The URL can be used to link to this page

Home My WebLink About203-012Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 S-117 203012 500292313700 3 9/19/2023 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, December 27, 2017 5:54 PM To: AK, GWO Well Integrity Engineer;AK, GWO SUPT Well Integrity;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS WELL PAD 5;AK, OPS Well Pad SW;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;Youngmun,Alex; Regg,James B (DOA);AK, GWO SR Slickline WSL;AK, GWO SR Fullbore WSL Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau;O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA); Romo, Louis A;AK, GWO Well Integrity Well Information Subject: OPERABLE: Producer S-117 (PTD#2030120) Barriers confirmed with a passing TIFL All, Producer S-117(PTD#2030120) was made under evaluation on 12/26/17 so that it could be brought online to diagnose a NOL excursion that occurred in October. The well was POP'd on 12/26 and a passing warm TIFL was performed on 12/27. The passing TIFL confirms integrity of the primary well barrier. At this time the well is reclassified as Operable. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 SCANNED .. ' Cell: 907-341-9068 ,Iro From: AK, G '. Well Integrity Engineer Sent: Tuesday, De - ber 26, 2017 7:43 AM To: AK, GWO SUPT Well ;•rity; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PC a Lead; AK, OPS Prod Controllers; AK, OPS WELL PAD S; AK, OPS Well Pad SW; Ak, Ops West Area TL; AK, RES GPB East - Opt Engr; AK, RES GPB West Wells Opt Engr; Youngmun, Alex; "Regg, James B(DOA) (jim.regg@alaska.gov)' (jim.regg@a a - •ov)'; AK, GWO SR Slickline WSL; AK, GWO SR Fullbore WSL Cc: AK, GWO DHD Well Integrity; AK, GWO Projects ! Integrity; AK, GWO Completions Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Danie, ' .n; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis 3; Munk, Corey; Obrigewitch, Beau; O'connor, ; herine; Sternicki, Oliver R; Worthington, Aras 3; "chris.wallace@alaska.gov' (chris.wallace@alaska.gov)'; Romo, Louis A; GWO Well Integrity Well Information Subject: UNDER EVALUATION: Producer S-117 (PTD#2030120) Sustained inn- .nnulus casing pressure above NOL • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, December 26, 2017 7:43 AM To: AK, GWO SUPT Well Integrity;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS WELL PAD S;AK, OPS Well Pad SW;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;Youngmun, Alex; Regg, James B (DOA);AK, GWO SR Slickline WSL;AK, GWO SR Fullbore WSL Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA); Romo, Louis A;AK, GWO Well Integrity Well Information Subject: UNDER EVALUATION: Producer S-117 (PTD#2030120) Sustained inner annulus casing pressure above NOL All, Producer S-117 (PTD#2030120) was made not operable on 10/18/17 for having sustained inner annulus casing pressure above NOL. The well did not go under evaluation on the 18th due to rig simops preventing repair/diagnostic work. The rig is now off the pad and the well is accessible for well work. At this time the well is reclassified as Under Evaluation so it may be brought online for a warm TIFL. Plan Forward 1. Operations—POP well UE 2. DHD—Warm TIFL 3. Slickline—(Pending) Change out screened orifice gas lift valve 4. DHD-(Pending)Warm TIFL 5. Well Integrity Engineer—Additional diagnostics as needed Please respond if in conflict, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, October 18, 2017 2:12 PM To: AK, GWO SUPT Well Integrity;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS WELL PAD S;AK, OPS Well Pad SW;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Frankenburg, Amy; Peru, Cale; Rupert, C. Ryan; Shriver,Tyson;Wellman,Julie; Youngmun,Alex;Zoesch, Eric; Regg,James B (DOA);AK, GWO SR Slickline WSL;AK, GWO SR Fullbore WSL Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA) Subject: NOT OPERABLE: Producer S-117 (PTD#2030120) Sustained inner annulus casing pressure above NOL All, Producer S-117(PTD#2030120)was reported to has sustained inner annulus casing pressure over NOL on 10/17/17. The pressures were reported to be T/I/O=2270/2100/Opsi. The well failed a subsequent cold TIFL. Due to Parker 272's foot print on 5-200, well work on 5-117 will be delayed until the rigs departure. The well is now reclassified as Not Operable. Plan Forward: 1. Slickline—Change out screened orifice gas lift valve, 2. Slickline—(Pending)set TTP& MIT-IA. 3. DHD-TIFL, monitor IA pressure. Please respond with any questions, Matt Ross (Alternate: Josh Stephens) SCANNED 7EB 2 ) 2ril Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, June 18, 2017 2:35 PM To: Regg, James B (DOA) Cc: Wallace, Chris D (DOA);AK, GWO SUPT Well Integrity;AK, GWO DHD Well Integrity Subject: Producer S-117 (PTD#2030120) High Inner Annulus Pressure Over NOL after pad shutdown. Mr. Regg, Gas lifted producer S-117 (PTD#2030120),were reported over NOL on 6/16/17. The pressures were reported to be T/I/O = 20/2010/Opsi . The high pressure event was discovered after a pad shut down and appears to be caused by a spike in the gas lift supply header pressure. The plan forward is to bleed the IA and perform follow up monitors to ensure this is not an integrity issue; if we see any repressurization the well will be made under evaluation at that time. Please reply with any questions, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 SCANNED JUN 2 S 2017, • • 4,000 3,800 3,600 - 3,400 - 3.200 3,000 - 2,800 - 2,600 - 2,400 - 2,200 - 2,000 - 1,800 - 1,600 - 1,400 t t a f -411V-0-41.--..-^0-0---.11, 1,2000 - 1,000 - 800 600 400 - 200 03/16/17 0323/17 03/30/17 CA 06:1 04/1117 01'2 '17 04'2 2 Image J.. ,bject Well History File CcJer Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. do 3 - OJ d Well History File Identifier Organizing (done) D Two-sided 111111111I111111111 D Rescan Needed I RESCAN DIGITAL DATA ~skettes, No. \ D Other, No/Type: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Color Items: D Greyscale Items: o Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: Scanning Preparation I x 30 =:=3D D Other:: Date: to.:}If D5 /5/ wrP· I I Date:t, :J.11·OS /51 I , + d.1 = TOTAL PAGES 5 J (Count~oe3 not indude cover sheet) IAA P Date: 10, r{). c¡ f). ì /5/ Y H mP BY: Helen ~ Project Proofing BY: Helen ~ BY: Helen (Maria") BY: Production Scanning Stage 1 Page Count from Scanned File: \. ç~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO Date:fo.;;"'1. OS" Is! YES NO Helen ..~ VVlP Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: Helen Maria Date: /5/ 111111111111111111I 1111111111111111111 1 I Date: /5/ Quality Checked 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: • • Anchorage, Alaska 99519-6612 June 25, 2009 k~~ ~~~~~~,~f~~~ J Mr. Tom Maunder ~~L ~ ~, 2009 Alaska Oil and Gas Conservation Commission ~;~_~~p:~~~ ~e~ ~, r~r ~~nre C~cnmi~~'s~€~ 333 West 7t~ Avenue ~~~~~~~~~ Anchorage, Alaska 99501 o2~3-Q1a- Subject: Corrosion Inhibitor Treatments of S-Pad S --~~.~'~: Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~:~~~~~j~~ ";' `, ~ ~~~r` ~ ~ii. ~ Torin Roschinger BPXA, Well Integrity Coordinator L~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Spad / omA 6/25/2009 Well Name PTD # Initial rop of cemant Vol. of cement um ed Final top of cement Cement rop off date Corrosion inhibitor Corrosion inhibirod sealant date ft bbis ft na al 5-016 1952020 025 NA 0.25 NA 2.6 5/30/2009 S-02A 7941090 025 NA 0.25 NA 1.7 5/25/2009 S-03 1811900 1325 NA 13.25 NA 92.65 5/20/2009 S-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1957890 0 NA 0 NA 0.9 5/26/2009 5-06 7821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 5-088 2010520 0 NA 0 NA 0.85 5/27/2009 S-o9 1821040 7.5 NA 1.5 NA 9.4 5/37/2009 S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 5-118 1990530 025 NA 025 NA 1.7 5/27/2009 S-12A 1851930 025 NA 0.25 NA 1.7 6/1l2009 5-13 1821350 B NA 8 NA 55.3 6/tl2009 S-15 1&40170 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-~s 1861160 075 NA 0.75 NA 22 5/19/2009 S-20A 2070450 025 NA 025 NA 1.3 5/19/2009 S-2t 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 S-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 5-23 7901270 025 NA 025 NA 1.7 5/25/2009 5-248 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-27B 203i68Q 0.5 NA 0.5 NA 2.6 5/31/2009 S-2B8 2030020 0.5 NA 0.5 NA 2.s 5/37/2009 S-29AL1 1960120 0 NA 0 NA 0.85 5/27/2009 S-3o 1900660 0.5 NA 0.5 NA S.i 5/37/2009 S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 5-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 S34 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 S35 1921480 0 NA 0 NA .e5in 5/31/2009 S36 1921160 0.75 NA 0.75 NA 425 5/27/2009 S-37 1920990 125 NA 125 NA 11.9 5/27l2009 S38 1921270 025 NA 025 NA 702 5/27/2009 5-41 1960240 1.5 NA 1.5 NA 7t,t 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5/30/2009 5-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 5-44 ~ 1970070 0.25 NA 025 NA 1.7 5/28/2009 S-to0 2000780 2 NA 2 NA 21.3 5/29/2009 S-107 2001150 125 NA 125 NA 71.9 5/29/2009 S402L1 2031560 125 NA L25 NA 71.t 5/31/2009 5-103 2001680 1.5 NA 1.5 NA 11.9 5/18/2009 5-104 2001960 1.75 NA 1.75 NA 75.3 5/20/2009 S-7o5 2001520 4 NA 4 NA s2.7 5/20/2009 5406 2010120 1625 NA 1625 NA t74.3 6J2/2009 S-107 2011130 2.25 NA 2.25 NA 28.9 5/78/2009 5-108 2071000 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 17.75 NA 11.75 NA 98.6 5/30/2009 S-111 2050510 2 NA 2 NA 19.6 5/30/2009 S-112 202i350 0 NA 0 NA 0.5 5/30/2009 5-713 2021430 1.75 NA 1.75 NA 22.1 5/18J2009 S-11aA 2021980 125 NA 125 NA tOZ 5/30/2009 5-715 2022300 2.5 NA 2.5 NA 272 5/29/2009 5-116 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 5717 2030120 1.5 NA 1.5 NA 75.3 5/29/2~9 5-118 2032W0 5 NA 5 NA 76.5 5/28/2009 5-179 2041620 1 NA 7 NA 52 5/30/2009 5-120 2037980 5.5 NA 5.5 NA 672 5@9/2009 S-121 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 S-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 5-124 2061360 1.75 NA 1.75 NA 11.9 5/26I2009 S-i25 2070830 2.25 NA 225 NA 20.4 5/28/2009 S-126 20770970 1.25 NA 125 NA 15.3 &1/2009 S20o 1972390 1.25 NA 125 NA 7a.5 5/28/2009 S-207 2001840 0 NA 0 NA 0.85 6/19/2009 5-213A 2042130 2 NA 2 NA 13.6 5/29/2009 5-2~5 2021540 2 NA 2 NA 18.7 6/1/2009 S-2t6 2001970 4.75 NA 4.75 NA 51 5/29/2009 5-217 2070950 025 NA 025 NA 7.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 S-401 2060780 16 NA 16 NA 99.5 6/2/2009 S-504 0 NA 0 NA 0.&S 5/28/2009 • • -.~.,- '• ~ 03~o~~zoos DO NOT PLACE =... ~~ ~~ ,~ ~, ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc /J~ DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Permit to Drill 2030120 Well Name/No. PRUDHOE BAY UN AURO S-117 MD 8325 ~ ------ TVD 7045 ~ Completion Date 5/1/2003 ,.- REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, PWD, RES, PEX, Sonic Well Log Information: Logl Electr Data Digital Dataset :-.,.~~p7' DMed/Frmt Number Name .2ð Directional Survey \, UP! ! EitY C Pds ! !"tOg ! Log '( tP C Pds !.eg.-/ C Pds !ÉÕ~~ ~g ¡~ C Pds ~ ! ¡ i:Er" i C Pds ¡ ~ ,log If ! i'm- C Pds i Log :~ (eo C Pds Directional Survey 12239 Rate of Penetration Rate of Penetration Gamma Ray 12239 Gamma Ray 12240 Caliper log 12239 L-tS- Veritiêãtion J",," W L Caliper log 12240 Sonic Sonic 12240 Neutron Neutron 12240 Density Density 12240 Induction/Resistivity Operator BP EXPLORATION (ALASKA) INC Completion Status 1-01L Samples No Current Status 1-01L fpf..f.¿ 17Ft.h ~~1 API No. 50-029-23137-00-00 UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Log Log Scale Media Interval Start Stop o 8325 Run No 1 25 25 Blu 25 Blu 25 2 o 8325 96 8325 96 8325 96 8325 96 8325 3176 8282 2 Blu 96 8325 3176 8282 25 3176 25 Blu 3176 25 3176 25 Blu 3176 25 3176 25 Blu 3176 25 3176 OHI CH Received Open 3/10/2003 Open 3/10/2003 Open 11/3/2003 Open 11/3/2003 Open 11/3/2003 Open 11/3/2003 Open 11/3/2003 Open 11/3/2003 Open 11/3/2003 8296 Open 11/3/2003 8296 Open 11/3/2003 8278 Open 11/3/2003 8278 Open 11/3/2003 8278 Open 11/3/2003 8278 Open 11/3/2003 8311 Open 11/3/2003 '- Comments Vision Gamma Ray Vision Gamma Ray Vision Gamma Ray Vision Gamma Ray Platform Express Borehole Profile Vision Gamma Ray Platform Express Borehole Profile Borehole Compensated Sonic Log Borehole Compensated Sonic Log Platform Express Neutron Density Porosity Log Platform Express Neutron Density Porosity Log Platform Express Neutron Density Porosity Log Platform Express Neutron Density Porosity Log Platform Express Array Induction Tool ~ DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Permit to Drill 2030120 Well Name/No. PRUDHOE BAY UN AURO S-117 Operator BP EXPLORATION (ALASKA) INC MD 8325 TVD 7045 Completion Date 5/1/2003 Completion Status 1-01L Current Status 1-01L ! (~ --- I nd uction/Resistivity 25 Blu 3176 8311 Open 11/3/2003 ~C Pds 12240 See Notes 25 3176 8311 Open 11/3/2003 ,..}kóg See Notes 25 Blu 3176 8311 Open 11/3/2003 ¡ : Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? ~ Chips Received? - Y / N Daily History Received? ~/N @N Formation Tops Analysis ¥ J ~4 Received? Comments: Compliance Reviewed By: ~ Date: ~O!J~ ~~ -" API No. 50-029-23137-00-00 UIC N Platform Express Array Induction Tool Platform Express Triple Combo Log Platform Express Triple Combo Log ~ ~03~OI8 11/3/2003 ScbluDlbepger NO. 3020 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5111 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Well Job# Log Description Date BL Color S-117 10564932 OH EDIT AIT/BHC/PEX DATA 02/22/03 S-117 10564932 PEX-AIT 02/22/03 1 S-117 10564932 PEX-NEUTRON DEN/POROSITY 02/22/03 1 S-117 10564932 PEX-TRIPLE COMBO 02/22/03 1 &03-0\ 9"- S-117 10564932 PEX-BOREHOLE PROFILE 02/22/03 1 S-117 10564932 BHC 02/22/03 1 S-117 40008650 OH EDIT MWD DATA 02/22/03 S-117 40008650 MD VISION GR 02/22/03 1 S-117 40008650 TVD VISION GR 02/22/03 1 CD ~' 1 j tyf}. .L{() 1 Jé)ó{ ~c¡ -~- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 RECEIVED NOV 03 2003 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TIN: Beth ~~~V\1k~ AI*, Oit " Gas CooS. CfJmmiIeion Andaonlge ReceiVedb~\lQ..<:: ~,--Ç)~\e--.~ Date Delivered: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well 1m Oil D Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4377' NSL, 4500' WEL, SEC. 35, T12N, R12E, UM At top of productive interval 3768' NSL, 2913' WEL, SEC. 34, T12N, R12E, UM X = 615248, Y = 5979915 10. Well Number At total depth 3758' NSL, 3012' WEL, SEC. 34, T12N, R12E, UM X = 615149, Y = 5979903 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Aurora Pool RKB = 64.4' ADL 028258 (Undefined) 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 2/17/2003 2/21/2003 5/1/2003 N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8325 7045 FT 8231 6953 FT 1m Yes 0 No (Nipple) 2208' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, PWD, RES, PEX, Sonic Classification of Service Well 7. Permit Number 203-012 8. API Number 50- 029-23137 -00 9. Unit or Lease Name X = 618930, Y = 5980580 Prudhoe Bay Unit S-117 23. CASING SIZE 20" 9-5/8" 7" WT. PER FT. 91.5# 40# 26# GRADE H-40 L-80 . L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 108' 42" 29' 3184' 12-1/4" 26' 8315' 8-3/4" CEMENTING RECORD 260 sx Arctic Set (Approx.) 