting a extension on getting the geochem sample for S -26. We will keep you apprised of our progress. Please contact me if you have any questions. Thanks. Mackie Mackie Derrick Aurora Production Engineer BP Exploration (Alaska) Irc- derrgm@bp.com (907) 564 5891 (office) (907) 250 1674 (cell) 11/24/2010 ' NOT OPERABLE: Producer S-26 1900580A Well l�� Secured With Load ill Page l of R��, James B (DOA) _ From: AK, D&C Well integrity ConndinotorkAKOCVVa|||nhoghb/Coondinotor@bp.00m] Sent: Saturday, November 13, 2010 8:12 PM To: Maunder, Thomas E(OOA);Regg. James B(DOA); Schwartz, Guy L(OC)A); AK, C}PSGC2OGW1; AK, C)P8 GC2 Facility {JTL; AK. <]PG GC2 Field [}&W1 TL; AK, OPS GC2VVa|)pod Lead; AK, OP8VVe|| Pad SW; AK, OP8 Prod Controllers; AK, REG GPB East Wells Opt Engr; AK, RES GPB West Wells Opt En8r; Ciamooki, Doug A; Enge|, Harry R; AK, D&CV0ra|ine Operations Team Lead; AK, O&C Well Services Operations Team Lead; 8oyed.Mohamed Cc: AK, O&C Well Integrity Coordinator; Ning, Whitney Subject: NOT OPERABLE: Producer S-26 (PTD #1900580) Well Secured With Load and Kill � AU. v / Well G-2O(PTD#1SDO58O) has been secured with a load and kill utilizing kill weight fluid on1 The well has been reclassified aa Not C3oenob|e and will the drilling rig moves - from it's current location onG-pad. At such time, further work will bedonetosva|uata the Tx|/\communication that had been observed. Please call if you have questions orconcerns. Thank you, Gamm&yMurph» (m|LTorinR000hinger) Well Integrity Coordinator N0 V 1 8 �M1D Office (&O7)859-51O2 Cell (SO7)752-U755 Pager (SO7)O58'51OO Ext. 1154 From: AK, o&C Well Integrity Coordinator Sent: Wednesday, October 20, 2010 9:59 PM To: 'naunder, Thomas s(u0A'/'xegg, James e(nOA)'/'Sch*artz, Guy (oOA)^guy. schwa nz@a|aska.govv/ AK, OpSGCZO6m/AK, OpSGCu Facility OTL/ AK, OpSGCz Field O&M TL; AK, Up3GczvvanpadLead; AK, Ops Well Pad SW; AK, OpS Prod Controllers; AK, ncS GPB East Wells Opt sngr; AK, RES GPB Central Prod Opt Engr, Cismoski, Doug A; Engel, Harry R; AK, D&C Wireline Operations Team Lead; AK, o&C Well Services Operations Team Lead; Sayed,Mohamed Cc: no»hinger,TorinT.; Quy,n8anv; Holt, Ryan P(ASmC) Subject: UNDER EVALUATION: Producer s'zo(pTo#z000sno)lopLFailed AU. Well S-26 (PTD #1900580) has been found to have sustained casing pressure on the IA. The wellhead pressures were Tubing/|/VOA equal to35OCZO4O/58Oon1O/17/2O1O. The well failed aT|FLon1O/2O/2D1O confirming tubing integrity ia compromised. The well has been reclassified om Under Evaluation and may continue tobo produced undaro28'doyo|oohvvhi|eeffodmtomiUgohetheoommunicoUonon000nnp|ohad. The plan forward is: 1. POP well 2. DHD: Re-T|FL 3. Giiok|ino: C/] GLVa pending T|FL results AT|O Plot and we||bona schematic have been included for reference. Thank you, lI/l5/20lA NOT OPERABLE: Producer S -26 (PT� #1900580) Well Secured With Load Kill Page 2 of 2 Mehreen Vazir (for the Well Integrity Coordinator Torin Roschinger /Gerald Murphy) Projects Well Integrity Engineer BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWellintegrityCoordinator @bp.com 11/15/2010 5-26 Commingled Production R~ort ~ Schwartz, Guy L (DOA) From: Ohms, Danielle H [Danielle.Ohms@bp.com] Sent: Friday, October 16, 2009 5:28 PM To: Schwartz, Guy L (DOA) Subject: S-26 Commingled Production Report Guy, Page 1 of 1 ~~ ~ ~lO--oS~ Following up on the S-26 Commingled Production Report, "RE: Conservation Order 457B (Rule 13) and Conservation Order 341 D(Rule 18) - Commingled production from the Aurora Oil Pool and Prudhoe Oil Pool in Well S-26" sent on 4-29-09. Attachment 1: Oil7racers Report No. 09-826 was listed as Confidential. I discovered that in order to change this labeling I would need to get approval from the GPB co-owners. A similar report for NK-43 sent to AOGCC on 6-19-07 did not include this detailed report from OilTracers. We provided the OilTracer data as back-up for S-26 though it likely did not need to be included as all of the relevent information is summarized in the report. Vt~*waute~~I~Cehrkee~rt#re eor~dentia} Iabeiing on fhe OilTracers report ineluded as an attachment. Danielle Ohms BP Exploration (Alaska) Inc. GPB West Waterflood Lead PE (907) 564-5159 ~~ay~i'i~,~~~~~y" ~,r ,' ~ ~' ~~4""' 1 Q/21 /2409 • • ~p BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 ":t: Anchorage, Alaska 99519-6612 June 25, 2009 ~ ~ Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. ~~3~"~~~"~ J~L ~ ~:, 2DC~ Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) S-pad .~ , n.re fi/25/2009 Well Name PTD N Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Conosion inhibitorl sealant date ft bbls it na al S-O78 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 0.25 NA 025 NA 1.7 SI25/2009 5-03 1811900 1325 NA 1325 NA 92.65 5/20/2009 5-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009 S-06 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 S-oaB 2010520 0 NA 0 NA o.85 5/27/2009 S-OS 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-t0A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 S-11B 1990530 025 NA 0.25 NA 1.7 5l27/2009 S-12A 1851930 025 NA 025 NA 1.7 6/1/2009 5-13 1821350 8 NA 8 NA 55.3 6/1/2009 S-15 1840170 025 NA 025 NA 3 6/2/2009 S-17C 2020070 025 NA 0.25 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-19 7861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 025 NA 0.25 NA 1.3 5/19/2009 5-27 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 S-22B 1970510 0.75 NA 0.75 NA 3 5/19/2009 S-23 1901270 025 NA 025 NA ~.7 5/25/2009 S-2a8 2031630 0.5 Nq 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 S-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-27B 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 5-288 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29A17 1960120 0 NA 0 NA 0.85 5/27/2009 S30 1900660 0.5 NA 0.5 NA 5.1 5/31/2009 S31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 S-32 1901490 0.5 NA 0.5 NA 3.4 5/31l2009 5-33 1921020 0.5 NA 0.5 NA 4.3 5/2&2009 S-3a 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 S35 1921480 0 NA 0 " NA .85in 5/31/2009 S36 1921160 0.75 NA 0.75 NA 425 5/27l2009 5-37 1920990 125 NA 125 NA 11.9 5/27/2009 S-38 1921270 025 NA 025 NA 102 5/27/2009 5-41 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 S-42 1960540 0 NA 0 NA 0.9 5/30/2009 S-43 1970530 0.5 NA 0.5 NA 1.7 5l28/2009 5-44 1970070 025 NA 025 NA 1.7 5/28/2009 5-100 2000780 2 NA 2 NA 21.3 5l29/2009 S-101 2001150 1.25 NA 125 NA 11.9 5/29/2009 5-102L7 2031560 125 NA 125 NA 11.1 5/31/2009 5403 2001660 1.5 NA 7.5 NA 11.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 75.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 5-106 2010120 16.25 NA 1625 NA 174.3 6/2/2009 S-107 2011130 2.25 NA 2.25 NA 26.s 5/18/2009 S-IOB 2011000 3.5 NA 3.5 NA 40 5/30/2009 S-109 2022450 2 NA 2 NA 21.3 5/30/2009 5-110 2011290 11.75 NA 11.75 NA 98.8 5/30/2009 S-11t 20505t0 2 NA 2 NA 79.6 5/30/2009 S-tt2 2021350 0 NA 0 NA 0.5 5/3072009 5-113 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 5-174A 2021980 1.25 NA 125 NA 102 5/30/2009 S-115 2022300 2.5 NA 2.5 NA 272 5/29/2009 5-116 2031870 1.5 NA 1.5 NA 13.6 5l28/2009 5-117 2030120 1.5 NA 1.5 NA 75.3 5/29/2009 S-118 2032000 5 NA 5 NA 76.5 5/28/2009 S-119 2041620 1 NA t NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 67.2 5/29/2009 5-72~ 2060410 4.5 NA 4.5 NA 53.8 5/28/2009 5-122 2050810 3 NA 3 NA 21.3 5/29/2009 S-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-124 2061360 1.75 NA 1.75 NA ~t.s 5/26/2009 5-725 2070830 225 NA 225 NA 20.4 5/28/2009 S-126 20710970 125 NA 125 NA 15.3 6/1/2009 5-200 1972390 125 NA 125 NA 14.5 5/28/2009 5-201 2001840 0 NA 0 NA 0.85 6/19/2009 5-213A 2042130 2 NA 2 NA 13.6 5/29/2009 5-215 2021540 2 NA 2 NA 18.7 6/1/2009 5-216 2001970 4.75 NA 4.75 NA 5~ 5/29/2009 5-277 2070950 025 NA 025 NA 1.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 5-401 2060780 16 NA 16 NA 99.5 6/2/2009 S-504 0 NA 0 NA 0.85 5/28/2009 ~ 02/24/09 ~Cb~~~1~1'~~h Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wou ~„h ~Vi~~ -~ s~ ~~C; NO.5109 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 MPS-43 AZCM-00001 -- --- FMI ~.a.o 12/29/08 o~ a.vwr 1 ~u 1 P2-41 AWLS-00009 SCMT - 01/01/09 1 1 MPS-43 AZCM-00001 SONIC SCANNER _/ 12/29/09 1 1 S-26 AYTU-00014 PRODUCTION PROFILE ( ~ _ r~~$C 02lis/09 1 1 F-45A AYLF-00018 LDL ~03-~~ (/1~~ _ 02/24/09 1 1 4-04lT-26 12083416 MEM LDL - / (p 02/21/09 1 1 09-34A AZ4D-00005 USIT - ~ 02/07/09 1 1 W-218 11968975 USIT (REVISED) .- ~-C.( / 12/11/08 1 1 L2-18A 11999063 RST ( 71/29/08 1 1 L2-33 11999065 RST - 12/07/08 1 1 4-10A/L-28 12017518 RST - 09/26/08 1 1 W-218 11968975 CH EDIT PDC GR (USIT) 12/11/08 1 PLEASE ACKNOWLEDGE RE CEIPT wv sir,N wr. enin wcTnennnir_ nn~e nnsv ~...~ r.,. -°""----" BP Exploration (Alaska) inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Stree)~~6 i}00' - Anchorage, AK 995tT38 ATTN: Beth Received by: p" C~ l~ 10/21 /08 ~chlumherger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh # P2-41 12034926 PRODUCTION PROFILE ~ 10/08/08 1- R-03A 12057651 INJECTION PROFILE 10!08/08 1 1 P2-13 12096919 SBHPS & PERF RECORD ~ 10!09/08 1 1 S-26 12017505 PRODUCTION PROFILE 10!10/08 1 1 S-05A 12086687 SCMT !q',~- ~~- 10/12/08 1 1 V-207P61 40017442 OH MWD/LWD EDIT 07/29/08 2 1 AI GAPC A/~V~IA~~~1 e~l~w~ e~~ ~~~r.~ w.i w.w. ..~... ...~ ---..-...-.~ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: t ,', t~ '~~~ N0.4934 Company: State of Alaska Alaska Oil & Gas Cons Comm 1 ~ ~ ,` ~~.- -, •..,. • n n~ Attn: Christine Mahnken ~. ,'~_ - ~ ~~~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: i • • STATE OF ALASKA 6~ IZ~~~I~~ ALAS~IL AND GAS CONSERVATION CO~SION p ~ 2008 WELL COMPLETION OR RECOMPLETION REPORT AND LOG JUN Alaska Oil & Gas Cons. Commission 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.105 zoAAC zs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions ~ b. Well ClassAnCh0~~0 ®Development xploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 05/21/2008 ~ 12. Permit to Drill Number 190-058 - 307-346 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 05/12/1990 13. API Number 50-029-22047-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 05/24/1990 14. Well Name and Number: PBU S-26 - 1635 FNL, 1160 FWL, SEC. 35, T12N, R12E, UM Top of Productive Horizon: 2180' FNL, 1891' FWL, SEC. 35, T42N, R12E, UM 8. KB (ft above MSL): 65.09' Ground (ft MSL): 29.5' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2511' FNL, 2121' FWL, SEC. 35, T12N, R12E, UM 9. Plug Back Depth (MD+TVD) 9393 - 9184 - Pool ~ ....Prudhoe Bay Field / Kupafuk Poole ~~~p°~~'~ 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 619322 y- 5979855 Zone- ASP4 10. Total Depth (MD+TVD) 9434 - 9225 ~ 16. Property Designation: ADL 028257 TPI: x- 620062 y- 5979321 Zone- ASP4 Total Depth: x- 620299 y- 5978994 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ^Yes ®No m' el tonic and tinted inf rm ion er AA 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIL / GR / BHC / CNL, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD' SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP' :BOTTOM SIZE CEMENTING RECORD PULLED 2 Surfac 110' rf 110' 13-3/8" 68# L-80 Surface 2683' Surface 2683' 17-1/2" 3295 cu ft Arcticset III & II 9-5/8" 47# NT80S Surface 8816' Surface 8609' 12-1/4" 1870 cu ft Class'G' 7" 26# L- 0 8570' 9434' 2 ' -1/2" 2 4 I 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH .SET MD PACKER SET MD 3-3/8" Gun Diameter, 4 spf 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 6780' 6691' MD TVD MD TVD 4-1/2", 12.6#, 13Cr80 & L-80 7034' - 8624' 7042' & 8540' 8951' - 9053' 8743' - 8845' 6870' - 6894' 6704' - 6727' 25 ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,! 4 ~'~D~ "- ~~~ "~ DEPTH INTERVAL MD AMOUNT He KING OF MATERIAL USED ~~~~ ~ ~ ~ ~ ~ ~~~~ 6870' - 6894' Perf Kuparuk Interval (04/03/08) 8550' Frac'd: Pumped 20,520#'s of 20/40 and 168,220#'s 16/20 Carbolite. Left 740#'s in wellbore (-10' - 30'), to be cleaned out when plugs are removed. 26. PRODUCTION TEST Date First Production: May 21, 2008 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date Of Test: 5/21/2008 HOUr'S Tested: 4 PRODUCTION FOR TEST PERIOD OIL-BBL: 244 GAS-MCF: 387 WATER-BBL: 28 CHOKE SIZE: 92 GAS-OIL RATIO: 1,588 Flow Tubing Press. 240 Casing Press: 1,500 CALCULATeD 24-HOUR RATE• OIL-BBL: 1,461 GAS-MCF: 2,320 WATER-BBL: 169 OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, ifrne~eded).`S~ubmit detailed descriptions, c(1o~r\e chips, photographs and laboratory analytical results per 20 AAC 250.071. C 6iu a k~j:~~f None ~.C`~M\v-~~ Q`WV~T~O~c~.v~~(~`2.~U ~t;~w ~~ ~~ .~ C~ ~ O~~ ~ lB~~..~ AUG ~ 6 2006 ~~~-~~ Form 10-407 Revised 02/2007 ~ [~; ~ n ~ t~ ~ j~ ~ONTINUED ON REVERSE SIDE ,~ l.7 28: GEOLOGIC MARKERS (LIST ALL FORMATIONS KERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Test ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Kuparuk 6856' 6691' None Sag River 8819' 8612' Shublik 8859' 8652' Sadlerochit /Zone 4 8949' 8741' Formation at Total Depth (Name): Sadlerochit 8949' 8741' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. / Si d ~~ ~~Da ~ gne Title Drilling Technologist Date ! Terrie Hubble PBU S-26 190-058 307-346 Prepared ByNameMumber. Terrie Hubble, 564-4628 Well Number P fmi N . / A rov I N Drilling Engineer: Jim Young, 564-5754 (Prod Eng) INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Satt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lifl, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only • S-26 Well History, Post Rig Workover Date Summary 4/30/2008 T/I/0=1740/1800/200 Assist Slickline, MIT IA PASSED to 3000 psi [Pre frac] Loaded IA w/ 350 bblsa of crude.SSL set spmg. Pumped 13 bbls crude down IA to reach test pressure. MIT IA passed 3rd attempt. IA lost 40 psi 1st 15 mins, IA lost 20 psi 2nd 15 mins for a total loss of 60 psi in 30 mins. Freeze protect flow line w/ 7 bbls meth & 19 bbls crude. FWHP's=2400/550/220. Annulus valves open to gauges and tagged. 5/2/2008 T/I/0= SSV/VAC/240. Temp= SI. IA FL (pre frac}. ALP shut-in Q 1980 psi. IA FL 150'. 5/11/2008 Heat Frac Tanks for S-26. Heated 5 frac tanks of water to 100°F, heated diesel tank to 90°F. 5/12/2008 FRAC Treatment. PJSM. Pump Data Frac - ISIP = 1980 psig. Lost Data Acquisition, but got it back. ANC picked closure 1760 psig & -17 min. Anchorage Engineering adjusts schedule 100 bbls pad volume and more volume in 1-4 interval. Pump Frac according to schedule extending the 8 ppa to promote TSO. Pumped a total of 20,520 #'s 20/40 and 168,220 #'s 16/20 (all that was on location). Go to flush and FP with -30 bbls diesel. Should have 740#s -10' sand left in well bore on underflush. Job is Complete: Slickline up next. 5/12/2008 T/I/0=2472/0/200 Maintain pressure on IA for Frac Crew. Pumped 16.9 bbls 70° DLS down IA to pressure up to 3300 psi. Pumped/bled as needed to maintain 3300-3500 IAP during frac. (See Log Tab). Bled IAP. IA valve & wing tagged upon departure. FWP's=2350/500/250. 5/13/2008 DRIFT W/ 3.75" CENT, TEL, S. BAILER. LOC TT C~ 6740' SLM, +40 CORR.TO 6780' MD. SD Q 6955' SLM (6995' MD), NO SAMPLE. SET 4-1/2" X C-SUB IN X-NIPPLE ~ 6628' SLM. PULLED RK-DGLVs FROM STA#2 ~ 6217' MD &STA#4 ~ 3635' MD. SET RK-LGLV IN STA#4 C«~ 3635' MD. 5/14/2008 SET RK-OGLV IN STA#2 ~ 6217' MD. PULLED EMPTY X C-SUB FROM X-NIPPLE Q 6628' SLM. LEFT WELL S/I, TURNED WELL OVER TO PAD OPER. 5/15/2008 ASRC unit #1 complete rig up, POP well thru sep, increasing choke. 5/16/2008 ASRC Unit #1 returning frac sand to tank, reduced choke. 5/17/2008 ASRC Unit #1 continue flowback, well S/I due to pinhole leak (erosion from sand) replace spoolpiece. 5/18/2008 ASRC Unit #1 finish UT inspection, S-26 POP Q minimum choke setting. 5/19/2008 ASRC Unit #1 increasing choke, prop flowback. 5/20/2008 ASRC Unit #1 continuing to increase choke and flowback frac. 5/21/2008 ASRC Unit #1, Cont. Frac F/B, Test well, Begin rig down. 5/22/2008 ASRC Unit #1 Rig down, Move to Peak washbay for vessel cleanout. 5/27/2008 WELL FLOWING ON ARRIVAL. SET4 1/2" X-CATCHER SUB C~? 6637' SLM. PULLED SPMG FROM ST# 1 Q 6537' MD. PULLED S/O GLV FROM ST# 2 Q 6217' MD. SET DGLV IN ST# 2 ~ 6217' MD. SET S/O GLV IN ST# 1 C~ 6537' MD. PULLED EMPTY X-CATCHER FROM 6637' SLM. WELL LEFT S/I OPER NOTIFIED. Page 2 of 2 • S-26 Well History, Post Rig Workover Date Summary 3/29/2008 WELL S/I ON ARRIVAL. PULLED BALUROD ASSY FROM HES RHC BODY 6670' SLM (RHC SET AT 6715' MD). PULLED RK-DGLV's AT ST#1 (6537' MD), ST#3 (5304' MD), AND RK-DCR AT ST#4 (3635' MD). SET RK-LGLV AT ST#4 (3635' MD), AND RK-OGLV AT ST#3 (5304' MD). SET PETREDAT RK- SPMG IN ST#1 (6537' MD). PULLED 4-1/2" RHC FROM 6715' MD. UNABLE TO LATCH BALL & ROD C~ 7033'SLM, RIH W/3.50 LIB IN PROGRESS. 3/30/2008 BAILED 3 GALLONS OF DRILL MUD/MILL DEBRIS FROM 7033'-7037' SLM W/10' x 3" P.BAILER. PULLED BALUROD ASSY AT 7040' SLM W/ 3" PUMP BAILER. RAN 10' x 3" PUMP BAILER TO 7040' SLM, POOH W/ EMPTY BAILER. 3/31/2008 PULLED 4-1/2" HES RHC PLUG BODY C«~ 7066' MD. DRIFTED TO 7400' MD W/ 3 3/8" DUMMY GUN, TEL, S-BAILER (NO RESTRICTIONS). WELL LEFT S/I ON DEPARTURE. 4/1/2008 T/I/O = 50/0/290 "'"MIT T PASSED to 3000 psi. Pumped 5 bbls diesel to reach test pressure. Tubing lost 50 psi 1st 15 min, 20 psi 2nd 15 min, for a total of 70 psi in 30 min. CMIT TxIA PASSED to 3000psi. Pumped 7.4 bbls diesel down IA to reach test pressure. Tubing and IA lost 40 psi 1st 15 min, 10 psi 2nd 15 min, for a total of 50 psi in 30 min. Bled well to production. Pumped 100 bbls diesel, 10 bbls meth down IA, through GLV's, up Tbg, to production. Brought gas lift online to sweep fluid out of well (3 hours.) Shut in gas lift, pumped 10 bbls meth down IA, brought well and gas lift back online. FWHP's = 580/1600/580. Annulus valves tagged and open to gauges. 4/2/2008 T/I/0=1420/1450/300 Freeze protect Flowline with 7 bbls neat methanol and 19 bbls crude. (WOA procedure) (Pre-frac)Tagged wing, divert and chem port. All casing valves open to gauges at departure. FW H P's=1420/1450/300 4/2/2008 T/I/0=980/1360/580. Temp=Hot. TG & IA FL (for EL). SI wing & A/L to let well settle out for 30 mins. TBG FL C~ 3498' (87 bbls). IA FL Q 5304' (so) (283 bbls). 4/3/2008 T/I/0= SSV/1460/320. Temp= SI. IA FL (for e-line). A/L shut-in C~ casing valve, ALP= 1850 psi. IA FLC~3 5060' (above sta # 3, s/o). 4/3/2008 WELL SHUT IN ON ARRIVAL. INITIAL WHP= T/IA/OA=1400/1400/250. SBHPS RAN FOR PRESSURE AT PERFORATION ZONE = 2303 PSI. FLUID LEVEL AT 5308'. PERFORATED INTERVAL 6870 TO 6894' WITH 3.375" POWERJET, 6SPF. WELL 1000 PSI UNDERBALANCED OVER PERF ZONE. SURFACE INDICATION OF GUN FIRING. VISUAL CONFIRMATION MADE ONCE GUN WAS ON SURFACE. WELL LEFT SHUT IN. FINAL W/I/O: 1550/1500/250. 4/17/2008 WELL S/I ON ARRIVAL. SET SS-CATCHER C~ 6638' SLM. 4/18/2008 PULLED PETREDAT RK-SPMG FROM STA #1 C~ 6537' MD. PULLED EMPTY SS-CATCHER FROM 6638' SLM. NOTE: ST#1 AT 6537' MD IS EMPTY (NO -GLV IN PLACE). WELL LEFT S/I, PAD OP NOTIFIED. 4/29/2008 WELL S/I ON ARRIVAL. SET 4 1/2" X-LOCK CATCHER SUB C~ 6624' SLM. PULLED RK-OGLV AT ST # 3 (5304' MD), PULLED RK-LGLV AT ST #4 (3635' MD). SET RK-DGLV AT ST #4 (3635' MD), RIH W/ RK-DGLV (ST #3, 5304' MD). JOB IN PROGRESS. 4/30/2008 SET RK-DGLV AT ST #3 (5304' MD), LRS LOADED IA W/ 350 BBLS CRUDE. SET RK-SPMG (Petradat) AT ST #1 (6537' MD), MIT-IA 3000 PSI (PASSED). PULLED EMPTY CATCHER SUB Q 6624' SLM. WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR. Page 1 of 2 TREE= 4" CM/ WEiLHEAD = FMC ACTUATOR - ~ OTIS KB. ELEV = 65.09' BF. ELEV = 37.49' KOP = 4400' .Max.... Datu Datu PJC DRAFT Angle = 23° @ 5178' m MD = 9073' m TV D = 8800' SS 20" CONDUCTOR, ID = ? 110 13-3/8" CSG, 68#, L-80 BUTT, ID = 12.415" 2683 4-1/2" SYMPHONY GUAGEw/ I-WIRE, ID= 3.94" (- Minimum ID = 3.80" @ 8613' 4-1 /2" OTIS XN NIP, MILLED OUT 4-1/2" TBG, 12.6#, 13CRVAM TOP, .0152 bpf, ID = 3.958" SA Y NOTES: NOTIFY GC OF ANY WELL OION WHICH COULD INCREASE FLOW OR S ~~ ~ ER N RATES TO 3" SKID FLOWLINE (POTENTIAL EROSION). "*"CHROMETBG'F*" 4-1/2" HES X NIP, ID = 3.813" GA S L IFf MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 4 3635 3635 0 MMG DOME RK 18 05/14/08 3 5304 5251 23 MMG DMY RK 0 04/18/08 2 6217 6094 22 MMG DMY RK 0 05/27/08 1 8537 6391 21 MMG S/O RK 22 05/27/08 6670' 4-1/2" HES X NIP, ID = 3.813" 6691' ~ 9-5/8" X 4-1 /2" BKR S-3 PKR, ID = 3.875" 6715' 1 4-1/2" HES X NIP, ID = 3.813" 6780' ~-~4-1/2" W/LEG, ID = 3.958" 19-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" I 4-1/2" TBG, 12.6#, 13CRVAM TOP, .0152 bpf, ID = 3.958" 4-1/2" TBG STUB (12!26/07) TOP OF 7" LNR 4-1/2" FASDRILL BP (12/15/07) 4-1/2" TBG, 12.6#, L-80 TDS, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, NT80 NSCC, ID = 8.681" PERFORATION SUMMARY REF LOG: SWS BHCS ON 05/24/90 ANGLE AT TOP PERF: 19° @ 6870' Note: Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" b 6870 - 6894 O 04/03/08 3-3/8" 4 8951 - 8961 C 08/26/90 3-3/8" 4 8965 - 9053 C 08/26/90 3-318" 4 9085 - 9130 S 09/10/94 3-3/8" 4 9184 - 9188 S 09!10/94 PBTD (TAGGED 01/17/93) 7" LNR, 26#, L-80 IJ4S, .0383 bpf, ID = 6.278" 4-1/2" HES X NIP. ID = 3.813" 9-5/8" X 4-1/2" UNIQUEOVERSHOT 9-5/8" X 4-1/2" OTIS PKR, ID = 3.85" 8570 ~ 9-5/8" X 7" LNR HGR, ID = ? 8593 4-1/2" PARKER SWS NIP, ID = 3.813" 8598 4-1/2" HES FASDRILL BP (12/09/07) 8613' 4-1/2" OTIS XN NIP, MILLED TO 3.80" (12/26/07) 8625' ~4-1/2" W/LEG, ID=3.958" I $627' ELMD TT LOGGED 06/15/90 9030 ~--{ 7" ZONAL ISOLATION PKR, (07/28/97) 9139' ~ FISH- BKR ECP, SCOOP GUIDES, RUNNING TOOL, AND OLD IBP 9178' ~ 7" MARKER JOINT DATE REV BY COMMENTS DATE REV BY COMMENTS 06/04(90 N18E ORIGINAL COMPLETION 05/14/08 KSB/TLH GLV GO 01/02/08 D14 RWO 05/31/08 DAV/TD GLV GO (5/27/08) 04/08/08 RRD/ SV PERFORATIONS (04/03/08) 04/08/08 DAV/PJC GLV GO 04/30/08 KSB/PJC GLV GO 05/09/08 ?/ PJC DRLG DRAFT CORRECTIONS PRUDHOE BAY UNff WELL: S-26 PERMIT No: 1900580 API No: 50-029-22047-00 SEC 35, T12N, R12E, 1635' FNL & 1180' FWL BP Exploration (Alaska) Page 1 of 2 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, May 05, 2008 4:27 PM To: 'Hubble, Terrie L'; Preble, Gary B (SAIC); Stewman, Sondra D Subject: RE: PBU 5-26 (190-058) Thanks Terrie. I appreciate your promptness. This one will be interesting for the production people to track. Since there are perfs in both Ivishak (Prudhoe) and Kuparuk (Aurora), it is right to call it a 2-oil. But as I understand it is likely that only the Aurora will be producing for the near-term. Tom From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Monday, May 05, 2008 4:01 PM To: Maunder, Thomas E (DOA); Preble, Gary B (SAIL); Stewman, Sondra D Subject: RE: PBU S-26 (190-058) Hi Tom, I have looked back and read my notes in regards to this well. I submitted the 10-407 for the S- 26 work that was done by D-14 as required by Sundry (#307-346). 1 was concerned about the "countdown clock" and did not want this report to be deemed late. I did recognize that the perfing operation had not been done yet, but made a decision to submit the 10-407 for the changes that had been made to the well, since I had no idea when the post rig perfing operation would be completed: I opted to submit the 10-407 and plan on submitting a revised or updated 10-407 for the post-rig perfing operation. It is currently on my (short) list to do and I hope to get to it shortly. Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Sunday, April 27, 2008 4:17 PM To: Preble, Gary B (SAIC); Stewman, Sondra D Cc: Hubble, Terrie L Subject: RE: PBU S-26 (190-058) Sondra and Gary, I got a bounceback from Terrie. As I have continued to read the sundry application, I see that stimulation of the Kuparuk was also intended. Gary, is that still the case? So far as I can see, as presently configured the well is producing out the of the Aurora Oil Pool (Kuparuk). Tom From: Maunder, Thomas E (DOA) Sent: Sunday, April 27, 2008 4:14 PM To: 'Preble, Gary B (SAIC)'; 'Hubble, Terrie L' Subject: PBU S-26 (190-058) Gary and Terrie, 1 am catching up on some paperwork on this well. 5/5/2008 Page 2 of 2 • • Terrie submitted the 407 for the workover which was to also have included perforating the Kuparuk. Gary submitted the 404 for the Kuparuk perFng on April 8. This is just a heads up (I have to check with Steve Davies) but l think a revised 407 should be submitted since the well is now can produce from the Ivishak and Kuparuk. Call or message with any questions. Tom Maunder, PE AOGCC 5/5/2008 • • Maunder, Thomas E (DOA) Fage 1 of 1 From: Maunder, Thomas E (DOA) Sent: Monday, April 28, 2008 3:08 PM To: 'Reem, David C' Cc: Young, Jim Subject: RE: PBU S-26 (190-058) Thanks Dave. My question is answered. From: Reem, David C [mailto:ReemDC@BP.com] Sent: Monday, April 28, 2008 2:54 PM To: Maunder, Thomas E (DOA) Cc: Young, Jim Subject: RE: PBU 5-26 (190-058) Tom, we had to make sure we had competent pipe from just below the Kuparuk and above which our test at 7200' provided (frac work on Kuparuk). The small leak between 7200' and 8484' is likely across from shale and not permeable (thus the very small leak rate at high pressure.) We chose not to isolate this leak as we do not believe any of the producing horizons can/will ever "inject" into this small leak while producing. This leak will be isolated with plugs in the tubing directly below the Kuparuk when it comes time to frac the Kuparuk. Hope this helps answer your questions. Thanks. Dave From: Maunder, Thomas E (DOA} [mailto:tom.maunder@alaska.gov] Sent: Sunday, April 27, 2008 4:49 PM To: Reem, David C Cc: Regg, James B (DOA) Subject: PBU 5-26 (190-058) Dave, I am catching on some past paperwork. I am reviewing the workover done on this well in late December/early January. The intent of the workover was to equip the well for commingled production in the welibore. I am curious why the casing leak was never resolved? It appears #hat it was never possible to get a M1T-T or a CMIT during the prerig work. The leak was small and a LLR was never able to be established using the available pumps. After the welibore had been cleaned out, the rig ran a RBP on 12127 and determined that the 9-5l8" casing was sound shallower than 7200'. However, when the first pressure test was attempted with the RBP @ 8484' (immediately above the tubing s#ub) the test lost 500 psi in 30 minutes. It appears that the rig tests confirmed the prerig tests. Was isolating the small leak ever discussed? I look forward to your reply. Tom Maunder, PE AOGCC 4/28!2008 ~~~~& STATE OF ALASKA ,SAN ~ ~ ~~~~' ALASKA IL AND GAS CONSERVATION COM~SION W L COMPLETION OR RECOMPLETION REPORT AND LQ~Iaska Oil & Gas Cons. Ccmm6ssiety Anchorage 1a. Well Status: ®Oil ^ Gas Plugged ^ Abandoned ^ Suspended zoAAC zs.