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Home My WebLink About204-257 In o m ua y s > _ o a c. � 0 O 0 H . L t C O z Y o ; a v a' co v o c o -6 �. p OS c < Q w N m O -C In m 0 in tn in LU w C7 T T T �+ N O a.+ 4., N 0 p Z 0 R R co Q C L f6 FF¢ O w W �L CL D O. Tu G J m ~ N V N `0 C -C > Z g'.. H Y .. O fa W CT. 41 u Ov co 41 W ❑ ❑ ❑ ❑ f0 4) C L Cr 1...c. L LU w w w _ C co 0 LL LL LL LL V w E -0 H Q J J J J Q O C 41 S"i . Q` Z Z Z Z 0) H 40 y LL LL LL LL 0o 0 d W CC L 41 LO •WMF 4.,+Li > u w L C w E 41' N O O 0 a U r 0 Z D C O -D C d 41 _ =r _O a O Q co >it > C as ,0 u fx J w '- Q 41 sc cu Ou cu > -Lu �-. a 7r O p wf= N itt 1:10 m a c) w m Q = - . M0, 000 V > a 0 J PI v CO J 7 0 °? a; ro q � � R a 0 W A W o > r r r I x x 5 r u ce ce ce c a ,o - x 0 0 0 0 V co co ;u = z w 2 w w 4J 4 zaMc. Nuwwww r1 p CV m m m < LLJUJLLID -C O O O Y E p2 2 2 Q 2 Q w ❑ ❑ ❑ Z v u o ` 2 Cl_ a a / o no T U C p �� W N M CO00 W p m o r u> u 0 O O O o CO CD 0 0 0 0 o + LLI R v ,( v `: too CO CD E > > > > X al W W Q Q Q Q 0 H R et X • C o N CO O O CO u LD O O O O N CO N M V T O M CCi4 N (O 4- 0 O M M N N 0 N N N N N 0 u N O) T _ p N N N N C 01 O O O OLIJ O O O O C N N N N Q a) u LII R a # E v > y _�CID W Y 8 C .L V GOYJI Q Q m M Q) N Y N 9 C 4� i O N 67 N CO M Z co N r• � fS7 � ~ Fe Q N La J fn Y E Z 4J c_ La Z _ �-i h R ., y rv,0 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 15-01B Mill CIBPs Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-257 50-029-20696-02-00 12470 Conductor Surface Intermediate Tieback Liner Liner 8834 79 2519 8888 8900 3725 11510 20" 13-3/8" 9-5/8" 7" 4-1/2" 8871 30 - 109 28 - 2547 26 - 8914 24 - 8924 8745 - 12470 30 - 109 28 - 2547 26 - 8317 24 - 8326 8154 - 8834 Unknown 470 2670 4760 7020 7500 11510 1490 5380 6870 8160 8430 8923 - 12350 4-1/2" 12.6# 13cr80 22 - 8750 8326 - 8843 Structural 4-1/2" Baker S-3 Hydro Set Packer 8693 8104 Bo York Operations Manager Jerry Lau jerry.lau@hilcorp.com 907.564.5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028306 22 - 8159 N/A N/A 172 183 10664 12465 10 43 490 388 268 254 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 8693, 8104 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 4:11 pm, May 12, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.05.12 13:06:37 - 08'00' Bo York (1248) RBDMS JSB 051525 DSR-6/3/25JJL 6/13/25 ACTIVITY DATE SUMMARY 4/12/2025 LRS CTU #2 w.0" Taperd .250-.134" DC-110 Job Objective: Mill & recover 2 CIBPs. Release & Recover WRP or Push Btm. Mobilize, snow removal. MIRU CTU #2. NU BOPs & Fnc Test. MU YJ 3.70" Venturi/burnshoe BHA. S.I. Well & FP flowline. ***Continue on WSR 4/13/25*** 4/13/2025 LRS CTU #2 w.0" Taperd .250-.134" DC-110 Job Objective: Mill & recover 2 CIBPs. Release & Recover WRP or Push Btm. Finish FP Flowline. L&K well. RIH w/ YJ 3.70" venturi/burnshoe BHA. Tag CIBP 9030' CTM, mill CIBP for 5hrs before it broke free. Push plug to second CIBP at 11,054' CTMD, jar down on plug in attempt to recover. POOH and did not recover CIBP. MU new burnshoe, RBIH and resume milling CIBP at 11,051'. Milled 4 hours and jar down multiple times. POOH and did not recover core CIBP. MU burnshoe and RBIH. ***Continue on WSR 4/14/25*** 4/14/2025 LRS CTU #2 w.0" Taperd .250-.134" DC-110 Job Objective: Mill & recover 2 CIBPs. Release & Recover WRP or Push Btm. RBIH and resume milling CIBP at 11,051'. Mill 2-1/2 hours, just stacking wgt no change motor work. POOH and did not recover any plug parts. Change motor and make up 3.71" 5 blade reverse junk mill. RIH and resume milling CIBPs at 11,051' CTMD. Mill on plug for 4.5hrs before it started moving down hole, push plug to WRP at 11,528'. POOH. BD YJ 3.71" 5 blade junk mill. Change Pack-offs. MU YJ 3.70" Venturi Junk Basket BHA. RIH. ***Continue on WSR 4/15/25*** 4/15/2025 LRS CTU #2 w.0" Taperd .250-.134" DC-110 Job Objective: Mill & recover 2 CIBPs. Release & Recover WRP or Push Btm. RIH w/ YJ 3.70" Venturi Junk Basket BHA to 9950¿ CTM. Pump RIH to tag WRP @ 11,531¿ CTM. Reciprocate up/down twice to 11,510¿ CTM. POOH. BD YJ Venturi / screen packed off w/ ~ cup metal CIBP parts. MU and RBIH w/ YJ 3.70" Venturi Junk Basket. Tag CIBP/WRP and perform 6 up/dn passes over plug, lightly jar on top of plug. POOH and only recovered coil shavings, make up WRP pulling tool BHA and RIH. Tag CIBP/WRP at 11,537' CTMD, attempt to latch by jarring down but could not get any overpulls. POOH and lay down WRP fishing tools. Make up 3.63" venturi BHA with cut lip wire grab shoe. RIH and tag fish at 11,531' start jarring and hoovering cycles. ***Job Continued on WSR 4/16/25*** 4/16/2025 LRS CTU #2 w.0" Taperd .250-.134" DC-110 Job Objective: Mill & recover 2 CIBPs. Release & Recover WRP or Push Btm. Working on top of fish at 11,531' start jarring and hoovering cycles. POOH. BD YJ venturi/cut lip and just wads of metal shavings and no indication from wire grabs. Change out Pack-offs and brass. RDMO CTU #2 ***Job Incomplete*** Daily Report of Well Operations PBU 15-01B Daily Report of Well Operations PBU 15-01B 4/22/2025 ***WELL S/I ON ARRIVAL*** RAN 4-1/2" BRUSH w/ 3.78" GAUGE RING TO XN, BRUSH NIPPLE @ 8,717' MD (tools / brush covered in metal shavings) PERFORM WELL CONTROL / MAN DOWN DRILL w/ DAY CREW T-BIRD FLUSHED TBG w/ 140 bbls CRUDE WHILE BRUSHING TBG SET 4-1/2" DREAM CATCHER IN X-NIPPLE @ 8,717' MD (confirmed set w/ check set) ***WELL S/I ON DEPARTURE*** 4/22/2025 T/I/O = 200/450/0 (TFS Unit 1 Assist SL w/ Brush & Flush) Pumped 140 bbls Crude down TBG while SL brushed FWHPS = 550/450/0 Pollard SL in control of well upon TFS departure · . Image Project Well History File Cover 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. J..O lJ. - a5-7 Well History File Identifier o Two-sided ""1111111111" II/ Organizing (done) o Rescan Needed III" 111111 II 1/111I RES CAN ~olor Items: o Greyscale Items: DIGITAL DATA ~skettes, No. d..- O Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Date 4-/13107 o Other:: Scanning Preparation BY: ~_ I Date y. 13/07 x30= ~D + ~1J Date: If/ k~ / 07 = TOTAL PAGES (Count does not include cover sheet) 151 mf I~IIIIIIIIIII! "III mp 53 YVlP BY: ~ 151 Project Proofing BY: ~ Production Scanning Stage 1 Page Count from Scanned File: G q (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES c;;.:) Date If-l '3/07 Stage 1 If NO in stage 1, page(s) discrepancies were found: 1111111111111111111 BY: NO 151 (VI; P YES NO BY: Maria Date: 151 1IIII11I11I11111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111I11 1111/ BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page,doc r2_01k-2-57 �25z� 0 I I o0 C 0 0 0 0 0 0 U U U U U U O °i O,-� r O ms U ct 6 1,� 1 2 N 1~ 0 0 � rn � ln Y O c0 ):, N N N N N N +z N Q) OS . O 7 7 C C 7 al N O � 'LI -A '" h g t� u N > -f f J z 1— u~ ~ ) u) U U) U) (7 LLLL LL LL LL LL LL , 0 0 0 0 0 0 1 .�- ,L F- F- F- F- F- F- p 0 0 0 0 0 0 N W W W W W W Ce3 000000 v1 0 0 0 0 0 0 CC ...1 J .J J J J Q N M 00 ri M .'R 8. kip Q in X X X X X X i M N ii I- Ln LA HZ O a o 0 CD GI e Cfa W a o 0 0 in 0 CD o > 0 O O O O O O 0. CC 0 0 0 0 0 0 o 62 o O r.: r a v r- o uu ® o r- 0 Tr CNA a) oo IMMI v o O O O m O O OA -o o� O L N In N '0 !T d'1 Q c9 m 0) Q .B v Y O i e-i C ✓ ( • v v 2 CO 0 7 faD g 7 N O Q O a v 004 E J N 03 be CO @ z co ca z = J '. CI oo N n.) 0 m o s 2 ' -5 0 o p s N o w CL ro t in t .. a p u -' ° v ci CO p in• O x a m oQ _____Ik. , STATE OF ALAWA OIL AND GAS CONSERVATION COMIWION RECEIVED REPORT OF SUNDRY WELL OPERATIONS AUG 0 6 2012 1. Operations Abandon U Repair Well U Plug Perforations U . Perforate U , Other LJ )C Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension 0 Change Approved Program El Operat. Shutdown 0 Stimulate - Other El Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development II . Exploratory El R 204 -257 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 — 50- 029 - 20696 -02 -00 , 7. Property Designation (Lease Number): .. 8. Well Name and Number: ADL0028306 PBU 15-01B . 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL " 11. Present Well Condition Summary: Total Depth measured 12470 feet Plugs measured 11030, 11510 feet true vertical 8833.95 . feet Junk measured None feet Effective Depth measured 12384 feet Packer measured See Attachment feet true vertical 8840.14 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 88 20" 94# H -40 22 - 110 22 - 110 1530 520 Surface 2526 13 -3/8" 72# L -80 21 - 2547 21 - 2546.94 4930 2670 Intermediate 8894 9 -5/8" 47# L -80 20 - 8914 20 - 8316.81 6870 4760 Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 3725 4 -1/2" 12.6# L -80 8745 - 12470 8153.86 - 8833.95 8430 7500 Perforation depth Measured depth See Attachment feet n t True Vertical depth See Attachment feet i"A� A�J 2, — .61L Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 18 - 8750 18 - 8158.66 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 481 174 524 1627 264 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development Q e Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil — 151 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Prepared by Garry Catron 564 -4424 Printed Name Nita Summerhay- Title petrotechnical Data Technician Si'' , f ' Phone 564 -4035 Date 8/6/2012 tt AUG 7 9 j � ti ' ` Form 10-404 Revised 10/2010 B® S A 1 2012 q �•� 7 Submit Original Only � , m \, • • Daily Report of Well Operations ADL0028306 CTU #8 w/ 1.75" CT (CTV =34.0) Objective -Drift, PPROF w /GHOST, MCNL /BORAX, set CIBP, add Perf. MIRU. MU 3.7" drift x 11.15'. RIH. Tagged TD @ 11505' CTD wgt back. Flag pipe POOH. 6/2/2012 « «JOB IN PROGRESS » »> CTU #8 w/ 1.75" C t (CTV =34.0) Objective -Drift, PPROF w /GHOST, MCNL /BORAX, set CIBP, add Perf. MIRU. MU 3.7" drift x 11.15'. RIH. Tagged TD @ 11505' CTD wgt back. Flag pipe POOH. 6/2/2012 « «JOB IN PROGRESS » »> CTU #8 w/ 1.75" CT (CTV =34.0) Objective -Drift, PPROF w /GHOST, MCNL /BORAX, set CIBP, add Perf. Continue POOH w/3.7" drift assembly. LD drift assembly, cut 125' pipe. 6/3/2012 « <JOB IN PROGRESS »» CTU #8 w/ 1.75" CT (CTV =34.0) Objective -Drift, PPROF w /GHOST, MCNL /BORAX, set CIBP, add Perf. Continue POOH w/3.7" drift assembly. LD drift assembly, cut 125' pipe. Flow well down the flowline to verify that there are not any hydrates present. Stabilized flow at 1100 psi WHP. MU logging BHA: for PPROF and