589 sx PF 'L', 269 sx Class 'G' 230 sx Lite, 174 sx Class 'G' AMOUNT PUllED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 4 spf 2-1/2" Gun Diameter, 6 spf MD TVD MD TVD 8104' - 8118' 6830' - 6844' 7930' - 7950' 6662' - 6681' 7950' - 7970' 6681' - 6701' 7970' - 7990' 6701' - 6720' 25. SIZE 3-1/2", 9.2#, L-80 TUSING RECORD DEPTH SET (MD) 7871' PACKER SET (MD) 7812' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect wI 80 Bbls Diesel & 60 Bbls Dead Crude 8104' - 8118' 7930' - 7990' Frac'd A Sands: Placed 5,800# of 12/18 Carbolite behind pipe Frac'd C Sands: Placed 173,900# 16/20 Carbolite behind pipe 27. Date First Production May 9, 2003 Date of Test Hou rs Tested 5/9/2003 14 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR TEST PERIOD Oll-Bsl 54 Oll-Bsl GAs-McF 28 GAs-McF WATER-Bsl -0- WATER-Bsl CHOKE SIZE GAS-Oil RATIO 176/64 520 Oil GRAVITY-API (CORR) Flow Tubing Casing Pressure CALCULATED Press. 272 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit coR~C 1:::.1 V I::: U No core samples were taken. ;;.,',',:, ," S:¿;:9 ' ~¿P.....1..- ' ~":-t1ri~" ¡: c.... .., ~ t,~,~ _:: - -k.._ fIJt:tMs BFl Gj=:' JUN MAY 3 0 2003 ~ .Î!1n~ . . Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Ugnu 4221' Ugnu M Sands 5702' Schrader Bluff N Sandstones 5988' Schrader Bluff 0 Sandstones 6140' Base Schrader / Top Colville 6529' HRZ 7882' Kalubik 7920' Kuparuk C 7922' ì<uparuk B 8010' Kuparuk A 8093' Miluveach 8164' 3652' 4780' 5000' 5117' 5422' 6616' 6653' 6654' 6739' 6819' 6888' 31. List of Attachments: Summary of Daily Drilling Reports and Post Rig Summary, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie HUbble~~ ~ Title Technical Assistant Date 05· 30 - D3 S-117 203-012 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Neil Magee, 564-5119 Permit No. / Approval No. 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 psrtinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: AttaChed supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. 17EM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: Common Name: Test Date 2/20/2003 LOT 5-117 5-117 Test Type Test Depth (TMD) 3,184.0 (ft) Leak-Off TestSummary TestDepth (TVD) 2,925.0 (ft) AMW 9.70 (ppg) Surface Pressure Leak Off Pressure (BHP) 500 (psi) 1,974 (psi) EMW 12.99 (ppg) ~ ---- Printed: 3/3/2003 8:19:08 AM ') ') BP Operations Summary Report Page 1 of? Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-117 S-117 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/5/2003 Rig Release: 2/25/2003 Rig Number: Spud Date: 2/17/2003 End: 2/25/2003 Date From - To Hours Task Code NPT Phase Description of Operations 2/15/2003 12:00 - 00:00 12.00 RIGD POST Blow down steam lines, Bridle up and disconnect Top Drive. Move camp and pits to new location. Move rig off S-28B and layover derrick. Move rig from S-28B to S-117. 2/16/2003 00:00 - 06:00 6.00 RIGU P PRE Spot and level sub and pit complexes over S-117. Ready and raise derrick. (Temp 30 below). Ready rig for drilling operations. Rig accept @ 06:00 hours. 06:00 - 08:00 2.00 RIGU P PRE Take on water in pits, and nipple up surface riser and spool. Rig up floor from derrick over move. 08:00 - 12:00 4.00 RIGU P PRE Pull down blocks from derrick and bridle down from derrick over move. 12:00 - 16:30 4.50 RIGU P PRE Nipple up 20" boot, drilling nipple, blank spool and flowline. Mix spud mud. Prepare MWD, Motor, etc., etc., in pipeshed and strap same. 16:30 -19:00 2.50 RIGU P PRE Continue to R/U and clean rig for drilling operations. Remove all excess vendors equipment from rig floor. P/U tools for spud. 19:00 - 00:00 5.00 RIGU P PRE P/U drillpipe, HWDP and collars 1 x1 and rack back in derrick. 2/17/2003 00:00 - 02:30 2.50 RIGU P PRE P/U BHA and orient same. Pre-spud meeting/Pre-job meeting for rigging up Schlumberger equipment in derrick. (Will need to Gyro upper hole section due to close approach issues) Fill hole with mud. Pressure test surface equipment to 3,500. Check cellar area for leaks. Walk High pressure mudline. 02:30 - 06:30 4.00 DRILL P SURF Spud and drill from 108' to 648' wilh following drilling parameters: 20-40 WOB; 80 RPM with 2,500 torque on bottom 500 to 600 GPM. 06:30 - 07:30 1.00 DRILL P SURF Run Gyro on Schlumberger E-line @ 648'. 07:30 - 08:00 0.50 DRILL P SURF Drill ahead as per directional plan from 648 to 770. Mud coming back contaminated from previous surface cement job. 08:00 - 12:00 4.00 DRILL N DPRB SURF Mud began coming back very thick and cement contaminated (from recently drilled nearby well S-115?). Confirmed problem with mud check. Treat mud as needed while circ/condition. Build sytem back to spud mud specs. 12:00 - 15:00 3.00 DRILL P SURF Drill 121/4 hole from 770-1096' as per directional plan. Maintain 300 Vis. and 60+ YP. Pumping between 600 to 650 GPM with 200 PSI differential. 15:00 - 16:00 1.00 DRILL P SURF Run Gyro on Schlumberger E-line @ 1096. 16:00 - 20:30 4.50 DRILL P SURF Drill surface hole from 1,096 to 1,563. Hole in good shape. 20:30 - 21 :30 1.00 DRILL P SURF Run Gyro on Schlumberger E-line @ 1,563. 21 :30 - 23:30 2.00 DRILL P SURF Drill surface hole from 1,563 to 1,750. Connections good. Hole in good shape. ART last 24 hours=2.91 AST============6.78 ADT============9.69 23:30 - 00:00 0.50 DRILL P SURF Circulate and clean hole prior to short trip with 80 RPM and 650 GPM. 2/18/2003 00:00 - 01 :30 1.50 DRILL P SURF POH with Bit number 1 with no adverse hole conditions. 01 :30 - 02:00 0.50 DRILL P SURF Break and grade RR bit #1. (7 6 WT A E I RG HR) Layout UBHO sub. P/U new MX-C1 and build back BHA #2. 02:00 - 02:30 0.50 DRILL P SURF Service Top drive. 02:30 - 03:30 1.00 DRILL P SURF TIH with bit # 2. Saw 1 0-15K bumps from 1,200 to 1,600. No fill on bottom. 03:30 - 12:30 9.00 DRILL P SURF Drill from 1750 to Surface hole TD @ 3200 as per directional plan. Building angle up to 45 degrees at surface hole TD. Drilling parameters: WOB 30 - 35 klbs 650 GPM @ 3180 psi. Printed: 3/3/2003 8:19:16 AM ) ) BP Operations Summary Report Page 20f 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-117 S-117 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/5/2003 Rig Release: 2/25/2003 Rig Number: Spud Date: 2/17/2003 End: 2/25/2003 Date From - To Hours Task Code NPT Phase Description of Operations 2/18/2003 03:30 - 12:30 9.00 DRILL P SURF Sliding High side. ART last 24 hrs = 0.92 AST last 24 hrs = 4.96 ADT = 15.57 12:30 - 14:00 1.50 DRILL P SURF Circulate and condition hole. 650 GPM @ 2920 psi. 80 RPM, 94 klbs ROT, 3 klbs torque 14:00 - 15:30 1.50 DRILL P SURF Short trip to 1550'. 114 klbs Up, 80 klbs Down. Pulled 20 - 25 klbs over off bottom. Minor tight spots from 2600 - 2400 and 2300 - 1900'. Wiped pipe through tight spots with no problem. 15:30 - 16:30 1.00 DRILL P SURF RIH to TD. Hit bridge at 2090'. MU top drive, wash and ream through bridge no problem. 5 - 10 klbs drag on TIH 16:30 - 18:00 1.50 DRILL P SURF Ream last stand to bottom at 3200'. No fill on TIH. Circulate and condition hole. 650 GPM @ 2920 psi. 80 RPM, 94 klbs ROT, 3 klbs torque 18:00 - 20:30 2.50 DRILL P SURF POH. 114 klbs Up, 80 klbs Down. No adverse hole conditions on trip out 20:30 - 21 :30 1.00 DRILL P SURF LD BHA 21 :30 - 22:00 0.50 DRILL P SURF Clean & clear floor 22:00 - 22:30 0.50 CASE P SURF MU cement XO on landing collar. Make dummy run with fluted hanger 22:30 - 00:00 1.50 CASE P SURF RU fill-up tool. CO bails. RU surface csg. equip. 2/19/2003 00:00 - 05:00 5.00 CASE P SURF RIH with 9 5/8 40# csg to TD. Shoe @ 3184' MD. No hole problems on TIH. Land casing on hanger - OK. 05:00 - 08:00 3.00 CEMT P SURF Circulate and condition hole prior to cement csg. Reduce FV to -60. Reciprocate pipe without problems - 150 klbs up 125 klbs down. 08:00 - 08:15 0.25 CEMT P SURF PJSM for cement job with crew & service companies. 08:15 - 08:30 0.25 CEMT P SURF Cont circ at 10 bpm while Howco airs & primes up. 08:30 - 10:45 2.25 CEMT P SURF Pump 10 bbl water. Test lines to 3500 psi. Pump 10 more bbl water. Pump 65 bbl Alpha spacer at 10.2 ppg - 5 bpm @ 200 psi. Release bottom plug. Mix & pump 435 bbls (600 sx) Permafrost L lead slurry at 10.7 ppg - 5.5 bpm @ 200 psi increasing to 400 psi at end. Saw bottom plug land on float collar at -235 bbl away & took 800 psi to rupture. Switch to tail slurry. Mix & pump 55 bbls (250 sx) Class G at 15.8 ppg. 3.5 bpm @ 400 psi. Reciprocate pipe throughout. 10:45 - 11: 15 0.50 CEMT P SURF Release top plug & Howco kick out with 10 bbl water to clear lines. Switch to rig pump and displace with mud at 8 bpm at 500 psi initial increasing to 900 psi. Approx 60 bbl into displacement, getting good cement returns back - divert to outside tank. Finish displacement and bump plug with 2000 psi as calculated. Got back 165 bbls lead cement. Bleed off pressure - floats holding. CIP @ 11 :15 hrs. Reciprocate casing throughout displacement - OK. 11:15-12:00 0.75 CEMT P SURF Rig down casing equipment 12:00 - 13:00 1.00 CEMT P SURF Rig down cementing head. Break out and lay down landing joint 13:00 - 15:00 2.00 BOPSURP SURF ND riser and blank spool. CO 20" boot to 16" 15:00 - 17:00 2.00 BOPSUR P SURF Remove riser from cellar. Bring in and warm up XO flange (11" 5M X 13-5/8" 5M) and tbg spool. 17:00 - 18:00 1.00 WHSUR P SURF NU FMC Gen-5 split unihead. Test metal-to-metal seal at csg. Printed: 3/3/2003 8:19:16 AM ) ') BP Operations Summary Report Page 30f 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-117 S-117 DRILL +COMPLETE NABORS ALASKA DRILLING 1 NABORS 9ES Start: 2/5/2003 Rig Release: 2/25/2003 Rig Number: Spud Date: 2/17/2003 End: 2/25/2003 Date From - To Hours Task Code NPT Phase Description of Operations 2/19/2003 17:00 - 18:00 1.00 WHSUR P SURF head to 1000 psi for 10 min - OK. 18:00 - 20:30 2.50 BOPSURP PROD1 Install XO flange (11" 5M X 13-5/8" 5M). NU 13-5/8 5M BOP's and related surface equipment. 20:30 - 21 :00 0.50 BOPSUR P PROD1 Rig up and flush BOP stack with ported sub 21 :00 - 21 :30 0.50 BOPSUR P PROD1 RU BOP test equipment 21 :30 - 00:00 2.50 BOPSUR P PROD1 Test BOP's and related Surface equipment to 250 psi low, 4000 psi high,S min each. Test annular preventer to 250 psi low and 3500 psi high,S min each. Witness of BOP test waived by Chuck Scheve AOGCC 2/20/2003 00:00 - 00:30 0.50 BOPSURP PROD1 Cont. test BOP's and related Surface equipment to 250 psi low, 4000 psi high,S min each. Test annular preventer to 250 psi low and 3500 psi high,S min each. Witness of BOP test waived by Chuck Scheve AOGCC. 00:30 - 01 :00 0.50 BOPSUR P PROD1 RD BOP test equipment. Install 9-1/8" wear bushing 01 :00 - 01 :30 0.50 DRILL P PROD1 Rig Service, service top drive and crown 01 :30 - 03:30 2.00 DRILL P PROD1 PU and RIH with 63 single joints of DP 03:30 - 04:30 1.00 DRILL P PROD1 Cut and slip 42' of drilling line 04:30 - 05:30 1.00 DRILL P PROD1 Stand back 21 stands of DP 05:30 - 07:30 2.00 DRILL P PROD1 PU and MU BHA. 21 Joints 4" HWDP, 3 blade reamer, 1 joint 4" HWDP. Orient BHA 07:30 - 09:30 2.00 DRILL P PROD1 PU and RIH with 66 single joints of DP 09:30 - 10:00 0.50 DRILL P PROD1 Circulate for casing test 10:00 - 10:30 0.50 CASE P PROD1 Test 9-5/8" 40# casing to 3500 psi for 30 min - OK 10:30 -12:00 1.50 DRILL P PROD1 Tag cement @ 3080'. Drill cement & float equipment. Float collar @ 3097', tag shoe @ 3183' 12:00 - 12:30 0.50 DRILL P PROD1 Drill to 3220. 20' of new hole for LOT. 110 klbs up, 82 klbs down, 93 klbs rotate. 60 RPM, 5 klbs WOB, 4 klbs torque 12:30 - 13:00 0.50 DRILL P PROD1 Change out spud mud for new 9.7 ppg LSND @ 462 GPM, 1210 psi, 60 RPM 13:00 - 13:30 0.50 DRILL P PROD1 Pull BHA inside casing. Perform LOT to 13 ppg EMW 13:30 -19:00 5.50 DRILL P PROD1 Directional drill from 3220' to 4498'. 116 klbs up, 92 klbs down, 103 klbs rotate. 10-15 klbs WOB, 5.5-7 klbs torque. 590 GPM, 2780 psi. Holding angle at -40 degrees, Azimuth -260 as per directional plan. Backream each stand, 500 GPM and 1870 psi on down stroke, and circulating a hi-vis barofibre sweep about every 300' to keep hole clean and reduce ECD's. 19:00 - 20:00 1.00 DRILL P PROD1 Circulate and condition mud while building volume 20:00 - 00:00 4.00 DRILL P PROD1 Directional drill from 4498' to 5120'.132 klbs up, 100 klbs down, 112 klbs rotate. 12-17 klbs WOB, 6-8 klbs torque. 590 GPM, 2740 psi. Holding angle at -40 degrees, Azimuth -260 as per directional plan. Backream each stand, 500 GPM and 1870 psi on down stroke, and circulating a hi-vis barofibre sweep about every 300' to keep hole clean and reduce ECD's. ART last 24 hrs = 3.64 hrs AST last 24 hrs = 0.53 hrs ADT = 19.74 hrs 2/21 /2003 00:00 - 04:00 4.00 DRILL P PROD1 Directional drill from 5120' to 5896'. Holding angle at -40 degrees, Azimuth -260 as per directional plan. Backream each stand, 500 GPM and 1870 psi on down stroke, and circulating a hi-vis barofibre sweep about every 300' to keep hole clean and reduce ECD's. 04:00 - 05:00 1.00 DRILL N DPRB PROD1 Driller noted 2 bbl pit gain at 5896' MD, shut well in. Monitor Printed: 3/3/2003 8:19:16 AM ) ) Operations Summary Report Legal Well Name: S-117 Common Well Name: S-117 Spud Date: 2/17/2003 Event Name: DRILL +COMPLETE Start: 2/5/2003 End: 2/25/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/25/2003 Rig Name: NABORS 9ES Rig Number: From-To Hours Task Gode N PT Phase Description of Operations 2/21/2003 04:00 - 05:00 1.00 DRILL N DPRB PROD1 pressures. Well stabilized at 50 psi SIDPP and 8 psi SICP. Bleed pressure off DP - OK. Open annular preventer, monitor well- NO FLOW. Slight gas cut mud, MW 9.7 ppgwith pressure balance. Plan to increase MW to 9.8 ppg while drilling ahead. 05:00 - 12:00 7.00 DRILL P PROD1 Directional drill from 5896' to 6923' as per directional plan. 173 klbs up, 116 klbs down, 137 klbs rotate. 