~os zoAAC zs.>>o ^ GINJ ^ WINJ ^ WDSPL WAG ^ Other No. of Completions One 1b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 01/02/2008 12. Permit to Drill Number 190-058 307-346 3. Address: P.O. Box 196612, Anchorage, Alaska 9 19-6612 6. Date Spudded 05/12/1990 13. API Number 50-029-22047-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 05/24/1990 14. Well Name and Number: PBU S-26 1635 FNL, 1160 FWL, SEC. 35, T12N, R12E, M Top of Productive Horizon: 2473' FNL, 2107' FWL, SEC. 35, T12N, R12E, U 8. KB (ft above MSL): 65.09' Ground (ft MSL): 29.5' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2511' FNL, 2121' FWL, SEC. 35, T12N, R12E, UM 9. Plug Back Depth (MD+TVD) .9393 9184 Pool 4b. Location of Well (State Base Plane Coordinates, NA 27): Surface: x- 619322 y- 5979855 Zone- ASP4 10. Total Depth (MD+TVD) 9434 9225 16. Property Designation: ADL 028257 TPI: x- 620284 y- 5979032 Zone- ASP4 Total Depth: x- 620299 y- 5978994 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ^Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and p ted information per 20 AAC 25.071): DIL / GR / BHC / CNL, USIT - 22. CASING, LINER AN EMENTING RECORD CASING SETTING DEPTH MD SETT D EPTH=TVD- HOLE OUNT WT. PER-FT. GRADE .TOP BOTTOM TOP BOTTOM SIZE •-.,PiIW.ED 20" Surface 110' Surfac 110' 13-3/8" 68# L-80 Surface 2683' Surface 2683' 17-1/2" 3295 cu ft Arcticset III & II 9-5/8" 47# NT80S Surface 8816' Surface 609' 12-1/4" 1870 cu ft Class'G' 7" 26# L-80 8570' 9434' 8364' 25' 8-1/2" 264 cu ft Class'G' 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SI DEPTH SET MD PACKER SET MD 3-3/8" Gun Diameter, 4 spf 4-112", 12. 13Cr80 6780' 6691' MD TVD MD TVD 4-1/2", 12.6#, 13 80 & L-80 7034' - 8624' 7042' & 8540' 8951' - 9053' 8743' - 8845' 25. ID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT H~ KIND Of MATERIAL USED 8598' t HES FasDrill (12109/07) 8580' S FasDrill (12/15/07) Fre a Protect w/ 162 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, a ): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-AP) (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewall re s Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize litholog nd presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory a lytical results per 20 AAC 250.071. None Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ~±~~~~~~, ~_ ~ / / /~y V 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Kuparuk 6856' 6691' None Sag River 8819' 8612' Shublik 8859' 8652' Sadlerochit /Zone 4 8949' 8741' Formation at Total Depth (Name): 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foreg 'ng is true and correct to the best of my knowledge. p~ 31~ b~ Signed Terrie Hubble Title Drilling Technologist Date PBU S-26 190-058 307-346 Prepared By Namemlumber. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Aras Worthington, 564-4102 Permit No. / A royal No. INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITenu 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only • • PBU S-26 (Permit to Drill #190-058) Note: This well was recently worked over by Doyon 14. The Application for Sundry Approval (#307-346) outlined a plan that was to re-complete this well, adding perfs to the Kuparuk formation (Aurora). The work was completed by Doyon 14 as planned, except for the perfing of the Kuparuk. That work is now planned to be done as well work (post rig). I am submitting the 10-407 as required by the Application for Sundry Approval and I will re-submit the 10-407 after the perfing operation has been completed. Further, since the perfing of the Kuparuk (Aurora) has not yet been completed, I have kept the "Number of Completions" as "One" and the "Field & Pool" as "Prudhoe Bay Field / Prudhoe Bay Pool". I will update those two fields when I submit the 10-407 reflecting the perfing of the Kuparuk. ~,~.~ Terrie Hubble Drilling Technologist 01 /31 /08 + Well History Well Date Summary S-26 12/8/2007 WELL FLOWING ON ARRIVAL (Pre RWO). DRIFT TUBING WITH 3.725" CENT, TEL, SAMPLE BAILER. .,J~.OCATED TUBING TAIL AT 8601' SLM, ELMD TT 8627. CORRECTION OF 26'. TAGGED BOTTOM AT 9014' SLM. 9014' + 26' CORRECTION TD AT 9040'. 13' OF PERFS COVERED. NO SAMPLE RECOVERED, R DOWN. TURN WELL BACK TO DSO. S-26 12/9/2007 WELL FLOWING UPON ARRIVAL. INITIAL WHP 1000/1400/600. SHUT WELL IN TO SET PLUG. SET HES FAS- DRILL PLUG 8,598'. WAIT FOR LRS TO TEST PLUG BEFORE JET CUT. CONTINUED. S-26 12/9/2007 T/I/0=1300/1430/500 Temp=Sl Assist E-line (RWO Prep) -MIT OA PASSED to 2000 psi, Bled OAP from 500 psi to 350 psi all gas. Pressured up OA from 300 psi to 2000 psi w/8.6 bbls crude. OA lost 40 psi in 1st 15 min. OA lost 20 psi in 2nd 15 min. Bled OAP from 1940 psi to 350 psi, all fluid (~3 bbls). Pumped 3 bbl meth spear, 393 bbls crude down IA to sweep gas into tbg taking returns to FL. Continued. S-26 12/10/2007 INITIAL WHP 1000/1400/600. WAIT FOR LRS TO TEST PLUG BEFORE JET CUT TBG. ,LUG DID NOT PASS PT. ,1ET CUT POSTPONED, RIG DOWN ELINE. WELL LEFT SHUT IN. FLOW LINE FREEZE PROTECTED PRIOR TO DEPARTURE. FINAL WHP 700/500/480. JOB COMPLETE. S-26 12/10/2007 Assist E-line (RWO Prep). Pumped 646 bbls crude (40 bbls over tbg and IA displacement volume) down IA to sweep gas into tubing taking returns down the flow line. MIT - T to 3500 FAILED IA TRACKED BECAME THE CMIT. CMIT- _ TxIA FAILED to 3500 psi in 3 attempts. Pumped total of 64 bbls of crude down tbg to test. On 3rd test T/IA lost 310/280 psi in the 1st 15 min and 220/260 psi in the 2nd 15 min, for a total loss of 550/540 psi in 30 min. Freeze protect flow line w/20 bbls neat methanol. Verify casing valves open to gauges, tag well & notify operator. Final W H P's=360/360/390. S-26 12/11/2007 T/I/O =VAC/20/340. SI. Monitor WHPS (pre FB). AL SI @ 1800 psi. S-26 12/11/2007 T/I/0= 50/50/380. MIT T FAILED to 3500 psi. CMIT-TxIA FAILED to 3500 (RWO prep). IAP tracked w/ Tbg. Pumped 26 bbls crude down Tbg to pressure TxIA to 3500. CMIT TxIA failed 3 attempts with loss of 260/300 1st 15 min, loss of 260/260 2nd 15 min. Continued. S-26 12/12/2007 T/I/0= 50/150/340. Temp= SI. ALP= 1920 psi (SI at casing valve). Tbg, IA and OA FL's (RWO prep). Tbg FL at surtace. IA FL at 132' (7.1 bbls). OA FL at 48' (2.8 bbls). S-26 12/12/2007 CMIT TxIA FAILED to 3500 psi. (RWO Prep) Pumped 3.2 bbls crude down Tbg at minimum rate in attempt to establish LLR. TxIA climbed from 2600 to 3500. CMIT TxIA failed. Loss of 220/260 psi 1st 15 min. and 260/260 during 2nd 15 min for a total loss of 480/520 psi for 30 min test. Bled back 13 bbls, leak too small for bio pump. FWHP= 60/120/380. Tags hung, casing valves open to gauges. S-26 12/15/2007 T/I/O = VAC/160/350. SI. Bleed WHPs to 0 psi, FLs (RWO prep). AL SI at 1030 psi. IA FL at 510', OA FL at 15'. T FL ?. Called grease crew and had AL gate valve, lateral valve and Wing valve serviced. Bled AL line to 0 psi (30 min). Bled IA to 0 psi (2 hrs) all gas. Bled OA to 30 psi (3 hrs) fluid/gas mix. Final WHPs =VAC/0/30, AL = 0 psi. S-26 12/15/2007 WELL SHUT IN UPON ARRIVAL. INITIAL T/I/O = 0/0/0 PSI. SET HES 4.5" FAS DRILL BRIDGE PLUG. TOP OF PLUG AT 8580'. MAX OD OF PLUG = 3.66", LENGTH OF PLUG = 29.62" JE7 CUT 4.5" TUBING AT 8515.5'. 7' STUB LOOKING UP ABOVE COLLAR BELOW. POOH. CONTINUED, JOB INCOMPLETE. S-26 12/15/2007 T/I/O = 0/0/50 Temp = S/I -CMIT TxIA FAILED to 3500 psi, Unable to establish LLR, amt too small, MIT OA PASSED to 2000 psi (RWO prep) -Pressured up TxIA w/54.5 bbls crude to 3500/3480 psi. Two tests attempted with similar results as CMIT days prior - T/I lost 500/480 psi in 15 minutes. Unable to establish LLR, amt too small. Bled TxIA. MIT OA to 2000 psi. Pressured up OA to 2000 psi with 11.3 bbls crude. OA lost 100 psi in first 15 minutes and 40 psi in second 15 minutes. For a total loss of 140 psi in 30 minutes. Bled back - 3 bbls. Well SI at wing and all other casing valves open to gauges at departure. Tagged wing, IA and OA with info. FWHP's=100/180/0. S-26 12/16/2007 T/I/0=0/50/100 [RWO prep] Circ out Tx IA, Pumped 5 bbls neat meth, 588 bbls 1 % KCL down Tbg, up IA taking returns through jumper down F/L. Continued. S-26 12/16/2007 POOH AFTER JET CUTTING TBG AT 8515.5'. WELL LEFT SHUT-IN. FINAL T/I/O: 0/0/0. JOB COMPLETE. S-26 12/16/2007 Circ-out TxIA, CMIT TxIA 3500 psi. Job Postponed. S-26 12/17/2007 Pumped 316 bbls 1%KCL (904 bbls total) down Tbg up IA taking returns through jumper line down F/L. Pumped 16C bbls 110°F diesel down IA up Tbg taking returns down F/L. Pumped 21 bbls neat meth through jumper line down F/L to freeze protect. U-Tube TxIA to freeze protect. CMIT TxIA FAILED to 3500 psi. 4 tests Pumped 18.3 bbls diesel to reach test pressure, T/IA lost and average of 950 psi in 15 min. Couldn't establish LLR (Leak too small for big pump). Bled Tbg & IA. MIT OA PASSED to 3000 psi. Pumped 3.5 bbls crude down OA to reach test pressure. OA lost 10 psi in 15 min's, 40 psi in 2nd 15 min's for a total loss of 50 psi in 30 min's. Bled OAP. Final WHPs=0+/0+/0. S-26 12/18/2007 T=VAC. Set 4-1/16" CIW "H" BPV,. (Pre Doyon 14). Set 4-1/16" CIW "H" TWC thru tree 100". No problems. C BP EXPLORATION Operations Summary Report Page 1 of 6 Legal Well Name: S-26 Common Well Name: S-26 Spud Date: 5/12/1990 Event Name: WORKOVER Start: 12/20/2007 End: 1/2/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 1/2/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase ', Description of Operations 12/20/2007 100:00 - 01:00 1.001 MOB P PRE PJSM -Prepare equipment to skid rig floor -Skid rig floor to 01:00 - 07:00 6.001 MOB P PRE 07:00 - 11:00 4.00 MOB P PRE 11:00 - 12:00 1.00 MOB P PRE 12:00 - 22:30 10.50 MOB P PRE 22:30 - 00:00 1.50 MOB P PRE 12/21/2007 00:00 - 07:30 7.50 MOB P PRE 07:30 - 09:30 2.00 MOB P PRE 09:30 - 12:00 2.50 MOB N WAIT PRE moving position Move rig off well MPH-19 -Position rig on pad -Install and function rear boosters Move rig from MPH pad to Milne Pointe "Y" Wait on Security at Milne Pointe "Y" Move rig f/ Milne Pointe "Y" to Spine Rd. Wait on Security at Milne Pointe Rd and Spine Rd intersection Move rig f/ Milne Point Rd -Spine Rd intersection to S pad turn off Move rig from S pad turn off to S pad Remove rear boosters -Slide out conveyor WOW: temperature C~ -40 F. Waiting for temperature to rise above -35 F to work on well site preparation 12:00 - 19:00 7.00 MOB N WAIT PRE Cont. WOW: temperatures still under -35 F. Cannot operate heavy equipment needed for pad preparation RU conveyor and cellar heaters. Accepted rig C~? 1200 hours. 19:00 - 00:00 5.00 MOB N WAIT PRE Waiting on pad preparation to spot rig on well. 12/22/2007 100:00 - 07:30 I 7.50 I MOB I N 07:30 - 12:00 4.50 MOB P 12:00 - 15:30 3.50 MOB P 15:30 - 16:30 1.00 MOB P 16:30 - 22:00 5.50 RIGU P 22:00 - 00:00 I 2.001 RIGU I P 12/23/2007 00:00 - 01:00 01:00 - 04:00 1.00 RIGU P 3.00 RIGU P 04:00 - 00:00 12/24/2007 100:00 - 19:00 NOTE: temperature above -35 F WAIT PRE Cont. waiting on pad preparation to spot rig on well. Remove front boosters and frame PRE Spread herculite and set rig mats on well site PRE PJSM -Spot rig on well S-26 and shim PRE PJSM -Skid rig floor to drilling position PRE Spot rock washer and berm - RU rig floor - RU beaver slide - lnstall well guard on well S-25 (adjacent to beaver slide) and build barricade in front of well guard PRE Take on 580 bbls of 120 deg. seawater in pits -Install secondary annulus valve on IA -Install pump in flange on wing valve PRE RU lines to tree (tubing and IA) PRE Spot and berm tiger tank - MU hardline and choke from tiger tank to rig -Hook up hardline to rig lines -Test hard line w/ air - Test w/ seawater to 3,500 psi. Good test. Blow down lines 20.00 RIGU N WAIT PRE Wait on DSM crew and lubricator to pull BPV: DSM crews on hold due to gas leak situation on DS-14 Clean and organize around rig 19.00 RIGU N WAIT PRE Wait on DSM crew and lubricator to pull BPV: DSM crews on 19:00 - 20:30 I 1.501 DHB I P 20:30 - 23:30 I 3.001 PULL I P 23:30 - 00:00 0.50 PULL P 12/25/2007 00:00 - 04:30 4.50 PULL P hold due to gas leak situation on DS-14 Rig maintenance. PU and rack back 276 jts (92 stds.) of 4" DP DECOMP PJSM - RU,.p;~J~A lubricator on tree. Test to 500 osi -Pull BPV, - RD lubricator NOTE: no pressure below BPV DECOMP Pump 110 bbls of 120 deg seawater down IA, taking returns out tubing to tiger tank to displace freeze protect in tubing. Established returns after pumping 61 bbls -Blow down lines - Switch lines -Pump 214 bbls of 120 deg seawater down tubing, taking returns out IA to tiger tank to displace freeze protect in IA. Established returns after pumping 14 bbls. DECOMP Shut in IA and tubing. Allow diesel to migrate in IA. DECOMP Pump 40 bbls seawater down tubing, taking returns out IA to Printed: 1/14/2008 8:58:15 AM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To 12/25/2007 00:00 - 04:30 S-26 S-26 WORKOVER DOYON DRILLING INC DOYON 14 Start: 12/20/2007 Rig Release: 1/2/2008 Rig Number: Page 2 of 6 Spud Date: 5/12/1990 End: 1 /2/2008 Hours Task ~ Code NPT Phase 4.501 PULL I P 04:30 - 06:00 1.50 DHB P 06:00 - 07:30 1.50 WHSUR P 07:30 - 09:30 2.00 BOPSU P 09:30 - 14:30 5.00 BOPSU P 14:30 - 16:30 2.00 BOPSU P 16:30 - 18:00 1.50 BOPSU P 18:00 - 21:30 3.50 BOPSU P 21:30 - 22:30 22:30 - 00:00 12/26/2007 00:00 - 01:00 01:00 - 02:00 02:00 - 04:00 04:00 - 06:00 06:00 - 09:00 09:00 - 09:30 09:30 - 15:30 1.00 BOPSU P 1.50 DHB P 1.00 DHB P 1.00 FISH P 2.00 PULL P 2.00 PULL P 3.00 PULL P 0.50 PULL P 6.00 PULL P 15:30 - 17:30 2.00 i PULL ~ P 17:30 - 18:30 1.00 PULL P 18:30 - 20:30 2.00 CLEAN P 20:30 - 00:00 3.50 CLEAN P 12/27/2007 00:00 - 01:00 1.00 CLEAN P Description of Operations DECOMP tiger tank. Shut in pumps. Check IA and still returning diesel. Pump additional 50 bbls of seawater down tubing. Check IA. Let more diesel migrate x 30 min. Pump additional 100 bbls seawater down tubing, taking returns out lA to tiger tank. Stop pumps. Check IA, still with gas /diesel returns. Pump additional 200 bbls down tubing taking returns out IA to tiger tank. Stop pumps. Verify well dead. NOTE: circulate down tubing a total of 590 bbls of seawater. Total volume Tubing + IA to the cut C~ 8,515' is 585 bbls DECOMP Install TWC -Test f/ below to 1,000 psi. Pressure bleeds off a rox. 100 si every 5 min. Pressure up to 1,000 psi f/ below several times w/ same result. Verify that no fluid is coming through TWC f/ below - T t to 3 500 si f/ above x 10 min. Test oood. Chart all tests. DECOMP PJSM - ND tree -Check XO onto tubing hanger and verified number of turns to MU. DECOMP PJSM - NU BOP stack and flow line DECOMP Rig Christmas Stand Down: had both crews in for Christmas gathering and meal. DECOMP PJSM -Cont. NU BOP and choke line DECOMP RU to test BOP. Tighten choke flange under rig floor DECOMP Test BOP and related equipment as per BP / AOGCC procedures and regulations. Test to 250 psi low - 3,500 psi high, 5 min each on chart. Full test w/ 4" test joint. Test also top rams to 4-1/2" test joint. Perform koomey test. Test witnessed by WSL and Tourpusher. Chuck Scheve, AOGCC rep, waived witness of test. DECOMP RD testing equipment -Blow down lines DECOMP RU DSM lubricator. Test to 500 psi DECOMP Pull TWC - RD lubricator NO E: no pressure below TWC DECOMP PJSM - MU spear -RIH and engage tubing hanger -Back out ULDS -Pull tubing hanger to rig floor, PUW = 144k (blocks weight = 50k) DECOMP Pump 40 bbls Safe Kleen pill followed by 40 bbls Safe Scab pill. Circulate surface -surface, 262 gpm / 910 psi NOTE: got crude with returns. DECOMP a ease spear from to ing anger and LD same -Blow down top drive - RU control line spooler - RU to LD tubing and completion equipment. DECOMP LD 4-1/2" 12.6# L-80 tubing to SSSV (52 jts), recovering control line. Recover 26 clamps and 3 bands. DECOMP LD SSSV - RD Schlumberger spooling unit DECOMP Cont. LD 4-1/2" 12.6# L-80 tubing and completion equipment. Total jts LD: 211 Also recover: 5 GLMs, 5.92' pup jt, 5.90' pup jt, 2.3' cut off DECOMP RD and LD tubing handling equipment -Clear and clean rig floor. Remove crude f/ floor mats DECOMP Install wear bushing DECOMP PU and MU BHA w/ Dress-off shoe -Dress-off mill assy. DECOMP RIH on 4" DP f/ 233' to 8,489' DECOMP Obtain parameters - Taa tubing stump ~ 8.514' - Washover and dress to 8,520' Printed: 1/14/2008 8:58:15 AM C BP EXPLORATION Page 3 of 6 Operations Summary Report Legal Well Name: S-26 Common Well Name: S-26 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Spud Date: 5/12/1990 Start: 12/20/2007 End: 1/2/2008 Rig Release: 1 /2/2008 Rig Number: Date From - To Hours Task Code NPT - _ ----- - 12/27/2007 00:00 - 01:00 1.00 CLEAN P 01:00 - 03:00 I 2.001 CLEAN I P 03:00 - 06:00 3,001 CLEAN ~ P 06:00 - 09:00 3.00 CLEAN P 09:00 - 11:30 2.50 CLEAN P 11:30 - 16:00 4.50 DHB P 16:00 - 17:00 1.00 DHB P 17:00 - 18:30 1.50 DHB P 18:30 - 19:30 1.00 DHB P 19:30 - 21:30 2.00 DHB P 21:30 - 22:00 0.50 DHB P 22:00 - 23:00 1.00 ~ DHB P 23:00 - 00:00 1.00 BOPSU P 12/28/2007 00:00 - 02:30 2.50 BOPSU P 02:30 - 05:00 I 2.501 BOPSUFi P 05:00 - 10:00 I 5.001 WHSUR I P 10:00 - 13:30 3.50 BOPSU~P 13:30 - 14:00 0.50 BOPSU P 14:00 - 15:00 1.00 DHB P 15:00 - 17:30 2.50 DHB P 17:30 - 19:00 1.50 DHB P 19:00 - 20:30 1.50 DHB P 20:30 - 00:00 3.50 DHB P 12/29/2007 100:00 - 01:30 I 1.50 I EVAL I P 01:30 - 02:30 I 1.00 I EVAL I P Phase Description of Operations DECOMP PUW = 180k -SOW = 175k - ROTW = 180k - TO = 2k ~ 80 RPM - 343 gpm ~ 1,200 psi. Slide over stump to 8,520' with no pumps and no rotation, OK -Stand back one stand and PU single - RU to reverse circulate -Attempt to reverse circulate, k off - RD reverse circ. lines and MU top drive -Attempt to um down pipe, pack off / no returns / no rotation DECOMP Work /jar pipe pulling max to 350k until free. Establish circulation and rotation DECOMP Pump and circulate Hi-vis sweep surface -surface, 9 bpm / 1,400 psi -Redress tubing stump to 8,520' -Pump and circulate Hi-vis sweep surface -surface, 9bpm / 1,400 psi - Flow check -Blow down top drive and kill line DECOMP POOH f/ 8,514' to 233' - C/O handling equipment DECOMP LD DCs, fishing jar, bumper sub, scraper, boot baskets, wash pipe and mills -Clean out boot baskets -Clear rig floor from Baker tools -Mobilize Halliburton tools to rig floor DECOMP MU RBP -RIH on 4" DP to 8,484' and set RBP DECOMP RU testing equipment -Pressure up casing to 3,500 psi - rnroi irn rnne n nci in 4!1 min +ee+ a~ o _ +oe+inn DECOMP Retrieve RBP -POOH to 7,200' -Set RBP DECOMP RU testing equipment -Test casing to 3,500 psi x 30 min on chart test ood - RD testin equi ment DECOMP POOH to 2,084' to PU RTTS packer DECOMP MU RTTS packer -RIH and set RTTS @ +/- 100' below rotary table. DECOMP RU testing equipment -Test RTTS to 3.500 psi f/ above x 30 min on chart, test good - RD testing equipment DECOMP Pull wear bushing - ND BOP DECOMP Cont. ND BOP and tubing spool. While ND, casin shows "growing". Raise BOP stack and tubing spool together. Casing "grew" aprox. 15". Stand back BOP stack. DECOMP Remove tubing spool. Move old tubing spool tree out of cellar - bring new tubing spool /tree in cellar, while waiting on spear to pull casing and set tension back on emergency slips. DECOMP Mob. spear to rig floor. PU and MU 9-5/8 spear. RIH and engage 9-5/8" casing. Back out LLDS. Pull casing to 230k total pull and set on slips (weight on slips 150k). Cut casing with Wachs cutter. Install packoff. NU new tubing spool. Test packoff to 3,800 psi DECOMP NU BOP DECOMP RU testing equipment -Test breaks to 250 psi low - 3,500 psi high 5 min each on chart - RD testing equipment and install wear bushing DECOMP MU retrieving tool -Retrieve and pull RTTS packer - LD packer DECOMP _RIH to 7,200' and retrieve RBP DECOMP POOH w ,200 to 4,560' DECOMP Rig service: cut and slip drilling line, service top drive DECOMP Cont. POOH w/ RBP f/ 4,560' to surface - LD RBP and running tool -Clear rig floor. DECOMP Mobilize shooting flange to rig floor - ND riser, flow line and pitcher nipple - NU shooting flange DECOMP Clean rig floor Printed: 1/14/2008 8:58:15 AM • BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: ~, From - To S-26 S-26 WORKO DOYON DOYON Hours VER DRILLI 14 ~i Task G INC Code . ~~~; NPT 12/29/2007 02:30 - 07:00 4.50 -_ __ EVAL _ __ P 07:00 - 14:00 7.00 EVAL P 14:00 - 22:00 8.00 EVAL P 22:00 - 00:00 2.00 EVAL P 12/30/2007 00:00 - 01:00 1.00 EVAL P 01:00 - 02:00 1.00 EVAL P 02:00 - 04:00 2.00 BUNCO P 04:00 - 07:00 3.00 BUNCO P 07:00 - 07:30 0.50 BUNCO P 07:30 - 12:30 5.00 BUNCO 12:30 - 13:00 0.50 BUNCO P 13:00 - 13:30 0.50 BUNCO P 13:30 - 15:00 1.50 BUNCO P 15:00 - 19:00 4.00 BUNCO P 19:00 - 20:00 1.00 BUNCO P 20:00 - 22:30 2.50 BUNCO P 22:30 - 00:00 1.50 BUNCO P 12/31/2007 00:00 - 01:30 1.50 BUNCO 01:30 - 02:30 1.00 BUNCO P 02:30 - 04:30 2.00 BUNCO P 04:30 - 10:30 6.00 BUNCO Spud Date: 5/12/1990 Start: 12/20/2007 End: 1 /2/2008 Rig Release: 1 /2/2008 Rig Number: Phase Description of Operations DECOMP Wait on Schlumberger: preparing flow tubes and well control equipment. DECOMP Spot Schlumberger - RU lubricator, W/L BOP, Flow tubes, sheaves and tools -Test lubricator and W/L pressure control system to 500 psi x 5 min. DECOMP RIH w/ USIT log on cement bond and casing condition mode to 8,490'. Log to surface. RIH and relog int. 8,400' - 6,000'. POH NOTE: Jim Young (BP) reviewed USIT log. Cement OK to proceed w/ completion operations DECOMP RD Schlumberger DECOMP Finish RD Schlumberger DECOMP ND shooting flange - NU pitcher nipple, riser and flow line RUNCMP RU to run 4-1/2" 13Cr80 VAM TOP tubing: C/O bales, install elevators and compensator, RU and test tongs and turn torque equipment. RUNCMP PJSM - MU and RIH lower completion string (short string):, Unique Overshot + 34 jts 4-1/2" 12.6# 13Cr80 VAM TOP tubing + X-Nipple + S-3 packer. Turn torque all connections RUNCMP RD tubing equip. - RU f/ 4" DP RUNCMP RIH w/ tubing string on 4' DP to 8,437' -Obtain parameters - PUW 163k, SOW 158k -Screw in TD -Break circ. w/ 2 bpm, 40 psi -Observe shear screws at 8,531' OS depth (8,527' top of cut jt) -Slack off and observe shear w/ 10k down wt. - Continue down and bottom out on collar at bottom of cut jt at 8,534' -Observe 50 psi pressure increase - PU 3' to OS depth of 8,531' -Top of Baker "HR" setting sleeve at 7,033' -Drop ball and rod RUNCMP Pressure up to 3,500 psi to set packed-Wait 10 min -Bleed pressure -Slack off 20k down wt -Rotate 15 turns to right to release running tool from packer - PU 2' -Install floor safety valve in DP RUNCMP Close pipe rams -Pressure up on annulus to 3,500 psi -Hold for 30 min -Record on chart -Good test RUNCMP Bleed off pressure -Blow down lines to annulus - CBU, 380 gpm / 1,020 psi RUNCMP POH and LD 4" DP f/ top of setting sleeve to +/- 1,300' RUNCMP RIH 18 stands 4" DP left in derrick to +/- 3,200' RUNCMP POH and LD 4" DP and Baker running tool -Pull wear bushing - Clear rig floor RUNCMP RU to run completion - RU Halliburton I-wire spool RUNCMP Cont. RU to run completion. RUNCMP MU and RIH 4-1/2" WLEG assy + 1 jt 4-1/2" 12.6# 13Cr80 VAM TOP tubing + X-Nipple assy w/ RHC-M plug + S-3 packer + X-Nipple assy + 1 jt 4-1/2" 12.6# 13Cr80 VAM TOP tubing + Symphony gauge assy. Turn torque all connections. Bakerlok all connections below packer RUNCMP Halliburton prepares I-wire -Connect I-wire to Symphony gauge and test. RUNCMP Cont. MU and RIH 4-1/2" 12.6# 13Cr80 VAM TOP tubing and completion equipment w/ I-wire. Turn torque all connections. Install one clamp every connection. Test I-wire every 5 jts. Run 47 jts to 2160' -Changed out 8 joints total out of 47 run -All Printed: 1/14/2008 8:58:15 AM BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: S-26 Common W ell Name: S-26 Spud Date: 5/12/1990 Event Nam e: WORKO VER Start : 12/20/2007 End: 1/2/2008 Contractor Name: DOYON DRILLIN G INC . Rig Release: 1/2/2008 Rig Name: DOYON 14 Rig Number: Date From - To !Hours Task Code NPT ' Phase Description of Operations 12/31/2007 04:30 - 10:30 6.00 BUNCO RUNCMP joints layed down were defective pin lengths (Too short) 10:30 - 17:00 6.50 BUNCO WAIT RUNCMP Pull protectors from pipe in pipe shed and inspect same - Unload remainder of pipe from pipe shed, replace w/ new pipe f/ CSP -Thaw, strap and drift new pipe. 17:00 - 00:00 7.00 BUNCO P RUNCMP Cont. MU and RIH 4-1/2" 12.6# 13Cr80 VAM TOP tubing and completion equipment w/ I-wire. Turn torque all connections. Install one clamp every connection. Test I-wire every 5 jts. 1/1/2008 00:00 - 03:00 3.00 BUNCO RUNCMP Continue to M/U and RIH 4-1/2" 12.6# 13Cr80 VAM TOP Tbg & completion equipment w/ I-wire. -Torque turn all connections. Install one clamp every connection. -Utilize "Jet Lube Seal Guard" thread compound. -Test I-wire every 5 joints. -Total jts run: 155. Install a total of 161 full clamps and 10 half-clamps. -Check PUW 125k /SOW 125k 03:00 - 05:00 2.00 BUNCO RUNCMP MU tubing hanger and landing joint. -Terminate and connect I-wire to tubing hanger per Halliburton. 05:00 - 05:30 0.50 BUNCO P RUNCMP Land tubing hanger. RILDS. Bottom WLEG C~? 6,780' md- S-3 Packer ~ 6,691' md. -Symphony Gauge ~ 6,608' md. -GLM #1 C~? 6,537' md. -GLM #2 C~3 6,216' md. -GLM #3 ~ 5,304' md. -GLM #4 @ 3,635' md. -X-Nipple @ 2,029' md.- Doyon 14 RKB to ULDS: 30.47'. 05:30 - 08:30 3.00 BUNCO P RUNCMP Pump seawater 482 bbls total. -150 bbls w/ corrosion inhibitor - 3 bpm / 240 psi. 08:30 - 11:00 2.50 BUNCO RUNCMP Drop Ball & Rod - R/U to pump down tubing -Pressure to 3500 -Hold for 30 min on chart -Good test -Bleed tubing to 1500 psi. -Pressure up on annulus to 3500 psi to test "IA" -Hold for 30 , -Bleed tubing from 3500 psi to 1200 psi (2300 differential) to shear DCR-1 valve at 3,635' md. -Establish circulation through shear valve C~ 3 bpm / 300 psi. 11:00 - 12:30 1.50 BUNCO P RUNCMP R/D test equipment. L/D landing joint -FMC install TWC. -Test from above to 3500 psi and from bottom to 1000 psi. -Hold f/ 10 minutes each on chart -Good test. 12:30 - 14:30 2.00 BOPSU P RUNCMP PJSM - N/D BOPE. 14:30 - 16:00 1.50 BOPSU P RUNCMP N/U 13 5/8" x 4 1/16" 5k adapter flange - terminate I wire. -Test adapter flange to 5000 psi f/ 15 minutes - OK. 16:00 - 17:00 1.00 WHSUR P RUNCMP N/U 4 1/16" 5k tree and test to 5000 psi f/ 5 minutes - OK. 17:00 - 18:00 1.00 WHSUR P RUNCMP Test lubricator to 500 psi - OK. DSM pulled TWC. 18:00 - 21:00 3.00 WHSUR N WAIT RUNCMP Wait on Hot Oil (LRS) for freeze protect. 