GHOST. Max OD = 2.875 ", OAL = 27.9'. RIH to 11,465' paint flag. Start POOH to log 3 passes from 11,465' - 10,000' @ 40,60,80 fpm. Stop counts @ 11,035', 10,875', 10,370', 10,220', 10,050'. POOH, Good data, Field Log reading, indicates main Gas flow coming from lower set of perfs. (11100- 11460'). RD PPROF tools, MU Borax logging string. Prep to RIH. 6/3/2012 « <JOB IN PROGRESS Cont from WSR 6/2/2012 »> CTU #8 w/ 1.75" CT (CTV =34.0) Objective -Drift, PPROF w /GHOST, MCNL /BORAX, set CIBP, add Perf. Continue POOH w/3.7" drift assembly. LD drift assembly, cut 125' pipe. Flow well down the flowline to verify that there are not any hydrates present. Stabilized flow at 1100 psi WHP. MU logging BHA: for PPROF and GHOST. Max OD = 2.875 ", OAL = 27.9'. RIH to 11,465' paint flag. Start POOH to log 3 passes from 11,465' - 10,000' @ 40,60,80 fpm. Stop counts @ 11,035', 10,875', 10,370', 10,220', 10,050'. POOH, Good data, Field Log reading, indicates main Gas flow coming from lower set of perfs. (11100- 11460'). RD PPROF tools, MU Borax logging string. Prep to RIH. 6/3/2012 «<JOB IN PROGRESS Cont from WSR 6/2/2012 »> CTU #8 w/ 1.75" CT (C1 V =34.0) Objective -Drift, PPROF w /GHOST, MCNL /BORAX, set CIBP, add Perf. Continue POOH w/3.7" drift assembly. LD drift assembly, cut 125' pipe. Flow well down the flowline to verify that there are not any hydrates present. Stabilized flow at 1100 psi WHP. MU logging BHA: for PPROF and GHOST. Max OD = 2.875 ", OAL = 27.9'. RIH to 11,465' paint flag. Start POOH to log 3 passes from 11,465' - 10,000' @ 40,60,80 fpm. Stop counts @ 11,035', 10,875', 10,370', 10,220', 10,050'. 6/3/2012 « <JOB IN PROGRESS Cont from WSR 6/2/2012 »> CTU #8 w/ 1.75" CT (CTV =34.0) Objective -Drift, PPROF w /GHOST, MCNL /BORAX, set CIBP, add Perf. Continue POOH w/3.7" drift assembly. LD drift assembly, cut 125' pipe. Flow well down the flowline to verify that there are not any hydrates present. Stabilized flow at 1100 psi WHP. MU logging BHA: for PPROF and GHOST. Max OD = 2.875 ", OAL = 27.9'. RIH to 11,465' paint flag. Start POOH to log 3 passes from 11,465' - 10,000' @ 40,60,80 fpm. Stop counts @ 11,035', 10,875', 10,370', 10,220', 10,050'. POOH, Good data, Field Log reading, indicates main Gas flow coming from lower set of perfs. (11100- 11460'). RD PPROF tools, MU Borax logging string. Prep to RIH. 6/3/2012 « <JOB IN PROGRESS Cont from WSR 6/2/2012 »> • CTU #8 w/ 1.75" CT (CTV =34.0) Objective -Drift, PPROF w /GHOST, MCNL /BORAX, set CIBP, add Perf. RIH w /Borax logging string. 2.2" x 24.64'. Make 2 baseline KCL passes from flag to 9950', & 2 borax passes, from flag to 9950', RIH flag pipe @ 11,000', +7' correction. POOH. MU WFT CIBP setting BHA. Set 4 -1/2" CIBP @ 11,030', set 2K down on plug twice. POOH. 6/4/2012 « «JOB IN PROGRESS »> Cl U #8 w/ 1./5" CT (CTV =34.0) Objective -Drift, PPROF w /GHOST, MCNL /BORAX, set CIBP, add Perf. RIH w /Borax logging string. 2.2" x 24.64'. Make 2 baseline KCL passes from flag to 9950', & 2 borax passes, from flag to 9950', RIH flag pipe @ 11,000', POOH. 6/4/2012 « «JOB IN PROGRESS »> CTU #8 w/ 1.75" CT (CTV =34.0) Objective -Drift, PPROF w /GHOST, MCNL /BORAX, set CIBP, add Perf. RIH w /Borax logging string. 2.2" x 24.64'. Make 2 baseline KCL passes from flag to 9950', & 2 borax passes, from flag to 9950', RIH flag pipe @ 11,000', POOH. MU CIBP setting BHA. Set4 -1/2" CIBP @ 11,030'. POOH. 6/4/2012 « «JOB IN PROGRESS »> CTU #8 w/ 1.75" CT (CTV =34.0) Objective -Drift, PPROF w /GHOST, MCNL /BORAX, set CIBP, add Perf. POOH w/WFT CIBP setting tool assembly. LD WFT tools /lubricator /injector, cut 125' pipe, change pack offs, inspect chains. 6/5/2012 «JOB IN PROGRESS »> Cl U #8 w/ 1.75" CT (CTV =33.1) Objective -Drift, PPROF w /GHOST, MCNL /BORAX, set CIBP, add Perf. POOH w/WFT CIBP setting tool assembly. LD WFT tools /lubricator /injector, cut 125' pipe, change pack offs, inspect chains. RIH w/25' of 3 -3/8" guns, Power Jet HMX 6 spf: 9940 - 9965'. 2nd run 3 3/8" PJ HMX x 25', perf from 9800'- 9825'. POOH 6/5/2012 « «JOB IN PROGRESS »> CTU #8 w/ 1.75" CT (CTV =34.0) Objective -Drift, PPROF w /GHOST, MCNL /BORAX, set CIBP, add Perf. POOH w/WFT CIBP setting tool assembly. LD WFT tools /lubricator /injector, cut 125' pipe, change pack offs, inspect chains. 6/5/2012 «JOB IN PROGRESS »> ClU #8w /1.75 "CT(CTV =33.1) Objective -Drift, PPROF w /GHOST, MCNL /BORAX, set CIBP, add Perf. POOH w/WFT CIBP setting tool assembly. LD WFT tools /lubricator /injector, cut 125' pipe, change pack offs, inspect chains. RIH w/25' of 3 -3/8" guns, 6 spf: 9940 - 9965'. 6/5/2012 « «JOB IN PROGRESS »> CTU #8 w/ 1.75" CT (CTV =33.1) Objective -Drift, PPROF w /GHOST, MCNL /BORAX, set CIBP, add Perf. Cont. POOH, Confirmed guns fired. Turn well back to Pad Op to Pop, RDMOL. 6/6/2012 « <JOB COMPLETE »» FLUIDS PUMPED BBLS 72 50/50 METH 160 BORAX 115 SAFELUBE KCI 433 1% SL KCL 780 TOTAL • Packers and SSV's Attachment ADL0028306 SW Name Type MD ND Depscription 15-01B PACKER 8693 8041.47 4 -1/2" Baker S -3 Packer 15-01B PACKER 8756 8101.83 5" Baker ZXP Top Packer • • Perforation Attachment ADL0028306 Perf Opera Meas Meas SW Operation tion Depth Depth TVD Depth TVD Depth Name Date Code Top Base Top Base 15 -01B 1/3/09 BPS 8730 12350 8139.47 8842.78 15-01B 2/13/09 BPP 8730 12350 8076.87 8780.18 15-01B 6/5/12 APF 9800 9825 8859.31 8859.51 15-01B 6/5/12 APF 9940 9965 8859.4 8858.31 15-01B 2/18/05 PER 10100 10190 8850.82 8848.07 15-01B 2/18/05 PER 10250 10350 8847.81 8848.42 15-01B 2/18/05 PER 10390 10440 8849.63 8850.98 15-01B 2/18/05 PER 10920 10970 8841.14 8837.46 15-01B 6/4/12 BPS 11030 11100 8830.98 8818.71 15-01B 2/18/05 PER 11100 11460 8818.71 8807.97 15-01B 4/26/09 BPS 11510 12350 8807.8 8780.18 15-01B 2/18/05 PER 11590 11730 8806.72 8801.56 15-01B 2/18/05 PER 11800 12150 8798.76 8790.53 15-01B 2/18/05 PER 12280 12350 8785.49 8780.18 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF TREE = CM/ • I'NELLHEAD= FMC 1 5-01 B SA NOTES: WELL> 70° 0 9630 ". PARENT A_CTUATO R -_. BAKER WELLBORE NOT SHOWN BELOW WHIPSTOCK. KB. ELEV ---- ___... ._.._ 63 "" "4 -1/2" CHROME TBG?" BF. REV = 41' KOP = 8924' Max Angle = 101 @ 11064" ' ' { 2093' —14-1/2" HES X NIP, ID = 3.813" Datum MD = 9442 Datum TVD= 8800' SS GAS LIFT MANDRELS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" —1 2547' I—■ ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3285 3278 15 KBG2 DONE BK 16 06/16/12 Minimum ID = 3.725" $738 3 5281 5060 28 KBG2 DOME BK 16 06/16/12 2 6900 6471 28 KBG2 DMY BK 0 02/17/05 4-1/2" HES XN NIPPLE 1 8353 7783 21 KBG2 DMY BK 0 02/17/05 /TOP OF 7" LNR H 8566' }-----_, 8672' I- 141!7' HES X NIP, ID = 3.813" 17" LNR, 29#, L -80, .0371 bpf, ID= 6.184" 1 8573' ' ' 4. Z X 8693' H 7" X 4-1/2" BKR S -3 PKR, ID = 3.875" I ' ' ( 8717' — 14-1/2" HES X NIP, ID = 3.813 "' 8738' H 4-1/2" HES XN NIP, ID = 3.725" 1 'TOP OF 4 -112" LNR' 874 5' ' ' —I 8745' H BKR LNR TIEBACK SLV, ID = 5.250" ' 4 -117' TBG, 12.6#, 13CR -80, -I 8750' 1 ii \ ' 8750' H4 -12" WLEG, ID = 3.958" VAMTOP,.0152bpf, ID= 3.958" 8756' H7" X 5" BKR ZXP LTP, D = 4.440" ' ( 8765' H T' X 5" BKR FLEX -LOCK HGR, ID = 4.440" ' 8771' 1-15" X 4-1/2" XO, ID = 4.000" l ' 9 -5/8" CSG, 47 #, L -80, ID = 8.681"' -1 8914' ■ MIL LOUT WINDOW (15 -018) 8924' - 8936' ' WHIPSTOCK (02/05/05) H 8924' 1 11030' I- 4-1/2" WFD CIBP (06/04/12) I2 -318" TBG STUB H 8942' ` 11510' 3.69" WFD WRP (0426109) lif PERFORATION SUMMARY 4 * ' PBTD ' 12384' � REF LOG: MWD ON 01/29/05 �/ ANGLE AT TOP PERF: 90° @ 98W ` Note: Refer to Production D8 for historical pert data ` SIZE SPF INTERVAL Opn/Sqz DATE •'• '# 3 -318" 6 9 800 -9825 O 06/05/12 ,. 3-3/8" 6 9940 - 9965 O 06/05/12 j' / ' - 9000' J CIBP (01/18/05) 1 ��i . 2 -7/8" 4 10100 - O 02/18/05 , ` ` � W° 2-718" 4 10250 - 10350 O 02/18105 >.,,;,- ..- ∎ Ale 2-718" 4 10390 - 10440 O 02/18/05 ;''% 2 -7/8" 4 10920 - 10970 O 02/18/05 ♦ 1 t t v 1��• � t • ■ 4-1/2" LNR, 12.6#, L -80, —' 12470' I 2 -7/8" 4 11100 -11460 c 02/18/05 4 ••••••4 2 -7/8" 4 • 11590 - 11730 C 02/18/05 '. . . . . . . . . . . 1 . . . 4 / IBT -M, .0152 bpf, ID = 3.958" 2 -7/8" 4 11800 -12150 C 02/18105 / 2 -7/8" 4 12280 - 12350 C 02/18/05 7" LNR, 29#, L -80, 9655' 0371 bpf, ID = 6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT r 1982 ORIGINAL COMPLETION 06/03/09 MV/TLH WRP SET (0427/09) WELL: 15-018 12/12/89 COM PLET ION 12/10/11 GW/PJC GLV CJO (07/26/08) PERMIT No: "2042570 11/25/98 N4ES CT SIDETRACK (15 -01A) 06/11/12 CJS/JMD SET CIBP & ADPERFS (06/04 -05/1 - API No. 50 -029- 20696 -02 02120/05 N2ES SIDETRACK (15 -01B) 06/16/12 PJC PERF ANGLE CORRECTION SEC 22, T11 N, R15E, 2387.08' FEL & 3522.85' FNL 02/07/07 MS/PJC DRLG DRAFT CORRECTIONS 06/19/12 MBMIJMD GLV C/O (06/16/12) 02/16/09 RMCISV TREE C/O (01/23/09) BP Exploration (Alaska) STATE OF ALASKA AAA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations 1 Perforate U Other U Performed: Alter Casing 0 Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 0 Exploratory ❑ 204 -257 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20696 -02 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028306 PBU 15-01B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 12470 feet Plugs measured 11030, 11510 feet true vertical 8833.95 feet Junk measured None feet Effective Depth measured 12384 feet Packer measured See Attachment feet true vertical 8840.14 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 88 20" 94# H-40 22 - 110 22 - 110 1530 520 Surface 2526 13 -318" 72# L -80 21 - 2547 21 - 2546.94 4930 2670 Intermediate 8894 9 -5/8" 47# L -80 20 - 8914 20 - 8316.81 6870 4760 Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 3725 4 -1/2" 12.6# L -80 8745 - 12470 8153.86 - 8833.95 8 7500 Algae Perforation depth Measured depth See Attachment feet u G L U IL True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 18 - 8750 18 - 8158.66 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes use and final pressure: 13. I _ „a ) Representative Daily Average Production or Injection Data T' Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 421 38977 0 0 1029 Subsequent to operation: 1011 18483 26 0 474 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development el Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 Printed Name Nita Summerha s Title Petrotechnical Data Technician Signatur- d — Phone 564 4035 Date 8/7/2012 _: T Al 1 ` Form 10 -404 Revised 10/2010 +'� y �� / � w Submit Original Only • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 71h Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, a° ~5 0~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, ~~~,~1~~ J.