100 RPM, 225 SPM, 550 GPM, 3770 psi. Backreaming each stand, reduced pump rate on down stroke, and circulating a hi-vis barofibre sweep about every 300' to keep hole clean and reduce ECD's. 12:00 - 22:30 10.50 DRILL P PROD1 Directional drill from 6923' to 8325' TMD, 7044' TVD - TD. Miluveach top @ 8162' TMD. 206 klbs up, 133 klbs down, 159 klbs rotate. WOB 10-25 klbs, 100 RPM, 540 GPM, 3760 psi. Backreaming each stand, reduced pump rate on down stroke, and circulating a hi-vis barofibre sweep about every 300' to keep hole clean and reduce ECD's. Calc ECD = 10.67 ppg, measured ECD = 11.1 ppg AST last 24 hrs = 1.54 hrs ART last 24 hrs = 11.6 hrs ADT = 32.88 hrs 22:30 - 00:00 1.50 DRILL P PROD1 Circulate sweep surf> surf, reciprocate DP at 100 RPM. Continue circulate and condition hole until measured ECD is within .3 ppg of the calculated ECD of 10.62 ppg. 2/22/2003 00:00 - 03:30 3.50 DRILL P PROD1 POH to csg shoe. Work through intermittent tight spots from 8060' to 7440' and again from 3472' to 3378'. Pulled 10-20 klbs over through tight spots, worked through a couple of times then continued POH no problem. Monitor hole fill every 5 stands during wiper trip. 03:30 - 04:00 0.50 DRILL P PROD1 Rig Service. Service top drive and crown 04:00 - 06:00 2.00 DRILL P PROD1 RIH to TD. No adverse hole conditions through the tight spots noted on POH. Monitor DP displacement every 5 stands on TIH. 06:00 - 07:30 1.50 DRILL P PROD1 Circulate sweep surf> surf. 550 GPM, 225 SPM, 3640 psi. Reciprocate pipe @ 100 RPM. 207 klbs up, 133 klbs down, 159 klbs rotate. Circulate until 1 0.1 MW both in and out and measured ECD .3 ppg over calculated ECD. 07:30 - 07:45 0.25 DRILL P PROD1 Monitor well prior to POH - No Flow 07:45 - 11 :30 3.75 DRILL P PROD1 POH for logs. Intermittent tight spots from 8233' to 7671'. No other adverse hole conditions. Stop and csg shoe and monitor well - No Flow. Monitor hole fill every 5 stands during POH. 225 klbs up, 130 klbs down. 11 :30 - 12:00 0.50 DRILL P PROD1 Stand back HWDP 12:00 - 13:00 1.00 DRILL P PROD1 LD Drill collars, MWD/LWD. Break out bit and LD motor. 13:00 - 13:30 0.50 DRILL P PROD1 Clean and clear rig floor 13:30 - 14:00 0.50 DRILL P PROD1 PJSM with NAD, SWS, BP covered E-line logging 14:00 - 20:00 6.00 EVAL P PROD1 RU SWS. PU and MU logging tools. RIH with E-line tools. Logs on bottom @ 16:15, log TD 8321'. LD and RD SWS. 20:00 - 20:30 0.50 DRILL P PROD1 Clean and clear rig floor 20:30 - 21 :30 1.00 DRILL P PROD1 MU BHA. Bit, NB stabilizer, float sub, jars 21 :30 - 22:00 0.50 DRILL P PROD1 RIH. Break circulation at csg. shoe. 92 klbs up, 79 klbs down. Monitor DP displacement every 5 stands on TIH 2/23/2003 00:00 - 01 :30 1.50 DRILL P PROD1 Continue RIH to TD. Break circulation at 5500' and again at Printed: 3/3/2003 8:19:16 AM ) ) BP Operations Summary Report Page 50f 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-117 S-117 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/5/2003 Rig Release: 2/25/2003 Rig Number: Spud Date: 2/17/2003 End: 2/25/2003 Date From - To Hours Task Code NPT Phase Description of Operations 2/23/2003 00:00 - 01 :30 1.50 DRILL P PROD1 6500'. No hole problems noted on TIH. Monitor DP displacement every 5 stands. 01 :30 - 03:00 1.50 DRILL P PROD1 Circulate and condition mud to run csg. Reciprocate DP at 150 RPM. 530 GPM, 3190 psi. circulate 2 X surf> surf. Mud properties before POH: PV - 11 YP - 16 MW -10.1 in, 10.3 out 03:00 - 06:00 3.00 DRILL P PROD1 Lay down drill pipe. Work tight spots @ 8100', F/ 7980' To 7920' and again @ 7650'. Pull 25 klbs over and work through tight spots. no increase in weight on second pull through. 215 klbs up, 122 klbs down. 16 bbl total loss during LDDP 06:00 - 07:00 1.00 DRILL P PROD1 Spot 265 bbl 20#/bbl Steel Seal pill across shrader @ 525 GPM, base of shrader @ 6528' TMD. Monitor well - No Flow. Pump dry job 07:00 - 10:30 3.50 DRILL P PROD1 Continue LDDP. Monitor well at csg. shoe - No Flow. 10:30 - 12:00 1.50 DRILL P PROD1 LD HWDP and BHA #4 12:00 - 12:30 0.50 CASE P COMP Flush stack. Pull wear bushing. PU casing hanger, make dummy run with hanger, LD same. 12:30 - 13:30 1.00 CASE P COMP Install 7" upper BOP rams. Install test plug, test door seals to 3500 psi for 10 minutes. 13:30 - 15:00 1.50 CASE P COMP Change out elevator bails. RU and function test casing equipment. Check stabbing board. 15:00 - 20:30 5.50 CASE P COMP PU & MU 7" 26# L-80 shoe track. Fill and check float equipment. RIH to csg. shoe with 7" 26# L-80 casing. Csg running speed limited to 1 min per joint. Fill every joint and break circulation every 25 joints for 5-10 minutes with Franks tool. Monitor csg. diplacement volumes. 105 klbs up, 95 klbs down. 20:30 - 21 :00 0.50 CASE P COMP Break circulation at csg. shoe. Stage up pumps to 6 BPM and 400 psi. Circulate 1-1/2 times the annular volume. 21 :00 - 00:00 3.00 CASE P COMP Continue RIH with 7" 26# L-80 csg. Through open hole section limit csg. running speed to 1-1/2 minutes per joint. Fill every joint and break circulation every 15 joints with Franks tool. Stage pumps slowly to a maximum rate of 7 BPM. Circulate for 15 minutes every 25 joints. Monitor csg. diplacement volumes. 2/24/2003 00:00 - 01 :30 1.50 CASE P COMP Cont. RIH with 7" 26# L-80 csg. 1-1/2 minute Per joint. Fill every joint, break circulation every 15 joints. Circulate 15 minutes every 25 joints. Monitor csg. displacemt. 01 :30 - 03:00 1.50 CASE P COMP Cont. RIH with 7" 26# csg. Losses noted - 2 bbl every 10 joints. Slow running speed to 15 ftlmin, increase circulation times to every 10 joints. Circulate 15 minutes every 20 joints. Monitor csg. displacement. 03:00 - 03:30 0.50 CASE P COMP Circulate bottoms up @ 6000'. Stage pumps - 2 BPM for 10 min., 4 BPM for 10 min., 6 BPM for 10 min. Reciprocate csg. while circulating. 170 klbs up, 120 klbs down. 03:30 - 08:15 4.75 CASE P COMP Cont. RIH with 7" 26# csg. Running speed 15 ftlmin, break circulation every 10 joints. Circulate 15 minutes every 20 joints. Monitor csg. displacement -losing 2 bbl every 10 joints. Total of 201 jts run. MU hanger and landing jt. Land casing with shoe at 8315' MD. 08:15 - 08:30 0.25 CEMT P COMP RD Franks fill-up tool. RU cement head & lines. Printed: 3/3/2003 8:19:16 AM ) ) BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-117 S-117 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/5/2003 Rig Release: 2/25/2003 Rig Number: Spud Date: 2/17/2003 End: 2/25/2003 2/24/2003 08:30 - 09:45 1.25 CEMT P COMP Break circ at 3 BPM @ 650 psi. Stage up to 7 BPM @ 900 psi. 240 klbs up. 130 klbs dn. No losses. Reciprocate pipe while circ. 09:45 - 10:00 0.25 CEMT P COMP PJSM for pumping cement. 10:00 - 10:45 0.75 CEMT P COMP Batch mix Tuned Light cement. 10:45 - 12:00 1.25 CEMT P COMP Pump 5 bbl water. Test lines to 4000 psi. Pump 40 bbl Alpha spacer at 10.5 ppg - 4 bpm @ 400 psi. Release bottom plug. Pump 122 bbl Tuned Light lead slurry at 11.3 ppg surface wt - 5.5 bpm @ 600 psi. Mix & pump 36 bbls Class G tail slurry at 15.8 ppg - 4 bpm @ 300 psi. 12:00 - 13:00 1.00 CEMT P COMP Release top plug and wash up cement line down flowline. Displace cement with seawater at 7 bpm @ 500 psi initial rising to 1800 psi at 260 bbl away. Slow to 3 bpm and finish displacement - final pressure @ 1900 psi. 13:00 - 13:15 0.25 CEMT P COMP Bump plug at calculated strokes and pressure up to 4000 psi - hold for 10 min to verify casing integrity. Bleed off pressure - floats held. CIP at 13:00 hrs. No losses noted & reciprocated pipe throughout job. 13:15 - 15:00 1.75 CEMT P COMP Rig Down cement head and casing equipment. CO bails. Clean and clear rig floor 15:00 - 16:00 1.00 WHSUR P COMP Install packoff. Run in lock down screws, Test to 4000 psi 16:00 - 16:30 0.50 WHSUR P COMP Bullhead 90 bbls of 10.1 ppg mud down the 7" X 9-5/8" annulus to ensure it is free of cement 16:30 - 17:30 1.00 BOPSURP COMP Change out upper pipe rams from 7" to 3-1/2" X 6" variables; Test doors and seal to 3500 psi for 10 minutes 17:30 - 18:30 1.00 RUNCOrvP COMP Cut and slip 70' of drilling line 18:30 - 19:30 1.00 RUNCOrvP COMP Rig up 3-1/2" tubing equipment 19:30 - 19:45 0.25 RUNCOrvP COMP PJSM BP, NAD, Baker on running 3-1/2" tubing 19:45 - 00:00 4.25 RUNCOrvP COMP PU and run 3-1/2", 9.2#, L-80, IBT-M tubing. Apply Best-O-Life 2000 dope and torque to mark. 2/25/2003 00:00 - 03:30 3.50 RUNCOrvP COMP Continue Run 3-1/2",9.2#, L-80 Tubing 03:30 - 04:00 0.50 RUNCOrvP COMP Change out elevators. PU and MU 1 joint 4-1/2" 12.6#, L-80. PU and MU tubing hanger. Land tubing at 0400, verified. 04:00 - 04:30 0.50 RUNCOrvP COMP Run in lock down screws. Rig up to reverse circulate clean seawater and corrosion inhibited seawater. 04:30 - 06:00 1.50 RUNCOrvP COMP Reverse circulate clean seawater and corrosion inhibited seawater down the 7" X 3-1/2" annulus. 06:00 - 06:30 0.50 RUNCOrvP COMP Drop Ball and Rod. RD landing joint. Close blind rams 06:30 - 08:00 1.50 RUNCOrvP COMP Pressure up Tbg to 4200 psi, hold for 30 min - 75 psi pressure losses. Bleed tbg pressure to 2500 psi. Pressure up 3-1/2" X 7" annulus to 3500 psi, hold for 30 min. - no pressure loss. Bleed down annulus pressure to 0 then bleed down tbg pressure to O. Pressure up annulus to shear DCR valve - SHEARED @ 2700 psi. Set TWC, test to 2700 psi. 08:00 - 08:30 0.50 RUNCOrvP COMP LD tbg equipment - tongs, slips, elevators, XO's 08:30 - 09:30 1.00 RUNCOrvP COMP LD mouse hole, install adapter flange to mud cross 09:30 - 12:00 2.50 BOPSUR P COMP ND BOP 12:00 - 15:30 3.50 WHSUR P COMP Pull tree and adapter into cellar, warm. NU tree and test to 5000 psi. Printed: 3/3/2003 8:19:16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BP Operations Summary Report S-117 S-117 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 2/5/2003 Rig Release: 2/25/2003 Rig Number: Date From - To Hours Task Code NPT Phase 2/25/2003 15:30 - 16:30 16:30 - 19:30 19:30 - 20:30 20:30 - 21 :00 RU lubricator and pull TWC with DSM RU and pressure test lines, Pump 80 bbl heated diesel down tubing annulus. Shut in allow to U-tube. Pump 60 bbl dead crude down 7" X 9-5/8" annulus @ 2.2 BPM. ICP -800 psi, FCP = 1250 psi -SIP=800 psi. Install BPV with Drill site maintenance. Test below to 2800 psi Secure cellar and tree 1.00 WHSUR P 3.00 WHSUR P caMP caMP 1.00 WHSUR P 0.50 WHSUR P caMP caMP Release Rig @ 21 :00 Page 7 of 7 Spud Date: 2/17/2003 End: 2/25/2003 Description of Operations Printed: 3/3/2003 8:19:16 AM ) ) Well: Field: API: Permit: Date S-117 Prudhoe Bay Unit 50-029-23137 -00 203-012 Accept: Spud: Release: Rig: 02/16/03 02/17/03 02/25/03 Nabors 9ES POST RIG WORK 04/24/03 SET STA# 1 OGLV, 22/64 PORT. PULL RHC PLUG BODY FROM 7841' WLM. DRIFT & TAG W/ 2.5" DG TO TO @ 8220' WLM (PBTD @ 8231' MD), SOFT BTM, SB FULL OF SAND. LEFT WELL SI, NOTIFIED PAD OP OF STATUS. 05/01/03 PERFORATED 8104'-8118' W/ 550 PSI UNDERBALANCE, TIED IN TO MWDGR 2/22/03. GUN SIZE 14', 2.5" HSD POWERJET GUN LOADED 4 SPF, 180 DEG PHASING. GUN WAS MAGNETICALLY DECENTRALIZED, 45 DEG FROM LOW SIDE. AFTER SHOOTING THE GUN, A PBMS WAS RUN FOR A SBHPS. PRESSURE STOPS TAKEN @ 7932' AND 8036'. TAG TO @ 8231' MD. WELL LEFT SHUT IN. 05/02103 T/I/O = 1900/1920/80, TIFL PASSED INITIAL IA FL @ 7777'. START IA BLEED DOWN S-115 FL @ 0930 HRS. 1030 HRS lAP @ 1300 PSI., IA FL @ 7692' (TP @ 1850, OAP @ 80) 1130 HRS lAP @ 1050 PSI., IA FL @ 7658, (TP @ 1850, OAP @ 80) 1230 HRS lAP 860 PSI., IA FL @ 7767' (TP AND OAP UNCHANGED) START 1 HR. MONITOR. FINAL WHP'S 1850/860/80. 05/03/03 T/I/O = 2140/1200/140. ATTEMPT ACID STIM. PUMPED 5 BBLS OF METHANOL, 7 BBLS OF 2% KCL AND 4 MORE BBLS OF METHANOL AND THE TBG LOCKED UP. ATTEMPTED TO PUT WELL ON PRODUCTION AND WING VALVE WAS SHEARED. CALLED GREASE CREW TO REPAIR WING VALVE. FIELD OPERATOR TO PUT WELL BOL AFTER WING IS REPAIRED. WILL CONTINUE WITH WELL WORK IN THE AM. 05/04/03 T/I/O = 600/600/50. INVESTIGATE POSSIBLE TBG HYDRATES. (PRE ACID STIM). SI WELL AND STARTED PUMPING DOWN TBG. CAUGHT FLUID WITH 43 BBLS AWAY, APPROX 5000'. PUMPED AN ADDITIONAL 16 BBLS AND TP ROSE TO 3000 PSI. CONTINUED PUMPING AT.6 BPM FOR 10 BBLS AND TP STARTED TO CLIMB. BACKED OFF RATE TO .2 BPM FOR AN ADDTIONAL 5 BBLS. SO AND MONITORED TP FOR 30 MIN. TP DROPPED FROM 3000 PSI TO 1750 PSI. BLED TBG TO 250 PSI. FREEZE PROTECTED FLOWLINE. RD, MOL. FINAL WHP'S = 250/600/50. 05/15/03 WELL SHUT IN ON ARRIVAL. FLOW LINE FREEZE PROTECTED. RIH W/ 2.80" CENT / TEL / SB. SO @ 3345 SLM. PARAFFIN ON TOOLS CALL FOR PUMP TRUCK. 05/16/03 PUMP HOT CRUDE AND BRUSH TBG. SET X CATCHER SUB. PULLED GLV'S FROM STA. # 1,2 & 4. SET DGLV STA-4 & STA-2. PREPARING TO LOAD AND TEST IA. 05/17/03 LOAD IA W/ 225 BBLS OF CRUDE. SET 1-1/2" SIDE POCKET MEMORY GAUGE IN STA# 1. MIT-IA 4000# (GOOD TEST). PULLED CATCHER. FLOW LINE HAS BEEN FREEZE PROTECTED. LEFT WELL SHUT IN. 05/18/03 HEAT FRAC TANKS TO 95°, HEAT DIESEL TO 90°; HOLD 3500 PSI ON IA DURING FRAC. FRAC'D KUP A SAND WITH YF-125LG AND 17.7K# OF 12/18 C-LlTE PROP. SCREENED OUT NWB TO 8000 PSI113 BBLS INTO THE 4 PPGA STG. PLACED 5.8K# PROP BEHIND PIPE AND LEFT 11.9K# IN CSG, (19.6 BBLS PROP), EXPECT SAND BRIDGES FROM NEAR SURFACE. AVG TREAT- 5300 PSI, LOAD TO RECOVER IS 600 BBLS. THE WELLBORE IS NOT FREEZE PROTECTED. LOST 1/2 OF ONE TREESAVER ELEMENT - 1.5" X .25" X 4" STRIP. HEATER ON WELLHEAD. PUMP 1.25" BALL THROUGH NEW REPAIRED STRING. ) 8-117, Post Drill & Complete Work Page 2 ) 05/19/03 RIH WI 2.1" J8 NOZZLE. JET FROM TREE WI XS FRESH WTR. GOT SAND RETURNS FROM SURFACE. JET 500' BITES/50' SHORT TRIPS UP. PUMP FLOPRO SWEEPS @ 4000',6000',7800'. JET LINER IN 50' BITES WI FLOPRO SWEEPS TO 8020'. CHASE TO SURFACE, WASHING GLM'S. RIH WI 2" BON & NO CHECKS. REVERSE TO 8050' CTM. SWAP WELLBORE FLUIDS TO 1% KCL. FP TO 2500' WI 50/50 METH. LEAK OFF TEST IS.5 BPM @ 3000 PSI. DUMPED 5 GALS OF LATEX ON TOP OF SAND @ 8069' CORRECTED TO WI 20' X 2-1/4" BAILER WI 2.70" CENT. ON BTM OF BAILER. PERFORATED INTERVAL 7970'·7990'. OS/20/03 PERFORATED INTERVALS, 7950'-7970', AND 7930'-7950'. FOR A TOTAL PERFORATED 60' USING: 2.5" HSD GUNS; HYPERJET 2506 RDX CHARGES; 6 SPF; 60 DEG PHASING; RANDOM ORIENTATION; EXPLOSIVE LOAD 10.5G. API PENETRATION = 13.1", ENTRANCE HOLE =0.43". FRAC'D THE KUP C SAND WITH YF125 LG SYSTEM AND 195.6K# OF 16/20 C-LlTE. NWB SIO TO 8050 PSI 78 BBLS INTO THE 10 PPGA STG WITH 10 PPGA PROP JUST ON PERFS. PLACED 173.9K# BEHIND PIPE, LEAVING 21.7K# IN CSG (36 BBLS PROP). MAX TREAT- 8050 PSI, AVG TREAT- 6155 PSI, LOAD TO RECOVER- 1750 BBLS. WELL IS NOT FREEZE PROTECTED WITH SAND BRIDGES TO SURFACE. LOST: ONE SMALL PIECE OF ONE TREESAVER ELEMENT, APPROX 1/2" X .25" X 2" STRIP. OS/23/03 POST FRAC FCO TO 8231' TAKING 500' BITES, WI 10 BBL HEC SWEEPS. 1 FOR 1 RETURNS. WELL STARTED FLOWING ONCE BELOW TT. CLEANED OUT TO 8231'. WASHED ALL JEWELRY AND JETTED TREE PULLING OOH. FREEZE PROTECTED TO 2500'. WELL SHUT IN. JOB COMPLETE. OS/25/03 RAN IN TO HYDRATES @ 243' WLM. FIRST ENERGY PUT 50 BBLS NEAT METHANOL AWAY. SET CATCHER @ 7839 WLM, PULLED STA'S 4 & 2 DGLV'S. TOOLS FELL SLOW DUE TO SOFT TAR IN THE WELL BORE. HOT OIL ON WAY TO PUMP HOT DIESEL, UNABLE TO GET DOWN DUE TO THICK TAR. OS/26/03 BRUSH & FLUSH TBG WI 110 BBLS OF HEATED DIESEL. (HAD JUMPER LINE HOOKED UP TO IA AND FLOWLINE TO TAKE RETURNS FROM TBG THRU STA. # 4 WHILE PUMPING.) SET STA # 4 @ 4129 WLM, 16/64 PORT, 1750 TRO. SET STA # 2 @ 6732 WLM, 16/64 PORT, 1807 TRO. PULLED 31/2" "X" CATCHER SUB FROM LOWER "X" NIPPLE(C/S WAS CLEAN, NO FILL). SPMG IN STA # 1. RETURNED WELL TO PAD OP, WELL TO REMAIN SII. ANADRILL SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Aurora Well.....................: S-117 API number...............: 50-029-23137-00 Engineer.................: St. Amour COUNTY: . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference. . . . . . . . . .: Drill Floor GL above permanent.......: 35.25 ft KB above permanent. . . . . . . : N/A DF above permanent.......: 64.40 ft ----- Vertical section origin---------------- La tit ude ( + N / S -) . . . . . . . . . : 0 . 00 f t Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- La tit ude ( + N / S -) . . . . . . . . . : - 999 . 25 f t Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 260.86 degrees [(c)2003 Anadrill IDEAL ID6_1C_IOJ 22-Feb-2003 02:55:46 Spud date. . . . . . . . . . . . . . . . : Last survey date..... ....: Total accepted surveys...: MD of first survey. ......: MD of last survey........: Page 1 of 5 17-Feb-2003 22-Feb-03 91 0.00 ft 8325.00 ft ,-" ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2001 Magnetic date............: 31-Dec-2002 Magnetic field strength..: 1150.01 HCNT Magnetic dec (+E/W-) .....: 25.97 degrees Magnetic dip.... .........: 80.81 degrees ----- MWD survey Reference Reference G..............: Reference H. . . . . . . . . . . . . . : Reference Dip........ ....: Tolerance of G...... .....: Tolerance of H.... .......: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1150.50 HCNT 80.82 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.80 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.80 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........: No degree: 0.00 ~ ANADRILL SCHLUMBERGER Survey Report 22-Feb-2003 02:55:46 Page 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 100.00 0.13 255.43 100.00 100.00 0.11 -0.03 -0.11 0.11 255.43 0.13 GYR 3 200.00 0.14 234.67 100.00 200.00 0.34 -0.13 -0.32 0.34 248.20 0.05 GYR 4 300.00 0.22 219.85 100.00 300.00 0.59 -0.35 -0.54 0.64 237.46 0.09 GYR 5 400.00 0.21 205.30 100.00 400.00 0.84 -0.66 -0.74 0.99 228.45 0.06 GYR 6 500.00 0.35 232.69 100.00 500.00 1.21 -1.01 -1.06 1.47 226.52 0.19 GYR 7 600.00 0.52 234.08 100.00 599.99 1.89 -1.46 -1.67 2.22 228.90 0.17 GYR ~/ 8 700.00 0.94 239.64 100.00 699.99 3.06 -2.14 -2.75 3.49 232.09 0.43 GYR 9 800.00 2.19 245.21 100.00 799.95 5.66 -3.36 -5.19 6.18 237.11 1.26 GYR 10 900.00 3.04 249.10 100.00 899.84 10.10 -5.10 -9.40 10.70 241.51 0.87 GYR 11 1000.00 4.34 251.90 100.00 999.63 16.43 -7.23 -15.48 17.08 244.97 1.31 GYR 12 1100.00 5.34 250.98 100.00 1099.27 24.75 -9.92 -23.47 25.48 247.10 1.00 GYR 13 1200.00 6.33 252.02 100.00 1198.76 34.78 -13.14 -33.12 35.63 248.36 1.00 GYR 14 1300.00 7.32 255.16 100.00 1298.05 46.57 -16.47 -44.52 47.47 249.70 1.06 GYR 15 1400.00 8.95 260.47 100.00 1397.04 60.69 -19.39 -58.35 61.49 251.62 1.79 GYR 16 1470.00 10.71 257.90 70.00 1466.01 72.63 -21.65 -70.08 73.35 252.83 2.59 GYR 17 1503.37 11.31 261.00 33.37 1498.76 79.00 -22.82 -76.34 79.68 253.36 2.53 MWD IFR MSA 18 1594.92 12.21 262.05 91.55 1588.39 97.66 -25.56 -94.80 98.19 254.91 1.01 MWD_IFR_MSA 19 1691.22 14.90 261.12 96.30 1682.00 120.22 -28.88 -117.12 120.63 256.15 2.80 MWD IFR MSA 20 1781.30 16.31 260.44 90.08 1768.76 144.45 -32.77 -141.04 144.80 256.92 1.58 MWD IFR MSA 21 1874.08 17.50 259.68 92.78 1857.53 171.43 -37.43 -167.61 171.74 257.41 1.30 MWD IFR MSA 22 1967.61 18.48 262.30 93.53 1946.48 200.31 -41.94 -196.14 200.57 257.93 1.36 MWD IFR MSA .-- 23 2060.60 21.55 263.25 92.99 2033.85 232.11 -45.92 -227.71 232.29 258.60 3.32 MWD IFR MSA 24 2154.35 25.15 264.34 93.75 2119.91 269.21 -49.91 -264.64 269.31 259.32 3.87 MWD IFR MSA 25 2247.44 27.79 262.68 93.09 2203.23 310.65 -54.63 -305.86 310.70 259.87 2.94 MWD IFR MSA 26 2341.27 30.82 260.09 93.83 2285.05 356.56 -61.55 -351.25 356.60 260.06 3.50 MWD IFR MSA 27 2434.00 32.41 256.89 92.73 2364.02 405.11 -71.28 -398.86 405.17 259.87 2.49 MWD I FR MSA 28 2527.37 35.13 257.60 93.37 2441.63 456.91 -82.73 -449.47 457.02 259.57 2.94 MWD IFR MSA 29 2619.95 37.79 259.44 92.58 2516.08 511.87 -93.65 -503.38 512.02 259.46 3.11 MWD IFR MSA 30 2712.81 40.64 259.82 92.86 2588.02 570.56 -104.21 -561.13 570.72 259.48 3.08 MWD IFR MSA [(c)2003 Anadrill IDEAL ID6 lC 10] MWD IFR MSA MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA ~ MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA --/ MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA ------ ------ Tool qual type Srvy tool type ------ ------ 0.45 0.72 0.31 0.77 0.48 0.45 0.84 2.03 0.52 0.57 0.38 0.72 0.42 0.35 1.07 3.08 0.83 1.19 0.48 0.62 2.02 0.31 5.17 0.61 1.04 3.17 0.47 0.54 0.97 0.92 DLS (degl 100f) 3 of 5 259.50 259.56 259.61 259.67 259.71 259.27 259.25 259.27 259.34 259.42 259.28 259.29 259.29 259.31 259.30 259.05 259.16 259.23 259.25 259.27 259.34 259.27 259.16 259.07 259.01 259.50 259.50 259.46 259.40 259.39 2210.13 2268.49 2327.76 2384.94 2442.05 1907.84 1969.57 2030.89 2090.86 2150.50 1586.20 1651.08 1715.78 1780.38 1844.08 1256.65 1322.77 1389.45 1454.64 1520.72 940.19 982.79 1049.99 1118.59 1188.82 633.87 698.17 760.90 828.69 866.50 -402.87 -2173.10 -411.13 -2230.92 -419.65 -2289.62 -427.87 -2346.24 -436.19 -2402.78 -355.18 -1874.49 -367.39 -1935.00 -378.06 -1995.39 -386.77 -2054.78 -394.86 -2113.94 -295.04 -1558.52 -306.87 -1622.31 -318.74 -1685.91 -330.40 -1749.46 -342.47 -1812.00 -238.68 -1233.77 -248.83 -1299.15 -259.74 -1364.95 -271.20 -1429.13 -283.14 -1494.13 -923.96 -965.61 -1031.26 -1098.28 -1167.01 -623.26 -686.46 -748.05 -814.55 -851.68 -173.94 -182.94 -197.40 -212.18 -226.66 -115.52 -127.28 -139.23 -152.45 -159.56 2209.50 2267.90 2327.21 2384.42 2441.56 1907.11 1968.79 2030.11 2090.12 2149.82 1585.60 1650.45 1715.14 1779.73 1843.39 1256.02 1322.18 1388.88 1454.07 1520.13 939.86 982.41 1049.53 1118.04 1188.20 633.69 697.97 760.67 828.42 866.21 4291.78 4363.24 4436.82 4508.97 4582.52 3938.86 4008.04 4078.73 4149.15 4219.97 3597.49 3664.28 3731.97 3800.32 3868.89 3269.22 3334.42 3400.40 3464.76 3531.02 2971.63 3016.85 3082.40 3143.28 3205.74 2657.84 2724.81 2789.54 2858.21 2895.86 [(c)2003 Anadrill IDEAL ID6 1C 10] 93.39 92.29 94.51 92.09 93.14 94.67 92.72 93.59 92.53 92.63 93.31 93.11 93.64 94.05 93.59 92.92 92.89 93.82 91.61 93.58 105.70 62.14 93.92 91.74 93.99 94.15 92.84 90.14 96.50 53.36 262.14 261.59 261.89 261.60 261.65 258.49 258.69 261.30 262.00 262.44 259.72 259.26 259.60 259.62 258.52 261.07 261.27 259.91 259.84 259.34 257.95 257.67 257.49 257.64 258.57 259.55 259.36 258.69 258.82 259.51 39.55 38.98 38.76 38.07 37.62 42.13 41.36 40.53 40.36 39.92 44.46 43.87 43.55 43.22 42.56 45.80 45.04 45.59 45.15 44.69 43.29 43.30 48.15 48.70 48.01 43.62 44.04 44.17 45.10 45.13 5079.34 5171.63 5266.14 5358.23 5451.37 4614.48 4707.20 4800.79 4893.32 4985.95 4145.42 4238.53 4332.17 4426.22 4519.81 3680.21 3773.10 3866.92 3958.53 4052.11 3245.50 3307.64 3401.56 3493.30 3587.29 2806.96 2899.80 2989.94 3086.44 3139.80 56 57 58 59 60 51 52 53 54 55 46 47 48 49 50 41 42 43 44 45 36 37 38 39 40 31 32 33 34 35 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- At Azim (deg) Total displ (ft) Displ +E/w- (ft) Displ +N/s- (ft) Vertical section (ft) TVD depth (ft) Course length (ft) Azimuth angle (deg) Incl angle (deg) Seq Measured # depth (ft) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Page 22-Feb-2003 02:55:46 ANADRILL SCHLUMBERGER Survey Report ANADRILL SCHLUMBERGER Survey Report 22-Feb-2003 02:55:46 Page 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (de g) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5545.51 37.35 261.26 94.14 4657.23 2498.84 -444.70 -2459.43 2499.31 259.75 0.38 MWD IFR MSA 62 5640.23 38.66 260.31 94.72 4731.86 2557.16 -454.05 -2517.00 2557.62 259.77 1.51 MWD IFR MSA - 63 5734.66 39.61 262.66 94.43 4805.11 2616.75 -462.86 -2575.93 2617.19 259.81 1.87 MWD IFR MSA - 64 5829.63 39.62 263.26 94.97 4878.27 2677.26 -470.28 -2636.03 2677.65 259.88 0.40 MWD IFR MSA - 65 5921.27 39.76 262.56 91.64 4948.79 2735.75 -477.50 -2694.10 2736.09 259.95 0.51 MWD IFR MSA 66 6015.44 39.79 261.81 94.17 5021.16 2795.98 -485.70 -2753.79 2796.30 260.00 0.51 MWD IFR MSA - 67 6106.98 39.44 261.99 91.54 5091.68 2854.34 -493.92 -2811.58 2854.63 260.04 0.40 MWD IFR MSA ~ - 68 6202.63 38.80 263.37 95.65 5165.89 2914.65 -501.61 -2871.43 2914.92 260.09 1.13 MWD IFR MSA 69 6295.33 38.87 264.07 92.70 5238.10 2972.71 -507.97 -2929.21 2972.93 260.16 0.48 MWD IFR MSA - 70 6387.77 38.36 262.96 92.44 5310.33 3030.34 -514.48 -2986.53 3030.52 260.23 0.93 MWD IFR MSA 71 6480.63 37.90 262.92 92.86 5383.37 3087.64 -521.53 -3043.43 3087.80 260.28 0.50 MWD IFR MSA - 72 6572.68 37.11 261.98 92.05 5456.40 3143.65 -528.89 -3098.99 3143.80 260.31 1.06 MWD IFR MSA 73 6666.02 36.05 261.35 93.34 5531.35 3199.27 -536.95 -3154.03 3199.41 260.34 1.20 MWD IFR MSA - 74 6758.91 35.27 260.03 92.89 5606.82 3253.42 -545.70 -3207.46 3253.55 260.34 1.18 MWD IFR MSA - 75 6852.40 34.41 259.38 93.49 5683.55 3306.82 -555.25 -3260.01 3306.96 260.33 1.00 MWD IFR MSA 76 6945.93 32.61 260.89 93.53 5761.54 3358.45 -564.11 -3310.88 3358.59 260.33 2.12 MWD IFR MSA 77 7038.94 31.38 261.06 93.01 5840.42 3407.73 -571.84 -3359.55 3407.87 260.34 1.33 MWD IFR MSA - 78 7133.68 29.17 263.08 94.74 5922.23 3455.47 -578.46 -3406.84 3455.60 260.36 2.57 MWD IFR MSA - 79 7227.19 26.84 264.34 93.51 6004.79 3499.32 -583.28 -3450.48 3499.43 260.41 2.57 MWD IFR MSA 80 7319.20 24.23 265.11 92.01 6087.81 3538.89 -586.94 -3489.96 3538.98 260.45 2.86 MWD IFR MSA 81 7413.14 22.67 263.53 93.94 6173.98 3576.20 -590.63 -3527.16 3576.27 260.49 1.79 MWD IFR MSA - 82 7507.20 22.10 263.74 94.06 6260.96 3611.98 -594.60 -3562.76 3612.04 260.53 0.61 MWD IFR MSA ~ 83 7600.75 20.72 265.12 93.55 6348.05 3646.06 -597.92 -3596.74 3646.11 260.56 1.57 MWD IFR MSA - 84 7694.51 18.31 264.62 93.76 6436.42 3677.30 -600.72 -3627.94 3677.34 260.60 2.58 MWD IFR MSA 85 7787.47 16.53 264.15 92.96 6525.11 3705.07 -603.43 -3655.63 3705.10 260.63 1.92 MWD IFR MSA - 86 7880.01 15.65 263.34 92.54 6614.02 3730.69 -606.22 -3681.13 3730.71 260.65 0.98 MWD IFR MSA - 87 7973.59 15.55 263.45 93.58 6704.16 3755.83 -609.12 -3706.13 3755.85 260.67 0.11 MWD IFR MSA - 88 8066.64 14.91 263.48 93.05 6793.94 3780.25 -611.90 -3730.41 3780.26 260.68 0.69 MWD IFR MSA - 89 8159.54 14.05 264.80 92.90 6883.89 3803.44 -614.28 -3753.52 3803.45 260.71 0.99 MWD IFR MSA - 90 8256.20 13.34 264.92 96.66 6977.80 3826.26 -616.33 -3776.31 3826.27 260.73 0.74 MWD IFR MSA - 91 8325.00 13.34 264.92 68.80 7044.74 3842.10 -617.74 -3792.12 3842.11 260.75 0.00 Projected [(c)2003 Anadrill IDEAL ID6 lC 10] bp S-117 Schlumberuer Survey Report - Geodetic Report Date: 22-Feb·03 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 260.750° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 fl Structure / Slot: 8-PAD I 8-117 TVO Reference Datum: KB Well: 8-117 TVD Reference Elevation: 64.400 ft relative to M8L Borehole: 8-117 UWUAPI#: 500292313700 Magnetic Declination: +25.783° Survey Name / Date: 8-117 / February 22, 2003 Total Field Strength: 57525.704 nT Tort / AHO / DOlI ERD ratio: 106.485° /3845.59 ft / 5.685 / 0.546 Magnetic Dip: 80.821° ~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: February 27,2003 Location Lat/Long: N 70.35559577, W 149.03415002 Magnetic Declination Model: BGGM 2002 Location Grid N/E YIX: N 5980579.930 ftU8, E 618930.140 ftUS North Reference: True North Grid Convergence Angle: +0.90964455° Total Corr Mag North -> True North: +25.783° Grid Scale Factor: 0.99991607 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/·S EJ-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (°/1 DDft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5980579.93 618930.14 N 70.35559577 W 149.03415003 100.00 0.13 255.43 100.00 0.11 -0.03 -0.11 0.13 5980579.90 618930.03 N 70.35559569 W 149.03415092 200.00 0.14 234.67 200.00 0.34 -0.13 -0.32 0.05 5980579.80 618929.82 N 70.35559542 W 149.03415262 300.00 0.22 219.85 300.00 0.59" -0.35 -0.54 0.09 5980579.58 618929.60 N 70.35559483 W 149.03415443 400.00 0.21 205.30 400.00 0.84 -0.66 -0.74 0.06 5980579.26 618929.41 N 70.35559397 W 149.03415607 500.00 0.35 232.69 500.00 1.21 -1.01 -1.06 0.19 5980578.90 618929.09 N 70.35559301 W 149.03415867 600.00 0.52 234.08 599.99 1.89 -1 .46 -1. 67 0.17 5980578.44 618928.49 N 70.35559178 W 149.03416363 700.00 0.94 239.64 699.99 3.06 -2.14 -2.75 0.43 5980577.74 618927.42 N 70.35558992 W 149.03417236 800.00 2.19 245.21 799.95 5.66 -3.36 -5.19 1.26 5980576.49 618925.00 N 70.35558660 W 149.03419219 -'" 900.00 3.04 249.10 899.84 10.10 -5.10 -9.40 0.87 5980574.68 618920.82 N 70.35558182 W 149.03422640 1000.00 4.34 251.90 999.63 16.44 -7.23 -15.48 1.31 5980572.46 618914.78 N 70.35557603 W 149.03427572 1100.00 5.34 250.98 1099.27 24.76 -9.92 -23.47 1.00 5980569.64 618906.83 N 70.35556867 W 149.03434064 1200.00 6.33 252.02 1198.76 34.80 -13.14 -33.12 1.00 5980566.27 618897.24 N 70.35555988 W 149.03441894 1300.00 7.32 255.16 1298.05 46.59 -16.47 -44.52 1.06 5980562.76 618885.89 N 70.35555078 W 149.03451153 1400.00 8.95 260.47 1397.04 60.71 -19.39 -58.35 1.79 5980559.62 618872.11 N 70.35554280 W 149.03462383 1470.00 10.71 257.90 1466.01 72.65 -21.65 -70.08 2.59 5980557.17 618860.42 N 70.35553661 W 149.03471908 1503.37 11.31 261.00 1498.76 79.02 -22.82 -76.34 2.53 5980555.91 618854.17 N 70.35553344 W 149.03476995 1594.92 12.21 262.05 1588.39 97.68 -25.56 -94.80 1.01 5980552.87 618835.77 N 70.35552594 W 149.03491980 8-117 ASP Final Surveys.xls Page 1 of 4 3/4/2003-10:51 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NJ-S EJ-W DLS Northing Easting Latitude longitude (tt) (0) (0) (ft) (ft) (tt) (tt) (0/100ft) (ttUS) (ftUS) 1691 .22 14.90 261.12 1682.00 120.24 -28.88 -117.12 2.80 5980549.20 618813.50 N 70.35551687 W 149.03510106 1781.30 16.31 260.44 1768.76 144.47 -32.77 -141.04 1.58 5980544.93 618789.65 N 70.35550624 W 149.03529526 1874.08 17.50 259.68 1857.53 171.45 -37.43 -167.61 1.30 5980539.85 618763.16 N 70.35549350 W 149.03551103 1967.61 18.48 262.30 1946.48 200.33 -41.94 -196.14 1.36 5980534.89 618734.71 N 70.35548119 W 149.03574266 2060.60 21.55 263.25 2033.85 232.13 -45.92 -227.71 3.32 5980530.40 618703.21 N 70.35547031 W 149.03599902 2154.35 25.15 264.34 2119.91 269.23 -49.91 -264.64 3.87 5980525.83 618666.34 N 70.35545941 W 149.03629893 2247.44 27.79 262.68 2203.23 310.66 -54.63 -305.86 2.94 5980520.46 618625.21 N 70.35544652 W 149.03663361 2341.27 30.82 260.09 2285.05 356.57 -61.55 -351.25 3.50 5980512.81 618579.95 N 70.35542759 W 149.03700213 2434.00 32.41 256.89 2364.02 405.13 -71.28 -398.86 2.49 5980502.33 