21:00 - 21:30 0.50 WHSUR P RUNCMP R/U Hot Oil and test lines to 3500 psi - OK. -PJSM. 21:30 - 00:00 2.50 WHSUR P RUNCMP Pump 162 bbls of diesel down annulus. -Take returns up Tbg 2 bpm / 650 psi. 1/2/2008 00:00 - 02:00 2.00 WHSUR P RUNCMP U-tube diesel. -R/D LRS (Hot Oil) hoses. 02:00 - 02:30 0.50 WHSUR P RUNCMP R/U DSM, install BPV. -Test from below 1000 psi / 5 minutes - OK. -R/D DSM. 02:30 - 03:00 0.50 WHSUR P RUNCMP R/D Lines. Remove double valve. Printed: 1/14/2008 8:58:15 AM Printed: 1/14/2008 8:58:15 AM _TREE = a" caw WELLHEAD = FMC AC1iJATOR= ~ OTtS KB. ELEV = 65.09' BF_ ELEV = 37.49' KOP = 4400' Max Angle = 23 ~ 5178' Datum MD = 9073' Datum TV D = 8800` SS DRLG DRAFT 13-3/8" CSC, 68#, NT-80, m = 12.d15" ~ 2683' 4112" TBG, 12.6!1, 13Cr80 Vam Top ~ = 3.958"WLE 6779' SA TES: NOTIFY GC OF ANY WELL OP TION WINCH COtX.D INCREASE FLOW OR S _~ ~ 9tOS10N RATES TO 3- SKN) FLOWLINE (P0T6YTIAL EROSION}. "'4-1f2' CHROME TBG 8 LMt""' 4112" HESX NF', ~=3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DAATE 4 3635 3635 O MMG DCR RKP 0 01101 /0$ 3 5304 5251 23 MMG DMY RK 0 01/01/06 2 6216 6094 22 MMG DMY RK 0 D1/01108 1 6537 6316 21 ltiA1JIG t)NIY RK 0 01/01/08 660$' 4112" HES SYM~FiONY GAUGE 6670' 4-112" HES X NIP, ID = 3.813" 6691' 41/2" Baker S3 Cr packer 6715' 41 !2" X N~, ID = 3.813" Minimum ID = 3.80" @ 8613' 4-1/2" OTIS XN NIP, MILLED OUT 7033` ~ ~ Baker Setting sleev ^-7041' BAKER S3 CR PACKER 4112" LNR, 12.66, 13Cr80 Vam Top ID = 3.958" -$610' 7066' 41/2" X NIP, !D = 3.813" " ' -8531' UNIOUEOVERSHOT LNR TOP OF 7 $SJp 8540' 9-5/8" OT1S PKR, ID = 3.85" SET FasDril ~ 8580` (Pre Rig} 4112" TBG, 12.60, L-80 T'DS, .0152 bpf, D = 3.958" $624' 8593' 4112" PARKER SWS NIP, ~ = 3.813" $598 4.5" HES FasDril 12-9-07 (Pre Ftlg} $613' 4112" OTIS XN NF', ID = 3.725" MILLED TO 3.80" 9-518" CSC, 47tF, L-80, !D = 8.681" I-i 8816' PERFORATION sUMMARY REF LOG: SWS BHCS ON 05/24/90 ANGLE AT TOP PERF: 4 ~ 8951' Note: Refer fo Production DB for h~torical perf data 5QE SPF NTERVAL Opn/Sqz DATE 3-3/8" 4 8951 - 8961 C 08/26/90 3-318" 4 8965 -9053 C 08/26!90 3.318° 4 9085 - 9130 S 09/10/94 3-318" 4 9184 - 9186 S 09/10/94 Kuparuk Ad-perts~ " --6850-6900' M D ~~ H 9390' 7" LNR, 26#, L-80 U4S, .0383 bpf, ~ = 6.27fi" $624' 4112" VWLEG 8627' ELMD TT LOGGED 06!15/90 9030' Z~ W/ RUNNING TOOLS 9139' BAKER ECP, SCOOP GLIDES, RUNNING TOOL, AND OLD ~P I 918i' 1 (MARKER JO~IT I DATE REV BY COMMENTS DATE REV BY CONVENTS 06/04/90 ORIGINAL COMPLETION 01102/08 Did RWO 01/02/08 ITCH CORRECTIONS PRUDHOE BAY UNIT WELL: S-26 PERMT No: 1900580 API No: 50-029-22047-00 SEC 35, T12N, R12E, 4635' FNL 81180' FWL ~ Exploration (Alaska 04/25/08 ~IhIIIII~U~I'~1' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh # NO.4673 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 nn nu nfinn n.,s,, o~ 2-52/S-14 11846807 PRODUCTION PROFILE (REDO) 08/18/07 1 1 F-22 12005209 MEM TEMP SURVEY 04/08/08 1 1 MPB-09 11963093 MEM PROD PFOFILE _ ~ 04/13/08 1 1 MPL-33 11963090 MEM INJECTION PROFILE ~ 04/11/08 1 1 MPF-89 11963092 MEM TEMP SURVEY 04/12/08 1 1 L5-29 11963087 MEM TEMP SURVEY ^-Q 04/04/08 1 1 S-26 12071843 SBHP SURVEY ~ 04/03/08 1 1 06-15 11962594 LDL 0 _ (0 04/09/08 1 1 W-30 12034892 PROD PROFILE jtt~.j~ /(,~~.(~ 04/11/08 1 1 L-221 11962592 USIT/CBL ~~~ ~jy~ _ ( ~~~ 04/07/08 1 1 4-14A/S-37 11970818 CH EDIT PDC GR JEWELRY ~_ ~ 03/24/08 1 18-328 11978442 MCNL - qi (, 02/26/08 1 1 G-24A 11660525 MCNL 3f' 02/02/07 1 1 .~_ ..~....~.. _......r ..r.i.-., , v . v.~w. ~..~u r.~~v , ~~. ~ vn~v~~vl] vlvG trvr ~ CHlin 1 v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~ ~~ - ~~~IVNE~ APR ~ 9 200 Anchorage, Alaska 99508 Date Delivered: ~ ~, ",'(~~~~~5 • Alaska Data & Consulting Service 2525 Gambell Street, Suite 40 Anchorage, AK 99503-2838 ATTN: Beth ~~~= Received by: v~ STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATION ASR o g zoos a~laska Oil & Gas Cans. Commission S A 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development r Exploratory ~ 190-0580 3. Address: P.O. Box 196612 StratlgraphlC ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22047-00-00 7. KB Elevation (ft): 9. Well Name and Number: 65.09 KB - PBU S-26 ' 8. Property Designation: 10. Field/Pool(s): ADLO-028257 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 9434 feet Plugs (measured) 9030' Junk (measured) 9139' true vertical 9224.76 ~ feet ~,~g ~~'``"~~'~"~~ '~`~~ '~ ~ ~~~~ Effective Depth measured 9393 feet true vertical 9183.9 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 20" SURFACE - 110' SURFACE - 110' SURFACE 2683' 13-3/8" 68# NT-80 SURFACE - 2683' SURFACE - 2683' 4930 2270 INTERMEDIATE 8810' 9-5/8" 47# L-80 SURFACE - 8816' SURFACE - 8609' 6870 4760 LINER 864' 7" 26# L-80 8570' - 9434' 8364' - 9225' 7240 5410 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 8624' 0 0 - Packers and SSSV (type and measured depth) 4-1/2" BAKER S3 CR PACKER 6691' BAKER S3 CR PACKER 7041' 9-5/8" OTIS PKR 8540' 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 213 ~ 1098 732 210 Subsequent to operation: 220 1317 6745 188 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: 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: N/A Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature Phone 564-4944 Date 4/8/2008 Form 10-404 Re~/ised 04/2006 ~ ~ ~ n ~ ~ ~ r~ g ~ Submit Original Only s-as 190-05$0 PERFORATION ATTACHAAENT // MDT MOB TVD TVO 8/28/1990 5/4lt991 7/18/1992 7/31/1992 1t/12M993 9/t0/t994 1W21/1996 12/9/2007 12/15/2007 12!2712007 3!31!2006 008 6 0 6 4 6638.74 6 661.43 n F 8,951 8,961 8,878.38 8,688.34 ER ePS ePS HPS HPP 8,985 9,053 8,692.3$ 8,780.01 PER HPS ePS BPS HPP 9,085 9,130 8,811.90 8,856.74 PER BPS BPP BPS HPP SOZ HPS BPS BPS BPP 9,184 9,186 8,910.54 8,912.53 PER B S BP HPP SQZ BPS BP HPS HPS BPP 8 18 8 518 8 244.89 $ 245.88 PER BPS BPP _._ APF~ ADD PERF -- - - - ~-~ ---_-_~ __..._.~ i _.-~ _ _ r-- ~ , BPP BRIDGE PLUG PULLED -- _ ~ _ ~T---- ~ - ~__ I ~T ~ - ~- _,,~,,,~,~ - M„-.____ _ ___..._ BPS BRIDGE PLUG SET ! ~ . ! I ~ FCO FIL FILL CLEAN OUT FILL s , i ~; ~ I ._.._.._.__._ . _ ,,, ; i._...._. _,_.i _~, _._- _ _._ _ ~ ,_,_ ._.. MIR MECHANICAL ISI~LA'CE Q REMOVE D ~ ~ ~~ ~ ~ ~ - - ~ - - -. - -.- -~- _ -. MIS K MECHANICAL ISOLATE EAK C A C D --- -._~ _ _._^ ^' ~-~- , ---~ .o._. ,._.._ ~ ML OH __ P ER "~- ME H NI AL L OPEN HOLE --- 4 PERF _.. ...__ -.. _._.._._ ... ___ - _.~._.. ;; -- I .-......____i -_~ __~ _ ____.,._._ ~._ _._...._._..~ ~_. _ ~ ..._-....__._._ ..____.__._,._. ~ _..__ ~ ~ -. __..____..~ ._.._...__,......_._ _ _ iiPF . REPERP ~~ w ~ _ rr 4- iii-- ~~ -- ~ --~-- - --- SL SPR SLOTTED LINER SAND PLUG REMOVED D ~ _a......_....' ___y__1 ~"'°_..,.__i __.____.__ ___._......__ ., u. -~ ,_......_,_...._.._ ~ ! -_.__.,,..,_.~..~ _ .,-...._.__; { __.__..._._ I ......__...~I .~__-~ ~ ..~ ._ I SQF SQZ STC SQUEEZE FA ED ~..,. . , SQUEEZE 37RADDLE PACK CLO SED .~ _ -~ ___._....,..._... .-._..._._.._,.._. ._...__~..~ _ ...,.....~ ..~..M__~,,, ~ ._._....._..._._ ~ ~....._...._._.,..,_~ ~ .....~._...__.~ ..-~~.-,. ...T ~~~ -_ ___- ...---- ----- ---- STO STRADDLE PACK OPE N ~ ._ s ~~~ I +~.'_ • • S-26 fs~ DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ---- ~ ACTIVITYQATE SUMMARY 4/3/2008''`'`'`WELL SHUT IN ON ARRIVAL*"" INITIAL WHP= T/IA/OA=1400/1400/250 i SBHPS RAN FOR PRESSURE AT PERFORATION ZONE = 2303 PSI. ';FLUID LEVEL AT 5308' PERFORATED INTERVAL 6870 TO 6894' WITH 3.375" POWERJET, 6SPF. WELL 1000 PSI UNDERBALANCED OVER PERF ZONE. 'SURFACE INDICATION OF GUN FIRING. VISUAL CONFIRMATION MADE'j 'ONCE GUN WAS ON SURFACE. '`'`JOB COMPLETE** ''`'`*WEL L VV/I/0: 1550/1500/250.*** FLUIDS PUMPED BBLS 1 diesel 1 Total 01 /18/08 1~~i~~~IJ~~~~~ NO. 4560 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 ~rt~~y~Qa$ ~~(') ~ ~ L~ULI Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~` N'4~6~1i9~7 D L UC" Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne, Pt. Mac, Orion, Borealis Woll .Inh $ Inn rlocerin4inn t1a4a RI Cnlnr Crl L-219 11966240 MDT ~ "}- IC 12122/07 1 L-114A 11970807 LDL 12/30/07 L-116 11962777 LDL (- ~ 12/31/07 1 V-211 12021135 MEM INJECTION PROFILE ~C(-- ai~ 12/29107 1 V-216 12021136 MEM INJECTION PROFILE U 12/30/07 1 L-219 12017479 ISOLATION SCANNER CBL _ L. 01102/08 1 P2-16 11975750 INJECTION PROFILE 12/31/07 1 F-32 11970707 LDL ~ - 01/04/08 1 15-046 12005202 MEM CEMENT BOND LOG ~ - 12/28107 1 G-31A 11962778 SCMT j - C 01/01/08 1 S-26 11978425 USIT 12/29/07 1 02-16C 11628793 MCNL ~- ~ 08/28/07 1 1 G-046 11628765 MCNL - ~ ~ 04/06/07 1 1 K-02D 11209613 MCNL ~' L 07/21/06 1 1 17-076 11649940 MCNL - ~- / ~ 02/17107 1 1 L2-28 11975742 RST = 12/05/07 1 1 Z-06 11968821 RST ~ 12/13107 1 1 PLtASt AGKNUWLtUGt KtGt1Y I tiY SIIaNING AND Kt 1 URNING QNt GDPY tAGN 1 V: BP Exploration (Alaska) Inc. ~` , F Petrotechnical Data Center LR2-1 i " ^ t~ ~ e fF ~ tj 900 E. Benson Blvd. "~ °'~ Anchorage, Alaska 99508 Date Delivered: ~~~~~ ~ ~• ;'(1~-, Alaska Data & Consulting Services 2525 Gambell Street, Suite 00 Anchorage, AK 99503- 83 ATTN: Beth Received by: • • ~~ ~Yt F ~ fi¢`3 }t ~ I ~ t ""'~ ~ ~_'l ('gg"` ~ fi j~~ ~ .~__ f s f ~ ~ ~ 1 1 ~ a SARAH PAL/N, GOVERNOR '~~ ~ i.~ ~. s.,, ~ "tit ~ ~.1 ~ ~ ~.~_;.t ~ i ~ l 4~~ ~. ~~ OIL tusL va--7 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA7`IOr1T COl-II-iISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. ., PO Box 196612 ~ .~. Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Unit Field, Pruhoe Bay Oil Pool, PBU S-26 Sundry Number: 307-346 Dear Mr. Reem: 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 (907j 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. DATED this~day of November,2007 Encl. Sincerely, /©~ ~ STATE F A~ASKA ~NOV 1 3 2007 ~/(l ~/ ALASKA OIL AND GAS CONSERVATION COMM SION ~J ~ ~~y 111 APPLICATION FOR SUNDRY APPROk~ Otl & Gas Cans. Commission 20 AAC 25.280 Anchorage 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ®Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations i~imulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool aivery~~ Other 2. Operator Name: 4. Current Well Class:. 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 190-058 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22047-00-00- 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: 13,200' PBU S-26 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028257 - 65.09' - Prudhoe Bay Field / Prudhoe Bay 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): 9434 9225 - 9393 9184 9030 9139 Casin Len h Size MD TVD Burst Colla se- Structural Cond r 110' 20" 110' 11 ' Surface 2683' 13-3/8" 2683' 2683' 4930 2270 Intermediate 8810' 9-5/8" 8816' 8609' 6870 4760 Pr ion Liner 864' 7" 8570' - 9434' 8364' - 9225' 724 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8951' - 9053' 8743' - 8845' 4-1/2", 12.6# L-80 8624' Packers and SSSV Type: 9-5/8" x 4-1/2"Otis Packer Packers and SSSV MD (ft): 8540' 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: December 15, 2007 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564-4102 Printed Name vid Reem Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-4102 Date Ir }- D Commission Use Onl Sundry Number: 3D~ - Conditions of approval: Notify Commission so that a representative may witness 34~ ^ Plug Integrity ,BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~C7 ~ es~ 30P ~ . Sv~DM~ ~ Q~J~US ~~ ~o S~~E~~~~~` vJ~'~'~b~f~.~ `n+;~ , ®~c.Q e ~-- a 3 no-~ ~v>~o~^ iL~e~ ~,.y`~if ~-P~.~ovecQ K .. t C ~e v ~c~ Cm~wlw ~Q p ~ sS v ~ ~ b ~-ti-e ~ ~ ~- ~.e s s r`ca~ ~ i ~. P ~ o ~.- e ss~ f ^~ (' R Q ` ~ Subsequent Form quired: ~~ or \, ~~ ~ ~F~ C'otis. ~~ yO`~ ' ~~-• vr. ec o~` to~ ~ APPROVED BY ~~" ^d~ A roved B COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 Submit In Duplicate 1NAL ~F~_ ~~~ ~ 700 • by G.ad, S-26 Rig Workover • Reason for RWO: Recomplete the well to include production from the Kuparuk Interval. Scope of Work: Pull 4 1/2" L-80 completion, run 4-'/2° Chrome completion straddling the Kuparuk interval. Perf and frac the Kuparuk. MASP: 2420 psi Well Type: Ivishak Producer Estimated Start Date: December 15, 2007 Pre-riq prep work: S 1 DGLVS. Drift down to -8700' and throu h tb tail for Fasdril plu E 2 Set Fasdril plug @ 8600' and in 4 ''/2" tbg tail (in 10' pup joint just below Parker SWS nipple Ref. 6/4/90 tubin tall F 3 MITT to 3500 si. CMIT to 3500 psi. MITOA to 3000 psi. W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well should be secured at this time with a Fasdril lu PPPOT-T 8~ IC. E 5 String shot and chemical cut @ 8514' md, in the top of the 2" 10' pup above the production acker -leave -8' of stub lookin up above collar below Ref: 6/4/90 tubin tall F 6 Circulate well with seawate. FP w/diesel thru the cut. Bleed WHP's to 0 si. O 7 Set a BPV. Remove the wellhouse & flow line. Level the pad as needed for the ri . Proposed Procedure: 1. MIRU. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the chemical cut. 2. Pull and LD 4 1/2" tubing string. ~~~ 3. Run USIT log across Kuparuk interval (cased by 9 5/8") SJ~w~~~ VS\'C'-~v p,~~ C.~, 4. Run packer and 1500' of 4 %2" chrome tbg and set packer just below Kuparuk interval (7000' md) ~~ ~~~-( 5. Run new 4-1/2" chrome tubing completion with sEas{EeF.packer set -6800' md. .~r~~~~ c~~cS~o~" o^ 6. Displace the IA to packer fluid and freeze protection. S~ y ~ v. ~~~~ 7. Test tubing and IA to 4000 psi. ~ ~, ~ `p 8. Set BPV. ND BOPE. NU and test tree. RDMO. 9. Set a second Fasdril plug ~ 7200' and and perforate the Kuparuk interval (E-line). 10. Fracture stimulate the Kuparuk interval and produce the Kuparuk. 11. Drill out the Fasdril (plugs) when commingling production is approved. SEE = 4" CIW WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 65.09' BF. ELEV = 37.49' KOP = 4400' Max Angle = 23 @ 5366' Datum MD = 9073' Datum TV D = 8800' SS 13-3/8" CSG, 68#, NT-80, ID = 12.415" I--I 2683' Minimum ID = 3.80" @ 8613' 4-1/2" OTIS XN NIP, MILLED OUT OF 7" LNR ~-{ $570' ~ 14-1/2" TBG, 12.6#, L-80 TDS, .0152 bpf, ID = 3.958" I~ $624' 9-5/8" CSG, 47#, L-80, ID = 8.681" I~ 8816' PERFORATION SUMMARY REF LOG: SWS BHCS ON 05!24/90 ANGLEAT TOP PERF: 4 @ 8951' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 4 8951 - 8961 O 08(26/90 3-318" 4 8965 - 9053 O 08126!90 3-318" 4 9085 - 9130 S 09110!94 3-3/8" 4 9184 - 9186 S 09/10/94 I PBTD I 7" LNR, 26#, L-80 U4S, .0383 bpf, ID = 6.276" I~ 9433' SA NOTES: NOTIFY GC OF ANY WELL S _~ ~ OPERATION WHICH COULD INCREASE FLOW OR EROSION RATES TO 3" SKID FLOWLINE (POTENTIAL EROSION). I ®' 2104' -~ 4-1 /2" OTIS SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3119 3052 1 OTIS DOME RA 16 03/09/03 4 5078 4981 23 OTIS DOME RA 16 03/09/03 3 7071 6828 18 OTIS DOME RA 16 03(09/03 2 8121 7851 7 OTIS DMY RA 0 03/09/03 1 8504 8232 6 OTIS SO RA 22 03/09/03 $~ 524' ~-~4-1/2" PARKER SWS NIP, ID = 3.813" $539' OTIS RATCH-LATCH ANCHOR 8540' 9-5/8" OTIS PKR, ID = 3.85" $593' -{4-1/2" PARKER SWS NIP, ID = 3.813" 8613' 4-1 /2" OTIS XN NIP, ID = 3.725" MILLED TO 3.80" 8624' 4-1/2" W/LEG 862 ELMD TT LOGGED 06/15/90 9030' I-(ZIP W/ RUNNING TOOLS 9139' BAKER ECP, SCOOP GUIDES, RUNNING TOOL, AND OLD IBP 9181' MARKER JOINT DATE REV BY COMMENTS DATE REV BY COMMENTS 06/04!90 ORIGINAL COMPLETION 04!28!03 ATDlTLH WAVER SAFETY NOTE 09!07101 RN/TP CORRECTbNS 09/24/05 EZL/TLH WAVER SFTY NOTE DELETED 10!06/02 JM/KAK GLV GO 10/13/02 JAUKK WANERSAFETY NOTE 02!22/03 JMP/KAK WANERSAFEfI' NOTE REV 03!09/03 JJ/TP GO GLV S PRUDHOE BAY UNIT WELL: S-26 PERMff No: 1900580 API No: 50-029-22047-00 SEC 35, T12N, R12E, 1635' FNL & 1160' FWL BP Exploration (Alaska) TREE = 4" CNV LHEAD = FMC ACTUATOR = OTIS KB. ELEV = 65.09' BF. ELEV = 37.49' KOP = 4400' Max Angie = 23 ~ 5366' Datum MD = 9073' Datum TVD = 8800' SS SA NOTES: NOTIFY GC OF ANY WELL OPERATION WHICH COIS.D INCREASE Fl.OW OR EROS~N RATES TO 3" SiOD FLOWLINE (POTENTIAL EftOSlOlb. -2200' ~-~{4-1 /2" HES X-Nipple, ID = 3.813" GAS LET MANDRELS S-26 Proposed 13-318" CSG, 68#, NT-80, ID =12.415" {-j 2683' 412" TBG, 12.6#, 13Cr80 Vam Top ID = 3.958" H -8820' Kuparuk Ad-perfs 'x6860-6900' MD 412" TBG, 12.6#, 13Cr80 Vam Top ID = 3.958" N -8510' TOP OF 7" LNR 8570' 4-12" TBG, 12.6#, L-80 TDS, .0152 bpf, ID = 3.958" 8824' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3600 RA 3 5300 RA 8200 RA 1 6750 RA 6780' 4-12' HES Symphony gauge 6790' 4-1 /2" X NIP, ID = 3.813" 8800 4-12" Baker Premiere packer 4-12" X Nip, ID = 3.813" -7000 HBaker S3 Cr packer ^'7020' 4-12" X NP, ID = 3.813" -8510' UNIQUE OVERSHOT 8540' 9-518" OTIS PKR, ID = 3.85" 8593' 4-12" PARKER SWS NIP, ID = 3.813" 8613' 412" 071S XN NIP, ID = 3.725" MILLED TO 3.80" 8627' ELMD TT LOGGED 08115/90 8624' 4-12" W1LEG 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 8816' PERFORATION SUMMARY REF LOG: SWS BHCS ON 0524!90 ANGLEAT TOP PERF: 4 ~ 8951' Note: Refer to Roduction DB for histor~al pert data SIZE SPF INTB~VAL Opn/Sgz DATE 3-3/8" 4 8951 - 8961 O 0826J90 3-318" 4 8965 -9053 O 0826J90 3-318" 4 9085 - 9130 S 09/10!94 3-3/8" 4 9184 - 9186 S 09V10l94 9030' I-~ 21P W/ RUNNING TOOLS 9139' ~ BA KER ECP, SCOOP GU~ES, RUNNING TOOL, AND OLD 18P 9181' MARKER JOINT 7" LNR, 26#, L-80 U4S, .0383 bpf, ID = 6.276" I~ 9433' DATE REV BY COMMBVTS DATE REV BY COMMEMS 06104180 OtiGINAL COMPLETION 0428103 ATD/TLH , WANBt SAFETY NOTE 09107/01 RNfTP CORRECTIONS 0924!05 EZLlfLH WANER SFTY NOTE DELET® 10/06/02 JMIKAK GLV CJO 10/13/ JALIKK WANER SAFETY NOTE 0222/03 JMPfKAK WANER SAFETY NOTE REV 03109103 JJlTP GO GLVS PRUDHOE BAY WWT WELL: S-26 PERMIT No: 1900580 API No: 50.029-22047-00 SEC ~, T12N, R12E, 1635' FNL & 1160' FWL BP Exploration (Alas ka~ RE: 5-26 Downhole Commingling application Maunder, Thomas E (DOA From: Maunder, Thomas E {DOA) Sent: Wednesday, November 07, 2007 11:30 AM To: Williamson, Mary J (DOA); Saltmarsh, Arthur C (DOA) Cc: Colombie, Jody J (DOA) Subject: RE: S-26 Downhole Commingling application Page 1 of ~CP~NE~ AUG ~ ~ 2008 Jane, I support their plan. A workover will be necessary to gain access to the 7" casing across the Kuparuk. It may be appropriate to have a bond log run in the 9-5/8" casing as part of that work. 1 have examined the well file and it appears that the 9-5/8" cement may have channeled since the 9-5/8" x 13-3/8" annulus became plugged and it was necessary to cut and pull the upper portion of the 9-5/8" casing. There isn't much information in the file regarding the cementing. isolation may be likely based on work attempted on W-29 which had suspect isolation; however it was not possible to squeeze cement as planned. In the order or AA submitting a 403 to conduct the workover should be specified since pulling/replacing tubing on development wells in Prudhoe Bay Field does not ordinarily require a sundry. Let me know if you need anything else. ~~`-~ US tT'~aes ~~e,tis L~~~ Tom c~c..c~,S t!-vpc,.~J~- ~ ~~~ ~1ti4~ From: Williamson, Mary1(DOA) N~~--~~ Sctu~s~-~~~°~ `~'~5~~~~~~~°~ Sent: Tuesday, November 06, 2007 4:41 PM yS b~~c~-~trc~.~,rc~'~cc~ . To: Saltmarsh, Arthur C (DOA); Maunder, Thomas E (DOA) ~Jt (~ ~ I Cc: Colombie, Jody J (DOA} ~j~- Subject; FW: S-26 Downhole Commingling application `~~ ~~~ Please review the commingle request and let me know if you have need for a hearing. I don't, do you? BP will still need to send in a 403, but I don't have a problem with the commingling. !'!! start working on the order. Roby, David S (DOA) Sent. ursday, October 04, 2007 12:51 PM To: Willis n, Mary J (DOA); Saltmarsh, Arthur C (DOA); Maunder, Thoma (DOA) Subject: FW: 6 Downhole Commirxxlling application A revised version of the~lication. Dave Roby Phone: 907-793-1232 email: dave.roby~a a_I_askagov From: Young, Jim [mailto:Jim.Young@bp. Sent: Thursday, October 04, 2007 11:55 To: Roby, David S (DOA); Colombie, J (DOA) Cc: Lenig, David C; Paskvan, Fra ;Ohms, Danielle H; Robles, Subject: RE: S-26 Downhole mminging application Jody, Please str" « File: Aurora IPA Commingle Request BP_COP-EMfinal.doc » from your with a hed for the official application. replace 4/27/2008 Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Prudhoe Bay Field "tZ,JI ti.. ~ 3 ~ ~ ~ 5 `~ Aurora Oil Pool and Prudhoe Oil Pool ~~~ ~ ~ C ~ °~y ~ Application to allow commingling of production from the Aurora Oil Pool and Prudhoe Oii Pool within Weil 5-26 By letter dated October 3, 2007, BP Exploration {Alaska} Inc. as Unit Operator of the Prudhoe Bay Unit requested the Commission to issue an order in conformance with 20 AAC 25.215{b} allowing commingling of production from the Aurora Oil Pool and Prudhoe Oil Pool within Well 5-25. The bottomhole ration of the well is in Section 35, T12N-R12E, Umiat Meridian. The Commission has tentatively scheduled a public hearing on this application for November 15, 2007 at 9:00 am at the offices of the Alaska Oil and Gas Conservation Commission at 333 West 7`" Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on October 25, 2007. If a request for a hearing is no# timely filed, the Commission may consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221 after November 10, 2007. In addition, a person may submit a written protest or written comments regarding this application and proposal to the Alaska Oii and Gas Conservation Commission at 333 West 7~' Avenue, Suite 100, Anchorage, Alaska 99501. Protests and comments must be received no later than 4:30 pm on November 9, 2007 except that if the Commission decides to hold a public hearing, protests or comments must be received no later than the conclusion of the November 15, 2007 hearing. If you are a person with a disability who may need special accommodations in order to comment or to attend the public hearing, please contact the Commission's Special Assistant Jody Colombia at 793-1221. '~----'' Cathy . Foerster Commissioner RE: 5-26 Downhole Commingling application Maunder, Thomas E (DOA) From: Roby, David S (DOA) Sent: Thursday, October 04, 2007 12:51 PM To: Williamson, Mary J (DOA); Saltmarsh, Arthur C (DOA); Maunder, Thomas E (DOA) Subject: FW: S-26 Downhole Commingling application Attachments: Young, Jim.vcf; Aurora IPA Commingle Request BP COP-EMfinal.pdf A revised version of the application. Dave Roby Phone: 907-793-1232 email:dav_e_,_roby@aiaska.gov ~,/~N~~ AUG ~ ~ 2008 From: Young, Jim [mailto:Jim.Young@bp.com) Sent: Thursday, October 04, 2007 11:55 AM To: Roby, David S (DOA); Colombie, Jody J (DOA) Cc: Lenig, David C; Paskvan, Frank A; Ohms, Danielle H; Robles, Marcelo Subject: RE: S-26 Downhole Commingling application Jody, Page 1 of 2 Please strike « File: Aurora IPA Commingle Reques# BP_COP-EMflnal.doc » from your records 8~ replace with attached for the official application. Dave - A couple minor changes we're made to clarify when monthly GC sampling would start & that we don't anticipate significant crossflow potential unless shut ins exceed 2 months {point at which isolation plug would be used). Thanks Jim Young «Young, Jim.vcfi> «Aurora IPA Commingle Request BP_COP-EMfinat.pdf» From: Young, Jim Sem: Wednesday, October 03, 2007 4:31 PM To: 'dave.robya~alaska.gov' Cc: Lerrig, David C; Paskvan, Frank A; Ohms, Danielle H Subject: S-26 Downhole Commingling application Hello Dave, This took a bit longer to get signets off than I'd hoped, but Frank signed this today. Tommorrow, you`ll get ahard- copy with Scott's signature on it as well, but 1 wanted to get something to you right away so we can get the ball 4/27/2008 RE: 5-26 Downhole Commingling application rolling on the public notice. Page 2 of 2 Thanks Jim « File: Kuparuk Ivishak Allocation Feasibility 07-616.pdf (Compressed) » « File: Aurora fPA Commingle Request BP_COP-EMfinal.doc (Compressed) » 4/27/2008 • • BP Exploration (Alaska), Inc. 900 East Benson Boulevard Post Office Box 196612 Anchorage, Alaska 99519-6612 Telephone (907) 564 581 October 4, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Application for Down-hole Commingling of Production from Aurora and Prudhoe Pools ~~ '~~ ,, r .,~ In its capacity as Operator of the Aurora Oil Pool (AOP) and the Prudhoe Oil Pool (POP), BP Exploration (Alaska} Inc. ("BP") hereby requests approval to commingle production from the AOP and POP in the same wellbore. Because commingling of production from the AOP and POP will not cause waste, but rather should allow for recovery of a greater quantity of oil, and such production can be properly allocated, BP requests that the Commission issue an order authorizing the commingling of production from the AOP and the POP within the same well-bore. Plans are to commence commingling of production from AOP and POP in Well 5-26 by the end of 2007 if approval can be obtained in time. --~ `--~ ~et~ -p ~ ~ '~ The following information is provided to support this application Please call Jim Young 564-5754 or Danielle Ohms 564-5759 if you have any questions. Sincerely, ~~'>~~~~ NC's ~ 20D7 Frank Paskvan/Scott Digert ,_ Subsurface Resource Managers, GPB WEST/ WF ~ ,......__...