~l,E ~ ~ ~C~'ir Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 Date' 01/05/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-01 B 2042570 50029206960200- NA Sealed NA 15-026 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-048 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-06A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-O8C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Seated NA 15-116 2041460 50029206530200 NA Sealed NA 15-126 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-258 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-266 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-296 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-31 B 2050860 50029222850200 NA 1.2 NA 3.4 11111 /2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-338 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10!2009 15-368 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-378 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-416 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-428 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-456 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-486 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-498 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 • • ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907] 793-1225 RE : Cased Hote/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert. A. Richey 130 West International Airport Road ~~- a ~~ Suite C Anchorage, AK 99518 ~~ ~~a Fax: (907) 245-8952 1 ] Production Profile 21-Dec-08 15-01 B Color Log / EDE 50-029-2069fr02 2] Signed . Print Name: ~I Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL _ ~ ~., ,.. ~ m! ~ -~ _-- WE891TE : ~ , ~ ~.,. ~~ C:~Documents and Settings\Ovmer~DesktoplTransmit_SP.docx OPERABLE: 15-OlB (PTD #2042570) Tubing integrity restored Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, July 29, 2008 7:33 AM ~Q To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS3 DS Ops Lead; GPB, F~~OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Roschinger, Torin T.; Sinyangwe, Nathan; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 15-01 B (PTD #2042570) Tubing integrity restored Hi all, Wel! 15-01 B (PTD #2042570) passed aMIT-IA on 07/29/08 after dummying_off the caas lift valves praying integrity has been restored. The well has been reclassified as Operable and may be brought on line when convenient for operations. le se be prepared for the IA pressure to increase due to thermal expansion as the IA is liquid packed. Thank you, Anna l~ui6e, ~1'. E. Well Integrity Coordinatar GPB Wells Group Phone; {907) 659-5102 Pager: {907} 659-5100 x1154 ~~N~~ SF~ ~. ~ 200$ From: NSU, ADW Well Integrity Engineer Sent: Wednesday, July 23, 2008 5:41 PM To: 'Regg, lames B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GCl/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer; Sinyangwe, Nathan; GPB, Gas Lift Engr Subject: UNDER EVALUATION: 15-016 (PTD #2042570) for Sustained casing pressure due to TxIA Comm Hi all, Well 15-01 B (PTD #2042570) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to SSV/2050/50 psi on 07/11/08. A subsequent TIFL failed on 07/20/08. The well has been reclassified as Under Evaluation and may be produced under a 28-day clock. Alternatively, operations may allow the IA pressure to continue to build pressure. The plan forward for the well is as follows: 1. DHD: TIFL -FAILED 2. S: Set DGLVs 3. F: MITIA to 3000 psi, LLR if fails A TIO plot and wellbore schematic have been included for reference. Please call with any questions. Thank you, ,Anna Dube, ~? ~ Well Integrity Goordinator 9/5/2008 OPERABLE: 15-O1B (PTD #2042570) Tubing integrity restored Page 2 of 2 • GPI Wells Group Phone: (907} 659-5102 Pager: (907} 659-5100 x'1154 9/5/2008 PBU 15-01 B PTD 204-257 ~:o0u,.....- ............................ 3.000 ?; 000 1,OOIj 03126108 05103108 05110'08 05117/08 05124!0^0 05131108 06i07.~08 06/13108 08/21108 0F128108 07/05/08 07/12108 07113108 r: TREE = FMC GEN 2 ,WELLHEAD FMC ACTUATOR- AXELSON PKB. ELEV = 63' BF. ELEV -. 41' KOP = ~.~~ 8924' Max Angle =101 cr 11064" ' - Datum MD = 9442 Datum TV D = 8800' SS ~ N B OW WHIPSTOCFNCT *~~ ~ HROMETBG* 13-318" CSG, 72#, L-80, ID = 12.347" 2547' Minimum IQ = 3.725" ~ 8738' 4-112" HES XN NIPPLE TOP OF 7" LNR 8566' 7" LNR, 29#, L-80, .0371 bpf. ID = 6.184" $.573' TOP OF 4-1/2" LNR ~ $745' 4-112" TBG, 12.6#, 13CR-s0, 8754` VAM TOP,.0152 bpf, ID = 3,958" 9-518" CSG, 47#, L-80, ID = 8.681 WHIPSTOCK {02105105} f 8914' f 2-318" TBG STUB f--~ 8942' PERFORATION SUMMARY REF LOG: MNID ON 01/29105 ANGLE AT TOP PEf2F: 94 @ 10100' Note: Refer to Production DB for Historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2-7/8" 4 10100 - 10190 O 02/18/05 2-7l8" 4 10250 - 10350 O 02/18/05 2-718" 4 10390 - 10440 O 02/18/05 2-718" 4 10920 - 10970 O 02118105 2-718" 4 11100 - 11460 O 02!18105 2-718" 4 11590 - 11730 O 02/18105 2-718" 4 11800 - 12150 O 02118/05 2-718" 4 12280 - 12350 O 02118105 7" LNR, 29#, L-80, .0371 bpf, iD = &.184" 9flflfl` ~--{CIBP(01(18/05) PBTD I-i 12384' 4-112" LNR, 12.6#, L-80, ~ 124 IBT-M, .0152 bpf, ID = 3.958" I 9655° # DATE REV SY COMMENTS 1982 _,..,,.,,_,.. ORIGINAL CflMPLETIflN ,,,,,,,.,,.,,,e 12/12189 COMPLETION 11125198 N4ES CT SIDETRACK (15-01A} ~~~ 02120/05 N2ES 8IDETRAC (15-Q1 B} 03101/05 RWL/TLH GLV CIO 02/07/07 MS/PJC DRLG DRAFTCORRECTIONS DATE REV BY COMMENTS PRUDHOE BAY UNIT WELL: 15-01 B PERMIT No: 2042570 AP[ No: 5fl-029-20696-02 SEC 22, T11 N; R15E, 2387.08' FEL & 3522.85' FNL BP Exploration {A{aska} 2fl93' -{4-112" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3285 3278 16 KBG2 DOME BK 16 03/01/05 3 5281 5060 28 KBG2 SO BK 20 03101!05 2 6900 6471 28 KBG2 DMY BK 0 02/17105 1 8353 7783 21 KBG2 DMY BK 0 02117/05 $672' 1- ~4-112" HES X NIP, ID = 3.813" 8693' 7" X 4-112" BKR S-3 PKR, ID = 3.875" $717' 4-112" HES X NIP, ID = 3.813" $73$' 4-112°' HES XN NIP. ID = 3.725" $745' BKR LNR TIEBACK SLV, ID = 5.250" $750' 4-112" WLEG, 1D = 3.958" 8756' 7" X 5" BKR ZXP LTP, ID = 4.440" 8765' 7" X 5" BKR FLEX-LOCK HGR, ID = 4.440" $771' - r5" X 4-112" XO, ID = 4.000" MILLOUT WINDOW {15-fl1 B) 8924' - 8936' • • MICROFILMED 03/01 /2008 DO NOT PLACE w~Y~~ ANY NEW MATERIAL UNDER THIS PAGE F:~L.aserFicl~\C~+rPgs_Inserts~Microfilm Marlcer.c~c \VELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 April 11, 2007 en A?R 1 " 'LOO? ScANM..... RE: MWD Formation Evaluation Logs: IS-OIB, AK-MW-3514716 15-OlB: Digital Log Images: 50-029-20696-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AJ.~D RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEiVE Signed:Q. ~ Date: APR"J ~?n07 n. " " /\'~ ;', ""j¡ Jl doJ.I-;)6~ F ~ I-S-(X)~ \q~ DATA SUBMITTAL COMPLIANCE REPORT 3/12/2007 Permit to Drill 2042570 Well Name/No. PRUDHOE BAY UNIT 15-01B Operator BP EXPLORATION (ALASKA) INC :> t.t¿ C (:::¿&~ ~ ~ API Nol50-029-20696-02-00 MD 12470..../ TVD 8834./ Completion Date 2/19/2005 Completion Status 1-01L Current Status 1-01L UIC N -- - - --------------------..----------- ~----_..__._--- - -- --------- - ---------..-----.-..-- - __ - ____n____ -._------------ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~_____n__.___,,_.._.._ ~_ __.____.____ __._..·___M___~~__ ------- DATA INFORMATION Types Electric or Other Logs Run: DIR / GR / RES / ASI Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Data Type ED i ED 41t ~ '- Well Cores/Samples Information: Electr Digital Dataset Med/Frmt Number D Asc D Asc Name Directional Survey Interval e Log Log Run OH/ Scale Media No Start Stop CH Received Comments 8899 12470 3/29/2005 8899 12470 3/29/2005 MWD 8927 8950 Open 1/29/2007 8927 8950 Open 1/29/2007 GR, ROP, NPHI, NCNT, RHOS ------------ Sample Set Sent Received Number Comments Directional Survey 14360 LIS Verification C ~ t..tS' 14360 Induction/Resistivity -----_._-------_..._~--- Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y @ Chips Received? """7'-f-N- Daily History Received? 0N ß/N e Formation Tops Analysis Received? ~. -----.--- - - ----------_._._-_._-~--~------- -- -------.-------.--- - - ----~---------------- ----.-.- _~.____________n___ ----,,---- ..----- - - ---------~--_.-------- Comments: __ ___ - __________________.____'__n"__ &ö --.----------,,---..-.--.......--------- Compliance Reviewed By: _... .- ------~ Date: -JI>rl¥~¿.~7- ---- -------------------- ----,-~._------- . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 November 27,2006 RE: MWD Formation Evaluation Logs: 15-OlB, AK-MW-3514716 1 LDWG formatted CD rom with verification listing. API#: 50-029-20696-02 PLEASE ACK.~O'VLEDGE RECEIPT BY SIGl'iìNG AND RETtJRNING A COPY OF THE TRA1~Sl\UTTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 1 i\ 0\~ ~j ':L:¡ Datè~"" J c" 0' S¡gned:{l.tL--- *,/ ,-.../. ^. gö4 ~~S -:; ''''¡ð~U . STATE OF ALASKA . ALASM AND GAS CONSERVATION COM ,ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Commission 1b. Well Classf\nebomge 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-257 13. API Number 50- 029-20696-02-00 14. Well Name and Number: ., No. of Completions 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1557' SNL, 4968' WEL, SEC. 22, T11N, R14E, UM Top of Productive Horizon: 3493' SNL, 1021' WEL, SEC. 21, T11 N, R14E, UM Total Depth: 628' SNL, 952' WEL, SEC. 21, T11 N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 676250 y- 5959930 Zone- ASP4 TPI: x- 674970 y- 5957965 Zone- ASP4 Total Depth: x- 674966 y- 5960831 Zone- ASP4 --------~~~~-------- -~------------+-~-- --------------- 18. Directional Survey 181 Yes 0 No 21. Logs Run: DIR I GR I RES 1 ABI 22. One Other 5. Date Comp., Susp., or Aband. 