618532.50 N 70.35540101 W 149.03738872 2527.37 35.13 257.60 2441 .63 456.92 -82.73 -449.47 2.94 5980490.09 618482.08 N 70.35536974 W 149.03779972 ~ 2619.95 37.79 259.44 2516.08 511.89 -93.65 -503.38 3.11 5980478.31 618428.35 N 70.35533989 W 149.03823747 2712.81 40.64 259.82 2588.02 570.58 -104.21 -561.13 3.08 5980466.84 618370.78 N 70.35531103 W 149.03870635 2806.96 43.62 259.55 2657.84 633.72 -115.52 -623.26 3.17 5980454.54 618308.85 N 70.35528011 W 149.03921082 2899.80 44.04 259.36 2724.81 698.00 -127.28 -686.46 0.47 5980441.77 618245.84 N 70.35524795 W 149.03972405 2989.94 44.17 258.69 2789.54 760.70 -139.23 -748.05 0.54 5980428.86 618184.46 N 70.35521531 W 149.04022412 3086.44 45.10 258.82 2858.21 828.46 -152.45 -814.55 0.97 5980414.58 618118.18 N 70.35517917 W 149.04076406 3139.80 45.13 259.51 2895.86 866.25 -159.56 ~851.68 0.92 5980406.89 618081.17 N 70.35515975 W 149.04106556 3245.50 43.29 257.95 2971 .63 939.90 -173.94 -923.96 2.02 5980391.36 618009.14 N 70.35512042 W 149.04165244 3307.64 43.30 257.67 3016.85 982.46 -182.94 -965.61 0.31 5980381.70 617967.64 N 70.35509582 W 149.04199063 3401.56 48.15 257.49 3082.40 1049.58 -197.40 -1031.26 5.17 5980366.20 617902.23 N 70.35505629 W 149.04252370 3493.30 48.70 257.64 3143.28 1118.11 -212.18 -1098.28 0.61 5980350.36 617835.46 N 70.35501589 W 149.04306787 3587.29 48.01 258.57 3205.74 1188.27 -226.66 -1167.01 1.04 5980334.79 617766.98 N 70.35497631 W 149.04362589 3680.21 45.80 261.07 3269.22 1256.10 -238.68 -1233.77 3.08 5980321.72 617700.42 N 70.35494345 W 149.04416799 3773.10 45.04 261.27 3334.42 1322.26 -248.83 -1299.15 0.83 5980310.53 617635.21 N 70.35491567 W 149.04469883 3866.92 45.59 259.91 3400.40 1388.96 -259.74 -1364.95 1.19 5980298.57 617569.60 N 70.35488584 W 149.04523312 ~ 3958.53 45.15 259.84 3464.76 1454.14 -271 .20 -1429.13 0.48 5980286.10 617505.61 N 70.35485449 W 149.04575422 4052.11 44.69 259.34 3531.02 1520.21 -283.14 -1494.13 0.62 5980273.13 617440.83 N 70.35482185 W 149.04628191 4145.42 44.46 259.72 3597.49 1585.68 -295.04 -1558.52 0.38 5980260.21 617376.63 N 70.35478930 W 149.04680479 4238.53 43.87 259.26 3664.28 1650.54 -306.87 -1622.31 0.72 5980247.37 617313.05 N 70.35475694 W 149.04732267 4332.17 43.55 259.60 3731.97 1715.23 -318.74 -1685.91 0.42 5980234.49 617249.64 N 70.35472447 W 149.04783912 4426.22 43.22 259.62 3800.32 1779.82 -330.40 -1749.46 0.35 5980221.83 617186.30 N 70.35469260 W 149.04835505 4519.81 42.56 258.52 3868.89 1843.48 -342.47 -1812.00 . 1.07 5980208.77 617123.96 N 70.35465958 W 149.04886283 4614.48 42.13 258.49 3938.86 1907.20 -355.18 -1874.49 0.45 5980195.07 617061.69 N 70.35462482 W 149.04937020 4707.20 41.36 258.69 4008.04 1968.89 -367.39 -1935.00 0.84 5980181.90 617001.38 N 70.35459141 W 149.04986153 4800.79 40.53 261.30 4078.73 2030.21 -378.06 -1995.39 2.03 5980170.28 616941.18 N 70.35456223 W 149.05035182 S-117 ASP Final Surveys.xls Page 2 of 4 3/4/2003-10:51 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NJ-S EJ-W DLS Northing Easting Latitude Longitude (ft) e) (0) (ft) (ft) (ft) (ft) (°/1000) (ftUS) (ftUS) 4893.32 40.36 262.00 4149.15 2090.23 -386.77 -2054.78 0.52 5980160.62 616881.94 N 70.35453837 W 149.05083401 4985.95 39.92 262.44 4219.97 2149.92 -394.86 -2113.94 0.57 5980151.60 616822.92 N 70.35451624 W 149.05131438 5079.34 39.55 262.14 4291.78 2209.60 -402.87 -2173.10 0.45 5980142.65 616763.90 N 70.35449432 W 149.05179471 5171.63 38.98 261.59 4363.24 2268.00 -411.13 -2230.92 0.72 5980133.47 616706.22 N 70.35447169 W 149.05226419 5266.14 38.76 261.89 4436.82 2327.30 -419.65 -2289.62 0.31 5980124.02 616647.67 N 70.35444837 W 149.05274074 5358.23 38.07 261 .60 4508.97 2384.51 -427.87 -2346.24 0.77 5980114.91 616591.19 N 70.35442588 W 149.05320051 5451.37 37.62 261.65 4582.52 2441.65 -436.19 -2402.78 0.48 5980105.69 616534.80 N 70.35440309 W 149.05365952 5545.51 37.35 261.26 4657.23 2498.93 -444.70 -2459.43 0.38 5980096.28 616478.29 N 70.35437979 W 149.05411950 5640.23 38.66 260.31 4731.86 2557.25 -454.05 -2517.00 1.51 5980086.02 616420.88 N 70.35435420 W 149.05458688 5734.66 39.61 262.66 4805.11 2616.84 -462.86 -2575.93 1.87 5980076.28 616362.10 N 70.35433008 W 149.05506538 .~ 5829.63 39.62 263.26 4878.27 2677.35 -470.28 -2636.03 0.40 5980067.91 616302.13 N 70.35430974 W 149.05555332 5921.27 39.76 262.56 4948.79 2735.83 -477.50 -2694.11 0.51 5980059.76 616244.19 N 70.35428995 W 149.05602485 6015.44 39.79 261.81 5021.16 2796.05 -485.70 -2753.79 0.51 5980050.62 616184.64 N 70.35426751 W 149.05650946 6106.98 39.44 261.99 5091.68 2854.41 -493.92 -2811.58 0.40 5980041.48 616127.00 N 70.35424499 W 149.05697862 6202.63 38.80 263.37 5165.89 2914.72 -501.61 -2871.43 1.13 5980032.84 616067.28 N 70.35422390 W 149.05746458 6295.33 38.87 264.07 5238.10 2972.78 -507.97 -2929.21 0.48 5980025.57 616009.61 N 70.35420647 W 149.05793372 6387.77 38.36 262.96 5310.33 3030.40 -514.48 -2986.53 0.93 5980018.15 615952.41 N 70.35418862 W 149.05839910 6480.63 37.90 262.92 5383.37 3087.69 -521.53 -3043.43 0.50 5980010.20 615895.63 N 70.35416931 W 149.05886108 6572.68 37.11 261.98 5456.40 3143.71 -528.89 -3098.99 1.06 5980001.96 615840.20 N 70.35414914 W 149.05931214 6666.02 36.05 261.35 5531.35 3199.32 -536.95 -3154.03 1.20 5979993.03 615785.31 N 70.35412706 W 149.05975899 6758.91 35.27 260.03 5606.82 3253.47 -545.70 -3207.46 1.18 5979983.43 615732.02 N 70.35410308 W 149.06019283 6852.40 34.41 259.38 5683.55 3306.87 -555.25 -3260.01 1.00 5979973.05 615679.63 N 70.35407695 W 149.06061947 6945.93 32.61 260.89 5761.54 3358.50 -564.11 -3310.88 2.12 5979963.38 615628.92 N 70.35405268 W 149.06103243 7038.94 31.38 261.06 5840.42 3407.78 -571 .84 -3359.55 1.33 5979954.88 615580.38 N 70.35403150 W 149.06142757 7133.68 29.17 263.08 5922.23 3455.52 -578.46 -3406.84 2.57 5979947.52 615533.20 N 70.35401337 W 149.06181154 ~ 7227.19 26.84 264.34 6004.79 3499.37 -583.28 -3450.48 2.57 5979942.00 615489.65 N 70.35400012 W 149.06216582 7319.20 24.23 265.11 6087.80 3538.93 -586.94 -3489.96 2.86 5979937.71 615450.23 N 70.35399008 W 149.06248643 7413.14 22.67 263.53 6173.98 3576.23 -590.63 -3527.16 1.79 5979933.44 615413.10 N 70.35397997 W 149.06278844 7507.20 22.10 263.74 6260.95 3612.01 -594.60 -3562.76 0.61 5979928.90 615377.57 N 70.35396907 W 149.06307747 7600.75 20.72 265.12 6348.05 3646.09 -597.92 -3596.75 1.57 5979925.04 615343.65 N 70.35395994 W 149.06335338 7694.51 18.31 264.62 6436.41 3677.32 -600.72 -3627.94 2.58 5979921.75 615312.51 N 70.35395227 W 149.06360664 7787.47 16.53 264.15 6525.11 3705.10 -603.43 -3655.63 1.92 5979918.59 615284.86 N 70.35394481 W 149.06383150 7880.01 15.65 263.34 6614.02 3730.71 -606.22 -3681 .13 0.98 5979915.40 615259.42 N 70.35393715 W 149.06403849 7973.59 15.55 263.45 6704.15 3755.84 -609.12 -3706.13 0.11 5979912.11 615234.47 N 70.35392921 W 149.06424145 8066.64 14.91 263.48 6793.94 3780.26 -611.90 -3730.41 0.69 5979908.94 615210.23 N 70.35392158 W 149.06443862 S-117 ASP Final Surveys.xls Page 3 of 4 3/4/2003-10:51 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 8159.54 14.05 264.80 6883.88 3803.45 -614.28 -3753.52 0.99 5979906.20 615187.17 N 70.35391505 W 149.06462620 8256.20 13.34 264.92 6977.80 3826.27 -616.33 -3776.31 0.74 5979903.78 615164.42 N 70.35390941 W 149.06481126 8325.00 13.34 264.92 7044.74 3842.11 -617.74 -3792.12 0.00 5979902.13 615148.63 N 70.35390555 W 149.06493963 '-" ~' S-117 ASP Final Surveys.xls Page 4 of 4 3/4/2003-10:51 AM Drilling & Measurements 3940 Arctic Boulevard Suite 300 Anchorage AK 99503 Tel (907) 273-1700 Fax (907) 561-8317 Date: Well Name: Company: API Number: AFE Number: Location: Field: Rig: ) ) ó?ó~ò/~ Schlumberger February 22, 2003 S-117 BP Exploration (Alaska) Inc. 50-029-23137-00 AUD5M0053 S-Pad, Prudhoe Bay Aurora Nabors 9ES Drilling and Measurements Field Support: Operations Manager: Field Service Manager: Greg Nutter Nate Rose Gavin Rennick Drilling and Measurements Field Crew: Cell Manager(s): SERVICES PROVIDED Services Directional Survey Service PowerPu1se - Gamma Ray VISION* Pressure While Drilling VISION* Gamma Ray OPERATING STATISTICS Total MWD Pumping Time: Total MWD Time Below Rotary: Total MWD depth interval: Total MWD Runs: JOB PERFORMANCE Directional Cell Engineer(s): Etienne Roux Mark St. Amour Brandon Barnes Services Dates Depth Intervals 17-Feb-03 to 22-Feb-03 17-Feb-03 to 18-Feb-03 20-Feb-03 to 22-Feb-03 20-Feb-03 to 22-Feb-03 108 ft to 8325 ft 108 ft to 3200 ft 3200 ft to 8325 ft 3200 ft to 8325 ft 60.7 hr 101.5 hr 8217 ft 3 Total L WD Pumping Time: Total L WD Time Below Rotary: Total L WD depth interval: Total LWD Runs: 33.55 hr 56 hr 5125 ft 1 The final MWD survey point was 8256.2 ft with an inclination of 13.34 degrees and an azimuth of 264.92 degrees. A survey was straight line projected ahead to TD using an inclination of 13.34 degrees and an azimuth 264.92 degrees. The final bottom hole location is: Measured Depth: True Vertical Depth: Displacement at Azimuth: 8325.00 ft 7044.74 ft 3842.11 ft at 260.75 degrees 1 .; ..~. ) ') Formation Evaluation 12 ~ in Surface Hole PowerPulse Gamma Ray was utilised for run I and 2. The real-time data received from the PowerPulse tool enabled the well-site geologist to pick the surface casing point below the SV3 sand at a depth of 3200 ft. On Run I Gyro Surveys were utilised up to a depth of 1470 ft due to interference from nearby wells. 8 3/4 in Production Section The following measurements were presented in real-time: ARC Gamma Ray, as and Annular Pressure while Drilling (APWD) data. The annular pressure sensor failed while drilling cement. The data sent up- hole was intermittently erratic. The readings from the sensor were usually too high. No problems were encountered with the GR measurement. At the conclusion of Run 3, the LWD tool memory was downloaded and recorded mode logs generated. ARCS Gamma Ray was provided from downhole memory. The final recorded memory data had good resolution over the logged section. Transverse Shock Transverse shocks were monitored in the MWD/L WD tools, which were infrequent and low in severity. Down-hole collar RPM was monitored in real-time, showing no appreciable stick slip encountered while drilling this well. Lesson(s) Learned It is unfortunate that the annular pressure sensor failed. Even though the APWD sensor was erratic, the baseline ECD from the sensor appeared correct, when all of the high readings were eliminated.. This baseline ECD was used as a guide as well as best drilling practices learned from previous wells of this kind to drill the production hole without any well control problems. Innovation(s) All of the tools were programmed and the recorded memory data retrieved from them while placed in the pipe shed instead of on the rig floor leading to a substantial reduction in rigtime required for the make up and break of the BHA respectively. Schlumberger Oilfield Services - Drilling & Measurements appreciates the opportunity to provide BP Exploration (Alaska) Inc. with MWD and L WD services. Sincerely, Mark St. Amour Cell Manager Drilling & Measurements 2 ) ') Dl 0 3-0 Ie:< MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No S-117 Date Dispatched: 15-Feb-03 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 RECEIVED MAR 1 0 2003 Alas..<3 (}'i & Gas Cons. Commiaaion AnchOl'a!; e Received By: ~(. O~ ) Please sign and return to: Anadrill L WD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1 , Dec '97 ~ c.-;J /ð\ c,-:J 'E r:~ . [) ®.. . ® (~ - r¡ /F.\. K Q- .~J [f1.\.~ _:=1 ~J f 11,-\ ...;::] InJ c~)_ \\ flU ,) I AlASKA OIL AND GAS CONSERVA.TION COMMISSION Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7rH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit S-117 BP Exploration (Alaska) Inc. Permit No: 203-012 Surface Location: 4376' NSL, 4499' WEL, SEC. 35, TI2N, RI2E, UM Bottomhole Location: 3767' NSL, 3070' WEL, SEC. 34, TI2N, RI2E, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law fron1 other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to cOlnply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this pelmit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Comn1ission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~,,~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this :l'?~day of January, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ~/GA- ì Il.,"¡O~ \ ) STATE OF ALASKA ) ALASKJ-\ JIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Î a. Type of work II Drill 0 Redrill 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil ORe-Entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 64.4' Prudhoe Bay Field / Aurora 3. Address 6. Property Designation Pool (Undefined) P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028258 4. Location of well at surface x = 618930, Y = 5980579 7. Unit or Property Name 43761 NSL, 4499' WEL, SEC. 35, T12N, R12E, UM Prudhoe Bay Unit At top of productive interval x = 615235. Y = 5979925 8. Well Number 37791 NSL, 2925' WEL, SEC. 34, T12N, R12E, UM 8-117 At total depth x= 615090, Y = 5979911 9. Approximate spud date 37671 NSL, 30701 WEL, SEC. 34, T12N, R12E, UM 02/05/03 Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well J 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028257, 3070' MD S-116 is 161 away at 400' MD 2560 8302' MD / 7064' TVD 16. To be completed for deviated wells 17. Anticipated pressure {se~O AAC 25.035 (e) (2)} Kick Off Depth 7251 MD Maximum Hole Angle 400 Maximum surface 2617 psig, At total depth (TVD) 6639' / 3280 psig 18. Casin~ Program Specifications Setting Depth Size TOD Bottom Casina Weiaht Grade CouDlina Lenath MD TVD MD TVD 20" 91.5# H-40 Weld 80' Surface Surface 110' 1101 9-5/8" 40# L-80 BTC 3215' Surface Surface 3215' 2939' T' 26# L-80 BTC-M 8301' Surface Surface 8301' 7064' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Hole 42" 12-1/4" 8-3/4" Quantitv of Cement (include staae data) ,260 sx Arctic Set (Approx.) 538 sx PF 'L', 297 sx Class 'G' 322 sx Lite, 169 sx Class IG' / /' 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 MD TVD Structural Conductor Surface Intermediate Production Liner R"" '. ~f·"'. 'C'''' 'i~'"" ~ t", 't') .. ~" "e",·.t ,1..,~.. ~, \1'" ~:.::, J '. 1\ 1 ,') "j '2' ~)¡ì\ '< ,. f.\ l \\ L j U \.¡ ',,' Perforation depth: measured true vertical 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 AAC 25.050 Requirements gee, 564-5119 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the fa oing is tr~~rrect to the best of my ~nowl~~ge . Signed Lowell Cr e ~ Æ~ Title Senior Dnlllng Engineer Date ¡ - ;J.I- 0 '1 ,) 'I:, : .,: I, . ." ~ilSibØ. '-.'Øìîlí: : ; ",,;,'> ':k:'.,~ .'" \ ',:, ,I ".:;.,¡::., :"'::,;,;.:::,,:,,' " Permit Number API Number APprovl1 q~YT ,/1 See cover letter . .<0 S - ð/ 2... 