~. *- Attachment 1: OilTracers Report No. 07-616 (CONFIDENTIAL) CC: Hank Bensmiller (ExxonMobil) Johnny Golden/Mark Menghini (CPAI) Sherry Gould (BP commercial) • Aurora Prudhoe Commingling 10/4/2007 Introduction Commingling of production within the same well-bore from two pools is permitted under 20 AAC 25.215(b) if the Commission, after notice and opportunity for public hearing, "(1) finds that waste will not occur, and that production from separate pools can be properly allocated; and (2) issues an order providing for commingling for wells completed from these pools within the field." Waste Will Not Occur 1. Production Considerations Well 5-26 penetrates the AOP and POP in areas where well rates from both Pools are very low. In low rate wells, frequent production problems (e.g., paraffin and hydrate deposition) are encountered due to low flowing temperatures associated with the North Slope permafrost. Intervention options such as hot-oiling, heat-trace, jet pumps, and continuous methanol injection can reduce down-time to as low as 10%. Although there is currently no AOP production from the 5-26 wellbore, the expected rate and remaining hydrocarbons do not justify drilling a standalone well. By commingling production from the two pools within the same well-bore, the fluid rate and velocity in the tubing can be increased, resulting in higher flowing wellhead temperatures and reduced production problems associated with wax and hydrate formation. Consequently, commingling of production from the AOP and POP within the same well-bore will not cause waste, but rather should allow for recovery of a greater quantity of oil. 2. Hydraulic Impacts on Production Well 5-26 was drilled in 1990 as a standalone producer from the POP, with a fracture stimulation. Production from Well 5-26 averages 800-950 stb/d liquid and 200-250 stb/d of oil, as shown in Table 1. This is considered a low rate for the existing 4-1/2" tubing, causing a large variability in test rates due to slugging. It is estimated that Well 5-26 has the • • Aurora Prudhoe Commingling 10/4/2007 hydraulic capacity for an incremental 500-900 stb/d of production without resulting in a significant change in flowing bottom hole pressure. Table 1 Well tests from 5-26, in standard oilfield units Well Bore Run Date Total Fluid Rate (bbls) Oil Rate (bbls) Water Rate (bbls) Form Gas Rate (mcfd) Gas Lift (mcfd) Gas Lift Press (psi) Form GOR (scf/ stbo) FTP (psi) WH Temp (f) WC Pct (%) 5-26 07/15/07 866 242 624 1,068 2,070 1,241 4,415 237 107 72 5-26 06/25/07 940 212 728 1,005 2,040 1,243 4,748 242 105 7? 5-26 06/07/07 848 216 632 976 2,060 1,229 4,525 231 103 75 5-26 06/01/07 935 227 708 1,155 2,060 1,218 5,096 242 104 76 Using the expected S-pad AOP productivity of 500 stb/d, the relative and combined capacities are depicted in Table 2. An increase in AOP production is expected from commingling due to reduced down-time associated with wax issues mentioned earlier. ~~ o~\y Table 2.5-26 liquid rate impact of commingling: Pool 2 wells Commingled delta (liquid) POP(75% wc) 900 stb/d 860 stb/d -40 stb/d AOP(0% wc) 450 stb/d 500 stb/d +50 stb/d Total 1350 stb/d 1360 stb/d +10 stb/d Fm. Gas Rate 1450 mcfd 1460 mcfd -8 mcfd AL Gas Rate 4000 mcfd 2000 mcfd -2000 mcfd Delta oil from wellbore = +490 stb/d ~v i \L~~ ~~ Due to the low current POP production rate, no additional artificial lift (AL) gas would be required to handle additional liquid from the AOP. In a gas handling constrained environment, the reduced AL gas required for the commingled well (relative to two wells) results in an increase in oil production rate by utilizing the AL gas elsewhere. Since commingling requires a shallower gas-lift injection depth, a rate impact is expected to the POP later in life as water-cut increases. However, because the oil cut is lower at this point, the impact on oil rates to the POP is more than offset by additional production from the AOP by the reduced down-time and gas-handling benefits. This selective application of commingled production will result in an increase of overall recovery from both the Aurora and Prudhoe oil pools. • • Aurora Prudhoe Commingling 10/4/2007 3. Cross flow Because both pools have similar in-situ fluid properties and share the same source of injection water, commingling should not result in formation damage. No fluid incompatibilities have been noted during ongoing surface commingling. Consequently, limits on cross flow are guided by reservoir management considerations. Pressure buildup behavior from both AOP and POP has been analyzed to assess cross flow potential and consequences. When a commingled well is shut- in, cross flow will be dictated by pressure buildup behavior within each pool. At initial shut-in, the pressure at each pool is equal to the wellbore pressure plus hydrostatic head caused by well bore fluid. The hydrostatic head between pools will be approximately 0.3 psi/ft and increases over time with producing water-cut. After a transient period after shut-in, the pressures within each pool will increase to a limit no greater than the average reservoir pressure. Direction of cross flow will be determined by which pool has the greater reservoir pressure at a given datum depth. A comparison of recent pressures in area wells is shown in table 3 to illustrate different cross flow scenarios. Table 3 Comparison of AOP & POP static pressure data near S-pad SW_ DATUM TEST_ PRES_ PRES_ PRESS_ DELTA PROJECT NAME DEPTH_SS DATE DAYS_SI DATUM 8800'SS PSI PRUDHOE S-26 8800' 9/11/05 6 3224 0.3PS1/FT ~-26~ AURORA S-108 6700' 6/14/07 14.92 2241. 2851 -373 AURORA S-108 6700' 3/29/06 300 2964 3574 370 At expected initial conditions of high AOP pressure in this area (>3000psi at 6700'ss datum), the differential pressure could exceed 300 psi. However, as confirmed by pressure-buildup analyses, low permeability in the AOP for this area results in an extremely long transient time before full reservoir is seen in the well bore. Consequently, POP reservoir fluids may slowly cross-flow into the AOP until pressures equalize. Reservoir modeling suggests that this volume is expected to be small. Well S-26 will be equipped with an X nipple between ~~0~ ,~, ---~ the AOP and POP perforations, as shown in figure 1, to allow isolation of the pools by ,~~ setting adown-hole plug for extended shut- ins (>2 months) or when separate zone pressure measurements are desired. • • Aurora Prudhoe Commingling Figure 1. Proposed commingled completion 10/4/2007 ~. TREE= 4" tlW WELLFEAD= FM AGTUnroR= on KB, aEV = 65.09 BF. B_EV = 37.49 KOP= 4400 Max Angle= 23 Q 5366 Datum MD= 9073 Datum ND= 8800'5 13-3/8" (SG, 68# NT-80, D=12.415" S-26 SAFETY NOT 6SS NOTIFY GC OF ANY VIAL OPERATION WNIC H COULD INC REASEFLOW OR EROSION RATE T03" SNDFLOWLINE(POTBJlIAL ER090N). 2704 41/2"OTCs SSSV NP,D=3.813" r -TOGO ( Fm RA D= 3.813" R32FORAl10N SUMIMRV R13= LOG: SWS BiGS ON CS/24/90 ANGLE AT TOP F92F: 4 ~ 8951' NOBe: Refer to Prod~ctim DB for hi5orbal pert data SQ.E SFF INIH2VAL OpNSgz O4TE 3-3/e" 4 8951 - 8961 O 08/2650 3-3/B" 4 8965- 9063 O 08/2650 33/8" 4 9065- 9130 S 09/1054 3-3/6" 4 9184- 9186 S 09/1054 $527' ELfrO Tf LOGGED O6/15/W $52A' 4-1/2" WLEG D4 TE RB/ 6Y COMNHJTS d1TE i~V BY OO M~HJrS 06A4/90 ORGINAL COMPLETION 01/28/03 ATD"TLH WAN62 SAFETY NOTE 09A7/01 RN'iP O~F2FECl1ONS 03/24/05 QL/RH WANBi ATV NOTE LBET® 10A6/02 JWKAK GLV 00 10/13/02 JAL/KK VLL4N ER Sq FT_IY NOTE 0222/03 JI1rP/KAK VWNB2 S4 FEfY NOTE FEV 03A9/03 J.VTP OO GLVS FdJNJNG TOOLS FRtDHJE BAY WR NO_L: 5-26 F9ZMTNO:'1900580 Afl No: 50-029-22047-m ~ F plot anon (Alaska( Appropriate Surveillance and Production Allocation Will Be Assured Appropriate surveillance and production allocatio n measures will be undertaken to meet reservoir management objectives and to provide an acceptable allocation methodology. 1. Production Allocation In addition to stand-alone tests prior to commingling, when commingling commences, monthly (30-producing days) geo chemical (GC) samples will be obtained and compared with production logs both initially and after 6-months of production. Fluid samples have • Aurora Prudhoe Commingling 10/4/2007 been obtained from both pools to verify that GC analysis will allow for metering of pool oil, water and gas to within allocation quality accuracy. See attached report from Oil Tracers for more detailed information on this. After one year of commingled production, GC analysis will be completed semi-annually and production logs will be repeated as necessary to assess production anomalies based on well test results. 2. Reservoir Surveillance Long-term development plans for AOP and POP pools include water-flood and Enhanced Oil Recovery using Miscible Injectant (MI) from the Prudhoe Bay Miscible Gas Project. Reservoir pressure and hydraulic communication to offset injection support will be determined by comparing initial pressure and production from each pool with subsequent well tests. If pressure maintenance is a concern, static pressures from each pool can be measured with the use of down-hole plugs and pressure gauges. If it is determined that a completion in one pool is adversely affecting production from the other pool, that completion can be isolated as necessary to ensure waste does not occur. To ensure the efficient allocation of MI, rate and pressure response to injection will be monitored in the production wells. Production fluid samples will be taken as needed to assess pattern efficiency based on the returned MI (RMI) ratio. Allocation of RMI from commingled production samples will be linked to gas production determined from production logging and GC analysis. Conclusion BP requests approval for well-bore commingling of production from AOP and POP, in Well 5-26. This activity will not create waste and produced liquids and gas from the separate pools can be properly allocated. During the first year of production geochemical analyses of oil samples will be performed monthly to verify agreement with stand-alone tests and production logging results. Thereafter, it is proposed that geochemical analysis be performed semi-annually to properly manage and allocate long-term production. Page 1 of 2 Maunder, Thomas E (DOA) From: Roby, David S (DOA) Sent: Wednesday, September 05, 2007 7:33 AM To: Maunder, Thomas E (DOA); Saltmarsh, ArthurC (DOA) ~,,J~~~ ~~G ~ ~ ~(j~$ Subject: RE: Meeting with BP re: S-26 commingling request I got an email from Jim Young this morning requesting to push back the meeting a week. So it will now be 9/12 at 10 AM in our offices. Dave Roby Phone: 907-793-1232 email: dave.roby@alaska.gov From: Maunder, Thomas E (DOA) Sent: Tuesday, September 04, 2007 12:51 PM To: Roby, David S (DOA); Saltmarsh, Arthur C (DOA) Subject: RE: Meeting with BP re: S-26 commingling request This could be very interesting. S-26 would indicate an Ivishak completion. Polaris is Schrader Bluff. Different crudes is not likely the major issue. Significantly different gas contents and pressure regimes could be. We might want to do a little homework on this one. Tom From: Roby, David S (DOA) Sent: Tuesday, September 04, 2007 12:48 PM To: Maunder, Thomas E (DOA); Saltmarsh, Arthur C (DOA) Subject: RE: Meeting with BP re: S-26 commingling request I can't remember off the top of my head but I'm pretty sure one of them wilt be POP, which is currently producing about 225 BOPD. I do recall him saying that the crudes aren't as different as there were in the case of the NK-43 commingling but he believes they are sufFciently different so the GeoChem will provide acceptable results. Dave Roby Phone: 907-793-1232 email: dave.roby@alaska.gov From: Maunder, Thomas E (DOA) Sent: Tuesday, September 04, 2007 12:42 PM To: Roby, David S (DOA); Saltmarsh, Arthur C (DOA} Subject: RE: Meeting with BP re: S-26 commingling request What reservoirs are they proposing to commingle? From: Roby, David S (DOA) Sent: Tuesday, September 04, 2007 12:41 PM To: Maunder, Thomas E (DOA); Saltmarsh, Arthur C (DOA) Subject: Meeting with BP re: S-26 commingling request Art and Tom: Jim Young, and probably others, from BP is going to be coming over tomorrow morning at 10 AM to discuss a pending application for downhole commingling in the PBU S-26 well. They witl propose to allocate production 4/27/2008 Page 2 of 2 based on geochemical analyses as was done for the NK-43 well. Yau guys are welcome to attend if you wish. Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission Phone: 907-793-1232 Fax: 907-276-7542 email: dave.roby@a_I_aska.gov 4!27/2008 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 E PL E W M A T E R IA L U N D E T'H IS MARKER R STATE OF ALASKA /'~--";KA OIL AND GAS CONSERVATION COMMI' REPOR'I-OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate × Plugging Pull tubing Alter casing Repair well_ Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1635'SNL, 1160'WEL, SEC. 35, T12N, R 12E At top of productive interval 2473'SNL,3172'WEL, SEC. 35, T12N, R 12E At effective depth 2508'SNL, 3159'WEL, SEC. 35, T12N, R 12E At total depth 2511 'SNL, 3158'WEL, SEC. 35, T12N, R 12E 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE=65.09 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-26(22-35-12-12) 9. Permit number/approval number 90-58 / 10. APl number 50- 029-22047 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length .. 9434'feet 9225'feet 9393'feet 9184'feet Size Plugs (measured) Junk (measured) Cemented Measured depth 138 2683 8810 110' 2655' 8782' .. 864' 20 i, '3 3/8" 9 5/8" 3295 cu ft Arcticset fll&fl 1870 cu ft Class G 7" 264 cuft Class G measured 8951 '-8961 ',8965'-9053', 8570-9434 Sqzd{9085L9130~9184c9186~ True vertical depth BKB 138 2646 8566 8392-9253 true vertical subsea8678'-8688',8692'-8780', Sqzd{8812'-8857',8911 '-8913'} Tubing (size, grade, and measured depth) 4-1/2" 12.6#L-80 @8624' Packers and SSSV (type and measured depth) Packer Set @8540' SSSV @2104' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 198 793 2634 2650 Tubing Pressure 243 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 7. I hereby qertify that the foreg~ng is true and correct to the best of my knowledge. Signed(~,,~,,,,~(; "~d_~.,-~''~ Title Senior TechnicalAssistant II Form 10-40t4 Rev 06/15788 Date SUBMIT IN DOPLr'CATE WELL S-26(22-35-12-12) NRWO(Maraseal) Operation 09/10/94 A NRWO (Maraseal GSO) was performed using the following fluids below: SUMMARY Run in hole with Baker 3 3/8" retrivable packer. Thru tubing tail. Park packer and kool down well with 70°F sea water. Locate tubing tail, XN, and X nipples. Make a (-) 17 ft correction. TEL arm now on depth with CBL dated 6/15/90. Drop down hole and position ball dropper. Pump ball and set packer. Sit down 3k lbs. Inject through packer @ 1.26 bpm, 1860 psi. Pump down coil annulus @ 3 bpm, 270 psi. Call out BJ and MI. RU BJ and pump 1000 gal 15% HCL @ 1.26 bpm. Saw sudden 300 psi pressure drop after 10 bbl acid away. Performed backside injection test again: 3 bpm @ 370 psi, no change from pre-acid test. Cooled formation down w/lake water @ 2 bpm.- pump 276bbl maraseal down coil @ 1.4 bpm avg. rate w/3400 psi increasing to 3750 psi while holding app. 400 psi On back side.starting W/3 bpm.decreasing slowly to 1.25 bpm as the maraseal was pumped & displaced, after all maraseal pumped & desplaced tbg pressure went to 0 psi w/180 psi on back side .bleed backside to 50 psi release packer with out problem - pooh w/coil lay down tools (left packer rubber in hole but recovered all bands ) freeze protect tbg. & flow line. BBLS. 1288 106 25 44 FLUIDS PUMPED Sea Water 2% KCL, cold water 15% HCL Methanol ,/Ui~ 2 7 '!l-}'-'~i'-i A!aska 0ii & (:-~as Corts~ C:~m.~nission LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 17 November 1994 Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION - - 1 PLS FINAL BL 1 PLS FINAL RF 1 PLS FINAL BL 1 PLS FINAL RF 1 PLS FINAL BL 1 PL$ FINAL RF 1 PLS/STP FINAL BL 1 PLS/STP FINAL RF 1 PLS FINAL BL 1 PLS FINAL RF 1 PLS FINAL BL 1 PLS FINAL RF 1 PLS FINAL BL 1 PLS FINAL RF Run ~ t Run ~ 1 Run # 1 Run ~ 1 Run ~ 1 Run ~ 1 Run # 1 Run ~ 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 2012.03 4123.04 4440.03 4887.06 4892.02 5613.02 5865.02 5600 B Street Suite 201 /-~ Attn. Rodney D. Paulson ~/ or ~ to~907> 563-7803 Received by: ~~ Da~e' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM' David Joh~ DATE: Chairma?...~-~ Blair Wondzell, ~ FILE NO: P. I. Supervisor'~_~:~ ~ Lou Grimaldi~ SUBJECT: Petroleum In§pector October 27, 1994 919JJZBD.DOC No flows BPX wells S pad Prudhoe Bay Field Wednesday, October 26, 1994: I verified the No flow status of 5 wells on BPX S pad in the Prudhoe Bay Field with the following results; Well Name S-13 S-16 ,S-20 S-26 S-28 Pe .rmit # 82-135 84-84 86-147 90-58 .Oil produced NONE NONE NONE NONE NONE Gas produced 135 SCF NONE 240 SCF 120 SCF NONE These wells were observed in this state for 4 hours each, the wells SSSV's were removed for these tests. I recommend No flow status be granted these wells. SUMMARY: I verified the No flow status of 5 wells on BPX S pad in the Prudhoe Bay Field. Attachments: None ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 27 April 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL S-26 (22-35-12-12) DESCRIPTION 1 PLS STATIC FINAL BL /a P,.S ST~?l~ ~ SEPIA 1 PLS STATIC FINAL BL // PLS STATIC RF SEPIA 2-14/0-16 i PLS STATIC FINAL BL ~ PLS ST~I~ R) SEPIA i PFC/PERF FINAL BL Jl PFC/PERF RF SEPIA ECC No. Run $ 1 5865.01 Run # i Run f 1 2012.02 Run # 1 Run f 1 5941.03 Run f I Run f 1 5708.05 Run $ I Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: Please sign and return to: Sonya Wallace (MB 3-3) 9 ]994 Petrotechnical Data Center BP Exploration (alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: ""---' · STATE OF ALASKA ~' AL_ .C~ OIL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging. Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1635'SNL, 1160'WEL, SEC. 35, T12N, R 12E At top of productive interval 2473'SNL, 3172'WEL, SEC. 35, T12N, R 12E At effective depth 2508'SNL, 3159'WEL, SEC. 35, T12N, R 12E At total depth 2511 'SNL, 3158'WEL, SEC. 35, T12N, R12E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5. Type of Well: Development X Exploratory Stratigraphic Service 9434' feet Plugs (measured) 9225' feet 9393' feet Junk (measured) 9184' feet 6. Datum elevation (DF or KB) KBE=65.09 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-26(22-35-12-12) 9. Permit number/approval number 90-58 / 10. APl number 50- 029-22047 11. Field/Pool Prudhoe Oil Pool Casing Length Size Cemented Measured depth Structural -- Conductor 110' 20" 138 Surface 2655' '3 3/8" 3295 cu ft Arcticset /I/&// 2683 Intermediate 8782' 9 5/8" 1870 cuft C/ass G 8810 Production -- Liner 864' 7" 264 cuft C/ass G 8570-9434 Perforation depth: measured 8951'-8961',8965'-9053',9085'-9130',9184'-9186' True vertical depth BKB 138 2646 8566 8392-9253 true vertical subsea8678'-8688',8692'-8780',8812'-8857',8911 '-8913' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 @8624' Packers and SSSV (type and measured depth) Packer Set @8540' SSSV @2104' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 300 942 258 1990 380 2209 1629 2570 Tubing Pressure 238 282 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby c~rtify that the foregoi~, is true and correct to the best of my knowledge. Signed /~vt ~,v~ ~,-~,~&~ Title Senior TechnicalAssistant I Form 10-404 Rev 06/15/88 /7- 1/21/92 1/25/92 WELL S-26(22-35-12-12) Stimulation/FRAC Performed a FRAC (IVISHAK) Treatment using the following fluids: FRAC: 20 BBLS 50# Gel Prepad to Establish Rate 91 BBLS 50# X-Link Gel Pad w/8% ESL 240 BBLS 50# X-Link Gel w 58,000# 16/20 RCP 68 BBLS 20# Gel Flush 150 BBLS Diesel to pt lines and freeze protect. Performed a Stimulation Wash using the following fluids below: FLUID~ PUMPED; 11 BBLS Slurry with total of 1510 lbs 20/40 carbolite in two pills 12 BBLS Gel Spacers 218 BBLS SeaWater 151 BBLS Diesel 26 BBLS ACATTACK fjh 6/26/93 · . BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 03/02/93 T# 84345 BP/PBU CH MAGNETIC TAPE W/LISTING Enclosed is your copy of the materials listed below. questions, please contact BP Well Records at (907) S-26 CH/PDK-100 FIN 01/17/93 #1 8778.00- 9352.00 1600BPI API#500292204700 9258->TP# 552.. If you have any 564-4004. ATLAS REF#5865 Information Control Well Records REC IV .D MAP, 1 0 199~ Alaska 011 & Gas Cons. Commission Anchorage BP EXPLORATION RECEIVED P EB 0 I 199 :~il & Gas Cons, Commission Anchorage BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 01/25/93 T# 84288 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A~~-176 J,~¥~ PRODUCTION LOG /~-30 ~% 0 PRODUCTION LOG / ~-05 ~'~ PRODUCTION LOG '>' PDK-IO0 01/16/93 #1 01/17/93 #1 01/16/93 #1 01/17/93 #1 9700.00-10300.00 ATLAS 5 " 10600.00-10946.00 ATLAS 5 " 11550.00-11930.00 ATLAS 5 " 8800.00- 9352.00 ATLAS 5 " Information Control Well Records '~'-' STATE OF ALASKA -- ,~--, --~"~/ /-. .,XA OIL AND GAS CONSERVATION COMMI.. )N (,'./. r¢-'~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing_ Stimulate X Plugging Perforate .... Alter casing Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1635'SNL, 1160'WEL, SEC.35, T12N, R 12E At top of productive interval 2473'SNL, 3172'WEL, SEC.35, T12N, R12E At effective depth 2508'SNL,3159 'WEL, SE0.35, T12N, R 12E At total depth 2511 'SNL, 3158'WEL, SEC. 35, T12N, R12E 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE=65.09 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-26(22-35-12-12) 9. Permit number/approval number 90-58/ 10. APl number 50- 029-22047 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical 9434'feet 9225'feet Plugs (measured) Effective depth: measured true vertical 9393'feet 9184feet Junk (measured) Casing Length Size Structural -- Conductor 110' 20" S u rf ace 2655' 13 3/8" Intermediate 8782' 9 5/8" Production -- Liner 864' Perforation depth: measured Cemented 3295 cuft Arcticset ill& !1 1870 cu ft Class G 7" 264 cu ft Class G 8951 '-8961 ', 8965'-9053 ', 9085 '-9130 ', 9184 '-9186' Measured de~h 2683 8810 8570-9434 True vertical depth BKB 138 2646 8566 8392-9253 true vertical subsea8678'-8688',8692'-8780',8812'-8857',8911'-8913' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 @8624' Packers and SSSV (type and measured depth) Packer Set @8540' SSSV@2104' Alaska 0ii & Gas Cons. 13. Stimulation or cement squeeze summary 5/o3/91A HCL Tubing Wash Treatment r, ........ 5/04/91 Set Inflatable Bridge Plug Intervals treated (measured) 50 bbls 12%HCL/10% Xylene W/ACI, AG-12, 102 bbls Diesel Treatment description including volumes used and final pressure 180 bbls PW,25 bbls Methanol,3 bbls Slurry 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 480 2033 3300 1529 320 850 J'~' 1915 690 565 278 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations O)1 X Gas Suspended 1 17. I hereby certify that the forego~ is true and correct to the best of my knowledge. Si,ned %____p(/,.ct.~,~}Z/-~-, k. / F', ~/V~, Title Senior TechnicalAssistant/ Form 10-404 Rev 06/15/88 ?- ' Service Date SUBMIT IN DUPLICATE BP EXPLORATION BP Exomrat~on (Alasxa) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage. Alas~<a 99519-6612 (907) 561-5111 DATE: 11/05/91 T~ 82969 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. W-24 ~,~,'% b S-26 COMPLETION 10/30/91 PRODUCTION LOG 10/31/91 8800.00- 9393.00 SCH 8850.00- 9052.00 SCH Information Control Well Records Adrian J. Martin ;'-,I:.: i',3,'833 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date'12/03/90 T#:81858 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. S-26 Prod-F 11/29/90 #1 8850-9384 Sch 5" S-28 Per/ 11/23/90 #1 9300-10029 Sch 5" W-04 CNL 11/28/90 #1 11500-12109 Sch 5" Yol 1 Comp 11/25/90 #1 7250-9762 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: ARCO CHEVRON EXXON MOBIL PHILLIPS TEXACO ~ ~¢~'%A~TE OF ALASK_/~ GEOSCIENCE ARCHIVES BP OPEN HOLE FINAl., Date :05/31/90 T#:81194 RECEIVED OCT 2 2 7990 ~aska 0/1 & Gas Cons, Commission ~chora~.o Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. -~S-26 ,8-26 ,.S-26 DIL/5t¢'~- 05/24/90 #1 8811-9428 Sch 2"/5" SS TVD 05/24/90 #1 8811-9398 Sch 2" ~, .... -~t~Z¢~9 0 #1. 10 nS_O.d_l .!41 $ ~ BHCS 05/24/90 #1 8811-9398 Sch 2"/5" CNL 05/24/90 #1 6600-9382 Sch 2"/5" STATE ONLY: Magnetic Single Shot Directional Survey Gyroscopic Directional Date: Jo~: Date: Job#: Inforation Control Well Records LR 2-1 J.. Dietz/S. McCurry STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMIvllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Slatus of'Well"' Classification of Service Well 2. NameofOperator 7. Permit Number - BP Exploration 90-58 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22047 4. Location of well at surface rd ...... 9. Unit or Lease Name "'~1635' SNL, 1160'~,'c~, SEC. 35, T12N, R 12E ~ .,~ ~ ----~--__ Prudhoe Bay Unit At Top Producing Interval i ~_//~,~_.,,~ i' i LO~AT!©~-----~ 10. Well Number At Total Depth ~t4t., .................... j._: ~~ Prudhoe Bay Field/Prudhoe Bay Pool ~-~2511' SNL, 3158' WCH_, SEC. 35, T12N, R12E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 65.09' I ADL 28257 05-12-90 05-24-90 08-26-90I JN/A feet MSL ONE 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDI 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 9434'MD/9225'TVD 9393'MD/9184'TVD YES [] NO [3I 2104'feet MD I 1946' 22. Type Electric or Other Logs Run DIL/GR/BHC/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. C-,-,-,-,-,-,-,-,~ADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Surface 11 O' 13-3/8" 68# L-80 Surface 2683' 17-1/2" 3295 cu ft Arcticset III & II 9-5/8" 47# NT80S Surface 8810' 12-1/4" 1870 cu ft Class G 7" 26# L-80 8570' 9434' 8-1/2" 264 cuft Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and _~5. TUBING RECORD interval, size and number) SIZE DEPTH SET {MDI PACKER SET {MD) At/as Wire/ine 3-3/8"@ 4 spf 4-1/2" 12.6# L-80 8624' 8540' MI) TVDss 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8951'-8961' 8678'-8688' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8965'-9053' 8692'-8780' 9-5/8" X 13-3/8" Freeze Protect annulus w/125 bbls 9085'-9130' 8812'-8857' 9184'-9186' 8911'-8913' Diesel 27. PROOUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) August 26, 1990 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL C, HOKESIZE IGAS-OIL RATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. OCT 2 2 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE , Jbmit in duplicate 29, 30, GEOLOGIC MARKEF. ~ ORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag 8819' 8612' Shubl/k A 8859' 8652' Zone 4 8949' 8741' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title PBU Lead Eno/neet Date //d"/.,~/¢¢ ~ - ! INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP EXPLORATION DAILY DRILLING REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Tuesday, May 15, 1990 WELL: S-26 (22-35-12-12) RIG: NABORS#18-E Day: 3 Depth at 0600 Hrs. = 2700' 24 Hour Footage = 110' APl No. 50-029-22047 AFE Number: 125217 AFE Amount = Current Field Costs = Current Operation: NU BOPE. Summary of Last 24 Hours: Drilled to 2700'. Ran 13-3/8" casing. Mud Type ..Mud Weight Spud Mud 10 Cf/gal Viscosity P V. YP .Fluid Lo,ss ~olids Temp 150 Sec. 21 36 15.0 cc 12.5% 48 °F Survey Depth Angle Direction N-S E-W Dog Leg ,,TVD Section Coordinate Coordinate °/100' Reviewed By: ,'~./4, BP EXPLORATION DAILY DRILLING REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Wednesday, May 16, 1990 WELL: S-26 (22-35-12-12) RIG: NABORS#18-E Day' 4 Depth at 0600 Hrs. = 4000' 24 Hour Footage = 1300' APl No. 50-029-22047 AFE Number: 125217 AFE Amount = Current Field Costs = Current Operation' POH for changing BHA. Summary of Last 24 Hours' Drilled and surveyed to 4000'. Mud Type Mud Weight Viscosity Low Solids 9.2 #/gal 33 Sec. P V YP Fluid Loss ,.Solids Temp 3 2 18.6 cc 6% 66 °F Survey Depth Angle Dire(;;tion NfS E-W ,Dog Leg TVD Section Coordinate Coordinate °/100' Reviewed By: ~,#, BP EXPLORATION DAILY DRILLING REPORT: PRUDHOE As of 0600 Hm. Thursday, May 17, 1990 WELL: S-26 (22-35-12-12) BAY UNIT RIG: NABORS#18-E Day' 5 Depth at 0600 Hrs. = 4914' 24 Hour Footage = 914' APl No. 50-029-22047 AFE Number: 125217 AFE Amount = Current Field Costs = Current Operation' POH for changing BHA. Summary of Last 24 Hours' Drilled and surveyed 12-1/4" hole to 4914'. Mud Tv.De Mud Weight Viscosity P V YP Low Solids 9.3 #/gal 36 Sec. 7 9 .Fluid Loss Solids Tem.