2/19/2005 6. Date Spudded 2/612005 7. Date T.D. Reached 2/15/2005 8. KB Elevation (ft): 62.6' 9. Plug Back Depth (MD+ TVD) 12384 + 8840 10. Total Depth (MD+TVD) 12470 + 8834 11. Depth where SSSV set (Nipple) 2093' MD 19. Water depth, if offshore NI A MSL CASING SIZE 20" 13-3/8" 9-518" WT. PER FT. 94# 72# 47# 29# 12.6# CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DePTH TVIJ HOLE GRADE Top BoTTOM lOP BoTTOM SIZE H-40 Surface 110' Surface 110' 30" L-80 Surface 2547' Surface 2547' 17-1/2" L-80 I SOO-95 Surface 8914' Surface 8914' 12-1/2" L-80 Surface 8924' Surface 8326' 6" L-80 8745' 12470' 8154' 8834' 6" CEMENTING RECORD 1842# Poleset 2300 sx Fondu, 400 sx PF 'C' 500 sx Class 'G', 55 Bbls PF 'C' 1220 sx Class 'G' 417 sx Class 'G' 7" 4-1/2" 23. Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-7/8" Gun Diameter, 4spf MD TVD MD TVD 10100' -10190' 8913' - 8911' 10250'-10350' 8910'-8911' 10390' - 10440' 8912' - 8914' 10920' - 10970' 8904' - 8900' 11100' - 11460' 8881' - 8871' 11590' - 11730' 8869' - 8864' 11800'-12150' 8861'-8853' 12280' - 12350' 8848' - 8843' 26. Date First Production: March 3, 2005 Date of Test Hours Tested PRODUCTION FOR 3/20/2005 6.2 TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 413 550 24-HoUR RATE OIL -BSL 3,013 24. SIZE 4-1/2", 12.6#, 13Cr80 RECEIVED MAR 2 4 2005 PBU 15-01 B 15. Field 1 Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028306 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED TUSING RECORD DEPTH SET (MD) 8772' PACKER SET (MD) 8716' 25. ACID, FRActURE,CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 85 Bbls of Diesel GAs-McF 5,273 GAs-McF 20,412 WATER-BsL -0- WATER-BsL -0- CHOKE SIZE I GAS-OIL RATIO 84.98 6,776 OIL GRAVITy-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". niÕ~'i¡-;';);i';"¡" RBDMS BFL MAFlJ4'2005 None -I. ~'~:~"'=r.;" -,:, ;t ~..ì ~ !' ! 2..?Z '/{¡ t~~.J ~j:: PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing OIL-BsL 778 Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~ 28. GEOLOGIC MARKER. 29. aRMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD TVD Sag River 8914' 8317' None Shublik A Shublik B Shublik C 8951' 8979' 8999' 8353' 8380' 8399' Sadlerochit 9030' 8430' 45SB 44SB 43SB 41SB 9047' 9087' 9117' 9195' 8447' 8486' 8515' 8587' Top CGL Base CGL 9209' 9276' 8600' 8661' 23SB 22TS 21TS 9336' 9396' 9473' 8715' 8765' 8822' PGOC 9502' 8841' Zone 18 9538' 8862' Zone 1 A 9642' 8906' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~. ~ Title Technical Assistant Date 03);¿lf los PBU 15-01 B 204-257 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Phil Smith, 564-4897 Permit No. I 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). tTEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 Submit Original Only Legal Name: Common Name: 15-01 15-01 B 2/5/2005 FIT 8,924.0 (ft) 8,289.0 (ft) 8.40 (ppg) 690 (psi) 4,307 (psi) 10.00 (ppg) . . Printed: 2/23/2005 11 :57:05 AM . . BP EXPLORATION Operations Summary Report Page 1 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-01 15-01 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1/29/2005 Rig Release: 2/20/2005 Rig Number: Spud Date: 1/27/1982 End: 2/20/2005 Date From- To Hours Task Code NPT Phase Dëscription of Operations 1/29/2005 12:00 - 21 :00 9.00 MOB P PRE Move rig over weill Double mat and spot over well. Hook up pits and pumps, spot cuttings tank, and RU all lines. Spot camp, Reviewed pre-spud check list with Toolpusher and driller. 21 :00 - 23:00 2.00 WHSUR P DECOMP Pre-spud meeting with crew and toolpusher for rig accept: 2 hour adjustment in time for double mat from 2300 hrs to 2100 Rig accept due to well height. Install Hand rails, check gas detection, Rig accepted at 21 :00 hours. Install secondary annulus valve. 23:00 - 00:00 1.00 WHSUR P DECOMP Hold pre-job safety meeting with Rig crew and Drill site maintenance. RU lubicator and pull BPV 1/30/2005 00:00 - 00:30 0.50 KILL P DECOMP Install secondary annulus valve. 03:00 - 01 :30 22.50 KILL P DECOMP Rig up lubricator. Pull BPV 50 PSI on tubing. Rig down lubricator and clear rig floor. 01 :30 - 02:30 1.00 KILL P DECOMP Rig up lines to circulate. Test lines to 3000 psi. 02:30 - 05:00 2.50 KILL P DECOMP Pump soap sweep and displace freeze protect. Fill well with sea water 10 barrel per minute @ 1000 psi. Monitor well and annular pressures. Well is dead. 05:00 - 05:30 0.50 KILL P DECOMP Dry rod backpressure valve (BPV). 05:30 - 09:00 3.50 KILL P DECOMP Bleed down control and chemical injection lines. Nipple down tree and adapter flange. Install blanking plug. 09:00 - 12:00 3.00 KILL P DECOMP Install Adapter flange and N/U BOP Hold pre-job safety meeting and review non-routine operation. Jack up rig and NU BOP Jack down rig. 12:00 - 14:30 2.50 KILL P DECOMP Nipple up and function test BOP. 14:30 - 15:00 0.50 BOPSUF P DECOMP Make up 31/2" test joint 15:00 - 19:00 4.00 BOPSUP P DECOMP Test BOP's 250 low and 3500 psi high. Test witness waived by Jeff Jones 1/30105. Bag tested to 250 and 2500 psi high. 19:00 - 19:30 0.50 BOPSUF P DECOMP Pull Blanking plug and break down test joint. 19:30 - 20:30 1.00 PULL P DECOMP PIU Lubricator extension and lubricator. Pull back pressure valve (BPV). Lay down Lubricator extension and lubricator. 20:30 - 22:00 1.50 PULL P DECOMP Make up landing joint & screw into hanger. Back out lock downs. Pull hanger to floor. Pulled free @ 115k 22:00 - 22:30 0.50 PULL P DECOMP PJSM: Rig up control line spooler 22:30 - 00:00 1.50 PULL P DECOMP Break and lay down hanger. Pull 3 1/2" tbg from 8420 to 7752 spooling control lines. 1/31/2005 00:00 - 06:00 6.00 PULL P DECOMP Lay down 3.5 tubing with control & chem inject line form 7552 to 3286 feet. 06:00 - 07:00 1.00 PULL P DECOMP Pre-job safety meeting to cut control line, Risk assessment and possible hazards. Cut control line and continue spooling. 07:00 - 12:00 5.00 PULL P DECOMP Lay down tubing from 3266. Rig tour change and handover discussed. 12:00·13:30 1.50 PULL P DECOMP Rig down tubing handling tools and lay down control line spooler. Printed: 2/2312005 11:57:12 AM . . BP EXPLORATION QperationsSummaryReport Page 2 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-01 15-01 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1/29/2005 Rig Release: 2/20/2005 Rig Number: Spud Date: 1/27/1982 End: 2/20/2005 Date From - To Hours Task Code NPT Phase Description of Operations 1/31/2005 12:00 - 13:30 1.50 PULL P 13:30 - 15:30 2.00 FISH P 15:30 - 17:00 1.50 FISH P 17:00 - 18:00 1.00 FISH P 18:00 - 18:30 0.50 FISH P 18:30 - 23:30 5.00 FISH P DECOMP DECOMP Make up 4" test joint, set test plug and test top and bottom rams 250/3500 psi. Bag 250/2500 psi Pull test plug. DECOMP Make up fishing BHA. Overshot and fishing jars. DECOMP Cut and slip drilling line for ton miles. DECOMP Service and inspect top drive. DECOMP Continue running in the hole picking up 4" drill pipe (singles). At 6200 feet 136K Hook load and 120K slack off weight. 23:30 - 00:00 0.50 FISH N 2/1/2005 00:00 - 01 :30 1.50 FISH P 01:00 - 02:00 1.00 FISH P 01 :30 - 02:30 1.00 FISH P RREP DECOMP Rig repair: PJSM and risk assessment to repair skate. DECOMP Pick up drill pipe from 6283 to 8429: DECOMP Up weight 175k Down weight 145k Engage fish Pull to 225K Twice. Jar free second hit. DECOMP Circulate bottoms up 12 BPM @ 2700 psi. Monitor well for flow or loss before pulling. 02:00 - 05:30 3.50 FISH P 02:30 - 06:30 4.00 FISH P 03:30 - 08:00 4.50 FISH P 08:00 - 09:30 1.50 FISH P 09:30 - 10:00 0.50 FISH P 10:00 - 12:00 2.00 FISH P 12:00 - 13:00 1.00 FISH P 13:00 - 14:30 1.50 FISH P DECOMP Pull out of hole 8445 to 404 feet DECOMP Stand back BHA (DC's) and lay down fish. Clear rig floor DECOMP Hold pre-job safety meeting to pick up second fishing assembly. Rig up slim handling tools. DECOMP Make up BHA to 151 feet and RIH to 519 feet picking up drill pipe DECOMP Rig down slim hole handling tools. DECOMP Run in hole with 4' drill pipe to 6959 feet I Hold tour change meeting and do crew hand over. DECOMP Continue running in hole to 8451 feet. DECOMP Wash through top of packer to 8511 feet pumping at 1 BPM @ 920 psi. Static hook load 170K: Slack off hook load 140K: load pipe with dry job. Continue to run in hole to 8529 feet. Engage fish 5k down weight and pull 25 K up jar free pull fish through packer assembly, 5 - 30K over pull. 14:30 - 18:00 3.50 FISH P 18:00 - 19:00 1.00 FISH P 19:00 - 20:00 1.00 FISH P DECOMP Pull out of hole with fish to 2519 feet. DECOMP Well flowing back over drill pipe. Allow well to equalize. Can not pump, may release fish. Flowed back, stabilized and stopped. DECOMP Continued to pull out of hole to BHA. Printed: 2/2312005 11:57:12 AM .' . . BP EXPLORATION Operations Summary ¡Report Page 3 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-01 15-01 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1/29/2005 Rig Release: 2/20/2005 Rig Number: Spud Date: 1/27/1982 End: 2/20/2005 Date From - To Hours Task Code NPT Phase Description of Operations 2/112005 19:00 - 20:00 1.00 FISH P 20:00 - 21 :00 1.00 FISH P 21 :00 - 22:30 1.50 FISH P 22:30 - 00:00 1.50 FISH P DECOMP DECOMP Rack back 4.75" DC's and lay down jars and bumper sub. DECOMP Rig up handling tools to handle fish and spear. 2/2/2005 00:00 - 00:30 0.50 FISH P DECOMP 00:30 - 02:30 2.00 FISH P DECOMP 02:30 - 03:00 0.50 FISH P DECOMP 03:00 - 06:30 3.50 FISH P DECOMP 06:30 - 12:00 5.50 FISH P DECOMP DECOMP Recovered and laid down deployment sleeve, pup joint and 13 joints tubing for 377.72 feet recovery. Also recovered the wireline bow spring centrilizer in the deployment sleeve under the fishing spear. Clear rig floor and conduct PJSM. Pick up Baker packer milling assembly. Service top drive and inspect rig. Trip in hole with packer milling assembly. Tag 3 1/2" x 7" packer 8460 +/- depth mill packer. Up weight 170K: Down weight 145K Rotating weight 160K torque = 4- 7K with sea water in hole. Hold pre tour safety meeting and change out with rig crew. 12:00 - 14:00 2.00 FISH P DECOMP Mill on packer @ 8460 - 8462at 90 rpm 19K weight on milL Up weight 170K : Down weight 145K Rotating weight 160K torque = 4 - 7K Circulate 290 GPM = 280 psi 14:00 - 16:30 2.50 FISH P 16:30 - 19:30 3.00 FISH P 19:30 - 20:00 0.50 FISH P 20:00 - 21 :30 1.50 FISH P DECOMP Circulate well through choke with small gas influx below packer after milling through. Monitor well and pump dry job. DECOMP Pull out of hole with fish to 425 feet. DECOMP Stand back 4.75" drill collars. 