50- c)¿ 9 - ¿ 3 (s 7 \ ~ ~IIO I) for other requirements Conditions of Approval: Samples Required 0 Yes 12!1 No Mud Log Req Ired 0 Yes æ1 No Hydrogen Sulfide Measures 0 Yes ~ No Directional Survey Required jgJ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU OtherdRtÓi~R{tI~~m pç ~. Pe..¡- 'Zð Áf\-L 25,(.'V3S(h.) (2.)( <kif ~t tQ.· y-e·t¡~l.Ó..c ~;...'t'.4'- t- K: ill Vl d M L BiI! by order 0 ~' '/1: Approved By Commissioner the commission Date \.~ 1 () /7 Form 10-401 Rev. 12-01-85 ubmit In T/¡plicate ) ..,WI1. bp ......~ ~~. .~i ~~. ·'4'¡\~ ) To: Winton Aubert, AOGCC Date: Jan. 21 , 2003 From: Neil Magee Subject: Dispensation for 20 AAC 25.035 (c) on 8-117 - permit submitted BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, support the rationale for the request. To date, none of the 40-plus Ivishak wells at S-pad, nor the recent AuroraJPolaris wells have experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. The first ten surface holes for the Aurora/Polaris development were drilled no deeper than the shale underlying the SV -1 sands; S-117 is planned to TD in the shallower SV -3 shale, as did the most recent wells. The shale underlying the SV 1 is the deepest planned surface casing setting depth for future pad development wells. This casing point is ±700' TVD above the U gnu horizon. The shallowest and most recent RFT points recorded in the area are from S-201, recording a pore pressure of 1,423psi at 3,175' TVDss (8.6 ppg EMW) and not exceeding 8.7 ppg EMW above 3700' TVDss. S-117 is planned to reach 9.5 ppg mud weight before TD at 2,939' TVD. Supporting surface hole gas detection informatj>n is on file with the AOGCC from the recently drilled S-.1-M as requested by AOGCC. ïiS ~6K Your consideration of the waiver is appreciated. Sincerely, ~~r Neil Magee GPB Rotary Drilling Engineer 564- 5119 ) ") IWell Name: 18-117 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Producer Surface Location: As-Built Target Location: Top Kuparuk Bottom Hole Location: x = 618,930.14' Y = 5,980,579.93' 4376' FSL, (9031 FNL), 4499' FEL (7801 FWL), Sec. 35, T12N, R12E X = 615,235' Y = 5,979,925' 37791 FSL (15011 FNL), 29251 FEL (23551 FWL), Sec. 34, T12N, R12E X = 615090.85' Y = 5,979,911.08' 37671 FSL (15121 FNL), 30701 FEL (22101 FWL), Sec. 34, T12N, R12E I I AFE Number: 1 AUD5MXXX I I Estimated Start Date: 12/5/2003 I RiQ: 1 Nabors 9ES /' I Operating days to complete: 111.8 I MD: 18302' I TVD: 17064' I I I RT/GL: 128.5' 1 I RKB/MSL: 164.4' I I Well DesiQn (conventional, slim hole, etc.): 1 Ultra Slimhole (Iongstring) I Objective: I Single zone producer into the Kuparuk formation. Mud Program: 12 %" Surface Hole (0-3215'): Densitv (ppg) 8.5- 9.2 9.0 - 9.5 9.5 max Initial Base PF to top SV SV toTD Viscosity (seconds) 250-300 200-250 150-200 Fresh Water Surface Hole Mud Yield Point API FL PH (lb/1 OOft~) (mls/30min) 50 - 70 15 - 20 30 - 45 < 10 20 - 40 < 10 8.5- 9.5 8.5- 9.5 8.5 - 9.5 8 3,4" Production Hole (3215' - 8302'): LSND Interval Density Tau 0 YP PV pH API 10' Gel (ppg) Fi Itrate Upper 9.7 4-7 25-30 10-15 8.5-9.5 6-10 10 Interval 9.9 - 10 / Top of HRZ 3-7 20-25 1 0-15 8.5-9.5 4-6 10 to TD S-117 Drilling Program-Draft Page 1 ) ) Hydraulics: Surface Hole: 12-1/4" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-1969' 550 4" 17.5# 90 1800 10.0 N/A 18,18,18,16 .942 1969'-3215' 650 4" 17.5# 110 2400 10.2 N/A 18,18,18,16 .942 Production Hole: 8 %" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 3215' - 8302' 600 4" 17.5# 240 3400 11.2 N/A 3x14,3x15 .969 Hole Cleaning Criteria: Interval Interval ROP Drill Pump Mud Hole Cleaning Condition Pipe GPM Weight Rotation 110'-3215' Surface Superior hole cleaning practices at to SV-3 connections will greatly enhance cuttings transport in the sliding mode 180 60 500 9.5 Acceptable 220 60 600 9.5 Acceptable 260 60 700 9.5 Acceptable 195 80 500 9.5 Acceptable 230 80 600 9.5 Acceptable 270 80 700 9.5 Acceptable 200 100 500 9.5 Acceptable 240 100 600 9.5 Acceptable 290 100 700 9.5 Acceptable 3215'-8302' 9-5/8" to Sweeps and fully reamed connections TD to maintain minimum hole cleaning requirements 240 80 500 9.7 Acceptable 265 80 600 9.7 Acceptable 300 100 500 9.7 Acceptable \0,,0 340 100 550 9.9 Acceptable 400 120 550 9.9 Acceptable S-117 Drilling Program-Draft Page 2 Directional: Ver. Anadrill P3 KOP: 725' Maximum Hole Angle: Close Approach Wells: None Logging Program: Surface Intermediate/Production Hole ) ) 40 deg at 2609' MD All wells pass major risk criteria. The nearest wells are: 8-115 - 19.5' ctr-ctr@ 750' 8-116 - 15.7' ctr-ctr @ 400' (planned) 8-213 - 32.4' ctr-ctr @ 950' 8-216 - 61.1' ctr-ctr @ 350' IFR-M8 corrected surveys will be used for survey validation. An electronic gyro will be needed for surface issues to 1000' MD. Drilling: Open Hole: Cased Hole: Drilling: Open Hole: Cased Hole: Formation Markers: Formation Tops SV6 Base Permafrost SVS SV4 SV3 SV2 SV1 UG4A UG3 UG1 Ma WS2 Na WS1 Oa Obf Base CM1(Colville) THRZ BHRZ (Kalubik) TKUP Kuparuk C2 LCU (Kuparuk B) Kuparuk AS TMLV (Miluveach) TD Criteria 8-117 Drilling Program-Draft TVDss 1570 1890 2180 2385 2775 2890 3240 3615 3935 4410 4700 4925 5040 5360 6540 654 6561 6575 6585 6675 6755 681 MWD I GR None None MWD/GR/PWD/RE8 PexlSonic Estimated pore pressure, PPG 8.6 ppg EMW Hydrocarbon bearing, 9.2 ppg EMW Hydrocarbon bearing, 8.8ppg EMW Hydrocarbon bearing, 8.8 ppg EMW Hydrocarbon Bearing, 9.5 ppg EMW Hydrocarbon Bearing, 9.5 ppg EMW Hydrocarbon Bearing, 9.5 ppg EMW 150' MD below Miluveach top ,0.0 Page 3 ) ) CasingITubing Program: Hole Csgl WtlFt Gr~e Conn Length Top 8tm Size Tba O.D. I MD/TVD MD/TVD bkb 42" Insulated 20" 91.5# H-40 WLD 80' GL 110'/110' 12 1A" 9 5/8" 40# L-80 BTC 3215' GL 3215'/2939' 8 314" 7" 26# L-80 BTC-m 8301' GL 8301 '/7064' Tubing 3 V2" 9.2# L-80 IBT Mod 7760' GL 7760'/6550' InteQrity TestinQ: Test Point Depth Surface Casing Shoe 20' min from su rface shoe Test Type LOT EMW 11.6 ppg EMW Target Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as a contingency if cement is not circulated to surface. Casinq Size 19-5/8" Surface I Basis: Lead: Based on conductor set at 110', 1969' of annulus in the permafrost @ 2250/0 excess and 496' of open hole from top of tail slurry to base permafrost @ 300/0 excess. Lead TOG: To surface Tail: Based on 750' MD(>500'TVD) open hole volume + 30% excess + 80' shoe track volume. Tail TOG: At -2465' MD Total Cement Volume: Lead 398 bbl / 2232 ffl / 538 sks of Halliburton Permafrost L at 10.7 ppg and 4.15 dIsk. Tail 61 bbl / 342 ffl / 297 sks of Halliburton 'G' at 15.8 ppg and 1 .15 dIsk. Casinq Size 17" Production Longstring I Basis: Stage 1: Based on TOC 500' above top of Kuparuk formation + 300/0 excess + 80' shoe Cement Placement: Tail from shoe to 7382' MD, lead from 7382' to 3678' - 500' above UG4A sand Total Cement Volume: Lead 128 bbls / 718 ffl / 322 sks of Halliburton "Tuned Light" at 12.0 ppg and 2.23 dIsk. 35 bbl / 196 ffl / 169 sks of Halliburton 'G' at 15.8 ppg and 1 .16 dIsk. Tail 8-117 Drilling Program-Draft Page 4 ) ) Well Control: I Surface hole will be drilled without diverter. The production hole well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test for future fracture stimulation treatment, the BOP equipment will be tested to 4000 psi. Oiverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: 3280 psi @ 6639' TVOss - Kuparuk C4 Sands 2617 psi @ surface / (based on BHP and a full column of gas from TD @ 0.10 psi/ft) 4000~i (The casing and tubing will be tested to 4000 psi as · Planned BOP test pressure: required for fracture stimulation.) · Planned completion fluid: 8.6 ppg filtered seawater / 6.8 ppg diesel Disposal: · No annular disposal in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at 08-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to 08- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. 8-117 Drilling Program-Draft Page 5 ) ) DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor was installed in Nov. 2002. 1. Weld an FMC landing ring for the FMC Ultra slim hole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up spool (diverter waiver applied for). PU 4" DP as required and stand back in derrick. 3. MU 12 %" drilling assembly with MWD/LWD (page 4) and directionally drill surface hole to approximately 100' TVD below the SV3 Sands. An intermediate wiper/bit trip to surface for a will be performed prior to exiting the Permafrost. 4. Run and cement the 9-5/8", 40# surface casing back to surface. 5. ND riser spool and NU casing / tubing head. NU BOPE and test to 4000 psi. 6. MU 8-3/4" drilling assembly with MWD/LWD(page 4) and RIH to float collar. Test the 9-5/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.7 ppg drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 8. Drill to +/-100' above the HRZ, ensure mud is in condition to 10.0 ppg and perform short trip as needed. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. 9. Drill ahead to TD at -150' MD below Top Miluveach. 10. Condition hole for Pex/Sonic logging. 11. Run Pex/Sonic. 12. Perform wiper trip and condition hole for running 7" 26# long-string casing. 13. POOH and lay down drillpipe. 14. Run and cement the 7" production casing in a single stage. (To be reviewed based on log/operational results.) Displace the cement with 8.5 ppg filtered seawater if single stage. 15. Freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on the Morning Report. 16. Test casing to 4000 psi for 30 minutes. 17. Run the 3-1/2", 9.2#, L-80 IBT completion assembly. Set packer and test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes. Shear DCK shear valve and install TWC. Test below to 1000 psi. 18. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 19. RU hot oil truck and freeze protect well by pumping diesel to lowermost GLM. Allow to equalize. 20. Rig down and move off. S-117 Drilling Program-Draft Page 6 ') ) 5-117 Drilling Program Job 1: MIRU Hazards and Contingencies ~ 8-Pad is not designated as an H28 site. Recent well test indicate no more than 7ppm H2S concentrations. Standard Operating Procedures for H2S precautions should be followed at all times. ~ The closest surface location is 8-115, 19' to the North. The well is expected to be on production and will require a surface shut in during move in. þ> Check the landing ring height on 8-117 prior to rig mobilization. The BOP nipple up may need review for proper space out prior to spud. Reference RPs .:. ItDrilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: DrillinQ Surface Hole þ> There are two nearby well in the surface hole. Refer to page 4 for details. þ> An electronic gyro survey is required per the directional plan to 1000' MD or until the magnetic interference at the surface has dissipated. þ> Gas hydrates have been observed in wells drilled on 8-Pad. These were encountered near the base of permafrost to TD in the 8V1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to Baroid mud recommendation þ> 8-117 will cross one fault in the surface hole @ 1850' MD' +/- 100'. Faults in this area have not been problematic. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations IIUlllUllmUllmllml!lla:lII\ml~IWIIIIII:IIU:LLlIWlml. T -11I_ JU_:_;T.IInLII:lull.....I7I11I11..:U:nIllIllIlUlllllwlil~lIInIlIlIllIlIllIlIIIlLUUI.IIIIC~UI.JU-· .t!:. U\-T.mIllUlllu:mIlUII.LlIIILLIL .II. --11I---\-:II:.tI...----Hr- .mll!mll!lllllll!lIIllII~lmlllll!I:IIIL_mUII_.. ITlUlIII."lIlImllllllllll..lILI.JL '\If>IIIIWIIIIIIIIIILlIU. ,-:I:"'II,IIU--JlIIIII Job 3: Install Surface CasinQ Hazards and Contingencies þ> It is critical that cement is circulated to surface for well integrity. 2250/0 excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. A 9-5/8" port collar will be positioned at ±1 OOO'MD to allow remedial cementing. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" 8-117 Drilling Program-Draft Page 7 ) 'ì ) Job 7: DrillinQ Production Hole Hazards and Contingencies ;.. S-117 will cross one fault - in the lower Colville - 6280'TVD, 7480' MD (+/- 125'). Lost circulation is considered to be a moderate risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. ~ KICK TOLERANCE: In the scenario of 9.5 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 11.6 ppg at the surface casing shoe, 10.1 ppg mud in the hole the kick tolerance is 25 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Manager if LOT is less than 11.6 ppg. ~ Previous wells S-200 and S-201 encountered overpressure (10.0 ppg EMW) while drilling the UG4A. Mud weights of 10.1-10.3 were required to contain the pressure. Several S-Pad wells drilled in 2000 used 10.5 ppg to drill this interval as a precaution. Since that time eighteen wells have been drilled on S Pad without encountering the overpressure. Gas cut mud, mud flow and oil in the returns may indicate that the overpressure is still present at which point the mud should be weighted up. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "Shale Drilling- Kingak & HRZ" 1!:~ -:III!I.I.. I..' ;-;lmlll',lllmmml:m:W1Ulllmr:mll Job 8: LOQ Production Hole Hazards and Contingencies ;.. Ensure the hole is in optimal condition prior to logging to ensure a successful logging program. Review the use of lubricant pill across logging interval. ;.. If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 7"longstring casing. Reference RPs .:. Follow Schlumberger logging practices and recommendations. .:. "Drillpipe Conveyed Logging" m"¡'i,;¡,'im»",v,;-,}»:v.;,,,,,,m~"''''')}'''¡nm,;;¡;;;;,;,;¡,;,;,,;;,;;;~.-m.-¡.-'iffl¡!~-¡!;mm¡;¡¡'~AA;¡J;¡¡~~mmmm;;mmh~:~mmmmmm¡¡,¡m~">I"w.-"m""""YJ!.)""')"'mJli:"';~m)jt;",;~"mmmmmmmmm;mm,-..-mmm~-'lMIi;m,-m~!h¡¡m¡mmmmmmm~mm¡';¡"-¡;,-.-AA-J,-¡;,:m,-¡'¡';N!<;¡m;;¡.¡¡.mmm,~JJmmmmmmmjumJ;:mmmm.ammmJm¡Jm.;.y;;',-m,-A Job 9: Case & Cement Production Hole Hazards and Contingencies ;.. The interval is planned to be cemented in a single stage with a 12.0 ppg lead (500'MD above the Schrader UG4Aa) and a 15.8 ppg tail (500' above the Kuparuk). If a single stage cement job is deemed too risky while drilling, then a 2 stage cement job may be performed. ~ Ensure the upper production cement has reached at least a 70BC thickening value prior to freeze protecting. After freeze protecting the 7" x 9-5/8" casing outer annulus with dead crude to (2300' MD, 2221 'TVD), the hydrostatic pressure will be 7.7 ppg vs 8.5 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present 8-117 Drilling Program-Draft Page 8 ) ) after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 110 psi underbalance to the open hole. ~ Cement is being placed from TD to 500' above the UG4A at 3678'. It may be prudent to insure the 9-5/8" x 7" annulus is clear if there is a delay in cement reaching adequate thickening/compressive strength development. ~ Ensure a minimum hydrostatic equivalent of 10.0 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of .hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. ~ Considerable losses during running and cementing the 7" longstring has been experienced on offset wells. A casing running program will be jointly issued by the ODE and Drilling Supervisor detailing circulating points and running speed. In addition a LCM pill composed of "Steel Seal" will be placed across the Schrader and Ugnu to help arrest mud dehydration. Reference RPs .:. Illntermediate Casing and Cementing Guidelines" .:. IIFreeze Protecting an Outer Annulus" ..,..;;.;....m,."",..........,,,..............,,.,,.,"'........,......