~ 10.2 cc 7% 72 °F Survey Depth Angle .Direction TVD N-S E-W. Dog Leg Section Coordinate ,Coordinate. °/100' Reviewed By: -p, H, BP EXPLORATION DAILY DRILLING REPORT: As of 0600 Hrs. Friday, May 18, 1990 WELL: S-26 (22-35-12-12) PRUDHOE BAY UNIT RIG: NABORS#18-E Day: 6 Depth at 0600 Hrs. = 6380' 24 Hour Footage = 1466' APl No. 50-029-22047 AFE Number: 125217 AFE Amount = Current Field Costs = Current Operation: POH looking for washout. Summary of Last 24 Hours: Drilled and surveyed to 6380'. Mud Type Mud Weight Viscosity Low Solids 9.6 #/gal 38 Sec. .,P V .,Y.P Fluid Loss Solids Temp 7 11 8.8 cc 8% 74 °F Survey Depth Angle Direction N-S ,.,E-W Dog Leg TVD Section Coordinate Coordinate °/100' Reviewed By' :~.~ BP EXPLORATION DAILY DRILLING REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Monday, May 21, 1990 WELL: S-26 (22-35-12-12) RIG: NABORS#18-E Day: 9 Depth at 0600 Hrs. = 8365' 72 Hour Footage = 1985' APl No. 50-029-22047 AFE Number: 125217 AFE Amount = Current Field Costs - Current Operation: Drilling 12-1/4" hole. Summary of Last 72 Hours: Drilled and surveyed to 8365'. Mud Type Lightly Dispersed Mud Weight Viscosity 9.9 #/gal 38 Sec. PV YP Fluid Loss Solids Temp 10 1 1 6.2 cc 11% 76 °F Survey Depth Angle Direction N-$ E-W Dog Leg TVD Section Coordinate Coordinate °/100' Reviewed By' ~.H. BP EXPLORATION DAILY DRILLING REPORT: PRUDHOE As of 0600 Hrs. Tuesday, May 22, 1990 WELL: S-26 (22-35-12-12) BAY UNIT RIG: NABORS#18-E Day: 10 Depth at 0600 Hrs. = 8821' 24 Hour Footage = 456' APl No. 50-029-22047 AFE Number: 125217 AFE Amount = Current Field Costs = Current Operation' POH and L/D BHA. Summary of Last 24 Houm: Drilled and surveyed to 8821'. Mud Type Mud Weight Viscosity Lightly Dispersed 10.0 #/gal 39 Sec. P V YP Fluid Los~ Solids Temp 12 12 6.0 cc 11% 99 °F Survey Depth Angle Direction N-S E-W, Dog Leg TVD Section Coordinate Coordinate °/100' Reviewed By' 9.~, BP EXPLORATION DAILY'DRILLING REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Wednesday, May 23, 1990 WELL: S-26 (22-35-12-12) RIG: NABORS#18-E Day: 11 Depth at 0600 Hrs. = 8821' 24 Hour Footage = 0 AP! No. 50-029-22047 AFE Number: 1o.5217 AFE Amount = Current Field Costs = Current Operation' RIH with Bit #11. Summary of Last 24 Hours: Ran 9-5/8" casing. Mud Tv.De Mud Weight Low Solids 8.8 #/gal Viscosity - 33 Sec. PV .YP,. Fluid Loss Solids 4 6 9.0 cc 4% Temp 92 OF Survey Depth Angle Direction TVD N-S E-W Section Coordinate Coordinate Dog Leg o/100' Reviewed By: '~. H. BP EXPLORATION DAILY DRILLING REPORT: PRUDHOE As of 0600 Hrs. Thursday, May 24, 1990 WELL: S-26 (22-35-12-12) BAY UNIT RIG: NABORS#18-E Day: 12 Depth at 0600 Hrs. = 9350' 24 HOur Footage = 529' APl No. 50-029-22047 AFE Number: 125217 AFE Amount = Current Field Costs = Current Operation' Drilling 8-1/2" hole. Summary of Last 24 Hours: Drilled and surveyed to 9350'. Mud Type ,Mud Weight Viscosity Low Solids 9 #/gal 37 Sec. PV ,YP Fluid LOSS Solids 5 8 9.0 cc 5% Temp 81 OF Survey Depth Angle Direction TVD N-S E-W Section Coordinate Coordinate Dog Leg o/100' Reviewed By :"~--' BP EXPLORATION DAILY DRILLING REPORT: As of 0600 Hrs. Friday, May 25, 1990 WELL: S-26 (22-35-12-12) PRUDHOE BAY UNIT RIG: NABORS#18-E Day: 13 Depth at 0600 Hrs. = 9434' 24 Hour Footage = 84' APl No. 50-029-22047 AFE Number: 125217 AFE Amount = Current Field Costs = Current Operation' Run 7" liner. Summary of Last 24 Hours: Drilled to 9434'. Logged. Ran 7" liner. Mud Type Mud Weight Viscosity Low Solids 9.0 #/gal 35 Sec. PV YP. Fluid LOSS Solids Temp 5 8 8.0 cc 5% 84 °F Survey Depth Angle Direction TVD N-S_ E:W Dca Lea -- -- Section Coordinate Coordinate "/100' Reviewed By: BP EXPLORATION DAILY DRILLING REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Tuesday, May 29, 1990 WELL: S-26 (22-35-12-12) RIG: NABORS#18-E Day: 17 Depth at 0600 Hrs. = 9434' 96 Hour Footage = 0 AP! No. 50-029-22047 AFE Number: 125217 AFE Amount = Current Field Costs = Current Operation' Lay down 9-5/8" casing. Summary of Last 96 Hours: Ran and cemented 7" liner. Cut 9-5/8" casing at 2061' for repairing the 9-5/8" x 13-3/8" annulus plug-off problem. The plug-off problem was caused by the cement channeling into the annulus during the 9-5/8" casing cement job. The well can not be freeze protected due to this problem. MudType Mud Weight Viscosity P V .Y,P, Fluid Loss Solids Temp Low Solids 9.0 #/gal 35 Sec. 6 8 8.0 cc 5% 81 °F Survey Depth An__n_qJ~ Direction TVD. N-S E-W Doa Lea Section C~ordinate Coordinate °/100' Reviewed By: -~. q BP EXPLORATION DAILY DRILLING REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Wednesday, May 30, 1990 WELL: S-26 (22-35-12-12) RIG: NABORS#18-E Day: 18 Depth at 0600 Hrs. = 9393' 24 Hour Footage = 0 APl No. 50-029-22047 AFE Number: 125217 AFE Amount = Current Field Costs = Current Operation: POH for back-off tool. Summary of Last 24 Hours: Ran back-off tool for disconnecting the casing and failed. Ran spear and found 1' fish. RIH with back-off tool and attempted to back-off casing. MudType Mud Weight Viscosity P V YP Fluid Loss Solids Temo NaCI 8.6 #/gal 26 Sec. cc °F Survey Deoth Anale Direction TVD N-S E-W Dog Leg Section Coordinate Coordinate °/100! Reviewed By: (~ BP EXPLORATION DAILY DRILLING REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Thursday, May 31, 1990 WELL: S-26 (22-35-12-12) RIG: NABORS#18-E Day: 1 9 Depth at 0600 Hrs. = 9393' 24 Hour Footage = 0' APl No. 50-029-22047 AFE Number: 125217 AFE Amount = Current Field Costs = Current Operation' RIH with 9-5/8" casing. Summary of Last 24 Hours' Attempted to back-off casing stub at 2061', but back-off tool hanger got hung up when top anchor entered. Ran 8-1/2" bit and tapered the casing stub. Tried back-off tool again and failed. POH. MudTyp~ Mud Weight Viscosity ,P V yP Fluid Loss Solids Temp NaCI 8.6 Cf~gal 26 Sec. cc °F N,S E-W Doa Lea -- -- Survey Depth Angle Direction TVD Section Coordinate Coordinate °/100' Reviewed By: ~.~k. BP EXPLORATION DAILY DRILLING REPORT: As of 0600 Hrs. Friday, June 1, 1990 WELL: S-26 (22-35-12-12) PRUDHOE BAY UNIT RIG: NABORS#18-E Day: 20 Depth at 0600 Hrs. = 9393' 24 Hour Footage = 0' APl No. 50-029-22047 AFE Number: 125217 AFE Amount = Current Field Costs = Current Operation: Circulate to clean up the hole. Summary of Last 24 Hours: Ran stdng mill and polished 9-5/8" stub to 2151'. Ran casing cutter and cut 9-5/8" casing at 2115'. Ran spear and recovered fish. RIH..with 11-3/4" wash over pipe and washed over 9-5/8" casing to 2173'. MudType Mud Weight Viscosity P V YP Fluid Loss Solids Terns) NaCI 8.5 #/gal 26 Sec. cc °F Survey Deoth Anale ~ TVD N-S E-W Dog Leg Section Coordinate Coordinate °/100, Reviewed By: ~?¢ BP EXPLORATION DAILY DRILLING REPORT: PRUDHOE As of 0600 Hrs. Monday, June 4, 1990 WELL: S-26 (22-35-12-12) BAY UNIT RIG: NABORS#18-E Day: 23 Depth at 0600 Hrs. = 9393' 72 Hour Footage = 0' AP! No. 50-029-22047 AFE Number: 125217 AFE Amount = Current Field Costs - Current Operation' Lay down drill pipe. Summary of Last 72 Hours: Back-off 9-5/8" casing at 2159' and freeze protected the annulus with 125 bbls of diesel. Cleaned up inside of 9-5/8" casing and 7" liner. Displaced mud with brine. Mud Type NaCI Mud Weight Viscosity P V Yp Fluid Loss Solids Temp 8.5 #/gal 26 Sec. cc °F Survey Deoth Angle Directiorl TV0 N-$ E-W Dog Leg Section Coordinate Coordinate °/100' Reviewed By: '~, H, BP EXPLORATION DAILY DRILLING REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Tuesday, June 5, 1990 (- - ~ WELL: S-26 (22-35-12-12) / ~,.' RIG: NABORS#18-E Day: 24 Depth at 0600 Hrs. = 9393' 24 Hour Footage = 0' AP! No. 50-029-22047 AFE Number: 125217 AFE Amount = Current Field Cost = Estimated Final Cost = Current Operation' U-tube with diesel. Summary of Last 24 Hours: Ran 4-1/2" tubing. Mud Type Mud Weight Viscosity #/gal Sec. P V, YP Fluid Loss Solids Temp cc OF Survey Depth Anale Direction TVE), N-$ E-W Dog Leg Section Coordinate Coordinate °/100' Reviewed By' BP EXPLORATION DAILY DRILLING REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Wednesday, June 6, 1990 WELL: S-26 (22-35-12-12) RIG: NABORS#18-E Day: 24 Depth at 0600 Hrs. = 9393' PBTD 24 Hour Footage = 0' AP! No. 50-029-22047 AFE Number: 125217 AFE Amount = Current Field Cost -- Estimated Final Cost = Current Operation' Cleaning pits and cellar. Summary of Last 24 Hours: Released rig at 0800 hrs on 6/5/90. MudType Mud Weight' Viscosity P V #/gal Sec. ,, Survey Deoth Angle DirectiOn TVD ,Y,P Fluid Loss Solids Temp cc °F N-S E-W Dog Leg Section Coordinate Coordinate °/100' Reviewed By: _,%./4, SUB. SURFACE DIRECTIONAL SURVEY ~]UIDANCE [~]ONTINUOUS [-flOOL Company BP EXPLORATION .... Well Name- S-26 (22-35-12-12)(1635' SNL,1160' WEL,SEC 35,T12N,R12E) Field/Location PRUDHOE BAY~ NORTH SLOPE~ ALASKA Job Reference No. 73922 Lo(:JC~ecl Ely: SCHWARTZ Date ,, SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR BP EXPLORATION S-26 (2.2-35-12-12) PRUDHOE BAY NORTH SLOPEr ALASKA SURVEY DATE= IS-JUN-90 ENGINEER= SCHgARTZ METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZo DIST.: PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 47 DEG 49 MIN EAST COMPUTATION DATE: 26~JUN-90 PAGE I BP EXPLORATION S-Z6 ¢22-35-12-12) PRUDHOE BAY NORTH SLOPEr ALASKA DATE OF SURVEY: 15-JUN-90 KELLY BUSHING ELEVATION: 65.09 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIHUTH DEPTH DEPTH DEPTH DEG MIN DEG 0.00 0.00 -65.09 0 0 N 0 0 E 10'0.00 100.00 34.91 0 6 N 45 16 W 200.00 200.00 134.91 0 10 S 59 38 E 300.00 300.00 234.91 0 12 N 21 59 W 400.00 400.00 334091 0 12 S 83 29 E 500.00 500.00 434.91 0 10 S 9 38 14 600.00 600.00 534.91 0 I N 59 I 14 700000 700.00 634.91 0 14 S 36 9 E 800.00 800.00 734.91 0 9 N ZO I 14 900.00 900.00 834.91 0 11 S 75 12 ~ 1000.00 1000.00 934.91 1100.00 1100.00 1034.91 1200.00 1199.99 1134.90 1300.00 1299.99 1234.90 1400.00 1399.99 1334.90 1500.00 1499.99 1434.90 1600-00 1599.99 1534.90 1700.00 1699.99 1634.90 1800.00 1799.98 1734.89 1900000 1899.98 1834089 0 13 N 25 18 Id 0 20 N 51 29 M 0 13 $ 21 39 bi 0 16 S 78 46 0 25 S 27 43 Id 0 17 S 3 16 # 0 29 S 20 27 kl 0 17 S 7 59 E 0 18 S 38 14 Id 0 10 S 7 42 E 2000.00 1999.98 1934.89 2100.00 2099.98 2034.89 2200.00 2199.95 2134.86 2300.00 2299.90 2234.81 2400.00 2399.86 2334.77 2500.00 2499.83 2434.74 2600.00 2599.81 2534.72 2700.00 2699.78 2634.69 2800.00 2799.74 2734.65 2900.00 2899.72 2834.63 0 6 N 78 18 E 0 39 S 75 40 E I 44 N 67 52 'E I 39 N 65 44 E I 30 N 63 38 E I 22 N 58 14 E I 22 N 60 65 I 26 N 64 55 E I 24 N 63 0 E 0 55 N 44 20 E 3000.00 2999.71 2934.62 3100.00 3099.71 3034.62 3200.00 3199.71 3134.62 3300.00 3299.70 3234.61 3400000 3399.70 3334.61 3500.00 3499.70 3434.61 3600.00 3599.70 3534.61 3700.00 3699.69 3634.60 3800.00 3799.69 3734.60 3900.00 3899.68 3834.59 ENGINEER: SCH14ARTZ 033 N 6 13 E 031 N 4 45 E 0 30 N 11 32 14 0 28 N 0 35 14 0 22 N 31 17 U 0 18 N 57 28 Id 018 N 7123 14 0 24 S 86 42 g 0 48 S 30 39 kl I 4 S 25 47 ~ VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/IdEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E -0.08 0.09 0.08 N 0.03 kl 0.01 0.32 0.05 S 0.03 N 0.05 0.57 0.12 N 0.18 E 0.03 0.72 0.08 N 0.12 E 0.00 0.62 0.15 N 0.14 E O.ZO 0.05 0.04 N 0.30 E 0.36 0.20 0.24 S 0.27 5 0.51 0.36 0.28 S 0.43 E 0.15 0.26 0.06 S 0.14 E 0.00 N 0 0 E 0.09 N 21 32 g 0.05 S 30 8 kl 0.21 N 55 5 E 0.15 N 55 19 E '~ o.2o N 4Z SS E 0.31 N 83 141, E 0.36 S 4P8 59 E 0.51 S 57 I E 0.15 S 65 36 E -0.06 0.16 0.02 N 0.07 ~ -0.58 0.32 0.44 N 0.39 14 -0.73 0.63 0.32 N 0.69 g -0.88 0.42 0.26 N 0.96 Id -0.97 0.19 0.09 S 1.39 W -0.65 0.52 0.70 S 1.51 ~ -0.44 0.03 1.35 S 1.82 14 -0.01 0.36 2.03 S 1.86 Id 0.22 0.94 2.43 S 1.91 14 0.46 0.10 2.90 S 2.01 W O. 07 N 75 0 Id 0.59 N 41 29 kl 0.76 N 65 34 g 0.99 N 75 4 14 1.39 S 86 21 14 1.67 S 65 I kl 2.26 S 53 21 14 2.76 S 42 27 W 3.09 S 38 12 ~ 3.53 S 34 43 14 0.63 0.00 3.03 S 1.90 14 0.70 3.56 3.05 S 1.82 ~ 1.77 0.22 2.08 S 0.51 E 3.05 0.67 0.86 S 3.33 E 4.06 0.00 0.31 N 5.76 E 4.89 0.00 1.52 N 7.97 E 5.55 0.25 2.76 N 9.99 E 6.45 0.00 3.85 N 12.20 E 7.43 0.49 4.93 N 14.50 E 7.87 0.24 6.08 N 16.13 E 3.58 S 32 0 Id 3.55 S 30 51 Id 2.14 S 13 40 E 3.44 S 75 32 E 5.77 N 86 56 E 8.12 N 79 11 E 10.37 N 74 34 E 12.80 N 72 29 E 15.32 N 71 13 E 17.24 N 69 20 E 7.72 0.53 7.08 N 16.84 E 7.22 0.00 7.97 N 16.98 E 6.63 0.09 8.84 N 16.97 E 6.02 0.89 9.63 N 16.85 E 5.38 0.00 10.33 N 16.6Z E 4.84 0.39 10.72 N 16.25 E 4.20 0.00 11.09 N 15.72 E 3.72 0.41 11.15 N 15.14 E 3.60 0.53 10.58 N 14.45 E 4.06 0.00 9.11 N 13.74 E 18.26 N 67 11E 18.76 N 64 50 E 19.13 N 62 29 E 19.40 N 60 16 E 19.57 N 58 9 E 19.47 N 56 35 E 19.24 N 54 48 E 18.80 N 53 37 E 17.91 N 53 47 E 16.49 N 56 27 E COMPUTATION DATE: 26-JUN-90 PAGE 2 BP EXPLORATION S-26 C22'35-12-12) PRUDHOE BAY NORTH SLOPE~ ALASKA DATE OF SURVEY: 15-JUN-90 KELLY BUSHING ELEVATION= 65.09 FT ENGINEER: SCHgARTZ INTERPOLATEO VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH OEPTH OEPTH OEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG 4000.00 3999.66 3934.57 1 27 4100.00 4099.58 4034.49 2 57 4200.00 4199.33 4134.24 4 51 4300.00 4298.75 4233.66 7 25 4400.00 4397.61 4332.52 9 45 4500.00 4495.79 4430.70 12 1 4600.00 4593.06 4527097 14 46 4700.00 4689.19 4624.10 17 7 4800.00 4784.14 4719.05 19 25 4900.00 4877.75 4812.66 21 41 5000.00 4970.39 4905.30 22 28 5100.00 5062.74 4997.65 22 36 5200.00 5154.98 5089.89 22 46 5300.00 5247.2! 5182.12 22 41 5400.00 5339.53 5274.44 22 34 5500.00 5431.90 5366.8! 22 28 5600.00 5524.31 5459.22 22 29 5700.00 5616.72 5551.63 22 27 5800.00 5709.11 5644.02 22 34 5900.00 5801.42 5736.33 22 38 6000.00 5893.71 5828.62 22 37 6100.00 5986.09 5921.00 22 31 6200.00 6078.49 6013.40 22 22 6300.00 6171.04 6105.95 22 9 6400.00 6263.72 6198.63 21 57 6500.00 6356.70 6291.61 21 13 6600.00 6450.08 6384.99 20 43 6700.00 6543.75 6478.66 20 14 6800.00 6637.79 6572.70 19 33 6900.00 6732.20 6667.11 18 59 7000.00 6826.95 6761.86 18 20 7100.00 6921.95 6856.86 17 56 7200.00 7017.28 6952.19 17 16 7300.00 7112.94 7047.85 16 31 7400.00 7209.10 7144.01 15 20 7500.00 7305.84 7240.75 14 0 7600000 7403.13 7338.04 12 29 7700000 7501.15 7436.06 10 34 7800.00 7599.66 7534.57 9 10 7900.00 7698.55 7633.46 8 4 S 5 53 E S 37 45 E S 45 35 E S 50 41 E S 51 26 E S 51 12 E S 51 19 E S 51 34 E S 51 30 E S 5131E 4.96 2.69 7.17 8.67 2.17 3.74 15.52 3.34 1.35 26.27 2.83 8.33 41.22 2.65 17.70 60.13 2.16 29.54 83.27 2.55 44.04 110.73 2.25 61.19 t41.99 2.30 177.06 1.51 S 51 34 E S 51 27 E S 51 33 E S 51 50 E S 52 0 E S 52 0 E S 51 58 E S 52 21 E S 52 43 E S 52 59 E 214.64 0.58 252.92 0.14 291.46 0.15 330.03 0.27 368.36 0.06 406.57 0.01 444.68 0.12 482.79 0.12 520.93 0.16 559.23 0.12 S 53 14 E S 53 36 E S 53 46 E S 53 50 E S 53 54. E 3 4¢ E S 54 59 E S 55 28 E S 55 9 E 597.56 0.28 635.69 0.26 673.72 0.28 711.39 0.38 748.74 0.44 785.34 0.59 820.91 0.45 855.70 0.86 889.41 0.60 922.11 0.51 S 54 44 E 953.84 S 53 58 E 984.84 S 50 59 E 1014..94 S 45 39 E 1044..04 S 40 46 E 1071.38 S 36 31 E 1096.37 S 32 10 E 1118.83 S 27 44 E 1137.64 S 24 1Z E 1153.64 S 19 4.4. .E 116&.98 0.50 0.97 1.57 1.89 1.72 1.60 2.81 1.30 1.84 0.69 13.19 E 15.02 N 61 28 E 15.10 E 15.55 N 76 4 E 19.73 E 19.77 S 86 5 E 27.91 E 29.12 S 73 23 E 39.60 E 4.3.37 S 65 55 E 54.39 E 61.89 S 61 30 E ,) 72.46 E 84.80 S 58 4.3 E 93.98 5 112.14 S 56 56 E 80.67 S 118.52 E 143.37 S 55 46 E 102.56 S 14.6.01 E 178.43 S 54. 55 E 125.97 S 175.50 E 216.03 S 54. 20 E 149.87 S 205.52 E 254.36 S 53 54 E 173.92 S 235.73 E 292.95 S 53 35 E 197.89 S 266.06 E 331.58 S 53 22 E 221.57 S 296.33 E 370.01 S 53 13 E 24.5.18 S 326.50 E 408.31 S 53 6 E 268.73 S 356.59 E 4.46.51 S 53 0 E 292.16 S 386.78 E 484.73 S 52 56 E 315.43 S 417.17 E 523.00 S 52 54 E 338.66 S 447.81 E 561.44 S 52 54 E 361.78 S 478.59 E 599.94 S 52 55 E 384.61 S 509.36 E 638.25 S 52 57 E 407.24 S 540.16 E 676.48 S 5Z 59 E 429.63 S 570.71 E 714.35 S 53 Z E 451.80 S 601.03 E 751.90 S_53 4 E 473.52 S 630.73 E 788.70 S 53 6 E 494.67 S 659.58 E 824.46 S 53 8 E 515.07 S 688.03 E 859.47 S 53 11 E 534.39 S 716.02 E 893.45 S 53 16 E 553.19 S 743.11 E 926.41 S 53 20 E 571.52 S 769.33 E 958.38 S 53 24 E 589.74 S 794.65 E 989.58 S 53 Z5 E 608.01 S 818.72 E 1019.80 S 53 24. E 627.32 S 840.49 E 1048.78 S 53 16 E 64.7.35 S 859.24 E 1075.80 S 53 0 E 667.11 S 875.06 E 1100.34. S 52 41 E 686.14 S 888.13 E 1122.30 S 52 19 E 703.29 S 897.95 E 114.0.59 S 51 56 E 718.72 S 905.57 E 1156.12 S 51 34 E 732.49 S 911.09 E 1169.03 S 51 12 E COMPUTATION DATE: 26-JUN-90 PAGE 3 BP EXPLORATION S-26 (22-35-12-12) PRUDHOE BAY NORTH SLOPEr ALASKA DATE OF SURVEY: 15-JUN-90 KELLY BUSHING ELEVATION: 65009 FT ENGTNEER: SCHIdARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/MEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN 8000°00 7797°66 7732°5T 7 4 8100000 7896097 7831°88 6 36 8200.00 7996031 7931.22, 6 30 8300000 8095067 8030.58 6 27 8400.00 8195.10 8130001' 5 56 8500.00 8294.57 8229.48, 5 55 8600000 8394003 8328.94 5 51 8700000 8493052 8428043 5 43 8800.00 8593.04 8527095 5 27 8900°00 8692066 8627.57 4 49 S 19 33 E 1178.65 S 20 7.1 E 1189.02 S 19 17 E 1199.16 S 17 13 E 1208.94 S 18 58 E 1218.13 S 19 55 E 1227.27 S 21 Z E 1236.46 S 19 52 E 17.45.47 S 20 22 E 1254.09 S 17 11 E 1261076 0.98 0.38 0.46 0.59 0.30 0.72 0.52 0.60 0.94, 0.34 745.03 S 915.4~ E 1180.33 S 50 52 E 756.04 S 919.49 E 1190.40 S 50 34 E 766.77 S 913.45 E 1200.29 S 50 18 E 777°55 S 926.88 E 1209.83 S 50 0 E 787072 S 930.20 E 1218093 S 49 44 E 797.42 S 933.6! E 1227.81 S 49 30 E 807.07 S 937.26 E 1236086 S 49 16 E 816.57 S 940.81 E 1245.76 S 49 3 E 825.71 S 944o16 E 1254o29 S 48 50 E 833.99 S 947.00 E 1261o89 S 48 38 E 9000.00 8792.30 8727.21 9100.00 8891.9¢ 8826085 9200.00 8991.58 8926.49 9300°00 9091.23 9026.14 9400.00 9190.88 9125.79 9434000 9224.77 9159.68 4 51 4 50 4 52 4 48 4 44 S 17 16 E 1269.07 S 19 10 E 1276.40 S 21 3 E 1283..90 S 22 22 E 1291.45 S 21 32 E 1298.94 S 11 32 E 1301.46 0.56 0.19 0.42 0.49 0.00 0000 8¢2.13 S 949.50 E 1169.14 S 48 26 E 850.15 S 952.12 E 1276.44 S 48 14 E 858°12 S 955.02 E 1283.91 S 48 4 E 865,,89 S 958.17 E 1291.45 S 47 54 E 873.58 S 961.31 E 1298,.94 S 47 44 E 876.19 S 962.34 E 1301.;46 S 47 41 E CONPUTATION DATE: 26-JUN-90 PAGE BP EXPLORATION S-Z6 (2Z-35-1Z-1Z) PRUDHOE BAY~ NORTH SLOPEr ALASKA DATE OF SURVEY: 15-JUN-90 KELLY BUSHING ELEVATION: 65°09 FT ENGINEER: SCHWARTZ INTERPDLATEO VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTI:CAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG WIN DEG WIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ· DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG WIN 0o00 0.00 -65.09 0 0 lO00.O0 1000.00 934o91 0 13 2000.00 1999.98 1934.89 0 6 3000°00 2999.71 293~.6~ 0 33 4000°00 3999.66 3934°57 I 27 5000.00 ~970.39 4905.30 22 28 6000.00 5893.71 5828.62 22 37 7000.00 6826.95 6761.86 18 20 8000.00 7797.66 7732.57 7 4 9000o00~ 8792.30 8727oZ1 4 51 N 0 0 E O. O0 O. O0 N 25 18 W -0.06 0.16 N 78 18 E 0.63 0.00 N 6 13 E 7.72 0.53 S S 53 E 4.96 2.69 51 34 E 214.64 0.58 53 14 E 597.56 O.Z8 S 54 44.E 953.84 0.50 S 19 33 E 1178.65 0.98 S 17 16 E 1269.07 0.56 0.00 N 0.00 ~ 0.00 N 0 0 E 0.02 N 0.07 W 0.07 N 75 0 N 3·03 S 1.90 W 3.58 S 32 0 W 7.08 N 16·84 E 18.26 N 67 11 E · 7·17 N 13.19 E 15.02 N 61 28 E ~ 125 97 S 175 50 E 216 03 S 54 20 E 361.78 S 478.59 E 599.94 S 52 55 E 571.52 S 769.33 E 958.38 S 53 24 E 745·03 S 915.48 E 1180·33 S 50 52 E 842.13 S 949.50 E 1269.14 S 48 26 E 9434.00 9224.77 9159.68 4 44 S 21 32 E 1301.46 0.00 876·19 S 962.34 E 1301.46 S 47 41 E COMPUTATION DATE: 26-JUN-90 PAGE S BP EXPLORATION DATE OF SURVEY: 15-JUN-90 S-26 (22-35-12-12) KELLY BUSHING ELEVATION: 65 09 FT PRUDHOE BAY ' NORTH SLOPEr ALASKA ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL OOGLEG RECTANGULAR COORDINATES HORIZo OEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MZN DEG MIN. FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -65'09 0 0 N 0 0 E. 0.00 0.00 0.00 N 0.00 E 65.09 65.09 0.00 0 6 N 10 34 W -0.02 0.00 0.02 N 0.00 W 165.09 165.09 100.00 0 9 S 18 25 E -0.08 0.29 0.02 N 0.09 W 265009 265.09 200.00 0 13 N 32 48 E 0.12 0.54 0.00 N 0.16 E 365009 365.09 300.00 0 8 S I 18 W -0.05 0.62 0.14 N 0.06 E 465.09 465.09 400.00 0 7 N 74 32 N 0.01 0.72 0.20 N 0.19 E 565.09 565.09 500.00 0 9 N 81 53 E 0.19 0.57 0.02 N 0.27 E 665.09 665.09 600.00 0 15 S 8 42 ~ 0.24 0.53 0.10 S 0.24 E 765.09 765.09 700.00 0 5 N 60 21 E 0.54 0.59 0.33 S 0.42 E 865.09 865.09 800.00 0 16 N 53 26 W 0.26 0.59 0.09 $ 0.27 E 965.09 965.09 900.00 0 8 1065.09 1065.09 1000.00 0 20 1165.10 1165.09 1100.00 0 13 1265.10 1265.09 1200.00 0 12 1365.10:1365.09 1300.00 0 19 1465.10 1465.09 1400.00 0 19 1565.10 1565.09 1500.00 0 27 1665.10 1665.09 1600.00 0 21 1765.11 1765.09 1700.00 0 12 1865.11 1865.09 1800.00 0 16 0 6 0 7 1 41 I 47 1 31 1 26 1 21 1 26 1 30 1 3 N 49 23 W 0.04 0.50 0.07 S 0.02 W N 40 30 W -0.38 0.04 0.30 N 0.25 W S 36 26 W -0.76 0.31 0.44 N 0.63 W N 89 30 W -0.79 0.00 0.27 N 0.82 W S 49 22 W -0.99 0.16 0.09 N 1.26 W S 2 7 E -0.77 0.62 0.53 S 1.52 W S 28 23 W -0.53 0.16 1.09 S 1.70 W S 9 56 E -0.17 0.23 1.84 S 1.90 W $ 7 23 W 0.18 0.27 2.31 S 1.85 W S 0 21 E 0.36 0.15 2.77 S 2.02 W 1965.11 1965.09 1900.00 2065.11 2065.09 2000.00 2165.13 2165.09 2100.00 2265.17 2265.09 2200.00 2365.21 2365.09 2300.00 2465.25 2465.09 2400.00 2565.27 2565.09 2500.00 2665.30 2665.09 2600.00 2765.34 2765.09 2700.00 2865.36 2865.09 2800.00 0 41 0 33 0 31 0 26 0 24 0 18 0 26 0 21 0 35 0 58 S 58 59 E 0.58 0.26 3.03 S 1.96 W S 56 46 W 0.60 0.63 2.99 S 1.91 W N 67 50 E 1.32 ~0.00 2.47 S 0.46 W N 66 15 E 2.62 0.00 1.29 S 2.37 E N 63 41 E 3.72 0.00 0.10 S 4.94 E N 59 50 E 4.65 0.51 1.09 N 7.26 E N 58 19 E 5.31 0.00 2.34 N 9.29 E N 64 14 E 6.13 0.00 3.48 N 11.42 E N 65 11 E 7.11 0.55 4.55 N 13.71 E N 49 41 E 7.82 0.38 5.68 N 15.70 E 2965.37 2965.09 2900.00 3065.38 3065.09 3000.00 3165.38 3165.09 3100.00 3265.39 3265.09 3200.00 3365.39 3365.09 3300.00 3465.39 3465.09 3400.00 3565.39 3565.09 3500.00 3665.39 3665.09 3600.00 3765.40 3765.09 3700.00 3865.41 3865.09 3800.00 N 31 15 E 7.88 1.68 6.73 N 16.73 E N 10 5 E 7o41 0.59 7.66 N 16.94 E N 3 33 W 6.87 0.54 8.53 N 17.01 E N 9 22 W 6.21 0.00 9.36 N 16.87 E N 24 8 W 5.59 0.18 10.12 N 16.73 E N 47 7 W 5.03 0.27 10.61 N 16.41 E N 54 9 W 4.41 0.51 10.99 N 15.91 E N 86 2 W 3.90 0.23 11.15 N 15.37 E S 42 54 W 3.55 0-69 10.92 N 14.69 E S 26 16.W 3.89 0.66 9.67 N 14.02 E 0.00 N 0 0 E 0.02 N 6 14 W 0.09 N 75 56 W 0.16 N 89 27 E 0.15 N 23 28 E '~ 0.27 N 43 58 E 0.27 N 84 55 E 0.25 S 67 44 E 0.54 S 52 I E 0.28 S 70 37 E 0.07 S 12 13 N 0.39 N 39 43 W 0.77 N 55 12 W O. 86 N 72 6 W 1.26 N 85 59 W 1.61 S 70 4i W 2.02 S 57 18 W 2.64 S 45 52 W 2.96 S 38 45 W 3.42 S 36 6 W 3.60 S 32 54 W 3.55 S 32 30 W 2.51 S 10 29 W 2.70 S 61 27 E 4.94 S 88 52 E ~ 7.3,r. N 81 28 E / 9.58 N 75 53 E 11.94 N 73 3 E 14.45 N 71 40 E 16.69 N 70 7 E 18.03 N 68 5 E 18.59 N 65 41 E 19.03 N 63 22 E 19.29 N 60 59 E 19.55 N 58 49 E 19.54 N 57 6 E 19.34 N 55 22 E 18.99 N 54 3 E 18.30 N 53 22 E 17.03 N 55 24 E COMPUTATION DATE: Z6-JUN-90 PAGE 6 BP EXPLORATION S-26 ¢22-35-12-12) PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY:' 15-JUN-90 KELLY BUSHING ELEVATION: 65.09 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG NIN DEG HIN 3965043 3965.09 3900.00 I 11 4065.48 4065.09 4000000 2 30 4165065 4165.09 4100.00 4 14 4266.09 4265.09 4200.00 6 33 4367.04 4365.09 4300.00 8 58 4468.65 4465.09 4400.00 11 23 4571.12 4565.09 4500.00 14 0 4674.81 4665.09 4600°00 16 32 4779.81 4765.09 4700.00 18 57 4886.38 4865.09 4800.00 21 27 4994026 4965.09 4900°00 22 26 5102.54 5065.09 5000°00 22 36 5210.96 5165.09 5100.00 22 46 5319.38 5265.09 5200.00 22 38 5427.68 5365.09 5300.00 22 33 5535.91 5465.09 5400.00 22 27 5644o13 5565.09 5500.00 22 29 5752.34 5665.09 5600.00 22 30 5860.64 5765°09 5700.00 22 37 5968099 5865.09 5800.00 22 40 6077.28 5965.09 5900.00 22 29 6185.51 6065.09 6000.00 22 24 6293057 6165.09 6100.00 22 10 6401.48 6265.09 6200.00 21 56 6509.00 6365.09 6300.00 21 9 6616.04 6465.09 6400.00 20 39 6722.73 6565.09 6500.00 20 4 6828.95 6665.09 6600.00 19 22 6934°76 6765.09 6700.00 18 46 7040.17 6865.09 6800.00 18 14 7145.29 6965.09 6900.00 17 37 7250.03 7065.09 7000°00 16 57 7354°30 7165.09 7100.00 15 54 7457.95 7265.09 7200.00 14 34 7560.97 7365.09 7300.00 13 16 7663.28 7465.09 7400.00 11 5 7764.96 7565.09 7500.00 9 44 7866.Z0 7665.09 7600.00 8 19 7967.16 7765.09 7700.00 7 28 8067.91 7865.09 7800.00 6 38 S 16 35 14 S 33 27 E S 42 44 E S 50 27 E S 51 28 E S 51 19 E S 5.116 E S 5131E S 51 33 E S 51 30 E ENGINEER: SCHNARTZ VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/MEST DIST. AZINUTH FEET DEG/tO0 FEET FEET FEET DEG ~IN 4.50 0.59 7.94 N 7.08 1.28 5.06 N 12.83 1.22 0.59 N 22.17 1.51 5.72 S 35.88 2.15 14.36 S 53.81 1.90 25.57 S 76.07 2.78 39.53 5 103.41 2.36 56.63 S 135.34 2.33 172.07 1.90 S 51 34 E 212.46 0.59 S 51 27 E 253.90 0.15 S 51 35 E 295.70 0.17 S 51 54 E 337.48 0.33 S 51 56 E 378.95 0.01 S 51 58 E 420.25 0.06 S 52 10 E 461.51 0.20 S 52 36 E 502.73 0.27 S 52 53 E 544.15 0.14 S 53 8 E 585.68 0.16 S 53 32 E 627.04 S 53 46 E 668.22 S 53 49 E 708.98 S 53 54 E 749.28 S 53 43 E 788.58 S 54 1 E 826.55 S 55 19 E 863.47 S 55 18 E 898.97 S 55 10 E 933.26 S 54 19 E 966.35 S 53 8 E 998.58 S 48 30 E 1029.64 S 42 48 E 1059.15 S 38 19 E 1086.17 S 34 1 E 1110.41 S 28 58 E 1131.14 S 25 52 E 1148.34 S 20 54 E 1162.71 S 19 8 E 1174.98 S ZO 7 ,E 1185.75 13.27 E 15.46 N 59 7 E 14.15 E 15.02 N 70 19 E 17.85 E 17.86 N 88 7 E 24.74 E 25.39 S 76 59 E 35.41 E 38.21 S 67 55 E ' 49.45 E 55.67 S 62 39 E ~) 66.8~ E 77.66 S 59 24 E 88.24. E 104.85 S 57 18 E 76.52 S 113.30 E 136.72 S 55 58 E 99.44 S 142.10 E 173.44 S 55 I E 124.62 S 173.79 E 213.85 S 54 21 E 150.48 S 206.28 E 255.3.3 S 53 53 E 176.56 S 239.06 E 297.19 S 53 33 E 202.50 S 271.9~ E 339.05 S 53 20 E 228.12 S 304.69 E 380.62 S 53 1.1. E 253.63 S 337.31 E 422.02 S 53 4 E 279.10 S 369.90 E 463.38 S 52 58 E 304.35 S 402.65 E 504.73 S 52 55 E 329.53 S 435.73 E 546.30 S 52 54 E 354.62 S 469.03 E 588.01 S 52 54 E 0.22 0.27 0.32 0.45 0.45 0.41 0.83 0.74 0.78 0.39 379.44 S 502.36 E 629.56 S 52 56 E 403.98 S 535.71 E 670.95 S 52 59 E 428.20 S 568.76 E 711.92 S 53 2 E 452.12 S 601.47 E 752.45 S 53 4 E 475.45 S 633.37 E 791.96 S 53 6 E 498.01 S 664.16 E 830.14 S 53 8 E 519.56 S 694.46 E 867.31 S 53 12 E 539.87 S 723.96 E 903.09 S 53 17 E 559.62 S 752.3& E 937.65 S 53 21 E 578.83 S 779.58 E 970.98 S 53 24 E 1.12 1.69 1.79 1.74 1.78 1.83 1.69 1.11 1.25 0.29 597.95 S 805.76 E 1003.39 S 53 25 E 617.53 S 829.93 E 1034.47 S 53 21 E 638.18 S 851.04 E 1063.74 S 53 8 E 658.87 S 868.75 E 1090.34 S 52 49 E 678.84 S 883.36 E 1114.07 S 52 28 E 697.23 S 894.68 E 1134.27 S 52 4 E 713.51 S 903.13 E 1150.98 S 51 41 E 727.98 S 909.42 E 1164.90 S 51 19 E 741.08 S 914.10 E 1176.77 S 50 58 E 752.58 S 918.21 E 1187.22 S 50 4~0 E COMPUTATION DATE: 26-JUN-90 PAGE 7 BP EXPLORATION S-26 (12-35-12-11) PRUDHOE BAY NORTH SLOPE9 ALASKA DATE OF SURVEY: 15-JUN-90 KELLY 9USHING ELEVATION: 65.09 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH OEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY'NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 8168057 7965.09 7900.00 8269022 8065.09 8000.00 8369083 8165.09 8100.00 8470037 8265.09 8200.00 8570.91 8365.09 8300.00 8671.43 8465.09 8400.00 8771.92 8565.09 8500.00 8872.33 8665.09 8600000 8972069 8765.09 8700.00 9073°05 8865.09 8800.00 6 31 6 31 6 3 5 52 5 51 5 50 5 36 4 50 4 55 4 53 S 20 18 E 1196.02 S 17 13 E 1205.95 S 18 29 E 1215.