21 :30 - 22:00 0.50 FISH P 22:00 - 23:00 1.00 FISH P 23:00 - 23:30 0.50 FISH P 23:30 - 00:00 0.50 FISH P 2/3/2005 00:00 - 02:30 2.50 FISH P 02:30 - 04:00 1.50 FISH P 04:00 - 04:30 0.50 FISH P DECOMP Break and lay down packer, tail pipe and clean out boot baskets. Recovered packer and 4 joints 3 1/2" tuning (tail pipe). Called Tool service to Norm test fish. DECOMP Test casing to 3500 psi for 30 minutes. DECOMP Make up Milling BHA and MWD. BHA #3 DECOMP Run in hole with DC's to 425 feet and test MWD. DECOMP Pick up 4 " drill pipe in trip in to allow to drill to TD and not have to pick up singels with whip stock. DECOMP PIU F/711' to 4449'. Picking up singles of drill pipe. DECOMP Continue running in hole with stands form derrick. RIH FI 4449 to 8744' DECOMP Fill pipe every 3000 feet and test MWD. Install blower hose and ready top drive. Pump 40 barrels high viscosity sweep and displace well to flo-pro mud. Pump at 300 GPM and 20oo-psi pump pressure. 04:30 - 05:00 0.50 FISH P DECOMP Log from 8900 to tubing top @ 8927' Tie in gamma to old logs. Printed: 2/2312005 11:57:12 AM . . BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/3/2005 2/4/2005 15-01 15-01 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Frorn - To Hours Task Code NPT Phase 04:30 - 05:00 0.50 FISH P 05:30 - 08:30 3.00 FISH P 08:30 - 09:30 1.00 FISH P 09:30 - 10:30 1.00 FISH P 10:30 - 11 :30 1.00 FISH P 11 :30 - 12:00 0.50 FISH P 12:00 - 14:30 2.50 FISH P 14:30 - 15:00 0.50 FISH P 15:00 - 16:30 1.50 FISH P 16:30 - 19:00 2.50 WHIP P 19:00 - 20:00 1.00 WHIP P 20:00 - 23:30 3.50 WHIP P 23:30 - 00:00 0.50 WHIP P DECOMP Page 4 of 13 Start: 1/29/2005 Rig Release: 2/20/2005 Rig Number: Spud Date: 1/27/1982 End: 2/20/2005 Description of Operations DECOMP Mill tubing from 8927 to 8939 feet. Milling slowed to < 5 feet per hour and pressures increased. Worked mills and attempted to mill again. No progress made. DECOMP Circulate bottoms up (CBU) 8939 feet 300 GPM 2100 psi. Monitor well for losses or gains. Pump dry job, blow down topdrive and remove blower hose for trip out. DECOMP Cut drilling line and adjust brakes. DECOMP Rig & Topdrive service. DECOMP POOH 8939 to 7436' Hold tour change and change out crews. DECOMP POH 7436 to 430 feet at bottom hole. DECOMP Rack back DC's and HWDP. DECOMP Lay down milling BHA. MWD and cleanout boot baskets. Clear rig floor and prepare next BHA to be picked up. WEXIT WEXIT WEXIT WEXIT 00:00 - 01 :00 1.00 WHIP P WEXIT 01 :00 - 01 :30 0.50 WHIP N HMAN WEXIT 01 :30 - 05:00 3.50 WHIP N HMAN WEXIT 05:00 - 06:00 1.00 WHIP N HMAN WEXIT 06:00 - 08:00 2.00 WHIP N HMAN WEXIT Pick up MWD and whipstock BHA. Talk to and up load MWD tool. Run in hole with Drill collars from derrick and HWDP. Surface test MWD all working well. Run in hole with drill pipe from derrick to 8590' Started-taking weight (5K) at +1- 8575 feet. Work down to 8595 Fear we might set WS! See Notes in remarks section. Work pipe, establish up and down parameters and break circulation. All indications are that WS is still attached and not set. Work pipe to 8955 feet with 7K maximum down weight, Not making progress, up weight indicates that WS is still latched up to whipstock. Unable to go down. Circulate while discussing options and strategy. Call Town Support Leader and relay information. See notes in remarks section DIMMS. POH with whipstock mills and BHA. No additional drag or loss of string weight. 175K up 150K down. From 8590 to 1127 Stand back BHA 1127' to 115' Hold pre-job safety meeting for operations. Lay down BHA using a piece of 7' casing as guide to ensure the WS could not release. 07:00 Friday crew change and hold PJSM with new crew coming on, all crew personnel, toolpusher, WSL, Sperry, and Baker. Printed: 2/2312005 11 :57: 1 2 AM -- . BP EXPLORATION Operations Summary. Report Page 5 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-01 15-01 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 1/29/2005 2/20/2005 Spud Date: 1/27/1982 End: 2/20/2005 Date From - To Hours Task Code NPT Phase Description of Operations 2/412005 06:00 - 08:00 2.00 WHIP N HMAN WEXIT Junk found on top of WS. Large chunks and slivers, 3 pieces total. 08:00 - 09:30 1.50 WHIP N HMAN WEXIT PJSM and review procedure to MU BHA: Make up Milling BHA with 6 1/16" full gauge string mill and boot baskets for clean out run. 09:30 - 12:00 2.50 WHIP N HMAN WEXIT Hold PJSM and review procedure for RIH. RIH to 7598' stands from the derrick 12:00 - 12:30 0.50 WHIP N HMAN WEXIT Continue to run in hole with stands from derrick form 7598 ' to 8532' 12:30 - 13:30 1.00 WHIP N HMAN WEXIT Fill pipe and start reaming at 8532 feet/175,Ooo# up; 145,000 down; 160,000# rotating at 100 rpm and 3000 ft/# torque. Ream from 8532' to 8942 feet. NO resistance or tight spots seen. 8942 was depth correction to this BHA. 13:30 - 15:00 1.50 WHIP N HMAN WEXIT Pump hi-vis sweep at 8942' while circulating at 400 GPM/1750 psi. No additional debris was seen on circulation. 15:00 - 18:00 3.00 WHIP N HMAN WEXIT PJSM and review procedure for POH: POH form 8942' to 1058 feet standing back stands in derrick. 18:00 - 19:00 1.00 WHIP N HMAN WEXIT Stand back HWDP and drill collars in derrick. 19:00 - 20:00 1.00 WHIP N HMAN WEXIT Lay down mills and clear rig floor. Some junk in boot basket. Slivers and chunks of large size. About 1/3 cup. 20:00 - 20:30 0.50 BOPSUP P WEXIT Pull wear ring. Make up test joint and set test plug. 20:30 - 00:00 3.50 WHIP P WEXIT Test X 14 on BOP's and choke manifold. 13X 250 psi low and 3500 psi high 1 x annular 250 low and 2500 psi high. All test were successful and held. One test on the upper top drive IBOP valve required bleeding off and retesting after it bleed down 100 psi in 5 minutes. Test 100% on second attempt. Test was witnessed by AOGCC representative Chuck Sheeve. 2/5/2005 00:00 - 01 :00 1.00 BOPSUF P WEXIT Test Upper and lower IBOP to 250 psi low and 3500 psi high. 01 :00 - 01 :30 0.50 WHIP P WEXIT Clear rig floor. Pull test plug and install wear bushing. 01 :30 - 04:00 2.50 WHIP N HMAN WEXIT Make up whip stock BHA and orient to MWD off set. Test MWD 250 GPM 540 psi. 02:30 - 08:00 5.50 WHIP N HMAN WEXIT RIH with WS filling pipe every 3000 feet and testing MWD. RIH at 2 minutes per stand maximum running speed. At Depth of NPT 8590 and start on productive time. 08:00 - 10:00 2.00 WHIP P WEXIT Orient to 79 degrees left of high side and tag up 8942 on depth. Set trip anchor with 20K Set down and shear lug at 35K down. Printed: 2/2312005 11 :57: 12 AM . . BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-01 15-01 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Task Code NPT Phase 2/5/2005 08:00 - 10:00 2.00 WHIP P WEXIT 10:00 - 12:00 2.00 STWHIP P WEXIT 12:00 - 21:00 9.00 STWHIP P WEXIT 21 :00 - 21 :30 0.50 STWHIP P WEXIT 21 :30 - 00:00 2.50 WHIP P WEXIT 2/6/2005 00:00 - 01 :30 1.50 WHIP P WEXIT 01 :30 - 03:00 1.50 WHIP P WEXIT 03:00 - 04:30 1.50 WHIP P WEXIT 04:30 - 06:00 1.50 STWHIP P WEXIT 06:00 - 09:00 3.00 STWHIP P WEXIT 09:00 - 10:00 1.00 STWHIP P WEXIT 10:00 - 11 :00 1.00 STWHIP P WEXIT 11 :00 - 12:00 1.00 STWHIP P WEXIT 12:00 - 00:00 12.00 DRILL P PROD1 Drill from 8954 to 9234 feet with 8.38 hours sliding and .55 hours rotating. Pick up weight 165K: Down weight 145K: 155K rotating weight with 5,000# torque. WOB 15 - 20k PROD1 Drill ahead, tuming and building with slow speed motor1.83 bend and Hughes MX18DX. Sliding at 15 - 30 FPH and rotating at 30 - 60 FPH. Motor yielding 18-degree doglegs with full slide. Zone 3 and 2 show drilling high % chert. Drilled to 9550 feet. Requiring 90% slide to yield 17 degree doglegs. 1.83 rotating hours and 7.18 sliding hours in 12 hours. 21712005 00:00 - 12:00 12.00 DRILL P Page 6 of 13 Start: 1/29/2005 Rig Release: 2/20/2005 Rig Number: Spud Date: 1/27/1982 End: 2/20/2005 Description of Operations Up weight 170K: Down weight 150K. TOW 8924' BOW 8936' Mill window with 40 rpm and 4000fV# torque. 8924 to 8928 feet. Hanging up slightly as the starter mill broke through and torqued as the full ga mill went out. Mill from 8928 to 8950 295 gallons per minute at 1575 psi. Torque = 4 to 5000 at 80 rpm. Running 7 to 15K weight on mills. Pull through window and wipe. Window looks good and no tight spots seen. Pull into casing and perform FIT test to 10PPG.Pressure up to 690 psi with 8.4 ppg mud weight and 8289 TVD Hold PJSM: POOH from 8950 to 3727' Tour crew change, review operations and duties. POH from 3727 to 1109 feet. Change out handling tools to handle BHA from 1109 to BHA'. Lay down whipstock mills. Lay down MWD in pipe shed and down load while flushing stack and surface equipment. Mills in good shape still 6 1/16" Mills were full gauge but had cement impacted in the water courses. Pull wear ring, flush stack and function BOP's. Install wear ring. PJSM to pick up BHA. Make up BHA. Set motor to 1.83 bend. Up load MWD tool and surface test BHA. RIH 361 to 8881 feet filling pipe every 3000 feet. PJSM and slip and cut drill. Service top drive, crown and rig. Break circulation and set tool face to 80 degrees left of highside to exit the window. Pass through window with no resistance. Printed: 2/2312005 11:57:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-01 15-01 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS2ES Start: 1/29/2005 Rig Release: 2/20/2005 Rig Number: Spud Date: 1/27/1982 End: 2/20/2005 2/7/2005 00:00 - 12:00 12.00 DRILL P PROD1 UP 170,000# Down 145,000# Rotating 160,000# Avg. WOB 20K 50 RPM torque running from 4 to 8000 ft/# Pumping 275 gpm 1980 psi off bottom. 2200 psi on bottom. 12:00 - 23:00 11.00 DRILL P PROD1 Drill ahead 9550 to 9843' landing in zone 1 A as directed by Geology. Target change to 4 feet above original well plan. 6.67 sliding hours 2.47 Rotating hours in past 12 hours. UP 170,000# Down 140,000# Rotating 160,000# Avg. WOB 20K 30 - 50 RPM torque running from 4 to 8000 ft/# Pumping 275 gpm 1980 psi off bottom. 2200 psi on bottom. ROP slowing and bit showing sign of wear. Pull for ROP. 23:00 - 23:30 0.50 DRILL P PROD1 Pump HI-vis sweep. and circulate into casing 273 gpm 2000psi. Monitor well/ static. PJSM to POH. 23:30 - 00:00 0.50 DRILL P PROD1 POH from 9843 to 8861 feet. No problem or tights spots Rig tour change and PJSM to continue pulling out of hole. 2/8/2005 00:00 - 01 :00 1.00 DRILL P PROD1 In casing shoe. Monitor well. Open cir-sub and increase flow rate to 440 gpm. Circulate well till shakers were clean. 