~,...,.,.,,....,,.,,.,,.. .....,.,........... ........... ."""""""""",.."""".....N...............~AW;.,-.-.-:::.-.-:.-.~-.-.'i.-.-.-.-.- Job 12: Run Completion Hazards and Contingencies ~ Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The well will be underbalanced if there is a casing integrity problem. ~ Shear valves have been failing at lower than the 2500 psi differential pressure. When testing annulus maintain no more than a 1500 psi differential: 2500 psi tubing pressure, 4000 psi annulus pressure. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus Operational Specifics · ND stack. NU tree and test to 250 and 5000 psi with diesel. Test packoff to 5000 psi. Pull TWC. · R/U hot oil truck and freeze protect well by reverse circulating diesel to the lowermost 4-1/2" GLM. Allow diesel to U-tube from annulus to tubing and equalize. Refer to RP: Freeze Protection of Inner Annulus. · Install BPV & test to 1000 psi from below. · Rig down and release the rig. 8-117 Drilling Program-Draft Page 9 TREE = 4-1/16" Cr.N WELLHEA D = FMC 'A'êTUÃÏ"OR ~...w""'"w"",,,,~w~'^"''''''^'NA'' ..,·.'.·...'..,·..."w.'.,·,,·.".....'.,·.'.·,·.'.·.'.',·,.'.'.'..,.,','.....','.....'."'.'.,'.......',.~,....._,'..,,",.,'.""..,.,·,.'.·,.'.....'.w.'.'...,,'. KB. ELEV = 64.4' 'B¡=':"ECBl";'w"...~.'~WM^W"."w^"'ÑA' .....'...','..'.'"",'.','...',',',", .'.',,,"".w.'..·...'.,·,'.'...,,.'.w,'...-.. .'.'""",.','.'0'10<.'.',','."0',.',""""""'''"'''''''''''''.'.....'.,,'. KOP = 300' r:;;¡ã'X'''Angìë;;'''''''-xx'''@^x-x"'x;? Õãtu;:;;·MÖ';"-··^"'M""'.W^"'~'" 'Õãtum"'iVÕ;'"'ww",,,)õó(ö'ŠŠ' ") 9-5/8" CSG, 40#, L-80, ID = 8.835" 1-1 3215' r-JI Minimum ID = 2.813" @ xxxx' 3-1/2" HES X NIPPLE I 3-1/2" TBG, 9.2#, L-80, IBT Mod Butt, .0087 bpf, ID = 2.992" 13-1/2" TBG, 9.2#, L-80, IBT Modified Butt .0087 1-1 7760' bpf, ID = 2.992" I PERFORA TION SUMMARY REF LOG: TCP ÆRF ANGLEATTOPÆRF: xx @ xxxx' Note: Refer to A-oduction DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DA TE I PBTD 1-1 I 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" 1-1 8220' 8302' DA TE REV BY COMMENTS 01/20/03 NM PROPOSED COMPLETION 5-117 ) =---1 1000' 1-1 9-5/8" TAM PORT COLLAR 1 I I I 2200' 1-1 3-1/2" HES X NIP, ID = 2.813" 1 ~ GAS LIFT MANDRELS ST MD ìVD DEV TYPE VLV LA TCH PORT I DATE 1 tbd MMG DCK-3 BTM 3.5x 1.5 2 5600 MMG Dummy BTM 3.5x1.5 3 4800 MMG Dummy BTM 3.5x1.5 4 3600 Dummy BTM 3.5x1.5 L - - . I I I / ~ :8: ~t . ~ DA TE REV BY COMMENTS XXXX' 1-1 Short Joint 1jt below I base Schrader 7675' 1-13-1/2" BKR CMD SLIDING SLV, ID = 2.813" 7700' 1-1 7" X 3-1/2" BKR PREMIER PKR, ID = I 2.992" 7726' 1-1 3-1/2" HES X NIP, ID = 2.813" 1 7746' 1-1 3-1/2" HES X NIP, ID = 2.813" 7760' 1-1 3-1/2" WLEG, ID = 2.875" 1 XXXX' 1-1 Short Joint 1jt above top I KUPA GPB BOREALIS WELL: S-117 PERMIT No: API No: SEC 35, T12N, R12E 903' FNL & 780' FWL BP Exploration (Alas ka) ') ) S-117 Well ,Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates may be encountered near the base of the Permafrost at 1969'MD and near the TD hole section as well. · S-30 and S-25 located on the Southern portion of the pad, reported outer annulus pressures in the past. In December 2002 S-25 was shut in. S-30 is on production however is being monitored. The pressure does not appear to have charged up any shallow sands in the wells drilled since that time. . · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. · A shallow fault may be encountered at 1850'. This fault has not been cause of concern in past crossings. Production Hole Section: · The production section will be drilled with a recommended mud weight of 10.0 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 9.5 pore pressure. · Previous wells S-200 and S-201 encountered overpressure (10.0 ppg EMW) while drilling the UG4A. Mud weights of 10.1-10.3 were required to contain the pressure. Several S-Pad wells drilled in 2000 used 10.5 ppg to drill this interval as a precaution. Since that time eighteen wells have been drilled on S Pad without encountering the overpressure. Gas cut mud, mud flow and oil in the returns may indicate that the overpressure is still present at which point the mud should be weighted up. · 8-117 will cross a fault at ~6285' TVD, 7480' MD (+/-150'). Lost circulation is considered to be a moderate risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. HYDROGEN SULFIDE - H2S . This drill-site is not designated as an H2S drill site. Recent wells tests indicate 7 ppm H2S concentration in Kuparuk wells. Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE S-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies I KBE KOP Bid 1.5/100 Cry 2.5/100 Cry 1.5/100 SV6 End Cry Base Perm bp Report Date: Client: Field: Structure I Slot: Well: Borehole: UWIIAPI#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid NIE YIX: Grid Convergence Angle: Grid Scale Factor: 5-117 Proposed Well Profile - Geodetic Report Minimum Curvature / Lubinski 260.860° N 0.000 ft, E 0.000 f\ KB 64.4 ft relative to MSL 0.000 ft relative to MSL 25.806° 57524.768 nT 80.820° February 05, 2003 BGGM 2002 True North +25.806° Well Head January 17, 2003 BP Exploration Alaska Prudhoe Bay Unit - WOA (Drill Pads) S-PAD / Plan S-117 S-117 S-117 50029 S-117 (P3) / January 17, 2003 60.525° /3899.44 ft /5.443/ 0.55:! NAD27 Alaska State Planes, Zone 4, US Feel N 70.35559577, W 149.03415003 N 5980579.930 ftUS, E 618930.140 ftUS -+D.90964455° 0.99991607 Survey I DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed I Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North·> True North: Local Coordinates Referenced To: Schlumberuer --~ Grid Coordinates Geographic Coordinates MD I Incl I Azim TVD I VSec N/-S El-W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 260.00 0.00 0.00 0.00 0.00 0.00 5980579.93 618930.14 N 70.35559577 W 149.03415003 725.00 0.00 260.00 725.00 0.00 0.00 0.00 0.00 5980579.93 618930.14 N 70.35559577 W 149.03415003 800.00 1.12 260.00 800.00 0.74 -0.13 -0.73 1.50 5980579.79 618929.41 N 70.35559542 W 149.03415596 858.33 2.00 260.00 858.31 2.33 -0.40 -2.29 1.50 5980579.49 618927.86 N 70.35559468 W 149.03416862 900.00 3.04 260.00 899.93 4.16 -0.72 -4.10 2.50 5980579.15 618926.05 N 70.35559380 W 149.03418332 1000.00 5.54 260.00 999.64 11.64 -2.02 -11 .47 2.50 5980577.73 618918.70 N 70.35559025 W 149.03424317 1100.00 8.04 260.00 1098.93 23.46 -4.08 -23.11 2.50 5980575.48 618907.10 N 70.35558462 W 149.03433768 1200.00 10.54 260.00 1197.61 39.61 -6.88 -39.01 2.50 5980572.43 618891.25 N 70.35557697 W 149.03446679 1300.00 13.04 260.00 1295.50 60.04 -10.43 -59.13 2.50 5980568.56 618871.19 N 70.35556728 W 149.03463017 ,~J 1400.00 15.54 260.00 1392.39 84.72 -14.71 -83.44 2.50 5980563.90 618846.95 N 70.35555558 W 149.03482756 1498.33 18.00 260.00 1486.54 113.09 -19.64 -111.38 2.50 5980558.53 618819.10 N 70.35554211 W 149.03505444 1500.00 18.03 260.00 1488.12 113.60 -19.73 -111.89 1.50 5980558.43 618818.59 N 70.35554187 W 149.03505858 1600.00 19.53 260.00 1582.80 145.78 -25.32 -143.59 1.50 5980552.34 618786.98 N 70.35552659 W 149.03531598 1654.89 20.35 260.00 1634.40 164.50 -28.57 -162.02 1.50 5980548.79 618768.61 N 70.35551772 W 149.03546563 1700.00 21.03 260.00 1676.60 180.43 -31.34 -177.71 1.50 5980545.78 618752.97 N 70.35551015 W 149.03559303 1800.00 22.53 260.00 1769.46 217.52 -37.78 -214.24 1.50 5980538.76 618716.55 N 70.35549255 W 149.03588966 1898.33 24.00 260.00 1859.80 256.35 -44.52 -252.49 1.50 5980531.41 618678.41 N 70.35547413 W 149.03620024 1969.05 24.00 260.00 1924.40 285.11 -49.51 -280.81 0.00 5980525.97 618650.18 N 70.35546050 W 149.03643020 Station ID S-117 (P3) report.xls Fe 11IIII 51 illty tLldy Page 1 of 3 1/17/2003-11 :15 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NJ-S EI-W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) Bid 3/100 2078.51 24.00 260.00 2024.40 329.63 -57.25 -324.66 0.00 5980517.54 618606.46 N 70.35543935 W 149.03678626 2100.00 24.64 260.06 2043.98 338.48 -58.78 -333.38 3.00 5980515.87 618597.76 N 70.35543517 W 149.03685706 2200.00 27.64 260.31 2133.74 382.53 -66.28 -376.79 3.00 5980507.68 618554.48 N 70.35541467 W 149.03720955 2300.00 30.64 260.52 2221.07 431.22 -74.38 -424.80 3.00 5980498.82 618506.61 N 70.35539254 W 149.03759938 SV5 2327.23 31.46 260.57 2244.40 445.27 -76.69 -438.65 3.00 5980496.29 618492.80 N 70.35538623 W 149.03771184 2400.00 33.64 260.69 2305.74 484.41 -83.07 -477.28 3.00 5980489.30 618454.28 N 70.35536879 W 149.03802551 2500.00 36.64 260.84 2387.51 541.96 -92.30 -534.08 3.00 5980479.17 618397.64 N 70.35534356 W 149.03848672 SV4 2578.35 38.99 260.94 2449.40 590.00 -99.90 -581.51 3.00 5980470.82 618350.34 N 70.35532279 W 149.03887184 2600.00 39.64 260.97 2466.15 603.71 -102.06 -595.05 3.00 5980468.45 618336.84 N 70.35531689 W 149.03898179 ~ End Bid 2604.06 39.76 260.97 2469.27 606.31 -102.47 -597.62 3.00 5980467.99 618334.27 N 70.35531577 W 149.03900265 SV3 3085.53 39.76 260.97 2839.40 914.23 -150.80 -901.72 0.00 5980414.85 618031.00 N 70.35518365 W 149.04147187 9-5/8" Csg pt 3215.61 39.76 260.97 2939.40 997.42 -163.85 -983.89 0.00 5980400.50 617949.06 N 70.35514797 W 149.04213907 SV2 3235.12 39.76 260.97 2954.40 1009.90 -165.81 -996.21 0.00 5980398.34 617936.77 N 70.35514261 W 149.04223910 SV1 3690.41 39.76 260.97 3304.40 1301.08 -211.51 -1283.78 0.00 5980348.09 617649.99 N 70.35501764 W 149.04457407 UG4 4126.18 39.76 260.97 3639.40 1579.78 -255.26 -1559.03 0.00 5980299.98 617375.49 N 70.35489798 W 149.04680897 UG4A 4178.22 39.76 260.97 3679.40 1613.06 -260.48 -1591.90 0.00 5980294.23 617342.71 N 70.35488370 W 149.04707586 UG3 4594.48 39.76 260.97 3999.40 1879.28 -302.26 -1854.82 0.00 5980248.29 617080.51 N 70.35476940 W 149.04921062 UG1 5212.37 39.76 260.97 4474.40 2274.46 -364.29 -2245.10 0.00 5980180.08 616691.30 N 70.35459964 W 149.05237942 Ugnu Ma 5446.52 39.76 260.97 4654.40 2424.21 -387.79 -2392.99 0.00 5980154.24 616543.81 N 70.35453532 W 149.05358017 Na 5726.19 39.76 260.97 4869.40 2603.08 -415.86 -2569.64 0.00 5980123.37 616367.65 N 70.35445848 W 149.05501443 Oa 5869.28 39.76 260.97 4979.40 2694.59 -430.23 -2660.02 0.00 5980107.57 616277.51 N 70.35441913 W 149.05574823 OBd 6090.42 39.76 260.97 5149.40 2836.02 -452.42 -2799.70 0.00 5980083.16 616138.22 N 70.35435837 W 149.05688231 OBt 6200.99 39.76 260.97 5234.40 2906.74 -463.52 -2869.54 0.00 5980070.96 616068.57 N 70.35432797 W 149.05744934 Base OBt 6253.03 39.76 260.97 5274.40 2940.01 -468.75 -2902.41 0.00 5980065.21 616035.79 N 70.35431365 W 149.05771621 Drp 1.5/100 6468.52 39.76 260.97 5440.06 3077.83 -490.38 -3038.52 0.00 5980041.42 615900.05 N 70.35425441 W 149.05882129 6500.00 39.29 260.97 5464.34 3097.87 -493.52 -3058.30 1.50 5980037.97 615880.32 N 70.35424581 W 149.05898188 --" 6600.00 37.79 260.97 5542.56 3160.17 -503.30 -3119.83 1.50 5980027.21 615818.96 N 70.35421903 W 149.05948144 6700.00 36.29 260.97 5622.39 3220.40 -512.75 -3179.31 1.50 5980016.82 615759.64 N 70.35419314 W 149.05996436 6800.00 34.79 260.97 5703.76 3278.52 -521.87 -3236.71 1.50 5980006.79 615702.40 N 70.35416816 W 149.06043038 6900.00 33.29 260.98 5786.62 3334.49 -530.65 -3291.99 1.50 5979997.13 615647.27 N 70.35414411 W 149.06087920 7000.00 31.79 260.98 5870.93 3388.27 -539.08 -3345.11 1.50 5979987.86 615594.30 N 70.35412101 W 149.06131047 7100.00 30.29 260.98 5956.61 3439.82 -547.17 -3396.03 1.50 5979978.97 615543.52 N 70.35409885 W 149.06172388 7200.00 28.79 260.98 6043.61 3489.12 -554.90 -3444.71 1.50 5979970.47 615494.97 N 70.35407767 W 149.06211911 7300.00 27.29 260.98 6131.87 3536.12 -562.26 -3491.14 1.50 5979962.37 615448.67 N 70.35405751 W 149.06249607 7400.00 25.79 260.99 6221.33 3580.80 -569.26 -3535.26 1.50 5979954.67 615404.67 N 70.35403833 W 149.06285427 S-117 (P3) report. xis Page 2 ot 3 1/17/2003-11 :15 AM Grid Coordinates Geographic Coordinates Station 10 MO Incl I Azim I TVD I VSec NI-S EI-W OLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 7500.00 24.29 260.99 6311.94 3623.12 -575.89 -3577.05 1.50 5979947.38 615362.99 N 70.35402016 W 149.06319355 7600.00 22.79 260.99 6403.61 3663.05 -582.15 -3616.49 1.50 5979940.49 615323.66 N 70.35400301 W 149.06351376 7700.00 21.29 260.99 6496.31 3700.57 -588.02 -3653.55 1.50 5979934.04 615286.70 N 70.35398692 W 149.06381464 7800.00 19.79 261.00 6589.95 3735.65 -593.51 -3688.20 1.50 5979928.00 615252.14 N 70.35397188 W 149.06409596 CM11 THRZ 7815.35 19.56 261.00 6604.40 3740.81 -594.32 -3693.30 1.50 5979927.11 615247.06 N 70.35396966 W 149.06413736 BHRZ 1 Kalubik 7837.61 19.22 261.00 6625.40 3748.20 -595.48 -3700.60 1.50 5979925.83 615239.78 N 70.35396648 W 149.06419663 End Drp 1 Tgt 7852.43 19.00 261.00 6639.40 3753.05 -596.24 -3705.39 1.50 5979925.00 615235.00 N 70.35396439 W 149.06423552 Top Kup 1 C4 7852.44 19.00 261.00 6639.41 3753.06 -596.24 -3705.39 0.00 5979925.00 615235.00 N 70.35396439 W 149.06423552 Kup C2 7863.00 19.00 261.00 6649.40 3756.50 -596.77 -3708.79 0.00 5979924.41 615231.61 N 70.35396294 W 149.06426312 '~ LCU I Kup B 7958.19 19.00 261.00 6739.40 3787.49 -601.62 -3739.40 0.00 5979919.08 615201.08 N 70.35394965 W 149.06451164 Kup AS 8042.80 19.00 261.00 6819.40 3815.03 -605.93 -3766.61 0.00 5979914.34 615173.95 N 70.35393784 W 149.06473255 TMLV 8100.97 19.00 261.00 6874.40 3833.97 -608.89 -3785.31 0.00 5979911.08 615155.30 N 70.35392973 W 149.06488437 TD 1 7" Csg pt 8301.92 19.00 261.00 7064.40 3899.39 -619.13 -3849.93 0.00 5979899.82 615090.85 N 70.35390166 W 149.06540900 LeQal Description: Surface: 4376 FSL 4500 FEL S35 T12N R12E UM Target: 3778 FSL 2926 FEL S34 T12N R12E UM BHL: 3756 FSL 3070 FEL S34 T12N R12E UM Northina eY) rftUSl 5980579.93 5979925.00 5979899.82 EastinQ eX) rftUSl 618930.14 615235.00 615090.86 - j - S-117 (P3) report.xls Page 3 of 3 1/17/2003-11 :15 AM I ! .....m.....m...n.m...mrn.......... n.....................n..............n KOP Bid 115/100 ~ 725MD 725TVD 0.00' 260~]00' az o depertur Cry 2 /100 ~ 858 Mµ 858TVD 2.00' 260 00' az X 2 dep rlure """'. . 7.. .-.... n. .n~~ß~~~'~.