¢8 S 19 41 E 1224.59 S 21 16 E 1233.81 S 20 17 E 1242.92 S ZO 18 E 1251.69 S 17 37 E 1259.75 S 16 53 E 1267.07 S 18 28 E 1274.41 0.40 0.10 0.42 0.80 0.96 0.11 0.76 0.22 0.39 ?63.43 S 922.24 E 1197.23 S 50 23 E 774.22 S 925.86 E 1206.91 S 50 6 E 784.74 S 929.19 E 1216.23 S 49 49 E 794.56 S 932.58 E 1225.17 S 49 34 E 804.31 S 936.19 E 1234.25 S 49 20 E 813.86 S 939.82 E 1243.24 S 49 6 E ) 823.17 S 943.22 E 1251.91 S 48 53 E 831.77 S 946.31 E 1259.90 S 48 41 E 839.90 S 948.81 E 1267.15 S 48 29 E 848.00 S 951.38 E 1274.45 S 48 17 E 9173.41 8965.09 8900.00 9273.77 9065.09 9000.00 9374.12 916S.09 9100.00 9434.00 9224.77 9159.68 4 54 4 44 S 20 34 E 1281.88 S 22 15 E 1289.47 S 21 32 E 1297.02 S 21 32 E 1301.46 0.21 0.24 0.00 0.00 856.00 S 954.21 E 1281.90 S 48 6 E 863.85 S 957.34 E 1289.47 S 47 56 E 871.59 S 960.52 E 1297.02 S 47 47 E 876.19 S 962.34 E 1301.46 S 47 41 5 SCHLUMBERGER ID I REC T I ON~L SURVE Y COMPANY B.P. EXPLORATION WELL S-26 (22-35-12-12) FIELD PRUDHOE BAY COUNTRY USA RUN ONE DATE LOOOED 1S - JUN - 90 REFERENCE 73922 WELL' S-26 122-35-12-12/ (1635' SNL, ll60' WEL, SEt .~5, T12N, R12E) HORIZONTAL PROJECTION NORTH 400 ~00 -200 -400 -6OO -8OO - 1000 SOUTH - 1200 REF 73922 SCALE = 1/2OO IN/FT · --¢--.f*-.~---f---{-..~---N--h--+ ...... ~...f....~.~..+..¢..+..~.~..~..*+...+~.+...~..+...i...F~+.~+~..k..~.~.~.~+.+..j..+~~...f...~ ...... +.---i..'f-+h--h-~--¢-.-i ...... !--'-~-'r?-'t-'z"r't'~"t'~tt'z't'tr::!;~il i;'~' .--N¢.-.~...¢ ....... ;...;..4...~ ....... ~.-.;.--~---¢---;--.~.-.N-~---~ ....... }..-;*--NN'.--N~-..~*.~ ..... ~_.~...~ ...... ~.4...;...; ....... ~...~...~...;...I...;...~...~.4 ...... ;-4.-.~-.-~.-.I..-;.-.;...~.4 ...... ;--.~...+...+..-+...~...~..+-.~ ....... ~...~..+..~...I...~...~...~....~ ....... ~-.-~..-~-..?-+..+-+..~ ...... ?+*.+..~.-.!.-~ ...~.L~ LLL.i ....... L.L~..h'...L.Lh.i ....... L~.-.¢...L-.t.--t...¢...;...t ...... z~ :~,, ,,~,J,zz~ z~z;t_z...:...z...t ...... z...¢...t...~..I...t.4...z...z ....... --*'-'?**'?**'¢ ....... t'"t'*'?***? ..... ?'?'*t't-?'"::'? :?~,~:::: i,~:-::]~ ::::'J:i: :::;-::~: :::!~::~i ]::;~::~: !~zz ~z¢...~ ....... ¢..,?...¢.-.;,..{...¢..,¢...¢...¢ ...... ~..-~,..¢.-4...~,-.¢-..~-..~..,~ ...... ¢-..¢...~--,~-,.~...~..~...¢...~ ....... ¢.-.~-.-¢...~...~.,.~...~..4...~ ....... e-~"-~"-~'*-{'"~"'~'"%"~ ....... :~i~'. .............. ~ ;i!~ i.l...~ ....... ~ ....... ~...i ...... i ............... k..~ ........... i ............... ; ....... }...;...;...¢...; ....... L..¢...¢...;...~...;...~...L..¢ ....... ¢...¢..¢..¢...t..;...;...;..;... '-r'TTT"}'T'T'-T"T ....... T-'T'"T"T"t'TT"r*? ...... T*TT'T"t! ......... T'''~ ..... -..:...'...;.--,h ....... ~..., ....... ----,.---+---.~-----~ ...... +---¢--.--,---, ....... ,--.,-+*~---,.-.~.--~---?1.-.?-..~---? ...... ~..-??--d-.-,...?--?-.?,--.~-.-~-.-??.-l'"r-rr: ....... ...!..i..~...i..L.L.~...L.~...:...~...L.~...L.~...~...~...~...~ ..... ;...t--~...~...l...~...~...~...; ....... ;---;---~.-.~-..~.--;.--~.--N~ ...... N~-.-~.--N~---~.--N+-..~-.-i-.-~-.-~...~..4-.-N+..-e+.-+ ....... --.~--.i---~---~-..[--i-.-Ni---i ....... i.-.i.--i.-.i---i*--i---N~--+[~..+--i---i---~--i---i-.-i---! ....... !.--i.--i.--i-.-!---i..-{.-~-..{ ...... ~'"{'"i'"!'"}'"~'"i"-{"'{ ....... {"'i'"{"'h{"'~"'{"'{'"~ ....... ~;..¢..*~.-.~...;.-.~..4---¢~ t ....... I~'''~''*t'''~'''~'''¢'''~'''¢'''~'''~'''4''*~'''~j!l~¢*''¢*''~'''~: ....... ~'"~'"~"'~*"¢'"~"?"?"? ...... t'"t'"?'*?'t'"t'*'r"?'*'?"r"t'*'t'"t*"?'T"?*"]'**?'"t:i ~! ...... r'r"r"t ...... , r"r'*?'"~ ....... r-'r'-r'-t~_ ..... .... ?"'?"~? ;i-.:i---Lbt-.-LN---,.--i---i---i..-N--~---t---t-.¢., t--'t--~-'-~--'h--t---~--'t ....... ~---~---~.-'~---t-'-~---t---t---t ...... t---t---~---t---f"-¢---t---~'-'~ ...... :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: · --~*-.t-'-+*-%'i'*+"%'t'"t ...... ??'-?t-'-t--*t*-'?"t'"~--'r"-t"-r--?*"t*",**'?'*'t*-r'*? ....... ?'"?'"?"'r"F"?"'?'"?"'t ....... ?---?--'?-'-r--g--?-'-?'-'?-'-r-----r--?'"r"? ....... ,.L..~...L..{...~...:...L..:...~;$:I.:.::L..L..:...¢...¢...¢...;...~...~..4...~ ........ ~...t...¢...~.-.{-..~.--¢--4---~ ....... +..-t--.~---~--.{---+.--~.--f.--f ....... ~-..~-.-~.--? ....... t"'t'"?'"t ....... ?'"t'"t"'?"','"t'"?'"t'"? ....... r.?--.r.-r-~.--r.-r-.r--r-- :::N--!-+.t-+-i-.-i.--i_,=~__ ...... i-..N.--N--N--i-.i.,~-~-H-'H---:+i+i---t--i'-i---H ....... i--i-'-?i"i--i---¢---:--i---t'--f-"f ....... t"'f'"f-"t ....... ...;.-+-..!..-i .-.t-.-;...i.-.¢.4..-~ ...!...N...!...t...i...i...i...~..~-- -,- ~-~' '~~zN..i...i...i...! ....... N-.H.--i-.-J---H-.i ....... i...+...H.--r.-i--.H...i-.. :---H-.-H ....... !-..!..-H ....... !"+'" +" +' 'J-!Ti + i: :? :::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::: !:::H:~ :::t::i:::n:::: -.44...N444...N ...... ~...;...;...~...!...;.4-..~4 ....... ~--.~-..i.4..,~...i...~ ....... !.+++-t-+++-! ...... ~---!++-.l-+++-~ ....... +..+..H.--t--'H-'-H ....... ~i!iI ![[,iiii~iill J iii ~i ~!~Lilt ".t...t...t...t...[T..t..TT.~.T.T...rTTrT..T..~.x~X~X~x~...z...`...~.~XCT~x~x~L..~....i....i ....... ~...~...t..~...~...~...~...~..-~ ....... ;...~...t...;...l...t...N¢...~ ...... ~..4...~...~.4-.-Nh-;-.-~-.. --'?-¢'--t---t--h"-t---?~"'t"'t'"t'"t'"h--'~'~zi ~ ~:::?:! h::!!i:~=============================== :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ....... ~...M...i...I...i...N4 ....... ¢...~44...h4...~4... ....... r"r-r"T*"?"'t ...... r"~'"r"r'-r'?"*t"'? .... r' TTTT~TTT ~t-'~/TT? ¢...~...~...¢..+..;..4..4...; ...... +..+.+..~ ...... ~..+.+..+ ....... +--+-+-+-+-+-+--f"! ....... {---i..f-+-'--+.-r.r-~ ....... r-r'r'r't'"r"r"r'? ....... r-rT"t ...... r'rT"i ....... I"T'T"i ,~ ~ .............. + ....... . ....... ....~..;...'..~ ....... ~ ............... ~...~ ...... ~...~ ....... ~ ....... ~...~...,.~.i.,.~...? ........... ?-.?-.,-,---I.--,-??~ ....... ?..?'-? ....... --?"?-- ...... ....... ....... :.+H---i--i--H.+-~---~-+H-+T+i'--?+-?-H---H---!-'-i--i'-i--i ....... i"i'"i'~~"i"ii"!'T'i"i"i"i'",'"?i'"?'t']'"?'i'"?'t ....... i'"t"'!'","'~"'?t"'i"::irii ....... ?iii' i:..t.-i-.;4..i..i44...~...!.-.N-..i4.-.i..-i...i4...!44.-.!4...,4444 ....... ;4-.-N--N--N---i---~...!---N.-.-i---i---N ....... !---i-+-i..-?H-.-!-..+ ....... i-"!-+-!'-'i ~.z...~...~ ...... ~...~..4.,.~...:..4...;..4...;...N~..4...~...~ ....... ~...~...~.,4...~...~...~...~...~ ....... ~---~-.+--~---t-.~----!..+.-~ ...... e-~--+-.t..--~...~-.-~-..~ ...... H-.+-+..~-'i--i ....... ,~ i ~ i ~ ~ i i Z i ~i.i..Z. i ...... i...i....i...i...~...~...L.;...; ....... ~...;...;...~...;...~...~...~..4~~iI.6000.~ ...... ~....~-4...~..+.+.+..?+ ....... +-..+...+.-+ ...... +--+-+-.+ ...... +"+-'?"?,"'r'?'?r' :"'t'"¢"'T'-'t-'y*?'"T"?! i~?,~ii;!i!:ii::,, ~il~!!~;!'~ !~ ;~!:~::~; ~l~...~...~..~ ....... ~...~...~...~**.*...¢...¢...~...~.-. .... f--!---t--N'"t"t'"t"'t"':"'t'"t-"f"'t'"?t"'f'"f"'f ....... t"'~'"??t"'?~"~-'t ....... T-'TT'T"T-T"'TTT ...... ::'i ,ii:...~...i...i~...~..~uu..l....t...~....;....~ ...... ~...~...z...~ ....... ~..-4.-4---~ ...... 4.--4.--~-*-~ ....... 4.*.~--4..-4 ...... ~--.+ ..... · ....... ~...+'"->--.~ ...... ?'"~*"?'"? ....... ?'"?--'?'"? ...... ?'"?"'?"?'"'"?"'?"."?" .... :::N:::;:::~:::I:::!:::~::-s..,..-~..-i-44.--~4...+...i4..-~...i4...i.+.!-.-!+!4 ....... i.+-i...d-+-!++ ....... +.+-+-.-H-+~ ~-+-'H-"i'"~"'!'+'i'"i ....... ~-'i--'!"-!--'h'"!-"~'-i ...... ~"i'+!-}:i-i!:i:: ~...~...~..++.~...~...~.~...~...~...N~...~...~...~..+.+..~...r..+.+.+..f`.r.~...?+..~ ....... --++--H--i-+++-+ ....... H---+'-i--i--i--i-'i--i ...... ?-f---t---ht'"t"-f---/ ....... ?-t'---i ...... t---t-'-t"-~ ....... t-"t"'t'"?'~'~'?'~?~'"rTr"T"T"? ....... T'TT"T'T"T'TT"T'"'T'T"T"T ....... T'T'T'T' '"t'TT"r"J"'r-rT"]~ ilJ iiJii i;i~t~ i~li[JiJi iiJilii!i iII!~'~ L....!...~....i.~ii...~~:~{L'L"i .... hi.,..~...~...h..~,...N-..'*"i"u~ ...... ~....~...~...; ........ ~....;...;...; ....... ~,..~...;....k ....... n'T'r',Tr'U'" ?N'i':,::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::..::n.:.~...~4...n...h× ........ :...!....~...i4 ....... ~...i...;...~... r'r"r--r-'t"'r'r'?"'r':"'?'"r'r'rT"r"T"r'i ....... f";'F"i'~ i i T ~ ~ i ! i , ! i i ! i i ~ ~ ~ ~ ~ ~ ~ ' ~ ~.~..L..L..~ .... i...~ ..... ; : :...¢...~...~...;...;...; ....... ;....~...;.4 ....... ;...;...~..4... ~...,.+...~..., +..~-+.~ ...... H.+ +..,-+-? +-.-, ....... ? ? ?,....~....~...?..? ....... .... '...'---'..-'---'---,.--'---'---, ....... '-"'""---'---,--"--'"-"--'""','"'"'""""""','"'"'""'"'" ....... "'M"'t"t ....... ?t"'T'"t'"i"'T'-T"'T'TT'T"T'T"T ....... T'"T'"T"T" i"T"T'"~ ....... ~"i'ii"3iiilLi...~ ....... ~.,.~...L.L.~...L.L..h.~ ....... ~...~...~...~...L.~....~...~ ....... ~...~...~...~..4...~...~...~ ....... ~...~..+..~ ....... ~..4-..N~.-- '-?--r--? ......... ~"?--'?? ....... ?~'"??'"T"T"'?'"T-T ....... T"'T"'?'"? ...... ??"'r'? ....... ~"T~'-[~? ! i ~,~ ~;~.i...I'~.i...$ ....... ~...z...¢.~ ...... !~..i .... !.~.~..4 ....... ~...¢...~...-; ............................. .... H+-i. ~.. ....... H---H.: ~---~--'J'. ...... ~H'+'¢'"t"t"'¢'"'~'"'~~ ~ ~ t ~ ~ ~ = ...... ........ ,...~....~---¢---¢-'-¢ ........... ....... t--'t-'-hi~...,.~....~ ........... ....... ~ ~i~ ~ !~i~!~ ~ ~ ~1~ ~u...jJ...L...L..~ ....... L.<..kkt..M...~.~....~...~...~...~..-~...~.4.4 ........ ~...~...~...~...I...~...~...~...!... .... e+*.f..{ ....... ?'?'f"i ....... ?"'T'"r'?"T"T"*r'r'T ....... r"T'*'T'*'T'"T'T"rT"? ........ F'T'"T*"T'T*T'"T'"T"'? ...... T-T*'Tij~T!? TT!TI~..~j...~ ....... ~...~..~Sj~iI)..L.!...L.L.r..L..h~...~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ....... ~--.N.+V-'H'-' ~-,,H,-,!,-,i--'!-+'i'+'i"- i.4---M-.-h+--h-i---i---! ....... ~----N'+'~'"N~"'~'+'!"'~'"i'++'T'+++"~ ....... H*++"h~'"M'"~ ...... t-"~'"~'"~'"!"'t"'t'"'i"-'i ....... t"'t""ht'"T"'i"'?'"t ....... .i.~.4i i'' i, i ii-i' ii .i...~ ..... i~i~ ~ iiiii'i' iiii' L-~--~;' ~ ;iii ;-; 4 .L.;ii,i ...... i...LL.;,iii ....... M...~-.~iiii iL'L'~"-L'ki'i'~-'i,, ~t ...... i.4.-..N ........ ....... i--i.4-..~-'---i .... ~i]~}'"~ ...... u~...i..4..-[.-i.4.-i..-~.--~,....,.......,...~... · ,., I~,,~ ,~ ,.~...I..~.~...~..., ...... ~...~...,-..4...,...,...,..., ....... ,...,...~..., ..... ~ ~ i i ....... L..i...i...z ....... i...i...i...~...;...~...~....N.~..l ~. ~ ..~...~ ...... ;..-.~.-.;...¢ ...... ~'"~" '"4'z I" i i-'-~ ...... %-+.-~"--r" ~4...~...~..~.~...t.-..~.~...~...~..+..~...~...~...~.....~..+.++...+.~..+.+...~+..~...+..+..~..+.+.+.4 ....... +--++.~ ....... ~-'+"i"'? ...... i-'i"'~-"i"-r--~"-t"-¢"-~ ....... r'r'?"}"T"? ..... I-,-i.--4--4---~---~--.4--4---~---4 ....... *-'-~---~'*'~"-t*"~*'~+"~ t?'"?'"? ...... ?'"¢*"?'"? ....... ?"t'**t'": ...... ?'"t"*t'"c _~..i..L.l..~.~.~..~.~Li..~..i.i.i..L.l...;-.-~.-.*...~ ....... ,...~...i...~ ....... L.$.4...;...;...~.i.i~ .... *-..;..-.i....i...L-.H...i...i ...... ~ . / . . ~ . ' .............. ~ ~ : : ~ z ~...~ .~....h.~...; ...... ¢...:..; : ' ' ~ ' ' "'i'T'H"I i i:i i ii-i i I::f ::::::::::::::: ::::::::::::::::::: ::::::::::::::::::::: ::::::::::::::::::::: ::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::: :4...i4...~4...¢444 ...... :::::::::::::::::::::::::::::::::::: .... ."','":",~:~ ,~T~,tT~T~T~ :~ !!!~ ~ ii!!~iii...L...~...~...~...~...~--.4 ...... ¢..-4...¢..-¢...~.-.¢...¢-..¢.-.; ...... ¢..-~..-¢...¢ ...... ;...~...4.--~... '-i--i---t---?'~'--¢-'~-y'! ....... t'"t'"!-t"'t"t"'r'h'"~"TT'rT"?rT"r'i ....... r'TT"]-'~'TTT'] ....... ~ ' ~ ~ ~ ~ ~ ~ ~ i ! ~ ! ~ ~ ! i i ~ ~ ~ : ~ i i i i ~.~..J..i...i...i...i...L..~...~...¢...¢ ...... ~...;...~...¢ ....... ~...¢..4...¢ ...... ¢-.-~.*-~..-~ ...... +..-~**+*.~ ...... ~..-+*--+*.+-. 4...i...t...i ...... '.i.n ....... i.i. i4---14-.i4-i ...... i-.-i.-.i.-.i---;--.i...i.-.i--! ..... ...~.4...L.i ....... ~...t..t.J ....... ;...L.;..4..-.4..4-.-;.-.; ...... ~-..~.-.~...~ ...... ~..+.+..~ ...... ~..+.-~---~--4--+-+-.N~ ....... H--+-+--~--++i---~ ...... i-'i--i---~ ...... .!i~ ~.. !!~ ~Lil ...... ¢..4...~...~...!..I..z...;...I ....... ~...~..4 .......... z...:...~...~ ....... ¢...z...z...z ...... z...~..~...;...I...~...~....~...~ ....... ~...~....~....~ ....... ~.-.~...~...~...I...~ ...... ~"'~ ..... ,:::~:N:::i::::::~:::i::~:::i:.::-i:::N--.!...!4-..i4--.i ...... ~--++.i ....... H+.i ....... H+-i.-.t-.-H.+-i ....... i-.H--i.-i-..i-+.H..:..-H..i--i-.'t"-H"'H ...... ~iii iili i.i~;ilii!i .... i.i.li..Li.!..M ...... M..i...L.hl...M...~ ....... ;..4...~.4..-!...N...N..-L..i...~...i...~ ........ !4.4.-..i ...... ;....!..-~..-i ....... i .......... ~."!'"'i'"i-"!"-+ ....... +'"!'"?"~'" ~", ...... ~'"~ ....... r"r'?, .... ::~:,~ : , : ,' :, ~ : ~ ~ ! ~,~ ~! ~ ~,~ ~ .... ~, ''t~..'.:...' .......'..4 ....... '...~]i....' ............ * ........ ~..-~..-t.-.i..-~...~ ....... i-.-~..-*.--~.-4 ....... ~--~**-½---~ ....... +'-'+'"~'*'~'"+"'~*"{*'*+"'~ ...... ¢'"~"'~'"~ ....... t"*+"'?"'? ....... *'-'?'"?"*,'"T"-?'r"?'"? ...... t'*'t"T"t-'*T"'t'"r'*T'"? ....... ,'"T'"?'"?'"i"'!'T'*~T -.L.~...L4..~.~...~.--~---~---~--4-.-~-.-~--+++--~ ...... ~-.-~---~---~ ....... ~-.-~---~----~ ...... ~...~-..N.h-~--.N~--.~-..~...~-..~.-4--+++--h++.? ...... H--+-+..f-+-+.+..~ ....... +--.~...f"'i-"t'"-???i :'+i'"!'"~ ....... H--i...! ....... !..i.-i.--{..i.+.!..i---f--~-'"H'--i-'--i'--j'-i'-i---!'-i ....... H'-i'-'i j---i-'i-"H'--:----i----!'---H'--j"'?"'!""H ....... -400 -200 0 200 400 600 800 1000 1200 EAST WELL- S-26 (22-35-1;_ 2) (1635' SNL, ll60' WEL, SEC 35, T12N, R12E) VERTICAL PROJECTION - l SOO - ] 000 -SOO 0 0 SOO 1000 I SOO 2000 m PROJECTION ON VERTICAL PLANE 1S2. - S]~. SCALED IN VERIICAL OEPTHS HORIZ SCALE = 1/SO0 IN/FT lEi. EEO Teleco Oilfield S~ as of Alaska Inc. 6116 Nielson Way Anchorage, AK 99502 (907) 562-2646 G i iV A L May 24, 1990 JOB #760 BP EXPLORATION (ALASKA) INC. WELL: S26 PRUDHOE BAY RIG: NABORS 1SE Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to BP Exploration (Alaska) Inc. Teleco is committed to providing the highest quality MWD Service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Jonathan G. Mapes Field Operations Supervisor JGM/el Enclosures A SGNAT COMPANY TELECO OILFIELD SERVICES SURVEY CALCULATIONS Date 5/22/90 Company: BP EXPLORATION Well: S26 Location: PBU Rig: NABORS 18E TELECO Job # Grid Correction: Magnetic Declination: Total grid correction: Proposed Direction: 760TAK 0.0° 30.0° 30.0° 136.5° MINIMUM CURVATURE CALCULATION Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' ******************************************************************************************************* TIE-IN TO SURFACE 479 976 1494 1991 0 0 0.0 69.0 0.01 -0.00 0.01N 0.01E 0.01 N 45.00E 0.00 SPERRY-SUN GYRO/SINGLE SHOTS 479 0.3 69.0 479.00 0.42 0.40N 1.02E 1.10 N 68.71E 0.05 497 0.3 318.0 976.00 -0.25 1.59N 1.31E 2.06 N 39.46E 0.08 518 0.5 190.0 1493.99 -0.04 0.21N 0.16E 0.26 N 38.06E 0.13 497 0.3 35.0 1990.98 1.03 1.04S 0.41E 1.12 S 21.42E 0.15 PAGE 1 Company: BP EXPLORATION, Well: S26, Location: PBU, Riq: NABORS 18E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' ******************************************************************************************************* 2465 474 1.5 63.0 2464.92 2.59 2.62N 6.53E 7.04 N 68.11E 0.27 TELECO SURVEYS 2757 292 1.5 69.7 2756.82 5.18 5.68N 13.52E 14.67 N 67.20E 0.06 2798 41 1.3 ~2.6 2797.81 5.52 6.08N 14.44E 15.67 N 67.15E 0.64 2850 52 1.3 52.1 2849.80 5.75 6.72N 15.43E 16.82 N 66.47E 0.46 2944 94 0.6 49.6 2943.78 5.88 7.69N 16.64E 18.33 N 65.19E 0.75 3039 95 0.7 13.8 3038.78 5.59 8.58N 17.16E 19.18 N 63.44E 0.43 3134 95 0.6 22.2 3133.77 5.07 9.60N 17.48E 19.95 N 61.23E 0.15 3197 63 0.6 355.5 3196.77 4.68 10.24N 17.58E 20.35 N 59.80E 0.44 3229 32 0.7 355.8 3228.76 4.40 10.60N 17.56E 20.51 N 58.88E 0.32 3324 95 0.5 349.9 3323.76 3.60 11.58N 17.44E 20.94 N 56.41E 0.22 3418 94 0.4 334.4 3417.76 2.95 12.28N 17.23E 21.16 N 54.51E 0.17 3513 95 0.4 326.3 3512.75 2.31 12.86N 16.90E 21.24 N 52.73E 0.06 3608 95 0.5 307.7 3607.75 1.57 13.39N 16.39E 21.16 N 50.75E 0.19 3704 96 0.4 238.8 3703.75 1.08 13.47N 15.77E 20.74 N 49.50E 0.54 PAGE 2 Company: BP EXPLORATION, Well: S26, Location: PBU, Riq: NABORS 18E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' 3799 95 0.8 197.3 3798.74 1.34 12.67N 15.29E 19.85 N 50.36E 0.60 3895 96 1.0 206.1 3894.73 1.96 11.27N 14.72E 18.53 N 52.57E 0.26 3955 60 1.0 200.5 3954.72 2.37 10.30N 14.30E 17.62 N 54.24E 0.17 4035 80 2.4 1~7.4 4034.69 4.33 8.22N 14.96E 17.07 N 61.19E 2.46 4132 97 3.8 138.6 4131.55 9.54 4.10N 18.18E 18.63 N 77.28E 1.52 4224 92 5.8 130.5 4223.22 17.21 1.20S 23.73E 23.76 S 87.09E 2.29 4319 95 8.3 130.8 4317.49 28.80 8.80S 32.57E 33.74 S 74.87E 2.63 4414 95 10.5 129.1 4411.21 44.21 18.74S 44.48E 48.27 S 67.15E 2.33 4510 96 12.4 130.1 4505.30 63.13 30.90S 59.15E 66.74 S 62.42E 1.99 4606 96 15.3 130.1 4598.50 85.97 45.70S 76.73E 89.31 S 59.22E 3.02 4700 94 17.5 129.8 4688.67 112.33 62.74S 97.08E 115.59 S 57.13E 2.34 4795 95 19.8 130.1 4778.67 142.51 82.25S 120.36E 145.78 S 55.65E 2.42 4888 93 22.1 128.8 4865.52 175.51 103.36S 146.05E 178.92 S 54.71E 2.52 PAGE 3 Company: BP EXPLORATION, Well: S26, Location: PBU, Riq: NABORS 18E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' ******************************************************************************************************* 4983 95 22.6 128.9 4953.38 211.31 126.02S 174.18E 214.99 S 54.11E 0.53 5078 95 22.7 129.8 5041.06 247.61 149.22S 202.47E 251.52 S 53.61E 0.38 5174 96 22.9 128.9 5129.55 284.52 172.80S 231.24E 288.67 S 53.23E 0.42 5270 96 22.9 1'~8.8 5217.99 321.54 196.24S 260.33E 326.01 S 52.99E 0.04 5366 96 22.9 128.9 5306.42 358.57 219.67S 289.42E 363.35 S 52.80E 0.04 5461 95 22.6 129.0 5394.03 394.99 242.77S 317.99E 400.07 S 52.64E 0.32 5553 92 22.7 128.2 5478.94 430.08 264.87S 345.68E 435.49 S 52.54E 0.36 5647 94 22.8 128.5 5565.62 466.06 287.43S 374.18E 471.83 S 52.47E 0.16 5741 94 22.7 128.2 5652.31 502.05 309.98S 402.69E 508.18 S 52.41E 0.16 5837 96 22.8 128.1 5740.84 538.78 332.91S 431.89E 545.30 S 52.37E 0.11 5931 94 22.9 127.6 5827.46 574.86 355.31S 460.71E 581.81 S 52.36E 0.23 6027 96 22.6 127.7 5916.00 611.55 377.99S 490.10E 618.93 S 52.36E 0.32 6123 96 22.6 127.9 6004.62 648.01 400.60S 519.25E 655.82 S 52.35E 0.08 PAGE 4 Company: BP EXPLORATION, Well: S26, Location: PBU, Riq: NABORS 18E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' ******************************************************************************************************* 6217 94 22.5 127.9 6091.44 683.66 422.74S 547.70E 691.87 S 52.34E 0.11 6311 94 22.4 126.3 6178.31 719.07 444.39S 576.33E 727.76 S 52.36E 0.66 6405 94 22.0 126.1 6265.34 754.02 465.37S 604.99E 763.28 S 52.43E 0.42 6500 95 21.4 1~6.1 6353.61 788 58 486.08S 633.38E 798.40 S 52.50E 0.64 6594 94 20.8 126.1 6441.30 821.86 506.01S 660.72E 832.23 S 52.55E 0.64 6689 95 20.3 125.6 6530.26 854.63 525.54S 687.75E 865.56 S 52.61E 0.56 6784 95 19.6 125.4 6619.56 886.45 544.37S 714.14E 897.96 S 52.68E 0.74 6877 93 19.2 125.2 6707.28 916.75 562.22S 739.35E 928.83 S 52.75E 0.44 6973 96 18.4 126.0 6798.15 947.13 580.23S 764.50E 959.76 S 52.80E 0.88 7067 94 18.0 127.3 6887.45 976.06 597.76S 788.07E 989.12 S 52.82E 0.60 7164 97 17.3 130.1 6979.88 1005.20 616.13S 811.03E 1018.52 S 52.78E 1.14 7260 96 16.5 134.4 7071.74 1033.01 634.87S 831.69E 1046.31 S 52.64E 1.55 7356 96 15.6 138.6 7164.00 1059.54 654.09S 849.96E 1072.51 S 52.42E 1.53 PAGE 5 Company: BP EXPLORATION, Well: S26, Location: PBU, Riq: NABORS 18E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' ******************************************************************************************************* 7451 95 14.2 143.5 7255.81 1083.87 673.04S 865.34E 1096.27 S 52.13E 1.98 7547 96 12.9 147.4 7349.13 1106.08 691.53S 878.12E 1117.73 S 51.78E 1.65 7641 94 10.9 153.0 7441.11 1124.91 708.29S 887.81E 1135.73 S 51.42E 2.46 7736 95 9.8 155.0 7534.57 1141.18 723.63S 895.30E 1151.17 S 51.05E 1.22 7830 94 8.4 159.7 7627.38 1155.08 737.32S 901.06E 1164.28 S 50.71E 1.68 7926 96 7.5 161.8 7722.46 1167.19 749.85S 905.45E 1175.63 S 50.37E 0.99 8020 94 6.6 160.8 7815.75 1177.66 760.78S 909.15E 1185.46 S 50.08E 0.97 8116 96 6.5 160.0 7911.12 1187.67 771.09S 912.82E 1194.91 S 49.81E 0.14 8211 95 6.5 163.6 8005.51 1197.39 781.30S 916.17E 1204.08 S 49.54E 0.43 8306 95 6.2 163.2 8099.93 1206.76 791.37S 919.18E 1212.91 S 49.27E 0.32 8402 96 5.9 162.0 8195.39 1215.85 801.03S 922.20E 1221.51 S 49.02E 0.34 8496 94 5.7 160.8 8288.91 1224.46 810.03S 925.23E 1229.71 S 48.80E 0.25 8590 94 5.8 159.4 8382.44 1233.09 818.89S 928.43E 1237.97 S 48.59E 0.18 PAGE 6 Company: BP EXPLORATION, Well: S26, Location: PBU, Riq: NABORS 18E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' ******************************************************************************************************* 8684 94 5.6 160.4 8475.97 1241.66 827.65S 931.64E 1246.18 S 48.38E 0.24 8766 82 5.4 161.8 8557.60 . 1248.80 835.09S 934.19E .1253.03 S 48.21E 0.29 PAGE 7 lO00 2000 ~3000 n4000 _/ >5000 6OOO 7OOO 8000 9OOO -1000 TE -'!CO Oilfield Service VERTICAL PROJECTION 1000 2000 3000 4000 5000 479 ' .25 deg 976 ' .25 deg 1494 ' .5 deg 1991 ' .25 deg BP EXPLORATION S26 ' PBU NABORS 18E JOB# 760TAK/O0 SCALE: 1 inch = lO00 feet 2465 ' 1.5 deg 2757 ' 1.5 deg 3039 ' .7 deg 3324 ' .5 deg 3608 ' .5 deg 3895 ' 1.01 Oeg 4132 ' 3.8 deg 4983 ' 22.6 deg 5270 ' 22.9 deg 5553 ' 22.7 Ueg 5837 ' 22.8 deg 6123 ' 22.6 deg 6405 ' 22.01 deg 6689 ' 20.3 Oeg 6973 ' 18.4 deg ' ~7260 ' 16.5 7547 ' 12.9 deU 7830 ' 8.4 deg 8116 ' 6.5 VERTICAL SECTION (ft) . TE -CO O~lf~eld Se~v~c ~ PLAN VIEX 2O0 BP EXPLORATION -'",x o :t ' S26 k'~ 4606 PBU ~ ' NABORS '18E '"~4888 ' dOB# 760TAK/O0 '"'~ 5o78 ' SCALE: x~l_70 · /inch= 200 feet ~o~. . 64 ' 45~ ' 7736 ' 8766 ' 200 400 6OO BO0 ~000 ~200 1400 1600 0 --t ZE EAST (ft) 1200 BP XPLORATION PAl:) S (22-:35-12'12) S 26 Controlled Drilling LES HENDERSON (907) 333-1552 Consultants, Inc. CONTROLLED DRILLING CONSULTANTS, INC. P.O. Box 190560 Anchorage, Alaska 99519-0560 (907) 333-1552 May 22,1990 Mr. Brian Rose BP Exploration Pouch 196612 Anchorage, Ak. 99519-6612 RE: Magnetic Single Shot Survey Job No.A-0590-O13 Well: S-26 (22-35-12-12) Prudhoe Bay Field North Slope, Alaska Date of Survey: 5-13-90 to 5-22-90 Dear Mr. Rose: Please find enclosed the "Original" and Four ~ ( 4+ copies of our Magnetic Single Shot Survey on the above well. The method used in calculating this survey was Radius of Curvature. The depth of the survey was 479,~ to 8766'. Thank you for giving us this opportunity to be of service. Yours very truly, Controlled Drilling Consultants, Inc. Directional Supervisor HORIZONTAL VIEW I~ P. EXPLORATION WELL S-26 (22-:55-12-1E) RADIUS OF CURVATURE MAGNETIC SINGLE SHOT SCALE~ I" = I000' ALL DEPTHS SHOWN ARE TVD .~ P EXPLORATTnU ';"i~L,~,IET'IC .... '._:',IFI.,LE ~3HOT SU~,c';,~'-,," RADIUS OF CLIRYATURE HETHC~D OF C:F:HPL~TA'TiOi,i E'hiSiNEER C, l.d, HARRINtSTOhi COHPiiTED FOR. CDC BY ARCTIC SLORE C-Oi.iSULT:t4G .......... , .......... i.~ IE. LL :_=:- 2 ~ KB ELE',/ cS5, 09 FT, S i.i P. V E :'.." f.) A T E ;'~ 5 ," '.; S .--; 90 PEC-~POSEE:: :E:,l:.~: S47-7_<0E TRUE "E'fiS", DRIFT VERTICAL. StJE~ DRIFT TOTAL COORDiHATES D. N DE'6, , ~ ........ E-i"~ ......... 4'?'~', 'o'0 4 ~ 7,5 ~ ~:.i~S"9 7o'OE , s ,, N , '~ s E .¢6 0 !:5 · 975,99 910,90 N42,'OOY 2., 17 N i ,4~ E i 428 ~925,88 N35, OOE ,52 N 95 E 2.465:. 1:.',~'.0:-.-'2464,9~ 2399,82 · NS:3,-O'OE 5,22 N 5,36 E ~, 98 I t8 9~o'~ ~ 273 40=5 o 24 4034 6~ ~969 57 S's- 4345.,.09 $50,'9.0E ~2.72 S 40.~6 E ':~:; 4606 if fa 4~'~- - ' c,~::: 4¢ 4~33 'x8 S49 90E 3':~ 67 S .... ..4.,. 0.0 ':4688,64 4'"'" "=" ,~', ¢ -' _ ': 4 8 u 22 6 4865 49 4800 40 :~51 ::":~' ':'" 34 '" 5i 4, iE,' E, 82, E, 9 D: S T R H C E I . 05 i , 0 $ 8,2,'3 iE,,27 22,00 23,i3 20,02 i8,31 28,90 42,6 ! S3.0J }09,J5 i39,26 ~ 72,3 5 355,00 500,2E, 647,76 754,36 $5(S, SO .. 4.' Y 'r ~ P ~,ELL S-26 ~:-.~; ~..::.,? 65, 09 FT- II RECORD FiF_. e~R',,~E'r'._,,_, . TRUE h' ~ .... T''~' ' ,,~E~S, DR~T VERTICAL DEPTH ANGLE DEPTH D 6 9 ?3' i':~-'"~'~ ......... 6'?' 9 9., 0 5 71e, 4 17 !~ 6980,85 ....... '~ ......... ~ "'~: .....~ ~" 99 .... ...... ..... 