01 :00 - 01 :30 0.50 DRILL P PROD1 Monitor well/ static. Pump dry job. 01 :30 - 04:00 2.50 DRILL P PROD1 POH to BHA to 361 feet. Change out handing tools 04:00 - 09:00 5.00 DRILL P PROD1 Continue to POOH with BHA. Flush tools with fresh water and pull to bit. Down load MWD tool. Change out motor to 5" Performance set at 1.5 bend. Pick up nukes. RIH with BHA. Last BHA drilled for 893 feet in 27.34 total hours on bottom. Bit pulled graded 2-4-BT-GR-E-I-ER-BHA. 09:00 - 12:00 3.00 DRILL P PROD1 Change out handling tools and RIH from 386 to 8886'. 12:00 - 13:00 1.00 DRILL P PROD1 Lubricate Rig and service. 13:00 - 14:00 1.00 DRILL N RREP PROD1 Trouble shoot top drive and repair. Torque boost not working. 14:00 - 14:30 0.50 DRILL P PROD1 Make up blower hose and RIH 14:30 - 18:00 3.50 DRILL P PROD1 MADD Pass. RIH from 9330 to 9843'. 18:00 - 21 :00 3.00 DRILL P PROD1 Drill 9843 to 9913' Slides are difficult hanging up. Torque is high at 9000- 10,000 FT/# Pumped beads to aid slide, no help. Slide hours =.65 I Rotate hours = .69 total drilling hours 1.34 total drilling hours. Drilled 70 feet total. Printed: 2/23/2005 11 :57: 12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-01 15-01 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1/29/2005 Rig Release: 2/20/2005 Rig Number: Spud Date: 1/27/1982 End: 2/20/2005 2/8/2005 21 :00 - 00:00 3.00 DRILL N RREP PROD1 Lost control of top drive. Trouble shoot. Work drill string and circulate while trouble shooting top drive. POH laying down singles as top drive would not allow to stroke full derrickand stand back stands. 5 - 10K drag pulling up. One tight spot at 9215 pulled 25K over. Pull into shoe to do rig repair. 2/9/2005 00:00 - 04:00 4.00 DRILL N RREP PROD1 Pre-Tour Safety before Crew Change: At casing shoe. Repair servive loop on Top Drive. Very windy with wind chills of -60 degrees F. Phase 2. 04:00 - 04:30 0.50 DRILL N RREP PROD1 Test Service loop and safetyl alarm system. 04:30 - 05:00 0.50 DRILL N RREP PROD1 PJSM : Trip in picking up singles to 9913' break circulation. 05:00 - 12:00 7.00 DRILL P PROD1 Drill ahead sliding as per goelogical change request. Drill ahead sliding to make turn. Geological steering to stay in good sand. Sliding difficult, BHA hanging up, very difficult to transfer weight while sliding. Torque high while rotating. Up weight = 170,000# Down = 145,000# Roating weight 160,000# Running 5 - 20K WOB RPM 70 Torque 7 - 10,000 ft# 12:00 - 00:00 12.00 DRILL P PROD1 Drill ahead sliding as per goelogical change request. Target 11800' MD to be at 8862' TVDKB Drill ahead slidingto maintain inclination. Geological steering to stay in good sand. Sliding difficult, BHA hanging up, very difficult to transfer weight while sliding. Torque high while rotating. Up weight = 170,000# Down = 135,000# Roating weight 155,000# Pumping 325 GPM 2450 psi on bottom. 2/10/2005 00:00 - 13:00 13.00 DRILL P PROD1 Drill ahead geo-steering as required. Having tough time sliding and keeping inclination. Drill to 10907. Have to have this slide and stalling while attempting to slide. Up weight = 170,000# Down weight = 135,000# Rotating weight = 155,000# Torque = 5-7,000 and peaking at 10K Weight on bit 12K 70 - 75 RPM 325 gpm 2800 psi on bottom pressure. 11 :30 - 12:00 Pre-tour safety meeting and rig crew change out. Holding PJSM prior to each change of operations, reviewing procedures. 13:00 - 14:00 1.00 DRILL P PROD1 Pump nut plug sweep and circulate into casing @ 325 gpm. 14:00 - 14:30 0.50 DRILL P PROD1 PJSM: POH from 10907 to 10383'. Bolt found on rig floor: Shut down to inspect. 14:30 - 15:00 0.50 DRILL N SFAL PROD1 Inspect derrick, top drive and IIR for loose equipment and/or missing bolt. Nothing found. 15:00 - 16:00 1.00 DRILL P PROD1 POH from 10383 to 8885. no over pull or tight spots, well looked good. 16:00 - 17:00 1.00 DRILL P PROD1 PJSM: Drop dart open cir-sub and increase circulation rate to clean well to 10 bpm. Circulate till shakers are clean. 17:00 - 17:30 0.50 DRILL N SFAL PROD1 Inspect top drive and all overhead equipemt. Still have not Printed: 2/23/2005 11:57:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-01 15-01 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1/29/2005 Rig Release: 2/20/2005 Rig Number: Spud Date: 1/27/1982 End: 2/20/2005 2/1 0/2005 17:00 - 17:30 0.50 DRILL N SFAL PROD1 found where bolt goes??? 17:30 - 18:30 1.00 DRILL P PROD1 PJSM: POH from 8885 to 6550' Control line to top drive parted. Shut down to repair. 18:30 - 20:00 1.50 DRILL N RREP PROD1 PJSM review non routine operations. Repair temperary top drive controll splice at broken point and re-attach. 20:00 - 00:00 4.00 DRILL P PROD1 POH from 6550 to BHA. Change out handling tools and pull and lay down BHA. Flush tools and read MWD. Lay down nukes. change DM from bottom to up in string to see if ABI will work better. PU fresh 5" motor set @ 1.5 bend 5 7/8" kick pad and jetted with 10/32 rotor jet to reduce bit RPM. PDC bit pulled looked the same as it did going in. 1-1-WT -A-X-I-XX-BHA Motor was also in good shape. CIO anyway. 2/11/2005 00:00 - 02:30 2.50 DRILL P PROD1 PJSM with new crew coming on tour. Change out BHA and make up new motor and bit. Running a Hughes MX18DX tri-cone on a 5" performance motor set at 1.5 Send with a 5 7/8" kick pad. Moved the DM up and H-simm down dropped nukes to aid in sliding and increase ASI data. 02:30 - 03:00 0.50 DRILL P PROD1 Test tools. ABI surface test and MWD working well. 03:00 - 07:00 4.00 DRILL P PROD1 RIH to window filling pipe every 3000' and testing MWD. Orient through window and continue tripping in hole. RIH pipe no taking correct fill. Float valve not holding. Pump Drill string volume to flush tools to prevent plugging off MWD or bit. From 359" to 8858' Set TF To slide through window, Torque Boost locked up. Can not run Top drive. 07:00 - 09:00 2.00 DRILL N RREP PROD1 Work on top drive torque boost. Change out electric over hydraulic cartridge control valves. 09:00 - 10:00 1.00 DRILL P PROD1 TIH to 10740. Tight start reaming to bottom. 40,000# drag up. Wash and ream from 10740 to 10775 feet. Torque stalling top drive at times. 10:00 - 12:00 2.00 DRILL P PROD1 Drill from 10907 to 10950' AST = 1.0 hours. Up weight = 170,000# Down weight = 135,000# Rotating weight = 155,000# Torque = 5,000 ft# off and 7,000 ft# on. WOB 20 - 25,000# with 75 surface RPM. @ 325 gpm motor RPM = 197 with a 10/32 rotor jet in motor reducing rev's I gallonto.60 12:00 - 18:00 6.00 DRILL P PROD1 Drilling ahead to 11060' attempting to slide. Short surveys indicating that the MWD I Motor have an offset error. BHA is not going where it is pointed. Calculated drill off TF 90 degrees behind the set TF. Adjust TF and attempt to slide watching he ASI to check results. Drill to 11105' 18:00 - 22:00 4.00 DRILL P PROD1 Attempt to compensate for off set error and slide watching every short survey and ABI. ASI showing 101 degrees. ABI not working on fly. stopping and pumping up surveys to check ABI. Able to drop inclination from 101 to 100 in 10 feet of slide but the off set seams to be floating (changing). Consult town and decide to POH and check MWD and offset. Printed: 2/23/2005 11 :57: 12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-01 15-01 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1/29/2005 Rig Release: 2/20/2005 Rig Number: Spud Date: 1/27/1982 End: 2/20/2005 2/11/2005 22:00 - 22:30 0.50 DRILL N HMAN PROD1 Circulate 2 x open hole volume. Drilling has been really slow so hole should be clean. Pull to shoe to open cir-sub. 22:30 - 00:00 1.50 DRILL N HMAN PROD1 Pull to window. drop dart and open cirsub. Circulate and pump dry job to POH. 2/12/2005 00:00 - 03:00 3.00 DRILL N HMAN PROD1 POH form window to HWDP top BHA. No tight spot seen on trip out to window. No problem coming into window with BHA. Flush BHA and stand back HWDP & NMFDC. 03:00 - 06:00 3.00 DRILL N HMAN PROD1 PJSM : Check MWD / Motor off set. LD MWD DM tool and change out motor. BHA found to have a 72-degree off. Change out BHA and PU new motor and ABI. C/O DM section on MWD. Flow test @ 300GPM 1490 psi. RIH from 360 to 8858 Fill pipe every 3000 feet. Float not holding, was changed out this run. Slip and cut driling line, service top drive and Install blower hose and set tool face to exit window. Trip in hole and take Cassandra surveys. Ream last stand as precasution to 11105' and shoot check shot and troft before sliding to reduce inclination. Slide to reduce inclination from 101 to 91 degrees. 11105 to 11131 slide at 160 RTF Slide 11131 to 11172 at LS TF Rotate 11772 to 11192 to clean up hole. Slide 11192 to 11124 110 TF Inclination at dropped to 91.5 degrees. Up weight = 170,000# Down Weight 145,000# Rotating weight 155,000# Rotating at 70 - 80 RPM torque 6000 - 8000 ft# 3.1 Sliding hours 2.91 Rotating hours 6.02 total drilling hours today. Currect TVD = 8870 @ 11500' MD Mus weight 8.7 ppg/ adding 25 BPH water. PROD1 Drilling ahead,11563 to 12450 geo-steering as required. Present target 11900' MD to be at 8857 TVD and continue a slight up trend. Present @ 11800' gamma 41 API. Rotating at 100 - 125 FPH sliding at 35 - 60 FPH. BHA trend is to drop slightly and having to slide to maintain inclination. Mud weight climb slightly to 8.7 ppg / start adding 30 bph water to reduce mud weight. YP is 31 and holding. Will dump and dilute. TD was extended to access the upper 1 B sand at the end of the well. Up weight = 170,000# Down Weight 145,000# Rotating weight 155,000# Rotating at 70 - 80 RPM torque 8000 - 9000 ft# Bit looks to be dull but still digging. 06:00 - 09:00 3.00 DRILL N HMAN PROD1 09:00 - 11 :00 2.00 DRILL P PROD1 11 :00 - 12:00 1.00 DRILL N HMAN PROD1 12:00 - 13:00 1.00 DRILL N HMAN PROD1 13:00 - 00:00 11.00 DRILL P PROD1 2/13/2005 00:00 - 19:00 19.00 DRILL P Printed: 2/23/2005 11 :57: 12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-01 15-01 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1/29/2005 Rig Release: 2/20/2005 Rig Number: Spud Date: 1/27/1982 End: 2/20/2005 2/13/2005 00:00 - 19:00 19.00 DRILL P PROD1 Slide hours 5.28 Rotate 13.32 19:00 - 20:30 1.50 DRILL P PROD1 PJSM prior to change of scope. Circulate @ 325 gpm 85 RPM Pump sweep and circulate around till shakers were clean. 