~4ß7.'IY~L 1 .00' 260.00' az 1 3 departure End Cry 1898 MD 1860 TVD I 24.00' 260.00' az 256 departure _.- ....... --t- ..- ........ - -.. ~ .-. -~ .¿;\Ii'f 1 \15t rvl!) I t;~4 'f\"!D .'- I Bid 3/100 . ~ 2079 MD 2024 TVD I ~.i. ........ 24.00' 260.00' az ¡ ___._._~~_ .-~~ ___...... 330_daparlu[e..~._ ~....~. I nc\SU P~'I fl) I· End Bid I I ...-<:" -i:~7t.M~6~~~ ~Ç? ,)\75 2~'J7 tVlD 27M T\ìD -- 606 departure ........... ..... :.... ..... ,...., ... . 8\')"4' ;;r;ïe r;;rn ;(,·.~;~9 r\.'() ..... "" Q) .- 9-518" CaD PI ;gCl) ~CI) 3000 _........;....~.........~:..~...................:. ...~..~~_~~...._..:: 5.. ,~æ~ ""''' '" "'" TV" _m_ ._n__. ~ _ .___ .. _mmn_.m...... m .... =p "'-..B.\ll...3~:s..MD ~,fq·f-I.l n'/!') '" T""" > I II 0 ! Hold Angle 39'.1'6° s::: i6 .. ~)Vì":,6!i(i"MI:r':\:,öi\' n;;('j ...! T"""ì:::= ",-,0 .r::.~ ë.~ ~ CO 4000- -~ ~~ 1:: CI) Cl)Q:: > > CI).£E :JW l- I- o _................-........1....... 1000 _........... ) ) VERTICAL SECTION VIEW Client: BP Exploration Alaska Well: S-117 (P3) Field: Prudhoe Bay Unit - WOA Structure: S-PAD Section At: 260.86 deg Date: January 17, 2003 Schlumberuer I ......L.n I ! 1 ..............".........~_.............,....._...... I ... '..n ./................m......... ..... I i I .................1 I 1 .................-........................"., I I i ........l. I i - - .-. .- -- - -- .- - -, 2000 -.--................---...---..... 5000 - 6000 - 7000 _................... ] "'j I .................~..................._.....~........_..... l¡":;::; ~i:~~14 MO ~$9~ì9 TV::! "lIüi;tJ¡~~g~?d~~\i9~'Yt)D::'- ... ...n ..... ..... ...~ ,.... ..._.................m..................................m......... .....m........__..................~......._....m~...m... ......~.................._....... .. ¡:JGï..·1.~~:1·2 M'i5" 44":~~ ¡vb I '''1 '''1 ....) ..... .......... ..... ..... ....~ ....,...., ......·................·....·~;;·;:~ï;o~....r....·............ :;;( ;~~~~~~~~:D ;;:~ 3078 departure' .. ¡:J~¡t;'lj' Mr:ï..!~(¡.r~:'r...1¡)·..¡¡C,·fj(j 'rvi:> I ....1 .. ~Jn '572;;'!\~O ·;tBf;~j'TVO.... :·····::,'>,,··,,1JIJ\\··Yi+D·:;o·"¡.¿,··TvØ::::·····:· ...." ...... ..... ..... ...~ .................................................. "I ! I ....¡.......... ................L..... ¡ I End Drp / TgI " ~.~:~t~::' -~~.,',. .......~~d/;~·~~ TVD 19.00' 261.00' az I 3899 departure 4000 ............................................ .......... .No... ;t~~l~1;:¡,~~;;~~·;¡~!:~;:;I~;,y?:~I~J~:¡.;~? . :W~:~f(Y: ó~fÖ..1t Trt~O ;~·1.i ~&~~~I:: "'1' · . · . ~~¡d~ n)~:B t'...lT, ~i#.~~: 'ffo :~#)Ç' f~it¡:. /:¡j.1 #'$::jt~fo ·~~,.~~:*..1:P:~ · . "".... .".... ,WNo ....... ...........j..... ............................... ................................... I 2000 ] ~ o I 1000 I 3000 Vertical Section Departure at 260.86 deg from (0.0, 0.0). (1 in = 1000 feet) -5000 , 2000 -. -4000 I , , .____....._._.____._._.__n___ __.___.______________________________ True North Mag Dee ( E 25.81° ^ ^ ^ I I- 0::: o Z 1000 - ...........-...-.-........-.-..-.. 0- I -1 000 -----~--I I- :::> o C/) V V V -2000 - t -5000 ~-- S TD/7"'CsgPt 8302 MO 7064 TVO 19.00' 261.00' az 6195 3850W t -4000 Client: Well: Field: Structure: Scale: Date: PLAN VIEW BP Exploration Alaska 8-117 (P3) Prudhoe Bay Unit - WOA S-PAD 1 in = 1000 ft 17-Jan-2003 -3000 I -1000 ------------------ ..--.---.-.--...----. - -2000 I ----------....-...---- -..----..-----..---.------ _____________n_________.____m________ ~~\ 1 \ ,. '5'00 End Drp 1 Tgt 6469 MD 5440 TVO 7852 MO 6639 TVO 39.76" 260.97' az 19.00' 261.00' az 490 5 3039 W 596 5 3705 W I -3000 «< WEST 1260.00° \d AZ\rout~ ...Bo------...---.........,.--~.-- I -2000 I -1000 EAST »> o I __·________.___.___.__..__..__..__n_._ KOP Bid 1.51100 725 MO 725 TVO 0.00' 260.00' az ON OE L Cry 2.5/100 V 858 MD 858 TVO 2.00" 260.00' az 05 2W _____m.__ ___.______._______ \~~.I ~;;;~O~48tTVO , 18.00 260.0Œ' az I 205 111W I ª. End Cry ª .' ¡ 1898MO 1860TVO ¡ ¡ 24.00" 260.00' az ¡ I 455 252W I Bid imoo ' 207Q MO 2G24 TVO 24.0þ" 260.00" az 575 325W Schlumberuer 1000 I -......-....--.-..---. - 2000 -~ -----.-------- - 1000 -.-----.....--.- - 0 -1000 ---'- -2000 I 1000 ) BP Exploration Alaska Anticollision Report ) . Company: Field: . ... . 'R;efer~JÙ:êSïte:· . ;Reter~ncé'WeU: . ·Rører~nce·Wellpath: , BP Amoco . prughqß Bay · pas Pad Plan $·417 PlanS-t1T .1/17/2003. Time:· 10:55:3,1' , J>age: 1 .. . ." ... .. . ..". .... . . .. . ... . . qo~~rdi~at~(NE) Referel1ëe: . . ... Well:Plan$~117; True North '. Vertical{I'YD} Rèference: ' S~117 Plàn64,4·. NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 64.40 to 8301.92 ft Maximum Radius: 3000.00 ft Reference: Error Model: Scan Method: Error Surface: Db:$ybase Principal Plan & PLANNED PROGRAM I$CW$A Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 11/5/2002 Validated: No Planned From To Survey ft ft 64.40 1000.00 Planned: Plan #3 V1 1000.00 8301.92 Planned: Plan #3 V1 Version: 2 Toolcode Tool Name GYD-GC-$$ MWD+IFR+M$ Gyrodata gyro single shots MWD + IFR + Multi Station Casing Points ·MD. TVD Diåmetéf Hole Size ft ft ,··...·in in 2565.52 2439.40 9.625 12.250 95/8" 8301.92 7064.40 7.000 8.750 7" Summary <...-.;.; Reference .. . Offset Ctr:'Ct.r .. No-'Go . AUowable Site MD MD·..· Distance .' Area Deviation . ft ft ft ft ft. PB $ Pad Plan $-116 Plan S-116 VO Plan: $- 394.39 400.00 15.78 8.25 7.53 Pass: Major Risk PB S Pad Plan $-118 Plan S-118 VO Plan: $- 444.33 450.00 15.60 9.35 6.25 Pass: Major Risk PB $ Pad $-01A S-01A V1 8268.14 8450.00 729.99 586.62 325.14 Pass: Major Risk PB $ Pad $-01 B S-01 B V1 1611.16 1600.00 727.63 28.43 699.22 Pass: Major Risk PB S Pad S-01 $-01 V1 8298.99 8600.00 737.93 423.51 328.08 Pass: Major Risk PB $ Pad $-100 S-100 V10 349.74 350.00 62.01 5.95 56.06 Pass: Major Risk PB $ Pad S-101 S-101 V2 649.40 650.00 32.58 12.77 19.82 Pass: Major Risk PB S Pad $-101 $-101PB1 V9 649.40 650.00 32.58 12.82 19.77 Pass: Major Risk PB $ Pad S-102 S-102V11 250.19 250.00 76.98 4.74 72.24 Pass: Major Risk PB $ Pad S-102 $-102PB1 V14 250.19 250.00 76.98 4.74 72.24 Pass: Major Risk PB S Pad S-103 S-103 V6 649.77 650.00 197.11 10.39 186.73 Pass: Major Risk PB S Pad $-104 S-104 VO 349.90 350.00 270.79 6.76 264.03 Pass: Major Risk PB $ Pad S-105 S-105 V5 798.17 800.00 262.16 13.33 248.83 Pass: Major Risk PB S Pad $-1 06 $-106 V2 294.19 300.00 226.98 6.45 220.53 Pass: Major Risk PB S Pad S-1 06 S-106PB1 V12 294.19 300.00 226.98 6.45 220.53 Pass: Major Risk PB $ Pad S-107 S-107 V35 444.37 450.00 181.98 9.03 172.95 Pass: Major Risk PB $ Pad $-108 $-108 V6 443.29 450.00 133.04 7.76 125.30 Pass: Major Risk PB $ Pad S-109 S-109 V5 598.79 600.00 89.68 10.70 78.99 Pass: Major Risk PB $ Pad S-11 0 $-110V18 494.22 500.00 101.87 10.10 91.78 Pass: Major Risk PB $ Pad $-111 Plan $-111 V1 Plan: $- 544.38 550.00 241.33 11.51 229.82 Pass: Major Risk PB $ Pad S-112 $-112V19 594.04 600.00 49.15 11.75 37.41 Pass: Major Risk PB $ Pad S-11 3 S-113V13 741.93 750.00 171.12 14.59 156.55 Pass: Major Risk PB $ Pad $-113 $-113A V2 741.93 750.00 171.12 14.44 156.70 Pass: Major Risk PB $ Pad S-113 $-113B V5 741.93 750.00 171.12 14.44 156.70 Pass: Major Risk PB S Pad $-114 $-114 V13 543.49 550.00 244.86 11.08 233.78 Pass: Major Risk PB S Pad S-114 S-114A V6 543.49 550.00 244.86 10.93 233.94 Pass: Major Risk PB $ Pad $-115 S-115 ST V1 Plan: Plan 749.89 750.00 19.52 12.44 7.11 Pass: Major Risk PB $ Pad $-115 S-115 V7 749.89 750.00 19.52 12.35 7.20 Pass: Major Risk PB S Pad $-200PB 1 $-200PB1 V4 1248.07 1250.00 48.11 17.59 31.25 Pass: Major Risk PB $ Pad $-200 $-200 V2 Plan: Undefin 1248.07 1250.00 48.11 17.70 31.14 Pass: Major Risk PB $ Pad $-201 S-201 V2 249.98 250.00 210.42 4.45 205.97 Pass: Major Risk PB $ Pad $-201 $-201 PB1 V11 249.98 250.00 210.42 4.45 205.97 Pass: Major Risk PB $ Pad $-202 Plan S-202 VO Plan: $- 699.08 700.00 120.98 13.30 107.68 Pass: Major Risk PB S Pad $-213 $-213 V6 948.47 950.00 32.43 13.40 19.11 Pass: Major Risk PB $ Pad $-214 Plan $-214 V1 Plan: $- 498.66 500.00 46.31 8.27 38.04 Pass: Major Risk PB $ Pad $-216 $-216 V1 349.71 350.00 61.08 7.26 53.82 Pass: Major Risk PB $ Pad S-41L1 $-41L 1 V1 1131.03 1150.00 202.26 18.88 183.41 Pass: Major Risk PB S Pad $-41PB1 $-41 PB1 V1 1131.03 1150.00 202.26 18.88 183.41 Pass: Major Risk PB $ Pad S-41 S-41 V1 1131.03 1150.00 202.26 18.88 183.41 Pass: Major Risk PB S Pad S-42PB1 S-42PB1 V1 1395.45 1400.00 179.12 19.60 159.57 Pass: Major Risk PB $ Pad S-42 $-42 V2 1395.45 1400.00 179.12 19.60 159.57 Pass: Major Risk PB S Pad $-43L 1 S-43L 1 V2 1097.31 1100.00 151.27 16.19 135.15 Pass: Major Risk PB $ Pad $-43 S-43 V3 1097.31 1100.00 151.27 16.19 135.15 Pass: Major Risk COJ11pany: .. Field: .. . Rèferèm:ë Site: . Referente)Vell: ·R:eferenceWellpath: Summary PB S Pad PB S Pad PB S Pad BPAmpCQ PruØhqe~ay PBSPåd · Plan $':117 Plan $-117 :Öff~etWellpath·· ~- ·;Wèll· . ... 8-44L 1 PB 1 S-44L 1 8-44 "- ) BP Exploration Alaska Anticollision Report 1/17/2003 ) Time: ·..10:55:31· Co;.ordinate(NE) Reference: ;. Vertfcäl (TVO) Rèferenct!i . .... ... ... . ... ...... ... . : .... Well: Plan. S~117.. True North ··S-111Plån64A:···· . 8-44L 1 PB 1 V3 8-44L 1 V5 8-44 V1 0 . Refereo.ce MD tt 1197.25 1197.25 1197.25 . Offset· ... MD ft 1200.00 1200.00 1200.00 qtrTÇtt~~~qo pistanëe Area. . .. ft ·t( 123.11 17.34 123.11 17.34 123.11 17.34 Pass: Major Risk Pass: Major Risk Pass: Major Risk Polygon 1 2 3 4 Site: PB S Pad , Drilling Target Conf.: 9," Description: Map Northing: 5979925.00 ft Map Easting : 615235.00 ft Latitude: 70°21 '14.272N +N/-S ft 151.74 146.98 -178.41 -172.45 Target: S-117 T1.1 +E/-W ft -107.61 192.37 212.21 -162.77 )veIl: Plan S-117 ~ Based on: Planned Program Vertical Depth: 6575.00 ft below Mean Sea Level Local +N/-S: -596.23 ft Local +E/-W: -3705.38 ft Longitude: 149°03'51.248W Northing ft 5980075.00 5980075.00 5979750.00 5979750.00 Easting ft 615125.00 615425.00 615450.00 615075.00 -200 -300 -4-00 -500 -500 -lOo -800 -900 0 CJ CJ CJ CJ CJ CJ CJ o 0 CJ CJ CJ CJ CJ CJ CJ o 0 ~ 0- m I LD l.f) -=I- (I) o 0 ~ ~ (I) (I) (I) (I) (I) (I) (I) I I I I I I I o ~ ~ ~ ~ " '.". .':.'--:--::-n' ...,'.- - -' ',',".:." ,p._ . - '.". _: n_>_, ........ ......................--_.................:.......... ............ .... .....:.......................:.. - .....' - -".. " . - ,_ n" d.. _ _ _ .' .- . . . .---. - -" . ....:--...::. ........ ....... ..........:-.. ....-.'.'... ........ .--.-.: ...... ...... - - .-- ---. . - . - - - . . .. ..- --.-... .. ....... .. .... ........ .... ..... .'. . - .. - - .- -- - . - ", - - . - . '._ n, ,_. .. '. . _ .'.,_,"'".' ......."-- _ - _ _ "./.- _- -"-'. .- -.'-.. -.-.-" ."-.-,..- :.-" . -.'.-.-.- ..--- '.'. .. ."__ '. - - 'n' . .-n'. _ ..._ _'_.' -.-...- ._ - _. '.n.. '.. -_.-.. '. - '._ - .,."-- - _.__ ."_.,_. -'._ - - -._.__ .-. - .'.'. _.'n ,'-,'... . . . .'_.-.-. .-,',.-.- .--',. -'-,-..- .'.' -. -' . ÄtÄSKA Ç)IL&G~SGONSER\ì'ATION C0fV1MISSION< 333 W 7THI A\{ENl:JE SUITE 1°9: ....} ANCHORAJ.3E, AK. ~9501 p054992 DATE INVOICE I CREDIT MEMO DESCRIPTION 12/19/2002 INV# CK121702A PERMITTO DRILL FEE THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ --- BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGf;, AK99519-6612 PAY: 'ú &In l!J . f:;"l...··... ;ID\ .... ·B.r . ~!) \tlfl TO THE ORDER OF: GROSS :)-- \ \ 7 NATIONAL CITY BANK Ashland, Ohio DATE Déqemþer19, ?002 ***************$100.00*** III n C; L q q ¡J III I: 0... ~ 2 0 ~ B g 5 I: 0 ~ 2 ? 8 g b III DATE CHECK NO. 12/19/2002 P054992 VENDOR DISCOUNT NET H RECEiVE i) Ji-\N '2 "\ 200~5 Alaska Oil & Gas Cons. Commission Anchorage 56-389 ---:ï12 No. P 054992 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT N°ly~~.l~.~;!::T.~~.!.~.9..!?t.X~....... . .J'......: ......~~: ..:~~~ :. :::-'::. :::'.:. :.:..... :::":' :::-(ß,:-~':\' ......}:..::/.~.::: :. ~.~./::,::.:. >~ ...... .~... ..... ....... ..... ...... ...... ..... :'\'~:::"" ......:~::::, :¿... ::"~ !~ ~\~j .... .... .' '.. '~:.: ~~':~.~::: ::¡:.:~':·::i::.. .:~:~:i~~~~·:·~s~!.~~;::\;~~:~~~ ::~:~~ ~ /~'::':~~'.\::j ') ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARA GRAPH S TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new well bore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CfiECKLlST . C'OMPANY . ßf)¿ WELL NAME fß¿¡ ..s -I) 7 PROGRAM:Exp _ Dev ~ Redrll_ Re-Enter _ Serv _ Wellbore seg _ FIELD & POOL . b 71 ó ).2- ð INIT CLASS ¿)c~ / -' n~ ? GEOL AREA ç ;' lÏ UNIT# / / C t)"ò ON/OFF SHORE O,.J ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ~ N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. W ell located proper distance from drilling unit boundary. ..; . Y N 6. W ell located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force.. . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . i'!. J N 12. Permit can be issued without administrative approval.. . . . . W N .' (Service Well Only) 13. Welll?cate? ~(in ~rea & strata ~uth?riz~ by injection order #_ ~.Y /// I 4, (Service Well Only) 14. All wells wlln ~ mile area of review Identified. . . . . . . . .'. ~~ ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ~N 16. Surface casing protects all known USDWs. . . . . . . . . . . '( N 17. CMT vol adequate to circulate on conductor & surf csg. . . . . .' N 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ~) 19. CMT will cover all known productive horizons. . . .' . . . .. . . N 20. Casing designs adequate for C, T, B & permafrost. . . . . .'. .. NAIL Q E ~ 21. Adequate tankage or reserve pit. . . . . . . . . . . . . . . . . . N c;t¡.vOìf~ -, . 22. If a re-drill, has a 10-403 fo~ abandonment been approved.. . . y-. N N/A- 23. Adequate wellbore separation proposed.. .... . . . . . .. . . œ N 24. Ifdiverterrequired, does 'it meet regulations. .. . . . . .... +~.. N ~lOt-¿··'¡.e.-ý". V'e¿"ÓlLRSi=t'cl ' 25. Drilling fluid program sChema. ~ic & equip list adequate. . . . "Y.'. N rntl..Y YVl~' J () t 0 P{J~ . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N PI' APPR DATE ~7: BOPE press rating appropriate; test to 4- ð 0 0 p sig. .' N rn ~ 'Z (,p f 7 f ~, , \ J 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . . N \;~C1A- 'tZL 0 ~ 29. Work will occur without operation shutdown. . . . . . . . . . . /R.. 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ChI! 31. Mechanical condition of wells within AOR verified. . . . . . . . -Y . N All Æ- 6?N W,A./. .4. APPR DATE ?i21fu /R , (Service Well Only) GEOLOGY APPR DATE ¡f{J{~ Ä~3 , (E«Xploratory Only) ( 32. Permit can be issued w/o hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if·off-shore). . . . . .. ...... 36. Contact namelphone for weekly progress reports. ...... ( GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Commentsllnstructions: RPffL., TEM JDH JBR COT DTS 0 j 1<"1-la~ ./ MJW MLB SFD WGA Rev: 10115102 G:\geology\permits\checklist.doc