7547 12 54 7',S50, 09 SUB SE,q 8020 6 ~6 78i6 R6 -'7= ':' OE 753 '-o ..... , I 47 ._, ~ 9 ..... ~ .... ~ ........ ~ ............... ~ ~ ~ - ~4, b! c,t ,,-,_ 0, fi9 t .... ,¢E ,.,,~,~.- $ 923,30 ,. ;. '-'LO.'-_-; 950:87 t 009,79 I O67,3 i I ! 08,65 i!56.0i ! i '? 7,3 ;2 i 195,78 1204,60 E ;221,46 E 1229,7i E 1244 WELL S-26 'MEASUREG DE'PT~ AN[:, OTHER DATA SINGLE SHOT SUF,'?EY FOR E?ERY EVEN I- aET C 0 f.! F' L! T E F' - k'8 EL FV TRUE MEASURED VERTICAL SUB i'iD- TVD ,~EP ,H DEPTH SEA DIFFERENCE '-¢ ER T ! C:A'L "-,~' ncF ..... ON UUHr..,_ .. T :, T 0 T A L COORD i i'iR TE S 565 565 665 6 "~ :' 865 865 965 965 .... T-(r6:5 i O 65. -- I i65 ! I65, ~.. t 2'6..5 } 265, "':' I:.3:65' I'~65 ~'"I ! 4E, 5 ! 465 ?;..: - · :15'E,:~ t b o .- ;.'i ........ :; ~':' 1765 1765 I :qA'~': } 865 ;: :.,?: ...: . .... !,~.~,;P_. ,....:,:.._.... ....... :~ ~ ~.~ .............. ......... : ........ ~j2_~.,~.:,,.,, :. = :.: ................ ~,~.5, ~:( '2.4.65: ,, 4,~ = ::"' . ' "" 25'65- - 258 5 ::,.~:..' ~e.~ 2765 · ~ ~ ~ ,~ .... 2965 29 ~,.., -65 0 0 ~00 0 0 600 0 0 700 0 0 800 0 0 900 0 0 ~000 O 0 I 'i O0 0 0 1200 0 0 0 0 0 O 0 0 0 0 0 0 2300 0 0 2400 0 0 25F~8 0 0 2600 0 0 27 O0 O O 2800 Cf: i;~ 2 900 0 0 !: "31'6 5'T"'. :: ~i65, 3i00 0 0 :u~..._:,.,,:~-.-.... :,: ...__. ;.~,..~, :f.~, ,,~ .:~ .. ~._- ........ . i ~t J;265 ..... ~265. 7200 0 0 < 6 5. 3 3.0 o o o , ~ ¢..~ ..... . ~" , ~'?' 3565 ,~5~5 . ..,00 0 0 ~., a, .:, O 0 ~:'~: 3865 ~865. 3800 O O ., · O0 S , 0 O .!5 N 2.1.4. ,2 0 S 2, :!; 9 .'E ") "3 ~ A 2.42 N i , 07 2,56 N .5s 3,49 ~'~ .... 2 , i 7 N . 66 , I E, S .. 37 N !, 63 N ~ 8 2, A~ N 2.95 E .3,87 N 4.4S 6. ~ 9 H 8. ~S 5 8,59 N ~2:9S 9,48 N '~4 ':~ =: 9,7i t,i ';6,;34 8,58 N i9.56 6.8 6 H i = , 7 $ ,.F~, r,., E: N i 4,33 OTNER DATA FOR EVERY EVEN !00 t/,~ S~JB SEA DEPTH, C 9 M P U T E' R .- ~:...' ~ !I ............................................. TRUE ,,:~o-J~:~- VERTICAL ._ .... DEPTH ..... DEPTH SE~ DIFFERENCE CORRECTION TOTAL ~9'65 ........... 3965, 4i66 4i65, .... 4266 ........... 4265 , 4469 4465, 46¢o~"~ .......... 4665 , 478.~ 476,5, :~'8':'e. ~,;, 48~5 , ..... ~:~'~'-A ............ 4965 :5':~'~?:~. , ~ ~ ~ ........ : - ~.¢ ~'~o ~ , .......................................... ~ .... ....... ?;':.: '.~. . $900 4 n,", 0 4i00 4o,:, 4BO0 4408 4500 4608 4700 4808 4900 5 O00 51 :; ':' 00 5300 63 8 540 O ~-o 5500 80 8 597 i 5865. :7E'788'": ~ T'-": 6 8, ~ ~, .....: Z 22. Z;;;;/..7:,.-. :.; 6619 6465 · 7-0:4 ~;: ~ 86 S. 5800 i 05 8 o o o ' 6~00 6200 ~, r, n i 46 ".' ..... :: ............. 6500 ~60 7 ~,.~: 0 u ....!?..~: ........... 6 6 7 0 O ~ '72 6 5 4 5 ~-..%. .......... : ...... ~ r~ 7065, ;:'000 t 86 ~"'-::" :-: :?~5:':6 - ' ' : ........... ~,....¢:, · ~ -:~ ............ . . ~ ~ ~ ~' ., ~,:~ ¢365. 7300 i6 5t 8 4,4 7 56 i9 39 s~. 7 ~ ! 0 97.24 t22.80 148,6. i ~; 74.66 2 'ii 0,96 227¢42 2 79 , 87 · ,?, ,,; ..,, ~ ',L' ¢- 74~i 357, .36 408,47 433,29 457,4: 4oL 5 03.33 566, 0'8 E, OS, ~7 625.97 6 4 6,76 667 . '.~4 6 S 7. 07 i6, i'~ E 2.'_~, .~, 7 :::, 4 .... '¢ .:?.: E 6.,':;, i9 E i 4'2..: .-'-.;; E 'l ..... E .E~ '::~ E 2S8,29 E 270,90 E 3 F:7 ..... ' 336,63 E :? 6 ¢:, , '' ~,,¢ <2, : 435,24 E 4 6 S _; ~7 E 5 O 0,95 E 566,56 E 599,26 E 662, 62 E 692 8:i E 72 i 92 E 749 80 E 776 4. V E 8 0 i 824 :3 4$ :"~": E. :?. 7 B, P, B~LL,.. .=,'"-26 i'i E'A S U F.: E F_.~ D ~'P-T Fi' AN[:, O'f'HER FEET 0 F S U E~ .: .,.:l DcF'vH l.t TRUE HENSURED VERTICAL SUE: 5E~ IH DEPTH SE~ H D .- T V b V E R T I C ~';.' L DIFFERENCE """ ~': "?' '-' - _ ~.dr-..¢.=,., I t' ON T 0 T ~ L ¢ ~..~ 7465 7766 '~- ' 7867 7665, ' --8"(~,-¢ .................... 7 8 6 5, ~ ¢ u 8 065. : 83,' I R~ '= .. 8672 8 465, 7400 I 99 2 7~, n f'~ on2 7700 203 7800 ~, f~ ~ O SOOO ¢.'~05 84 00 '2 07 884,58 E 8 '._'-.': 2 - .7 i) E E;?7..E:~ E 90.2: Si.-..:.E 906. '~.::3 E ~.., , 922,6 !5 EE i<E; 'EL-*:~': E:5 0'.=] c7 8,P, t.v~ELL S-26 S Z k:3 EL.E:.,,' 65. 09 F":'. -~.R~UE~; FOR EVEN :'NTERPOLATED "~'"" ' T~UE -' i~E'~S'U'RE[:~ VERT ~ CAL : DEPTH DEPTH ! 0 00 ,,~_~':lS Re.. DEP: .. 93: 5. 935: 975, ' '9,'64 N '-3_ ,_,: '=:',., , i P": , 62 i"-~ 49 04, '~: ::::3,86 S 7000 8 OOO :::::::::::::::::::::::::::::::::: 2i'. .......... ..i::.:::'. ........ AOGC~ GEOLOGICAL MA'i'ERi~LS iNVEntORY UST check off or list data as it is received.*list received date for 407. if cored inter'id core analysis I.~i ' dw ditch intc~'als ' not re~juired list as NR ,~.,~'! ", co re' descriptio~l. ~,~ ~di~ital data NO. {to the nearest foot) {!nth/100'1 iiiii ii i i - ! I m i i ii ii i BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :09/04/90 T#:81630 FROM: SUBJECT: Information Control Well Records LR2-1 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. S-26 Collar 08/27/90 #1 8906-9364 Atlas 5" W-03 PFC 08/28/90 #1 9450-9850 Atlas 5" W-31 PFC 08/26/90 #1 11537-11840 Atlas 5" Z-08 PFC 08/29/90 #1 8800-11542 Atlas 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS R ES E RV_.~O[R.-., .~~___.~ ALASK_A~~ "'ARCHIVES s .E10 Alaska 0il (;0mmtss't0n BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date: 06/20/90 T#:81306 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. C-01 PERF 06/16/90 #1 8794-9070 SCH 5" J-08 PERF 06/15/90 #1 12040-12376 SCH 5" S-26 CBT 06/15/90 #1 8520-9363 SCH 5" S-26 CET 06/15/90 #1 8520-9386 SCH 5" Z-07 TUBING POIST REC 06/12/90 # 1 11782-12866 SCH 5" Z-20 STATIC 06/13/90 #1 11052-11300 SCH Z-20 LEAK DEK 06/13/90 #1 9795-11480 SCH 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES Alaska Oil & Gas Cons. ,,~mmJssion Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: ARCO DATE: 06/08/90 EXXON T# 81252 PHILLIPS '-ARCRIVES SYSTEM Tape & Transmittal Only BP MAGNETIC LIS TApE & LISTING Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. So26 OH/DIL/BHC/CNL 05/24/90 #1 9448-6594.5 TP#07090: Sch#73891 1600bpi AP1#50-029-22047 ***ARCHIVES ONLY: Information Control Well Records LR 2-1 J. Dietz/S. McCurry R IVED 2 1990 Alaska Oil & Gas Cons. Commission Anchorage May 8, 1990 Telecopy: (907)276-7542 G. W. Kirton PBU Lead Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Prudhoe Bay Unit S- 26 BP Exploration (Alaska) Inc. Permit No. 90-58 Sur. Loc. 1635'SNL, !160'EWL, Sec. 35, T12bl, R12E, L~A Btmhole Loc. 2500'S~rL, 3300'I,~L, Sec. 35, T12N, R12E, UM Dear Mr. Kitten: Enclosed is the approved application for permit to drill the above referenced w~ll. The p~rmit to drill does not axempt you from obtaining additional pemits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting deteminattons are made. · "~e Commission will advise you of those BOPE tests that it wishes to witness. /... C. V. Chatterton' Chairman o f Alaska Oil and Gas Conservation Commission BY ORDER OF THE COI~MISS!O~ dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 27, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton $-26 (22-35-12-12) PBU Enclosed, in triplicate, is form 10-401, our Application for Permit to Drill the above named well. Also included are the attachments listed on the application form and a check in the amount of $100.00 to cover the permit filing fee. Yours very truly, G. W. Kirton PBU Lead Engineer GWK/KTH CC D. Hsu Well File STATE OF ALASKA ALASKA L~IL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] RedrillDIlb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exr)/oration KBE = 66' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P, O, J~OX 196612. Anchora(3e. Alaska 99519-6612 ADL 28257 4. Location of we~,,a,t/surf-ace 7. Unit or property Name 11. Type Bond(see 20 AAC 25.o2s) 1635' SNL, 1160"1#~:L, SEC. 35, T12N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2500' SNL, 3300' WEL, SEC. 35, T12N, R12E S-26 (22-35-12-12) 2S 100302630-277 At total depth 9. Approximate spud date Amount 2500' SNL, 3300' WEL, SEC. 35, T12N, R12E May 18, 1990 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(UDandTVD) prope~L line 28258 @ 1978' feet S-05 @ 391'/35' feet 2560 9434'MD/9220'TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 A^C 2s.o3s (e)(2)) Kickoff depth 4ooo/6934feet Maximum hole angle 23/ o Maximum surface 3330 pslg At total depth (TVD) 8800'/4390 pslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD M D TVD (include stage data) 20" Cond. 80' Surface 110' 110' 17-1/2" 13-3/8" 68# L-80 Butt 2650' Surface 2680' 2680' 3295 cu fl Arcticset II and III 12-1/4" 9-5/8" 47# NT80-S NSCC 8780' Surface 8810' 8596' 1870 cu fl Class G 8-1/2" 7" 26# NT-80 NSCC 874' 8560' 8346' 9434' 9220' 285 cu fl Class G 19. To, be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate ~ ~ := Production Liner ~PP~ Perforation depth: measured .~aska,0jl& Gas Cons, C0fflmJssJotl true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drillin.~"]5?~.(~ [] Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements r-I 21. I hereby certjfy that the fore.going is true and correct to the best of my knowledge Signed ~ '~-'~.~'/¢;~'~ Title PBU Lead Engineer /_-/z/3~//~ Date - ~ Commission Use Only Permit Number IAPI number IApproval date ISee cover letter ?O --,.5"~ ICC-cz?'-- z2o~4z_? I 05/08/90 Ifor other requirements Conditions of approval Samples recLuire, d [] Yes ~ No Mud Icg required [] Yes ~I~No Hydrogen sulfide measures [] Yes ,,1~ No DirectionaZ i survey requ~re~ ~Yes [] No Other: by order of Approved by (_ /',/' , (,,. ~"~_//-~,~/~ Commissioner ~ne commission Date Form 10-401 F Submit iplicate PROPOSED DRILLING AND COMPLETION PROGRAM WELL S-26 [22-35-12-121 PBU AFE No. 125117 Install and cement 80' of 20" conductor to surface. The drilling fluid program will consist of an 8.5 - 9.5 ppg spud mud in the 17- 1/2" hole, a 9.0 - 9.7 ppg water base mud in the 12-1/4" hole and a 8.8 ppg water base mud in the 8-1/2" hole. Drill 17-1/2" hole to 2700' TVD(BKB) and cement 13-3/8" L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 3710 psi at 8800' TVD(SS) based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVD(SS) and an oil column to 8800' TVD(SS). Directional drill 12-1/4" hole to the 9-5/8" casing point above the Sag River Sandstone. Run 9-5/8" 47# L-80 NSCC casing to within 5' of 12-1/4" TD and cement with Class G cement around the 9-5/8" shoe. The annulus will be freeze protected by dry crude. Directional drill 8-1/2" hole to TD. Run 7" liner from TD to 250' inside 9-5/8" casing shoe and cement using Class G cement. Clean out to 7" float equipment. Change over to NaC1 completion fluid. Test casing and lap to 3000 psi. Run 9-5/8" production packer on tubing. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 100' below base of permafrost. Install and test Xmas tree with diesel. Displace tubing to diesel. Set and test packer. Shut down rig operations for perforating subsequent to rig release. will be perforated in accordance with normal practices. The well Fluids incidental to the drilling of a well will be pumped down the 9-5/8" x 13- 3/8" annulus of the well. Tubing Size: 4-1/2", 12.6# L-80 TDS TBG with 5 GLM's. Tailpipe Size: 4-1/2", 12.6# L-80 TDS TAILPIPE DH: 4-10-90 20" Conductor ./LIMINARY WELL PLAN WELL 5-26 [22-35-12-12] PBU PROPOSED DEPTH BKB I!0' Ball Valve 2100' 13-3/8" Casing Shoe 17-1/2" Open Hole 2680' 2700' Cement Top 3000' 4-1/2" 12.6# L-80 TDS. Tubing with 5 GLM's 9-5/8" Packer 8510' 7" Tieback Assembly 8560' 9-5/8" Shoe 12-1/4" Open Hole 8810' 8815' 7" 26# NT-80 Liner 7" PBTD 7" Liner Shoe 8-1/2" Open Hole 9394' 9434' 9434' BOP STACK CONFIGURATION 13 5/8", 5000 PSI WP TRIPLE RAM STACK DRILLING RISER ANNULAR PREVENTER PIPE RAMS I BLIND RAMS 2" KILL LINE MANUAL HYDRAULIC 'GATE GATE DRILLING SPOOL 4" CHOKE LINE HYDRAULIC MANUAL GATE GATE PI PE RAMS RECEIVe;: ~,APR .~ o 191:~,~ ~nchora?~ nmi,s~ion SURFACE HOLE DIVERTER SYSTEM Two lines venting 90 deg. apart in directions that ensure safe down wind venting, and ex- tending to a point at least 100' from any potential source of ignition. 43' 10" Full Opening Valves 35' or as requi'red Dresser Sleeve 10" Diverter Line NOTES 1. All pipe connections 150# ANSI Flanges or welded connections and secured to prevent movement. 2. Manual 10" [aill~all~valves mechanically connected to ensure · that one valve is fail-safe open at all times. 3. All turns are 90 deg. and targeted. 10" Full opening ball valve w/Hydraulic Actuator Cellar 20" Diverter Spool w/10" Side Outlet KRL 12/18/89 PRELIMINARY WELL PLAN WELL: S-26 AFE NUMBER: 125117 LOCATION: S u r fac e: Target: T.D.: 1635' SNL, 2500' SNL, 2500' SNL, [22-35-12-12] ll60'WEL, 3300'WEL, 3300'WEL, PBU Sec. 35, T12N, Sec. 35, T12N, Sec. 35, T12N, R12E R12E R12E ESTIMATED START: May 1990 OPR. DAYS TO COMPLETE: 20 CONTRACTOR: Nabors 18E MAX ANGLE/SECT COURSE/KOP/BUILD RATE: 22.92/S 43.5 E/4000/2.5 Item TVD(SS) MD(BKB) Mud Wt. 110 8.5 2680 9.5 5349 9.0 8810 9.7 8821 8.8 8947 8.8 9058 8.8 9434 8.8 20" CONDUCTOR 80 13-3/8" SHOE 2614 BASE WEST SAK FORMATION 5225 9-5/8" SHOE 8530 TOP SAG RIVER SANDSTONE 8541 TOP SAD~ROCH1T 8667 TARGET 8778 TOTAL DEPTH 915 4 LOGGING PROGRAM: Open Hole - Record all logs on magnetic tape where applicable. 12-1/4" Hole: Optional MWD GR/RES: RFT/GR: HRSC (Kuparuk only) 8-1/2" Hole: DIL/BHC/CNL/GR (Optional LDT): RFT in Sag River, Zone 3 and 4, and below OWC Cased Hole CBT/CET/ Gyro DH: 4-10-90 and perforate after rig release. 20 30 40 I0 20 ' 30 40 I I0 (Actual) .t 27 2G ¸2 5 WELLS 2O 'o/ t (Actual) 34 - ~ S-I (Proposed)~ s-2c (Act~a~) J LAT. : 70°2!'13.01 ',, S-8 (Proposed)~~ ' ~ ~l°J X= 618,919 t =, - -- ~--~-*** -4- - S-24.~_ '°9~' ~ o o _~ (Proposec) j 'mi i S-6 -- ' o ~ ~ _,. ~ ~ ~0o ~l T. II N. '-- O~ 0 ~, roposffal ]j , -~ I ~ '~'~ _ I s-.~ J PORTION OF TII S 12N~ 12E,~M. SCALE 1":1/2 MILE ~- J4 - ,'2.122 /J4 - 2~ -/2 -/22 -27-12-12] ~/ /22-27-12- 12) f/I- 02-//-/2) v4 - ~5- ,; 'J -/2 ? ?1- .54-/2-/Z) ~ / PAD DETAIL SCALE I": 400' CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered to practice land surveying in the State of Alaska and that this plat represents a location survey of the weltpad shown and the wells thereon. This survey was made by me or under my supervision and all dimensions and other details are correct. Bottom hole locations are furnished by others. Date Surv. eyor ADDED PROPOSED 8HL 5-24 81 S-26 ADDED PROFOSED BHL.S-21 ADDED PROPOSED BHL S-'20 AODED PROPOSED BHL S~19 ADDED PROPOSED BHL S-12A REVISED PROPOSED BHL S-4 & 5. ADDED PROPOSED BHL S-4 R, 5. ADDED ACTUAL 8HL S. I RD, S-2,& 5-3.~ REVISED PROPOSED BHL S-8 TO ACTUAL ; REVISED PROPOSED S-6. ADDED PROPOSED BHL S- 6 8~T. ADDED PROPOSED BHL S- 1:5i ADDED ACTUAL BHL S-9 ~ REVISED BHL S- I0,11,~ 12 FROM PROPOSED TO ACTUAL. ADDED PROPOSED BHL S- 14 ADDED PROPOSED BHL S-8. REVISED BHL S-ID & II'iDELETED BHL S-7,8,8~9. ADDED PROPOSED BHL S-7,8,9,~ lO. 4/~6/9o ~..---.5 / 2;5/90 7/22/86 4 /2 /~6 7/31/85 5/9/83 9/27/82 ~ :.:~. 8/31/82 ~L.~t 81~2/82 ¢_~- ~,~. 7/30/82 GCc, 7/ 7 /82 ~ 61 8 182 ~ 5/Z4/82 PA D "S" Lo coted in NE I/4 PROTRACTED SEC. 35.T. 12 N.,R. 12 E., UMIAT MERIDIAN, AK. Surveyed for SOHIO ALASKA PETROLEUM CO. Surveyed by F. M. LINDSEY & ASSOC. LAND & HYDROGRAPHIC SURVEYORS 2_502 West Northern Lights Boulevard Box 4-081 Anchorage, Alaska A - 12588 - el $45DU~124:[DRAN034]S26 CLOSAP SHORT.LIS;22 Search Radius= 200 COURSE LINE For proposed well: S26 [22-35-12-12] Location = W-E S-N TVD(SBS) Top 619322.00 5979855.00 -66.00 Bottom 620157.00 5979003.00 8778.00 10-APR-1990 16:10 ----- Closest Approach Analysis --- Date: 10-APR-90 Time: 16:10:46 Note: Ail depths in feet Below Kelly Bushing (BKB) t23 : Closest Approach WELL IDENT /PROPOSED% /NEARBY~ TVD DEPART TVD DEPART A029-2069500 S-3 1098.9 A029-2069800 S-2 3213.6 A029-2072800 S-Il 2896.6 A029-2072900 S-12 98.9 A029-2076500 S-10 2598.4 A029-2077100 S-9 3836.6 A029-2077800 S-8 3798.0 A029-2080400 S-14 0.0 A029-2081000 S-13 298.4 A029-2082900 S-7 1398.6 A029-2083900 S-6 2897.9 A029-2086900 S-5 391.5 A029-2095900 S-4 2591.9 A029-2111300 S-15 2766.0 A029-2112300 S-16 A029-2115600 S-18 A029-2141900 S-12A A029-2161100 S-19 A029-2163700 S-20 CLOSEST DISTANCE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0 0.0 0.0 1100.0 3215.4 2898.4 100.0 2600.0 3837.6 3799.7 1.8 300.0 1399.8 2899.9 400.0 2599.9 2778.7 7.1 99.5 51.2 1.3 5.8 270 .8 130 9 0 0 0 7 6 2 15 3 1 6 16.7 376 .4 180.0 249.7 655.4 806 .2 579.3 414.6 324.6 1025.0 914.7 253 .0 136.9 34.9 70.2 347.2 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 0 .0 0.0 6.5 0 .0 795.0 3705.0 0.0 3709.7 78 .8 296.5 4496 . 0 54 . 3 4511 . 0 186 . 7 199 . 5 Vertical Intersection /PROPOSED~ /NEARBY~ TVD DEPART TVD DEPART VERTICAL DISTANCE 6286.7 770.4 2936.0 619.3 --3351.9 5147.9 288.9 4338.7 214.1 -811.2 5464.3 422.7 3972.5 351.0 -1492.8 5310.9 357.8 4183.1 280.0 -1129.4 $45DUA124:[DRAN034]S26 CLOSAP SHORT7.LIS;13 10-APR--1990 ---- Closest Approach Analysis --- Date: 10-APR-90 Time: 16:11:32 Search Radius= 200 7 DEGREE LEAD LINE For proposed well: S26 [22-35-12-12] Location = W-E S-N TVD(SBS) Top 619322.00 5979855.00 -66.00 Bottom 620254.61 5979111.11 8778.00 Note: All depths in feet Below Kelly Bushing (BKB) 16:11 Page Closest Approach WELL IDENT /PROPOSED% /NEARBY% CLOSEST TVD DEPART TVD DEPART DISTANCE A029-2069500 S-3 1098.9 0.0 1100.0 7.1 A029-2069800 S-2 3213 .6 0 .0 3215.4 99.5 A029-2072800 S-ll 2896.6 0.0 2898.4 51.2 A029-2072900 S-12 98.9 0.0 100.0 1.3 A029-2076500 S-10 2598.4 0.0 2600.0 5.8 A029-2077100 S-9 3836.6 0.0 3837.6 270.8 A029-2077800 S-8 3798.0 0.0 3799.7 130.9 A029-2080400 S-14 0.0 0.0 1.8 0.0 A029-2081000 S-13 298.4 0 .0 300.0 0.7 A029-2082900 S-7 1398.6 0.0 1399.8 6.2 A029-2083900 S-6 2897.9 0.0 2899.9 15.3 A029-2086900 S-5 391.5 0.0 400 .0 1.6 A029-2095900 S-4 2591.9 0.0 2599.9 16.7 A029-2111300 S-15 2766.0 0.0 2778.7 376.4 A029-2112300 S-16 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW A029-2115600 S-18 NO COORDINATE POINTS A029-2141900 S-12A 0.0 0 .0 A029-2161100 S-19 3705.0 0.0 A029-2163700 S-20 4398 .0 34.8 180.0 249.7 655.4 806 2 579 3 414 6 324 6 1025 0 914 7 253 0 136 9 34 9 70 2 347 2 WITHIN SPECIFIED SEARCH WINDOW 6.5 0.0 795.0 3709.7 78.8 296.5 4417.3 157.0 204.6 Vertical /PROPOSED~ TVD DEPART Intersection /NEARBY~ TVD DEPART VERTICAL DISTANCE 5781.5 556.8 2635.3 391.2 -3147.5 5007.4 229.5 4163.0 147.2 -846.4 5447.7 415.6 3887.7 299.5 -1560.9 5271.5 341.2 4069.2 234.3 -1204.0 MUD WEIGHT CALCULATIONS WELL S-26 (22-35-12-12~ Mud Wt. (8-1/2" Hole): P @ Sag River: P @ Sadlerochit: P @ Top Sadlerochit: OB @ Sag River: OB @ Top Sadlerochit: Current GOC: 9-5/8" Casing Shoe: Top Sag River: Top Sadlerochit: 8.8 ppg. 3750 psi. 3700 psi. at 8800' TVDSS 3623psi. 190 psi. 333 psi. Not Present 8596' TVDBKB 8607' TVDBKB 8733' TVDBKB CEMENT CALCULATION 13-3/8" CASING Measured Depth: 2680' Basis: 2 X Annular Volume Total Cement Vol: 3295 cu ft Lead Slurry Vol: 2009 cu ft (1036 Sx Arcticset III @ 1.94 Cu ft/Sk) Tail Slurry Vol: 1286 cu ft (1383 Sx Arcticset II @ 0.93 Cu ft/Sk) 9-5/8"CASING Measured Depth: 8810' Basis: 90% Annular Volume to 13-3/8" + 50 cu ft Total Cement Vol: 1870 cu ft Lead Slurry Vol: 1295 cu ft (724 Sx G+8% @ 1.79 Cu ft/Sk) Tail Slurry Vol: 575 cu ft (500 Sx Neat G @ 1.15 Cu ft/Sk) 7" LINER Measured Depth: 9434' (Shoe) - 8560' (Hanger) Basis: 1.5 X Annular volume to 9-5/8" shoe + 150 cuft Total Cement Vol: 285 cuft (245 Sx @ 1.16 Cu ft/Sk) DH: 4-10-90 HUD A~YrE: T~ A~Jy Pl~.t. T,gldK. Choke Manifold Poor Boy Degasser · Brandt Vacuum.-Type Degasser Brand t Dual Tandem Shale Shaker Pioneer Mud Cleaners ~Pioneer MKI Centrifuge KILL LII~ TO 1 - RecOrding drilling fluid pit 'level indicator with both visual and audio warning de~ices at driller's console ' · 1 - TriP Tank (75 BBL.) 1 - Drilling fluid flow sensor with readout at driller's console 11 - 5 Hp Agitators CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) Loc ,, thru 8 (8) (3) Aamin 9. ' (9 thru f3) * 10. (10 and 13) 12. 13. (4) Cas ~ ' ~-K.~,.~l.....,~'-~_- e o (14 thru 22) (5) BOPE (23 thru 28) Lease & Well No. YES NO Is the permit fee attached .......................................... 2. Is well td 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 wellbore plat included ................ 7. Is operator the only affected party .......................... ....... 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground, source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... 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 wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate .~ Are necessary diagrams and descriptions of diverter and BOPE attached. ,~ Does-BOPE have sufficient pressure rating - Test to ~O~O psig .. ..~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. ' (29 thru- 31') rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UN IT ON / OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX . . . InfOrmation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. , i i CROFiL 4ED$ - 26 ~.~DHOE BA¥~ RECEIVED MAR 1 0 199~ 011 & Gas Cons. Commission Anchorage Run 1' 17 - January - 1993 PDK-1001GR Borax Log 8778 Tape Subtile ~ is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD S- 26 (22-35-12-12) 500292204700 BP EXPLORATION (ALASKA) INC ATLAS WIRELINE SERVICES 25-FEB-93 5865.00 K. BRUNNER L. LE 35 12N 12E 1635 1160 66.60 65.10 35.60 RECEIVED MAR 1 0 1996 Alaska Oil & Gas Cons. Commission Anchorage OPEN HOLE CASING DRILLERS CASING 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 8816.0 47.00 7.000 9433.0 26.00 4.500 8624.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: UNKNOWN BASELINE DEPTH GRCH 8763.0 8763.0 8821.0 8821.0 8859.0 8859.5 8868.5 8869.0 8880.5 8880.5 8890.0 8891.0 8896.5 8898.0 8903.5 8904.5 8910.5 8911.5 8919.5 8920.5 8934.0 8934.5 8940.5 8941.0 8946.0 8946.5 EQUIVALENT UNSHIFTED DEPTH 8948.5 8980.5 8987.5 9010.5 9024.0 9061.0 9078.0 9082.5 9114.5 9118.5 9121.5 9182.5 9197.5 9239.5 9242.5 9249.0 9317.0 9320.0 9323.5 9362.0 $ REMARKS: 8949.0 8981.0 8988.5 9010.5 9023.5 9061.0 9078.0 9083.5 9115.0 9119.5 9122.0 9183.5 9198.0 9240.5 9243.5 9250.0 9318.5 9321.5 9324.5 9362.0 PDK-100/GR LOG TIED TO CBL RUN 15-JUN-90. RATE FOR FLOWING PASS: OIL = 0.75 BOPD WATER = 3.43 BWPD GAS = 1.14 MMSCFD GOR = 1524 LIFT GAS = 2.53 MMSCFD CHOKE = 96 FWHP = 280 PSI FWHT = 172 F WATERCUT = 82 % MADE 1 FLOWING PASS. MADE 1 SEAWATER PASS AFTER PUMPING 190 BBLS SEAWATER. LOGGED 1 PASS AFTER 60 BBLS BORAX AWAY. LOGGED ANOTHER PASS AFTER 120 BBLS BORAX AWAY. MADE LAST PASS AFTER 30 BBL SEAWATER FLUSH. OPEN .HOLE GAMMA RAY FOR DEPTH MATCHING SUPPLIED BY BP EXPLORATION (ALASKA) INC (12-FEB-93). SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS SGMA DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT SGMA (PDK) PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS SGMA. $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 8778.0 9331.0 PDK 8791.0 9342.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 8763.0 8821.0 8823.5 8859.0 8880.5 8890.0 8900.0 8909.0 8948.0 8961.0 8984.0 8996.5 9059.5 9078.0 9106.5 9118.5 9182.0 9197.5 9239.0 9245.0 9316.5 9319.5 9323.0 9362.0 $ REMARKS: SGMA 8763.0 8820.5 8823.0 8859.5 8880.5 8890.5 8900.5 8910.5 8948.5 8961.5 8985.0 8996.5 9059.5 9078.5 9106.5 9119.5 9182.5 9198.5 9240.5 9246.0 9319.5 9321.0 9323.5 9362.0 EQUIVALENT UNSHIFTED DEPTH BASE FLOWING PASS. GRCH SHIFTED TO OPEN HOLE GAMMA RAY. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ CN : BP EXPLORATION WN : S - 26 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH'PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 SS PDK 68 1 CPS 8 MSD PDK 68 1 CU 9 RATO PDK 68 1 10 RBOR PDK 68 1 11 RICS PDK 68 1 12 RIN PDK 68 1 13 SGMA PDK 68 1 CU 14 SGMB PDK 68 1 CU API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 06 511 09 0 4 4 00 201 24 1 4 4 39 705 61 6 4 4 74 169 61 6 4 4 00 201 24 1 4 4 71 162 89 6 4 4 05 626 89 6 4 4 00 201 24 1 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 96 761 61 6 4 4 00 201 24 1 56 * DATA RECORD (TYPE# 0) Total Data Records: 75 966 BYTES * Tape File Start Depth = 9362.000000 Tape File End Depth = 8763.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17986 datums Tape Subfile: 2 239 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8786.0 9340.0 8800.0 9352.0 BASELINE DEPTH GRCH 8763.0 8763.0 8826.5 8826.5 8828.0 8831.5 8853.5 8854.0 8864.0 8867.0 8868.0 8875.0 8880.0 8890.0 8891.0 8903.5 8904.5 8910.5 8919.5 8920.5 8922.5 8937.0 8940.0 8940.5 8956.0 8965.0 8966.0 8979.0 8982.5 9004.0 9004.5 9015.5 9015.5 9024.5 9024.0 9036.0 9036.0 9044.0 9043.5 9052.5 9052.5 9054.0 9059.0 9059.5 9078.0 9079.0 9085.5 9087.0 9114.5 9115.0 9120.0 9120.5 9121.5 9128.0 9134.0 9134.5 9140.5 9141.5 9177.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 8763.0 8828.0 8831.5 8854.0 8864.5 8875.0 8880.0 8912.0 8924.0 8937.5 8956.5 8980.0 8983.5 9054.5 9121.0 9129.0 9177.5 9185 .§ 9191.5 9192.5 9197.5 9233.0 9233.5 9236.5 9239.0 9243.0 9247.0 9248.5 9249.0 9249.5 9250.5 9251.5 9252.0 9254.5 9309.5 9313.5 9316.0 9317.0 9319.0 9323.0 9323.5 9331.0 9362.0 $ REMARKS: 9186.5 9192.5 9193.5 9198.0 9235.0 9235.5 9238.0 9240.5 9244.0 9248.0 9250.0 9249.5 9250.5 9251.0 9251.5 9252.5 9253.5 9256.0 9312.5 9316.5 9319.0 9319.0 9321.0 9324.5 9325.0 9332.0 9362.0 BASE SEAWATER PASS. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ CN : BP EXPLORATION WN : S - 26 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE~ 64 ) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 GRCH PDK 68 1 GAPI BIF PDK 68 1 BKL PDK 68 1 CPS BKS PDK 68 1 CPS CSLS PDK 68 1 CU LS PDK 68 1 CPS SS PDK 68 1 CPS MSD PDK 68 1 CU RATO PDK 68 1 RBOR PDK 68 1 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 05 626 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 11 RICS PDK 68 1 12 RIN PDK 68 1 13 SGMA PDK 68 1 CU 14 SGMB PDK 68 1 CU * DATA RECORD (TYPE# 0) Total Data Records: 75 4 4 4 4 4 4 4 4 56 966 BYTES * 23 260 40 23 260 40 96 761 61 00 201 24 Tape File Start Depth = 9362.000000 Tape File End Depth = 8763.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17986 datums Tape Subfile: 3 168 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8786.0 9340.0 8800.0 9352.0 BASELINE DEPTH GRCH 8763.0 8763.0 8823.5 8827.0 8827.0 8853.5 8854.0 8858.0 8858.5 8858.5 8869.5 8875.5 8880.5 8907.0 8908.0 8910.0 8918.0 8919.0 8927.0 8927.5 8927.5 8928.5 8937.5 8951.5 8953.0 8961.5 8983.5 9042.5 9059.0 9061.5 9075.0 9075.5 9078.0 9106.5 9119.0 9149.0 9154.0 9155.0 9177.0 9184.5 9190.0 9191.5 9196.5 9201.5 9202.5 8952.0 8953.5 9042.5 9075.0 9076.0 9149.5 9157.0 9158.0 9178.0 9191.0 9197.