20:30 - 22:30 2.00 DRILL P PROD1 PJSM: Pull out of the hole to casing shoe on short trip. Draw works making noise. Inspect draw works. Elmago bearing out. Will take 24 hours to repair. 22:30 - 00:00 1.50 DRILL N RREP PROD1 Working on Elmago brake on draw works. 2/14/2005 00:00 - 03:00 3.00 DRILL N RREP PROD1 PJSM prior to disassembling the cat shaft and elmago brake unit. Remove cat shaft. 03:00 - 11 :00 8.00 DRILL N RREP PROD1 Wait on crane 11 :00 - 12:00 1.00 DRILL N RREP PROD1 PJSM critical lift procedure reviewed. Spot crane and review lift. Time for tour change, shut down and did crew change. Hook up and circulate well. Mud starting to smell. Raise PG to 10. Circulate hole volume. 12:00 - 15:30 3.50 DRILL N RREP PROD1 Held PJSM and reviewed critical lift procedure with new crew. Lift out cat shaft and lay on rig floor. Make lift on brake unit and set to ground. Load onto truck. When brake unit was loaded on truck a small amount of gylcol leaked form the lower drain fitting onto the ground. 5700 was called and assessed. Less than 1 cup (4" x 5" spot) classified a leak and cleaned up. Captured in IR report # 2005-IR-1243736 in Traction. 15:30 - 20:00 4.50 DRILL N RREP PROD1 PJSM: Clean out draw works and prep for replacement of brake unit. Elmago unit taken to Nabors shop to be changes out and mounting pieces swapped. 20:00 - 00:00 4.00 DRILL N RREP PROD1 PJSM review critical lift procedure. Attempt to set brake unit. Needed modified due to drain outlet being in the wrong position. Call out welder and set brake unit in truck shop and secure for modification. 2/15/2005 00:00 - 01 :30 1.50 DRILL N RREP PROD1 Welder moving the 4" return / drain line on brake unit. All work being preformed in truck shop. Crane on standby while modifications are carried out. 01 :30 - 02:00 0.50 DRILL N RREP PROD1 PJSM review critiallifting procedures with all involved. Apoint tool pusher lift leader. Complete pre-lift check list. 02:00 - 03:00 1.00 DRILL N RREP PROD1 Carry out lift operations and set elmago unit into place. All went smooth. Crane holding unit while shimming is carried out. 03:00 - 06:00 3.00 DRILL N RREP PROD1 Installing new elmago brake unit and setting cat shaft. Should take 3 - 6 hours to finish repairs if all goes well. 06:00 - 13:00 7.00 DRILL N RREP PROD1 Install chain guards, inertia brake assy. & cat shaft. Pick up tools & adjust inertia brake. 13:00 - 14:30 1.50 DRILL P PROD1 RIH from 8859' to 12404'. 14:30 - 15:30 1.00 DRILL P PROD1 Break eire, wash from 12404' to 12450'. Drilling from 12450' to 12470'. ART = .4 hrs. RWT = 155, UWT = 175, DWT = 125, 80 RPM, WOB = 22K, pump @ 3050 psi. 15:30 - 17:00 1.50 DRILL P PROD1 Circ. high vis sweep, 320 GPM @ 3000 psi. Spot 125 bblliner running pill. Monitor well. 17:00 - 18:30 1.50 DRILL P PROD1 POH from 12470 to 8859' Printed: 2/23/2005 11 :57: 12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-01 15-01 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 1/29/2005 2/20/2005 Spud Date: 1/27/1982 End: 2/20/2005 2/15/2005 18:30 - 19:00 0.50 DRILL P PROD1 Open circ. sub, pump dry job and blow down Top Drive. 19:00 - 22:00 3.00 DRILL P PROD1 POH from 8858' to 360', hole in good shape. 22:00 - 00:00 2.00 DRILL P PROD1 UD BHA from 360', flush MWD & motor with water, down load, clear rig floor. 2/16/2005 00:00 - 06:30 6.50 P OTHCMP RIH with 4.5" 12.6# L-80 IBT liner. Baker lok btm 3 jts, check floats. RIH with 91 joints. Fill pipe @ 10 jt. intervals. 06:30 - 07:30 1.00 P OTHCMP M/U hanger assy. & 1 stand of D.P. Circ liner volume @ 3 BPM @ 380 PSII 5 BPM @ 450 PSI.UWT = 75K, DWT = 75K 07:30 - 09:00 1.50 P OTHCMP RIH from 3735' to 8905', fill pipe @ 10 std intervals. UD 2 joints of D.P. 09:00 - 09:30 0.50 DRILL P OTHCMP Circ. liner volume, 3 BPM @ 640 PSI, 4 BPM @ 750 PSI, 5 BPM @ 860 PSI, 6 BPM @ 970 PSI, UWT = 155K, DWT = 135K 09:30 - 11 :00 1.50 DRILL P OTHCMP RIH from 8905' to bottom @ 12470' fill pipe on the run. Hole in good shape. 11 :00 - 13:30 2.50 DRILL P OTHCMP Install cement head & single of D.P. Break circ & tag bottom. UWT = 180K, DWT = 140K, Circ open hole volume X 3 @ 3 BPM @ 990 PSI, reciprocate pipe. Stage pump up to 5 BPM @ 1350 PSI. Batch mix cement. 13:30 - 15:30 2.00 DRILL P OTHCMP Pump 5 bbl H20, test lines to 4500 PSI, pump 15 BBL CW-100 preflush.@ 8.5 PPG. Pump 25 BBL mud push X spacer @ 9.5 PPG. Pump 85 BBL class G cement @ 15.8 PPG. Wash lines & drop plug, pump remaining perf pill & mud. Bump plug, set liner on bottom & pressure up to 4000 PSI to set hanger, check floats & bleed off. Weight set hanger, rotate 20 turns to the right to set ZXP packer. CIP @ 1515 hrs. Pressure up to 1000 PSI WI rig, pick up & unsting. Bring pumps up to 180 SPM, pump 40 BBL. Slow pumps to 2 BPM, rotate & set down 50K to weight set packer. 15:30 - 16:30 1.00 DRILL P OTHCMP CBU @ 110 SPM, @ 1500 PSI. Reciprocate pipe. UWT = 150K, DWT = 135K. Approx. 20 BBL cement returns to surface. 16:30 - 17:30 1.00 DRILL P OTHCMP Displace well to seawater @ 10.5 BPM @ 2650 PSI. 17:30 - 22:00 4.50 DRILL P OTHCMP UD cement head. POH from 8744' to Running tool. UD tool. Clear rig floor. 22:00 - 00:00 2.00 DRILL P OTHCMP Pull wear ring & install test plug. Test BOPE, 250 PSI low I 3500 high. 2/17/2005 00:00 - 05:00 5.00 BOPSUF P OTHCMP Test BOP. 250 psi low, 3500 psi high. Annular to 250 psi low & 2500 psi high. Witness of test waived by Jeff Jones with AOGCC. Tested 2 ea top drive IBOPs, 15 ea. choke manifold valves, upper VBRs, lower VBRs, blind shear, annular, 1 ea HCR choke & kill, 1 ea manual choke & kill, 2 ea lower mud cross valves, perform Koomey test. 1 extra IBOP valve failed and will be changed out. (Witness Jim Willingham bp) 05:00 - 05:30 0.50 PERFOB P OTHCMP Test casinglliner to 3500 psi & put on chart. Hold test for 30 min. Test OK. 05:30 - 10:30 5.00 PERFOB P OTHCMP PJSM. P/U perf guns & first firing head to 1447'. R/U power tongs & change out elevators. P/U 14 jts of 2 7/8" PAC pipe to 1879'. Change out elevators, P/U guns & 2nd firing head to 2268'. Change out elevators & P/U 46 jts of PAC pipe & XOs to 3696'. Rig down power tongs, change out elevators. UWT = 60K, DWT = 60K. Perf 1210' @ 4 SPF. 10:30 - 15:00 4.50 PERFOB P OTHCMP RIH with perf guns on 4" drill pipe. Tag landing collar, P/U to Printed: 2/23/2005 11:57:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-01 15-01 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1/29/2005 Rig Release: 2/20/2005 Rig Number: Spud Date: 1/27/1982 End: 2/20/2005 2/17/2005 10:30 - 15:00 4.50 PERFOB P OTHCMP 12350', on depth. 15:00 - 15:30 0.50 PERFOB P OTHCMP Break circ. close annular preventor, pressure up to 3000 psi, bleed off, fire guns. 5 bbl fluid loss. 15:30 - 16:30 1.00 PERFOB P OTHCMP POH from 12350' to 10080', monitor well, pump dry job, blow down surface equip. 16:30 - 18:30 2.00 PERFOB P OTHCMP UD drill pipe from 10080' to 7155' 18:30 - 20:00 1.50 PERFOB P OTHCMP Cut & slip 90' of drill line, inspect brakes & adjust, service crown & Top Drive. 20:00 - 22:00 2.00 PERFOB P OTHCMP UD drill pipe from 7155' to 3696'. 22:00 - 00:00 2.00 PERFOB P OTHCMP Rig up 2 7/8" handling equip & UD pipe & firing head. 2/18/2005 00:00 - 07:30 7.50 PERFOB P OTHCMP POH UD remaining perf guns & 2 7/8" PAC drill pipe from 2268', all shots fired. Rig down power tongs. Clear & clean rig floor. Perf intervals 10100-10190, 10250-10350, 10390-10440, 10920-10970, 11100-11460, 11590-11730, 11800-12150, 12280-12350. Total perfs = 1210'. 07:30 - 15:00 7.50 PERFOB P OTHCMP MIU mule shoe, RIH with D.P. from derrick to 5695'. POH LDDP. Clear & clean rig floor & wind walls. 15:00 - 17:30 2.50 RUNCOMP RUNCMP Service top drive & drawworks. Change IBOP valve. 17:30 - 19:00 1.50 RUNCOMP RUNCMP PJSM. Pull wear ring. Rig up to run 4.5" CR13 Vam Top tubing completion. 19:00 - 00:00 5.00 RUNCOMP RUNCMP Make up tail pipe & packer assy, bakerlok all connections below packer. Use Jet Lube Seal pipe dope. Torque pipe to 4440 ft Ibs. 2/19/2005 00:00 - 07:30 7.50 PERFOB P OTHCMP Run 4.5" 13CR Vam Top tubing completion. Set WLEG +-6' into 4.5" tie back sleeve. Top of 4.5" tie back @ 8744', bottom of tie back @ 8756'. Use Jet Lube Seal Guard pipe dope. Torque pipe to 4440 ft. Ibs. Bakerlok assy. below the packer. UWT = 125K, DWT = 120K. 07:30 - 08:30 1.00 PERFOB P OTHCMP M/U tubing hanger & land tubing. RILDS. 08:30 - 10:00 1.50 PERFOB P OTHCMP Reverse circ. clean seawater with corrosion inhibitor @ 3 BPM @ 320 PSI. 10:00 - 11 :30 1.50 PERFOB P OTHCMP Drop 1 7/8" ball & rod down tubing. Pressure up to 3500 PSI & set packer. Test tubing for 30 min on chart. Test 4.5" X 7" annulus to 3500 PSI for 30 min on chart. Bleed tubing pressure & shear DCK valve. 11 :30 - 12:00 0.50 PERFOB P OTHCMP Install 2 way check valve & test to 1000 PSI. 12:00 - 14:30 2.50 PERFOB P OTHCMP Blow down surface equip & nipple down BOPE. 14:30 - 19:00 4.50 PERFOB P OTHCMP Clean & prep well head, install 11" X 5M adaptor flange & 4 1/8" 5M tree. Test tree to 5000 PSI, OK. 19:00 - 19:30 0.50 PERFOB P OTHCMP R/U Drill Site Maint. lubricator & pull 2 way check valve. 19:30 - 00:00 4.50 PERFOB P OTHCMP R/U Little Reds hot oil truck & pump 85 BBLs of diesel freeze protect heated to 65 degrees. U-tube annulus to tubing. Install BPV & test from below to 1000 PSI. R/D hot oil & circ lines. Remove secondary annulus valve, secure well. Empty pits & clean. Rig released @ 00:00 hrs 2-19-2005 Printed: 2/23/2005 11 :57: 12 AM . . svy4501 Survey Ref: BPXA North Slope Alaska BPXA 15-01 B Job No. AKZZ3514716, Surveyed: 16 FebruarY,2005 Survey Report 1 March, 2005 Your Ref: API 500292069602 Surface Coordinates: 5959929.68 N, 676249.80 E (70017' 45.9880" N, 148034'21.8416" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 62. 60ft above Mean Sea Level S¡ .......1 ·....,:V-SUï! DRILLING sefR\tIc:efs " '''' """"'"'''''''' A Hallibunon Company " BPXA Survey Report for 15-018 Your Ref: API 500292069602 Job No. AKZZ3514716, Surveyed: 16 February, 2005 North Slope A/aska 8PXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 8899.60 14.900 217.190 8240.29 8302.89 2051.588 1489.09 W 5957843.75 N 674809.23 E -2488.42 Tie On Point MWD+IIFR+M8 8924.00 14.750 217.190 8263.88 8326.48 2056.55 8 1492.87 W 5957838.69 N 674805.57 E 0.615 -2494.53 Window Point 8943.79 15.580 209.290 8282.98 8345.58 2060.888 1495.69 W 5957834.30 N 674802.85 E 11.243 -2499.64 8974.28 12.340 191.440 8312.58 8375.18 2067.648 1498.34 W 5957827.47 N 674800.36 E 17.557 -2506.89 . 