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 8763.0 8823.0 8859.0 8869.5 8875.5 888O.5 8911.0 8928.0 8938.0 8962.0 8984.5 9059.0 9062.0 9079.0 9106.5 9120.0 9185.0 9192.5 9202.5 9204.0 9239.5 9247.0 9252.5 9253.0 9259.5 9310.0 9311.0 9312.0 9312.5 9313.5 9316.5 9317.0 9319.0 9331.0 9362.0 $ REMARKS: 9312.5 9313.5 9314.5 9319.0 9362.0 9241.0 9248.0 9253.5 9254.5 9261.0 9313.0 9316.5 9319.5 9321.0 9331.5 9362.0 60 BBL BORAX AWAY PASS. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ CN : BP EXPLORATION WN : S - 26 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 SS PDK 68 1 CPS 4 8 MSD PDK 68 1 CU 4 9 RATO PDK 68 1 4 10 RBOR PDK 68 1 4 11 RICS PDK 68 1 4 12 RIN PDK 68 1 4 13 SGMA PDK 68 1 CU 4 14 SGMB PDK 68 1 CU 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 05 626 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 56 * DATA RECORD (TYPE~ 0) Total Data Records: 75 966 BYTES * Tape File Start Depth = 9362.000000 Tape File End Depth = 8763.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35972 datums Tape Subfile: 4 157 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8785.0 9340.0 8799.0 9352.0 BASELINE DEPTH GRCH 8763.0 8763.0 8814.0 8821.0 8821.5 8826.5 8826.5 8828.0 8828.5 8831.5 8832.5 8833.0 8853.5 8854.5 8863.0 8864.0 8865.5 8866.5 8874.0 8880.5 8907.5 8909.0 8910.0 8918.0 8919.5 8919.5 8938.5 8984.0 8985.5 9004.0 9005.0 9020.5 9020.5 9026.0 9026.5 9030.5 9031.0 9042.5 9042.5 9060.0 9060.5 9075.5 9076.0 9120.0 9121.0 9136.5 9137.5 9152.0 9153.5 9187.0 9189.0 9190.5 9191.0 9192.0 9191.5 9195.0 9233.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 8763.0 8814.0 8828.0 8829.0 8832.0 8832.5 8833.0 8866.5 8867.5 8874.5 8881.0 8911.5 8921.0 8939.5 9188.0 9193.0 9196.5 9235.0 9240.0 9246.5 9250.5 9251.0 9255.5 9310.0 9311.5 9312.0 9312.5 9314.0 9331.5 9334.0 9362.0 $ REMARKS: 9313.5 9314.0 9315.0 9316.5 9362.0 9242.0 9248.0 9252.0 9253.0 9257.5 9313.5 9317.5 9332.5 9335.0 9362.0 120 BBL BORAX AWAY PASS. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ CN : BP EXPLORATION WN : S - 26 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 SS PDK 68 1 CPS 4 8 MSD PDK 68 1 CU 4 9 RATO PDK 68 1 4 10 RBOR PDK 68 1 4 11 RICS PDK 68 1 4 12 RIN PDK 68 1 4 13 SGMA PDK 68 1 CU 4 14 SGMB PDK 68 1 CU 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 05 626 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 75 Tape File Start Depth = 9362.000000 Tape 'File"End Depth = 8763.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35972 datums Tape Subfile: 5 155 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8786.0 9340.0 8799.0 9352.0 BASELINE DEPTH 8763.0 8814.0 8821.5 8824.5 8825.5 8828.0 8828.5 8869.0 8880.5 8896.5 8907.0 8910.5 8914.0 8915.0 8918.0 8927.0 8938.5 8943.0 8952.5 8988.5 8991.0 9004.0 9015.5 9020.5 9024.0 9042.5 9060.5 9063.5 9075.5 9077.5 9085.5 9090.5 9106.5 9114.5 9119.0 9120.0 9123.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH GRCH SGMA 8763.0 8763.0 8813.5 8821.5 8824.5 8825.5 8869.5 8881.5 8897.5 8908.0 8919.0 8927.5 8953.0 8989.0 8991.0 9004.0 9015.5 9020.0 9023.5 9042.5 9075.5 9087.0 9091.0 9115.0 9120.5 8827.5 8828.5 8880.5 8912.0 8915.5 8916.0 8919.0 8939.0 8943.5 9060.5 9063.5 9078.5 9107.0 9120.0 9124.0 9136.5' 9177.0 9178.5 9182.0 9185.5 9192.0 9197.5 9202.5 9232.5 9237.0 9240.0 9248.5 9251.0 9251.5 9254.5 9310.0 9311.5 9313.5 9316.5 9317.5 9331.0 9362.0 $ REMARKS: 9137.0 9177.5 9179.0 9183.0 9186.5 9193.0 9197.5 9203.5 9234.0 9238.0 9241.5 9249.5 9252.0 9253.0 9256.0 9313.0 9313.0 9316.5 9319.5 9319.0 9332.0 9362.0 9362.0 30 BBL SEAWATER FLUSH PASS. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ CN : BP EXPLORATION WN : S - 26 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 GRCH PDK 68 1 GAPI BIF PDK 68 1 BKL PDK 68 1 CPS BKS PDK 68 1 CPS CSLS PDK 68 1 CU LS PDK 68 1 CPS SS PDK 68 1 CPS MSD PDK 68 1 CU RATO PDK 68 1 RBOR PDK 68 1 RICS PDK 68 1 RIN PDK 68 1 SGMA PDK 68 1 CU SGMB PDK 68 1 CU 4 4 06 511 09 0 4 4 00 201 24 1 4 4 39 705 61 6 4 4 74 169 61 6 4 4 00 201 24 1 4 4 71 162 89 6 4 4 05 626 89 6 4 4 00 201 24 1 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 96 761 61 6 4 4 00 201 24 1 * DATA RECORD (TYPE# 0) Total Data Records: 75 966 BYTES * 56 Tape File Start Depth = 9362.000000 Tape File End Depth = 8763.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 53958 datums Tape Subfile: 6 164 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8778.0 PDK 8790.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9332.0 9344.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 17-JAN-93 FSYS256 REV:G002 VER:2.0 1330 17-JAN-93 9390.0 9364.0 8800.0 9352.0 1200.0 YES TOOL NUMBER 2725XB 2324NA 2120XA 0.000 9433.0 0.0 PROD. FLUIDS/BORAX 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 1200 FAR COUNT RATE HIGH SCALE (CPS) : 3200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 60000 TOOL STANDOFF (IN): 0.0 REMARKS: BASE FLOWING PASS. $ CN : BP EXPLORATION WN : S - 26 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO.PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SS PDK 68 1 CPS 4 22 SPD PDK 68 1 F/MN 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 32 125 68 0 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 05 626 89 6 4 05 626 89 6 88 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 213 Tape File Start Depth = 9347.000000 Tape File End Depth = 8763.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 89724 datums Tape Subfile: 7 288 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last fi~e. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8786.0 PDK 8798.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 9346.5 9359.0 17-JAN-93 FSYS256 REV:G002 VER:2.0 1459 17-JAN-93 9390.0 9364.0 8800.0 9352.0 1200.0 YES TOOL NUMBER 2725XB 2324NA 2120XA 0.000 9433.0 0.0 PROD. FLUIDS/BORAX 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 1200 FAR COUNT RATE HIGH SCALE (CPS): 3200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: BASE SEAWATER FLUSH PASS. $ CN : BP EXPLORATION WN : S - 26 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SS PDK 68 1 CPS 4 22 SPD PDK 68 1 F/MN 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 32 125 68 0 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 05 626 89 6 4 05 626 89 6 88 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 216 Tape File Start Depth = 9362.000000 Tape File End Depth = 8770.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 108446 datums Tape Subfile: 8 291 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8786.0 PDK 8798.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9343.0 9356.0 17-JAN-93 FSYS256 REV:G002 VER:2.0 1622 17-JAN-93 9390.0 9364.0 8800.0 9352.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ TOOL NUMBER 2725XB 2324NA 2120XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 9433.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG): PROD. FLUIDS/BORAX 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 1200 FAR COUNT RATE HIGH SCALE (CPS) : 3200 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN) : REMARKS: 60 BBL BORAX AWAY PASS. $ CN : BP EXPLORATION WN : S - 26 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SS PDK 68 1 CPS 4 22 SPD PDK 68 1 F/MN 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 32 125 68 0 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 05 626 89 6 4 05 626 89 6 88 * DATA RECORD (TYPE~ 0) 1018 BYTES * Total Data Records: 213 Tape File Start Depth = 9359.000000 Tape File End Depth = 8775.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 143476 datums Tape Subfile: 9 288 records... Minimum record length: Maximum record length: 62 bytes 1018 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8785.0 PDK 8797.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9346.0 9358.0 17-JAN-93 FSYS256 REV:G002 VER:2.0 1717 17-JAN-93 9390.0 9364.0 8800.0 9352.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ TOOL NUMBER 2725XB 2324NA 2120XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 9433.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PROD. FLUIDS/BORAX 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 1200 FAR COUNT RATE HIGH SCALE (CPS): 3200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: 120 BBL BORAX AWAY PASS. $ CN : BP EXPLORATION WN : S - 26 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SS PDK 68 1 CPS 4 22 SPD PDK 68 1 F/MN 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 32 125 68 0 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 05 626 89 6 4 05 626 89 6 88 * DATA RECORD (TYPE~ 0) 1018 BYTES * Total Data Records: 216 Tape File Start Depth = 9362.000000 Tape File End Depth = 8770.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 162934 datums Tape Subfile: 10 291 records... Minimum record length: Maximum record length: 62 bytes 1018 bytes Tape Subfile 11 is type: LIS FILE HEADER FILE NUMBER: 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 5 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8785.0 PDK 8797.0 $ LOG HEADER DATA STOP DEPTH 9345.0 9357.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 17-JAN-93 FSYS256 REV:G002 VER:2.0 1813 17-JAN-93 9390.0 9364.0 8800.0 9352.0 1200.0 YES TOOL NUMBER 2725XB 2324NA 2120XA 0.000 9433.0 0.0 PROD. FLUIDS/BORAX 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 1200 FAR COUNT RATE HIGH SCALE (CPS): 3200 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS) : 60000 TOOL STANDOFF (IN): REMARKS: 30 BBL SEAWATER FLUSH PASS. $ CN : BP EXPLORATION WN : S - 26 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SS PDK 68 1 CPS 4 22 SPD PDK 68 1 F/MN 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 32 125 68 0 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 05 626 89 6 4 05 626 89 6 88 * DATA RECORD (TYPE# 0) Total Data Records: 216 1018 BYTES * Tape File Start Depth = 9361.000000 Tape File End Depth = 8768.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 198056 datums Tape Subfile: 11 291 records... Minimum record length: Maximum record length: 62 bytes 1018 bytes Tape Subfile 12 is type: LIS 93/02/25 01 **** REEL TRAILER **** 93/ 2/26 01 Tape Subfile: 12 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 26 FEB 93 3:37p Elapsed execution time = 1 minute , 29.2 seconds. SYSTEM RETURN CODE = 0 3~OQg H~ON t NOZ~VaOq. a. X3 ~ ~ HDDO~O~ ~N ~.N~N [N~WOD qM~ ,09~[ '9 q.N~ ,~E9I 3~09~ iH~ON :H9~O~O~ ~V9 ~OHO~ :Qq2i~ oq : 3dX£ 3qIJ /90/06 : 90~00 ~ NOi~83A DIq~ : 3DIA~3~ &IQ3 : 3d¥I 9~0IA3~ l : # NOi~V~NItNOD t68£L DlgA : NIDI~O /90/06 : q33H 9flOIA384 : # NOIiYaNIANOD Dlq~ : NIDISO /90/06 £1~3 : 3~N 3DIA~ u~s~q uo;~ea~I~aA edei si cblumberger Alaska Computln~ Center I-jUN-1990 12:12 LOG MEASURED FROM RKB ELEVATIONS KB: 66.6 24-MAY-1990 1 9436 9436 DATE LOGGED: RUN NUMBER: TD DRILLER: TD LOGGER: ABOVE PERMANENT DATUM DF: 65,1 GL: 35.6 CASING: 9 5/8" ~ DRILLER DEPTH OF 8~16 AND LOGGER DEPTH OF 8811 BIT SIZE: 8 !/2" TYPE FLUID IN HOLE: LOW SOLIDS DENSITY: 9,1 VI$COSITY~ 35 PH: 9,5 FLUID LOSS~ 8'0 MUD RESISTIVITY: 3 66 ~ 56 FILTRATE RESISTIVITY: 4:03 ~ 56 MUD CAKE RE$I:$TIVITY: 3.78 $ 56 TIME CIRCULATION ENDED: 13:00 24-MAY TIME LOGGER ON BOTTOM: 19:45 ~XIMUM TEMP RECORDED: !84 bOGGING DISTRICT: PRUDMOM BAY LOGGING ENGINEER~ SARBER WITNESS: BLUNDELL/SIOK TOOL NUMBERS: SGC-JC-3109 CNC-A-~286 S.ALC-MA-~55 SLSsWA~200.4 DIC-DA~IO06 IEM'BD'I448 SL~-DA"1552 NLM-BC-~338 FIEND RE~ARKS~ TOOL. STRING (BOT-TOP) i,5" RUBBBER STANDOFFS AND A ~5' MOIRE FINDER USED ONTHE DiL AND 8MC, A BOWSPRING~ USED ON THE"CNL' NEUTRON ~ATRIX USED ~ SAND, ~OLE DATE JOB STARTED: 3~-MAY'90 JOB REFERENCE NO: 73891 LDP/ANA: KOHRING PAGE: FILE - EDIT,O0~ BP EXPLORATION PRUDHOE BAY S-26 (22-35-12-12) 15 Tape verification Listing ch!umberger Alaska Computing Center 1-JUN-1990 12:12 * 50-029-22047 , , , * DATA SAMPLED EVERY * DATA INCLUDED - , * TOOL EXTENSION ~ TYPE USED * DIT-D ,DIL * BHC ,BHC * CNT-A/D/H ,CNL -,5000 FEET TOOL NANE DUAL INDUCTION SFL BOREHOLE COM, ENSATED SONIC COMPENSATED NEUTRON 9427' TO 8811' 9398' TO 8811' 9382' TO 6595' PAGE{ 3 TABLE TYPE : CONS TUNI VALU ?T FT FT FT FT Bp EXPbORATZON PRUDHOE. BAY $-2.,6_(22-35-12 1 ) · .50_"029'22047 2, 1635' rNb& t'160 35 12E NORTH SLOPE ALASKA USA 5491 0, RKB 66,60001 65,10001 35,6 9436,' 9428, 88!1. 11:00 24-~AY CN WN API~ FL SECT RANG COUN STAT Ni!TI WlT~ PDAT EPD APD TDD TL I TCS FWL DEFI Compan[ Name Field .amc ~e~l Name APl Serial Number Fiel Location Section ?o~nship Range iounty tare or Province Nation witness' Name ServiCe Order Number Permanent datum bog Measured from Bottom bog Interval ToP boo'Interval Time Circulation-stopped Time Logger At Bottom TbAB 19:45 24-~AY i 99 89 99 0 99 89 ' 89 8 59 KL 9 99 ~ 99 O0.I EL 0 99 0 99 m~aBO~d uot3e~'TTdd~ u~ moa3 3nd%nO ~3T~o~od uo~3neN ~OdN A3'ImOaOd uo~3neN ~emzeq~ HdN~ -~3~so~od uoa3'neN uo~sue~ Iei~u~3od snoeue3uoas dS uo~su~ te~ue}od snoeueluoas xl~At~s~sea passe3oad p~epue3g uoTl~npu! mn e~eN Ieuueq3 q~deO emammmmmamameamalaaaaammammmamamammmamaaaammmmmmmmmmammmmmm ~e3ue3 bu~3ndmo3 e4sel~ ~eb~eq~nZq~ buI3stq uol%e3i~iaeA ade&'~i Tape verification Listing chlumberoer AlasKa ComPuting Center 1-dU~-lggO 12:12 PAGE: TYPE REPR CODE VAbUE 0 66 0 ILD DIL OHPP 549178 IL~ DIL OH~P 5~9178 SFLU DIL OH~P 549178 SP DIL MV 549178 GR DIL GAPI 549178 T~S DI.L LB 549178 DT BHC US/F 549178 TT1 BHC S 549178 TT2 BHC S 549178 TT3 BHC $ 549178 TT4 BBC US 549178 SP BHC ~V 549178 G~ BHC GAPI 549178 TENS BHC 58 549178 NPMI CN5 PU 549178 TNPH CNL PU 549178 TNRA CNL 549~78 NPOR CNL PU 549.78 RCNT CNL CPS 549178 SET TYPE ~ s~;v, ~ '"'""'"'"'"""'"'"'"'""'"' '""""'"" .. AP! APl APl API FIbE NU"B NUNS SIZE PROCESB ~~~;~~;~;~~~~~~~~~~~~;;~~~"~"~ ~., s t,ooooo oo o , ~ ~ ~ ~. oooooooo o~i{~ ~ o, , , ~ ~.oooooooooo o~~ o, , , ~ ,.oooooooooo o~~,o o, o, , , ~ ~,oooooooooo o~~ ~,o, , , ~ ~ oooooooooo o~~,o o, o, , , ~ ~.oooooooooo o~~{o o,, , , ~ ,.oooooooooo DATA DEPT. TSP DIL T1BHC TNSP 8HC CNL RCFT CNL TENS,CNL DFPT. TT1BHC _NSP BHC T":'PH RC'FT CNL 9448,000 -~2,469 0,001 '32,.469 24,483 1183,763 3210.000 9400 000 -69 500 0 001 =69 500 24 483 1183 763 ILD DIL GR DIL TT2 B~C GR BHC TNRA CNL CSTC CNL ILD GR TT G~ BH'C TNRA CNL C~TC C~L 0 26 279~ 1 26 279~ 652 IL~ OIL 078 TENS OIL 000 TT3 BHC 078 TENS BHC 363 NPOR CNL 147 CFTC CNL 6~3 IL~ ov~ yf] T~ ~ 000 BH.C 078 TENS BHC 363 NPOR CNL 147 CFTC CNL 5 3210 0 3210 24 1201 114 SFLU,DIL 000 DT.BHC 001 TT4,.BHC 83 RCNT'CN~ t 706 SFLU 4684 000 DT BHC 0 i TT4 BHC CNL ,90':.50:0 425'000 ~24'365 ~2917,404 ~26.078 3,648 :90~563 416,250 :24'365 ~:29t7,404 :26,078 I$ e Verification LiSting Ta-e~ Alas a tng Center chlum rger k Compu DEPT, SP.DIb ?T! BHC SP:BHC TNPH,CNL RCFT.CNE TENS,CNL DEpT, SP,Dlb TTI,BHC SP,BHC TNPH,CNL RCFT,CNL TENS,CNL DEPT SPDIb TT1BHC SP BHC TNPM CNb RCFT CNL TENS,CNL DEPT SPDIB TT! BBC SP BHC TNPH CHh RCFT CN5 iTENS CNL DEPT, SP'DIL sp~s~c RCFT[ Nb TFNS Nb DEPT, SP.DIL $P,BHC TNPH'CNL RCFT,CNb T.EM$*CNb DEPT' .TT!,BHC 4684.000 9200.000 ILO.OIL '46,031 GR,DIL .4~,001 TT2.BHC ,031 GR.BHC 25.760 TNRR,CNL !194.164 CMTC.CNL 4620'000 9100.000 IbD,DIL =51.500 GR,DIL 0,001 TT2.BHC '51~,500 GR..BHC '25,555 TNRA,CNL 1135,I29 CNTC,C'Nb 4624.000 9~00,000 ILD.DIL 52,031 GR,:D.IL 0,001 TT2.BHC .-52'031 GR'BHC 25,303 TNRA,CNb 1!62'577 CNTC,CNL 4568,000 8900,000 !LO,OIL 2§,484 GR.,DIL '001 TT2'BHC 22,484 GR,BHC 27'~54.4 TNRA~CNL 887,2!7 CNTC,CNL 4584'000 . 1-jUN-1990 12:12 09 ILS,OIL 88 TENS.DIL 000 TT] BHC 688 :BHC POR.CNL 47 CFTC.CNb 00 TT3.,BHC 59 TEN$.BHC 77 NPOR,CNL 86 CFTC.CNL 1.4 909 ;466 277~,890 TENS,OiL TT3,BHC NPOR,CNL CFTC,CNL 28:7:5,1.19 TENS,OIL TT3,BHC TENS.,BHC NPOR,CN5 CFTC'CN5 1:3. 2 8~::39 00o 25:~,954 TENS'OIL TT3,.BHC :TEN$,.BHC NPOR,CNb CFTC,CNL 8800,000 ILD.DIL 27,:01:2 'I07~000 GR'DIL 61'844 TENS,DXL 0,:000 TT2,BHC 6V~0008 TT'3,B.C -t07.,000. GR;BHC 44 ':TENS,BHC '236 TNRA;CNL ~'~i9 .NPOR,CML 4644,000 87. oo.ooo o'ott, 93'500 GR,DIb 0,000 TT2'BHC -93'500 GR'BHC 50.043 TNRA'C)~L 23,656 000 656 TENS IL T?3,.BHC TENS,BHC NPOR,CNb 2,378 4584.000 0,001 4584.000 28.622 1240,953 4'519 4620.000 0.001 4620.000 25.463 1149,035 14,032 462~,:000 ,:001 4624;000 ~25.1i8 '::I156,~276 16-542 4568'000 o'ool 4568',0:00 120~'i301 4584.~000 0;001 4584.000 ,674 1:0 ,443 :2ooo'ooo .,~:000 464~ ,000 4644.000 ,.566 2000.000 4652.000 0 .:000 4652 ' 000 50~35~ 8FLU.DIL DT,.BHC TT4,BHC NPH~-,CNL RCNT,CNL GR,CNL :$FLU,.DIL DT,.BHC x?4-s~c NPHI~-CNL RCNT,,CNL . .GR,:CNL SFLU.DIL D~,BHC TT4.,BHC NPH~.:CNb RCNT,CNL ~GR-CNL SFLU.DI'L DT'BHC ?T4,BHC NPHI:,CN~ RCN~-CN~ GR,~CNL SFLU,:.DIL DT,BHC TT4"BHC NPHI.,CN~ RCNT,CN5 GR,CNL DT,BHC ~TT4..BHC RCNT*CNL GR,:CNL DT .BHC :TT4 8HC 'RCNT ..CNL PAGE{ 5,932 90,063 404,750 :26,454 3179,.716 22,688 14,602 85'000 402,250 :':29i7,542 22,359 20,973 86,000 400,250 ,.25,.89'7 !'293~.'6.83 ,3~'.:766 :22,960 .83;000 :38~i:000 i2"~90 :3067'704 33,219 13.391 82,688 '366~250 ~27'802 '2274,10~ 81,938 :12,366 56;875 283;500 54,55! .1:233'097 :6!:,844 16,990 8 7 5 36 554 Tape verif~ication Ltstlnq chlomberger Alaska Computing Center RCFT CNL TrNS:C L DFPT, SP,Dlb TTt,BHC SP,BHC TNPN,CNL RCFT,CNL ?EN$,CNL DEPT, TT1,BHC SP,BHC TNPH,CNL RCFT CNb T.ENS~CNL TSP'DIL, T!,BHC SP,BHC TNPH,CNL TENS,CNL DEPT, TT!,BHC SP,BHC TNPH,CNL RCFT,CNL TT! BHC :$P BHC .TENS,.CNL DEPT i..SP~Dib TT!~BHC _uSP.aHC T!PH*CNL TENS~CNL DEPT. ~SP'D!L ..... 'TI.,BHC ~SP,BHC 327,~15 4652, O0 8600,000 999.250 999.250 999.250 '999,~$0 31§,219 456 ,000 8500,000 -99 250 '999.250 '999.250 490.961 4548,000 8400,000 -999, 50 '999,~50 :999,250 999'250 385,229 4488'000 8300,000 -999; -999;~5050 -999.250 -999.250 382,736 4404,000 s2oo'ooo :999,250 ~999,250 :~999,250 999,250 293,510 4400,000 loo'ooo -999,250 -999.250 -999.250 -999'250 426,61~ 4368.00 8000'000 -999~250 -999.250 -999,250 CNTC.CNL 1-jUN-1990 12:12 1114.802 CFTC.CNL 333,135 - 99. 5o TT2.BHC '999.250 TT$.BHC -999. 50 GR.BHC -999.250 TENS.BHC -999.250 TN~A CNL ~.263 NPOR,CNL -999.250 CNTC:C~L 129 .856 CFTC,CNL 301,265 ILD.DIL GR.DIL TT2.BHC GR BHC TNRA:CNL CNTC.CNL ILD'DIL GR,DIL TT2,BHC GR,BHC TNRA,CNL CNTC,CNL ILD.DIL GR'DIL TT2,BHC GR,BHC TNRA'CNL CNTC.CNL ILD.DIL GR~DIL TTR,BHC GR,,BHC TNRAj:CNb CNTC.CNL ILD.DIL GR.DIL TT2.BHC GR;BHC TNRA.CNL CNTC~CNL -999 -999 -999 -999 1566 250 IbM.OIL 250 TENS*DIL 250 -TT3,.BHC 250 TENS.BHC 328 NPOR.CNL 435 CFTC,.CNb '250 999,250 '99~,'250 ,777 1472,~52 TENS.OIL 'TT3,BHC TENS,.BHC. NPOR,CN5 CFT~,CNL -999.250 -999~.~250 -999':250 -999.250 3,828 ~432'743 TT],BHC TEN$~BHC NPOR'CN.b CFTC.CN5 '9~9,250 9,:2~0 ,905 :TEN$:,DX'L :TT3,.BHC NPOR,CNb CFTC,CNL -999250 -999 ~0 -999 210 '999.2§0 !52~'774 ,824 XLM,DXL TT3.BHC ~ENS,.BHC NPO.R,CNh CFTC,CNb '999,'250 -999.250 .-999;250 IL~.DIL T E.N $ * D X b TT] ,..BHC TENS,.BHC ILD. GR,DiL TT2 *BHC GR.BHC '999.250 '999. .999.~50 50 '999,250 '999,250 497.921 ~999,.250 999-,250 -999~2'50 -999.,250 -999,250 '999,250 ~999.250 .1999.250 '1999,250 999'250 .400,374 -999;,2$0 ~999~250 '999,:250 '308.237 :999,250 .999;:2S0 .999,-250 .999,250 999.250 424,:512 '999 25'0 -999:250 -999 250 -999 25:0 GR.CNL SFLU,DIL DT.BHC TT4~BHC NPHI..CNL RCNT.CNL GR.CNL SFLU,DIb D~.BHC TT4.BHC NPH{,CNL RCN~.CNL GR,CNL DT,.BHC :TT4'BHC RCNT:*CNL G'R,CNL SFLU,..DIb :D~,BHC TT4'.BHC NPHI*CNL RCN'T*C:N~ :GR'CNL SFLU,DIL DT.BHC ?T4.BHC NPH~,CNL RC~T~CNb :GR,CN~ SFLU'DI.b DT,.BH¢ NPNI~CNL CNT,CNL GR*:CN5 SFLU,.DIL DT*.BHC ?T4 ,BHC NPH.~ ~:CN~ PAGEI 61,656 '999,250 '999,250 '999,250 52.152 1332;209 68.~25 :"999.250 '999.250 :"999.250 ,827 ':39,594 -999,250 ::-999'250 :-999.250 .43'2~7 56,688 :~:'999'250 :999,250 :999.250 44,217 ~1444:'961 64,~88 :-999,250 :.-999,.250 ~52',323 143t"7:50 :66'000 ~::999,250 :999*,250 ::'999~250 43,225 iI. 60~061 49,281 ~'999'250 .'.'999,:250 999,:250 :36'190 Tape Verification Listing chlumberger AlaSka Computing: Center TNPH.CNL -999 250 TNRA. CNL RCFT.CNL 483!218 CNTC,"CNL TENS.CNL 4340 000 DEPT, 7900.000 IbD.DI5 TTI.BHC -999 50 TTI.BHC SP.BHC '999.250 GR.BHC TNPH.CNL '999 250 TNRA.CN5 RCFT.CNL 254:464 CNTC.CNL TENS,CNL 4328.000 DEPT. 7800.000 ILD"DIL SP.DIL -999 250 GR,DIb · TTI,BHC -999i250 TTI.BHC SP,BHC -999 250 GR,BHC TNPH.CNL -999 250 TNRA.CNL RCFT,CNL 346 581 CNTC'CN5 TENS,.CNL 4312,000 ' !'JUN-1990 1'2:12 388 NPOR,.CNL, '999.250 ILM.DIL -999,250 TENS.DI5 -999.250 TT3,BHC -999,250 TENS.BHC .498 NPOR.CN5 125 '87i CFTC,CNb "999.250 '999.250 '999,250 "999,250 4.029 1288.167 DEPT, !700.000 ILD,DIL '999,250 SP.DIb ,999.250 GR,DIb '"999'250 TT1,BHC ' 9'250 TTI,BHC -999'250 99"250 GR.BHC -999,250 T. PH,CNL -999,250 TNRA,CNL 4' TENSeCNL 4340,000 DEPT, !690,000 ILD,DI5 SP'DIL ~9~9;:250 GR'DIL TT!"B"C 99~.250 TT2'BHC TN~.BHC 99 ,250 GR..BHC :! *CNb "999,250 ?NRA~CN5 R. CFT,CNL 26~.397 CNTC'CNL TEN$'CNL 440..000 DEPT 7500.000 ILD,DI5 SP:DIL '-999,250 GR,DIL TTi,BHC :-999,~50 TT2.BHC SP'BHC -999,:250 GR,BHC TNPH,CN5 ."999,250 TNRA"CNL RCFT'CNL 381,720 CNTC.CNL !T~NS.CNb 4128,000 DEPT,: 1400,000 ILD,DIL SP,DI5 999,250 GR,DIL TT!,BHC -999~250 TT2.BHC TENS Nh 4144.000 ILM,DIL TENS TT3 BHC TENS .BHC NPOR CNb CFTC cab IbM,DIL .~TENS*DIb :TT3..BHC TENS'BHC CFTC':C~ :'999,250 '999,250 :'999.250 "999'250 ,I20 t1'9~.862 ~T3*.BHC ~?ENS,BHC NPOR,CNb ~CF?C,CN~ "999.250 '999,2~0 "9'99;2 0 250 T~3*BHC TENS,BHC NPOR,CN~ CFTC,.CN5 "999,250 '999, 5 "999.2 0 '~ILM,DiL :TENS,DIL T?3.BHC ?ENS'BHC NPOR,CN~ CFTC~CN~ -999.250 490.138 '999.250 '999,250 -999. -999.~5°50 -999,250 296.244 '999.250 -999,250 '999,250 '999,:250 "999,250 :'343,276 -999 ~50 50 0 "999,250 324'§~3 - §9,250 ;'999.250 -999.250 :"999,2.50 296,733 ::999'250 ::999,250 ::999'250 "999':250 ~37i:,247 :-999,:250 .-999,250 -999,~2:50 -999,:250 -999'.250 304,?94 RCNT,CNL GR,CN[, SFLU.DIL DT.BHC TT4,BHC NPHI.CNL RCNT.CNb GR,CNL 'SF~V'DI~ ,BHC ?74,~.C NPHI,.CNL RCNT,CNL GR*CN5 . .BHC TT4;BHC NPHI,CN5 RCNT,~NL GR,CNL D~,.BHC TT4.BHC NPH~...CNL GR,CNL SFLU,.DIL :DT,,BHC NPHX*:CNL RCNT'CNL TT4.BHC NPHI:~.CNL RCN. T~CNL :GR'CNL PAGEI 1725.984 41.688 '999,250 '999.250 '9~9,250 6,437 1:2~6.683 1,344 :-999~50 :;-999:. 5o 9,250 '"9~7,885 ~"999',250 :'999,250 :::"999,250 .50,819 1392,i25 59,53i :-999,250 :-999,250 .:-999.250 49,531 -999..150 '999,.~50 "II: {, 146"031 "999 ~0 :"'999~;~50 !~36' 5. $ ,~ 5 65 IS Tape verification Listing chlumberger Alaska Com..Puting Center DEPT, 7300.000 ILD.DXb SP,DIL -999,250 GR,DIb BHC -999,250 TT2,BHC TNPH CNL -999,250 TNRA,CNb RCFT!CNh 303.460 CNTC,CNB TENS CNE 4054,000 DEPT. 7200.000 lbo DEL SP Plb -999,250 Gm,DEb TTI~BHC -999.250 TT2,BHC SP,BHC '999,250 ~GR.BHC TNpH,CNL '999.250 TNRA,CNb RCFT.CNL 322,156 CNTC,CNL TEN$.CNL 4030.000 DEPT 'SP TT1BHC SP BHC TNPH CNL ReFT TENS CNL DEPT, TTI,BHC SP.BHC TNPH,CNL RCFT~CNb ~TENS'CNb DEPT, 'TTI'BHC SP'.BHC TNPH,CN~ RCFT-CNb DEPT, SP,PI~ TT~,BHC ~$P,BHC TNP~,CNb TI: HC SP RCFT'CNb !-JUN-1990 12:12 -999,250 iL~.DIL -999,250 TENS,DIL -999,250 TT3,BH¢ '999.250 TENS*.BHC 3.944 NPOR.CNb 1246,101 CFTC.CNb -99~ 250 IbM.DIb -99 ~250 TEN$.DX~ -999.250 TT),BHC "999.250 TEN$.BHC 4.~4~ NPOR.CNL 1278,754 CFTC.CN5 -999.250 -999.250 -999~250 -999.250 '-999.,250 '308,-667 '999,250 '999-250 '999,250 =999,250 '999,,250 328,014 7100.000 IbD,DIL '99~ i~O IbM.Bib ~999.250 '999,250 GR.DIb -99 :. 0 ~T£NS.DI~ .999,250 '999~250 TT2,BHC "999,250 TT3,.BHC .999~250 740 NPOR,CN~ -999.250 -999,250 TNR. A,CN~ ~'9 5 CFTC, 356,416 CNTC,CN~ 136 5 CN~ '.~60,970 3894'000 ' ' ' 7000,000 IbD,DIL -9~9'.25 -999,250 GR,DI5 '9 9,25~ ~'999250 TT2,BHC -999.,2 g '999:'250 ~GR.BHC '999,2 -999'250 TNRA,CNL ~ 42 326,543 CNTC,CNb 129 :~08 3980'000 GR.DIL TT2,BHC GR'BHC TNRA~CN5 CNTC'CN5 6900,000 ~999,~50 .999,250 1999,250 ~999'250 337.0~0 3854'000 "IbM,DIb iTT]'BHC ~TENS,.BHC NPOE-CN5 CFTC'CNL -999,250 -999,250 " 9-50 ~TEN$,Dib: :TT3,BHC' :?EN$,.BHC~ NPOR,CNb ~CFTC,CNb '999 '999 '999 '999 4 I198 50 :TT3,,.BHC 50 'TEN$'BHC 474 NPOR~CN~ 903 CFTC,CN5 -999. 50 -999~50 -999. 4,422 1232,179 IL~..:DIb TENS.DIL TT3,.BHC TENS,.BHC NPOR,CNL CFTC,CNL 6800.000 IbD.Dlb "999.250 GR'DIL · '999'250 TT2;BHC '999~:250 :GR,BHC -.999'250 TNRA,CN~ 295'390 CNTC,CN5 3854.000 6.700.000 ibD.DIb -999,250 GR,Dib · '999'R50 TT2'BHC -999'250 GE'BHC .-999.250 TNRA~CN~ 295'390 CNTC~CNL 37~4,000 ~999,.250 .999,250 -999,,.250 -999'~250 -999,.250 34t':043 ,'999,250 :'999-250 '999~2:50 "999~':250 :'999,.250 .336,658 '~999-250 999.250 '999,250 .-999:,::250 '999-250 "281,691 "999.:250 .999'250 .999'.250 999,.~50 '300.554 SFLU,DEL DT,.BHC TT4.BHC NPHI,CN~ RCNTeCNb GR,CNL SFLU,D][b DT,BHC TT4..BHC NPHI,CNb RCNT,CNb GR-CNb srbu OIL D~ BHC TT4 BHC NPHI. CNb RCNT CNL ..8rbU,Dlb .DT;BHC ~?T4,.BHC 'NPHI,CNb RCN~"CNb GR~CNL SFbU,DIb iT~4.BH¢ NPHI:~CNb ECN'T'CN~ GR,.CNb DT-BHC ~TT4;BHC RCNT'CN~ GR,CN5 SFLU..DiL DT,BHC TT4,BHC NPHI.:,iCNL RCNT,.CNL GR,CN.~ PAGE= ~999"250 999'250 '999,250 46'330 1365"515 55~594 "999,250 "999~250 "999,250 .53,607 1268~'1~00 '59,469 '999.'250 "999~250 '999,250 42,604 1.474.1,25 49,531 :999,::50 :,,,.:.)so .999,:250 1332,~ '~:999~250 999~250 46,479 1234'995 55,250 -99 50 -999,~ 5,9 0 · 06 3 :'99 50 55;~037 Tape Verification Llsttng chlumberger Alaska Computing Center t-JUN-1990 12=12 PAGE= DEPT, 6600,000 ILD DIL SP,DIL -999,250 GRiDIh TTI.BHC '999.250 TT2 BHC SP.BHC '999,250 GR,BHC TNPH.CNL '999.250 TNRA,CNL RCFT CNL 307.631 CNTC.CNL TENS:CNL 3720.000 DEPT. 6594.500 ILD.DIL T~.BHC '999"250 TT2oBNC .BHC -999.250 GR,BNC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL 329,233 CNTC.CN5 TENS.CNL 3834.000 END OF DATA -999,250 -99 -99~ 250 25O -999 250 4 005 t242 857 '999,250 -9 '250 -999,250 IbM.OIL TENS,DXb TT3..BHC TENS.BHC NPOR.CN5 CFXC.CNb ~IbM.DXb TENS.OIL TT3,.SHC TENS,BHC NPOR,CNL CFTC,CNL -999,250 SFLU.DIb :999.250 DT'.B,C 999.250 TT4,BHC -999,250 NPH~,CN~ -999"250 RCN~.CNL 30!.570 GR,CNb · :999.250 SFLU,DIb .999.250 DT,BHC .999,250 TT4,BHC .999.250 NPHZ.CNb 999-250 RCNT,CN5 331.425 GR-CNL -999~250 -999,250 -999,~250 1267.8 80,t88 -999,250 -999,250 ~999.~250 43;9?2 t369~20 :77,'81:3 **** FILE TRAILER **** FiLE NAME = EDIT .,00I SERVICE : FLIC VERSION = O01A04 DATE = 90/06/ ! MAX AEC ~SIZE ~ 1024 .FILE TYPE = LO LAST FILE = **** TAPE TRAILER **** ,SERVICE NAME : EDIT DATE ; 90/06/ 1 ORIGIN : FL!C TAPE NA~E : 73891 CONTINUATIOn,! # : l P. EV!OUS :TAPE : COMMENT : BP, PRUDHOE BAY, S-26 .,C22"35'12-12), API ~50-0~9-22047 **** REEL TRAILER SERVICE NAME = EDIT DATE ORIGIN REEL NAME ~ 73891 CONTINUATION 8 : PREViouS REEL CON~ENT : BP, PRUDHOE BAY, $-26 (22-35-12-12), API #50-029-22047