9004.55 9.440 166.320 8342.32 8404.92 2073.23 S 1498.40 W 5957821.88 N 674800.43 E 18.154 -2511.98 9040.35 9.640 136.420 8377.65 8440.25 2078.26 8 1495.63 W 5957816.92 N 674803.31 E 13.700 -2515.37 9073.11 13.000 117.850 8409.78 8472.38 2081.97 8 1490.48 W 5957813.33 N 674808.55 E 15.010 -2516.56 9100.85 16.090 103.100 8436.63 8499.23 2084.308 1483.97 W 5957811.15 N 674815.11 E 17.307 -2515.93 9133.81 20.030 87.450 8467.98 8530.58 2085.088 1473.88 W 5957810.61 N 674825.22 E 18.865 -2512.38 9163.93 23.680 76.960 8495.94 8558.54 2083.49 8 1462.82 W 5957812.46 N 674836.24 E 17.704 -2506.26 9193.20 23.980 73.120 8522.72 8585.32 2080.438 1451.40 W 5957815.78 N 674847.58 E 5.398 -2498.68 9227.24 23.950 66.730 8553.83 8616.43 2075.708 1438.44 W 5957820.82 N 674860.44 E 7.622 -2488.91 9255.32 24.650 59.960 8579.43 8642.03 2070.51 8 1428.13 W 5957826.25 N 674870.62 E 10.224 -2479.85 9287.27 24.160 59.630 8608.52 8671.12 2063.87 8 1416.72 W 5957833.15 N 674881.87 E 1.592 -2469.02 9318.93 27.700 50.630 8637.00 8699.60 2055.92 8 1405.43 W 5957841.37 N 674892.97 E 16.692 -2457.05 9350.19 32.540 43.660 8664.04 8726.64 2045.22 8 1394.00 W 5957852.33 N 674904.14 E 19.080 -2442.52 9377.91 35.220 37.540 8687.06 8749.66 2033.488 1383.98 W 5957864.30 N 674913.89 E 15.641 -2427.65 9410.93 38.370 31.010 8713.51 8776.11 2017.14S 1372.89 W 5957880.90 N 674924.59 E 15.198 -2408.15 9441.77 42.270 28.340 8737.02 8799.62 1999.808 1363.03 W 5957898.47 N 674934.04 E 13.829 -2388.27 9471.76 46.710 28.680 8758.41 8821.01 1981.348 1353.00 W 5957917.16 N 674943.63 E 14.826 -2367.30 9506.08 52.220 28.080 8780.70 8843.30 1958.40 8 1340.61 W 5957940.39 N 674955.48 E 16.110 -2341.27 . 9537.13 56.460 28.260 8798.80 8861 .40 1936.168 1328.71 W 5957962.89 N 674966.86 E 13.664 -2316.09 9565.52 59.540 29.250 8813.84 8876.44 1915.068 1317.12W 5957984.26 N 674977.95 E 11 .245 -2292.07 9600.24 65.790 28.300 8829.78 8892.38 1888.03 8 1302.29 W 5958011.63 N 674992.14 E 18.164 -2261.31 9629.92 71.360 27.040 8840.62 8903.22 1863.57 8 1289.47 W 5958036.38 N 675004.39 E 19.178 -2233.72 9659.81 77.250 25.420 8848.70 8911.30 1837.77 S 1276.76 W 5958062.47 N 675016.49 E 20.384 -2204.97 9691.78 83.200 24.130 8854.13 8916.73 1809.188 1263.57 W 5958091.37 N 675029.01 E 19.031 -2173.48 9723.84 87.100 24.370 8856.84 8919.44 1780.06 8 1250.45 W 5958120.79 N 675041.44 E 12.188 -2141.54 9752.83 87.590 24.660 8858.18 8920.78 1753.71 S 1238.43 W 5958147.41 N 675052.83 E 1.964 -2112.58 9801 .03 89.690 20.900 8859.32 8921.92 1709.298 1219.78 W 5958192.26 N 675070.44 E 8.933 -2064.44 9869.74 88.890 18.060 8860.17 8922.77 1644.53 S 1196.87 W 5958257.54 N 675091.82 E 4.294 -1996.06 9918.03 91.360 16.040 8860.07 8922.67 1598.36 8 1182.72W 5958304.02 N 675104.89 E 6.607 -1948.24 9962.16 92.840 14.450 8858.45 8921.05 1555.82 8 1171.12 W 5958346.83 N 675115.49 E 4.920 -1904.77 10007.84 93.020 14.360 8856.12 8918.72 1511.638 1159.77W 5958391.27 N 675125.80 E 0.440 -1859.93 10055.19 93.330 12.460 8853.49 8916.09 1465.65 8 1148.81 W 5958437.50 N 675135.68 E 4.060 -1813.61 1 March, 2005 - 16:12 Page 2 of 5 DrillQuest 3.03.06.008 '. BPXA Survey Report for 15-018 Your Ref: API 500292069602 Job No. AKZZ3514716, Surveyed: 16 February, 2005 North Slope Alaska 8PXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10102.61 93.520 12.180 8850.66 8913.26 1419.408 1138.71 W 5958483.97 N 675144.69 E 0.713 -1767.43 10148.57 91.230 12.300 8848.76 8911.36 1374.538 1128.97 W 5958529.06 N 675153.37 E 4.989 -1722.64 10212.57 90.370 10.310 8847.86 8910.46 1311.788 1116.43 W 5958592.08 N 675164.44 E 3.387 -1660.46 10241.63 89.880 9.100 8847.80 8910.40 1283.138 1111.53 W 5958620.83 N 675168.67 E 4.492 -1632.42 10275.27 90.250 8.430 8847.76 8910.36 1249.898 1106.40 W 5958654.19 N 675173.01 E 2.275 -1600.12 10307.05 89.810 7.090 8847.75 8910.35 1218.408 1102.11 W 5958685.77 N 675176.56 E 4.438 -1569.76 . 10335.29 88.830 5.320 8848.08 8910.68 1190.338 1099.06 W 5958713.91 N 675178.96 E 7.164 -1543.03 10369.34 88.150 4.740 8848.98 8911.58 1156.42 8 1096.08 W 5958747.87 N 675181.14 E 2.624 -1511.03 10398.74 88.270 4.620 8849.90 8912.50 1127.13 8 1093.68 W 5958777.21 N 675182.85 E 0.577 -1483.47 10428.54 88.580 4.230 8850.72 8913.32 1097.438 1091.38 W 5958806.95 N 675184.46 E 1.671 -1455.58 10462.42 89.140 3.860 8851.39 8913.99 1063.65 8 1088.99 W 5958840.79 N 675186.05 E 1.981 -1423.94 10492.28 89.260 3.280 8851.81 8914.41 1033.85 8 1087.13 W 5958870.62 N 675187.21 E 1.983 -1396.14 10519.71 88.580 2.340 8852.32 8914.92 1006.46 8 1085.79 W 5958898.04 N 675187.91 E 4.229 -1370.74 10553.56 89.320 1.690 8852.94 8915.54 972.63 S 1084.60 W 5958931.88 N 675188.31 E 2.909 -1339.57 10584.74 91.360 1.160 8852.76 8915.36 941.46 S 1083.82 W 5958963.06 N 675188.35 E 6.760 -1310.99 10612.60 91.360 0.700 8852.10 8914.70 913.628 1083.37 W 5958990.91 N 675188.15 E 1.651 -1285.56 10648.13 91.480 1.000 8851.22 8913.82 878.108 1082.84 W 5959026.43 N 675187.85 E 0.909 -1253.14 10676.17 91.670 0.520 8850.45 8913.05 850.Q7 8 1082.47 W 5959054.46 N 675187.56 E 1.840 -1227.57 10707.45 92.100 359.370 8849.42 8912.02 818.81 8 1082.50 W 5959085.71 N 675186.80 E 3.923 -1199.25 10740.95 93.020 359.070 8847.92 8910.52 785.35 8 1082.96 W 5959119.15N 675185.56 E 2.888 -1169.10 10800.27 93.520 359.480 8844.54 8907.14 726.138 1083.71 W 5959178.34 N 675183.42 E 1.089 -1115.74 10853.48 91 .230 357.360 8842.33 8904.93 672.99 8 1085.17W 5959231.43 N 675180.71 E 5.862 -1068.19 . 10878.75 90.250 356.770 8842.01 8904.61 647.76 S 1086.47 W 5959256.62 N 675178.82 E 4.527 -1045.86 10906.90 91.420 355.650 8841 .60 8904.20 619.67 S 1088.33 W 5959284.66 N 675176.30 E 5.753 -1021.18 10938.27 94.140 350.210 8840.07 8902.67 588.59 8 1092.18 W 5959315.64 N 675171.72 E 19.369 -994.63 10982.08 95.750 348.510 8836.30 8898.90 545.708 1100.24 W 5959358.33 N 675162.66 E 5.334 -959.15 11004.50 95.810 348.730 8834.04 8896.64 523.83 8 1104.64 W 5959380.09 N 675157.75 E 1.012 -941 .18 11028.99 97.860 349.420 8831.12 8893.72 499.968 1109.25 W 5959403.85 N 675152.58 E 8.826 -921 .49 11064.12 101.060 351.760 8825.35 8887.95 465.788 1114.91W 5959437.88 N 675146.11 E 11 .231 -892.90 11095.35 100.420 349.000 8819.53 8882.13 435.53 8 1120.04 W 5959468.00 N 675140.28 E 8.921 -867.64 11125.61 96.930 349.340 8814.97 8877.57 406.168 1125.66 W 5959497.24 N 675133.97 E 11.587 -843.38 11156.79 93.770 350.220 8812.06 8874.66 375.61 8 1131.17 W 5959527.65 N 675127.75 E 10.517 -818.01 11187.99 92.040 351.820 8810.48 8873.08 344.83 8 1136.03 W 5959558.30 N 675122.17 E 7.548 -792.17 11218.63 91.980 352.360 8809.40 8872.00 314.508 1140.25 W 5959588.53 N 675117.24 E 1.772 -766.45 11279.98 90.990 355.220 8807.81 8870.41 253.548 1146.88 W 5959649.32 N 675109.18 E 4.932 -713.99 1 March, 2005 - 16:12 Page 3 of 5 Dri/lQuest 3.03.06.008 BPXA Survey Report for 15-01 B Your Ref: API 500292069602 Job No. AKZZ3514716, Surveyed: 16 February, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1000) 11309.75 90.060 356.950 8807.54 8870.14 223.84 S 1148.91 W 5959678.96 N 675106.45 E 6.597 -687.92 11353.78 89.880 356.190 8807.56 8870.16 179.89 S 1151.55W 5959722.83 N 675102.79 E 1.774 -649.19 11402.24 89.200 356.050 8807.95 8870.55 131.54 S 1154.82 W 5959771.09 N 675098.38 E 1 .433 -606.75 11447.31 90.490 356.900 8808.07 8870.67 86.56 S 1157.60W 5959816.00 N 675094.55 E 3.428 -567.14 11496.11 90.060 355.900 8807.84 8870.44 37.86 S 1160.66 W 5959864.61 N 675090.35 E 2.231 -524.28 11589.60 91.300 355.250 8806.73 8869.33 55.34 N 1167.87 W 5959957.62 N 675080.95 E 1 .497 -442.84 . 11682.39 92.530 355.230 8803.63 8866.23 147.76 N 1175.57 W 5960049.83 N 675071.09 E 1.326 -362.31 11775.28 92.350 353.970 8799.67 8862.27 240.15 N 1184.30 W 5960141.99 N 675060.19 E 1.369 -282.24 11868.08 90.620 354.530 8797.27 8859.87 332.45 N 1193.59 W 5960234.05 N 675048.74 E 1.959 -202.49 11961.19 89.440 354.420 8797.22 8859.82 425.13 N 1202.56 W 5960326.49 N 675037.60 E 1.273 -122.26 12011.78 92.220 353.380 8796.49 8859.09 475.42 N 1207.93 W 5960376.64 N 675031.05 E 5.867 -78.94 12056.35 93.090 353.440 8794.42 8857.02 519.65 N 1213.04 W 5960420.74 N 675024.90 E 1.957 -41.00 12105.53 92.470 353.500 8792.04 8854.64 568.45 N 1218.63 W 5960469.40 N 675018.18 E 1.267 0.88 12149.14 91.420 353.120 8790.56 8853.16 611.74 N 1223.71 W 5960512.55 N 675012.08 E 2.560 37.98 12181.87 91.230 353.280 8789.80 8852.40 644.23 N 1227.58 W 5960544.94 N 675007.45 E 0.759 65.80 12212.97 92.840 352.880 8788.70 8851.30 675.08 N 1231.33 W 5960575.70 N 675002.98 E 5.334 92.18 12243.52 92.340 352.680 8787.32 8849.92 705.36 N 1235.16 W 5960605.88 N 674998.44 E 1.762 118.01 12338.39 95.070 353.140 8781.19 8843.79 799.30 N 1246.85 W 5960699.52 N 674984.55 E 2.918 198.24 12384.14 94.080 352.150 8777.54 8840.14 844.52 N 1252.68 W 5960744.60 N 674977.66 E 3.055 236.77 12401 .94 94.140 351.280 8776.26 8838.86 862.09 N 1255.24 W 5960762.10 N 674974.69 E 4.887 251.62 12470.00 94.140 351 .280 8771.35 8833.95 929.19 N 1265.53 W 5960828.94 N 674962.82 E 0.000 308.10 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. . Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 24.970° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12470.00ft., The Bottom Hole Displacement is 1570.02ft., in the Direction of 306.287° (True). 1 March, 2005 - 16:12 Page 4 of 5 DrillQuest 3.03.06.008 BPXA Survey Report for 15-01 B Your Ref: API 500292069602 Job No. AKZZ3514716, Surveyed: 16 February, 2005 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8899.60 8924.00 12470.00 8302.89 8326.48 8833.95 2051.58 S 2056.55 S 929.19 N 1489.09 W 1492.87 W 1265.53 W Tie On Point Window Point Projected Survey . Survey tool program for 15-018 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8899.60 0.00 8899.60 8302.89 12470.00 8302.89 BP High Accuracy Gyro - GYD-CT-CMS (15-01) 8833.95 MWD+IIFR+MS (15-01 B) . 1 March, 2005 - 16:12 Page 5 of 5 DrillQuest 3.03.06.008 , TREE =. WELLHEAD = ACTUA TOR = KB. ELEV = ~,. .... .............."u~..,~.." . ~ BF. ELEV = ~~ .~~'@,m..~~~~~~~~,",~<n.m'~' KOP= Max Angle = Datum MD ,; DatumìVD= L:w' NOTES: FMC GEN 2 FMC AXELSON 63' ? _-01 B Proposed FROM DRLG - DRAFT 3100' I ~ 1-1 41/2" X Landing Nipple (3.813" ID) ~\\(o . "~~""'".~ 8800'SS ~ 113-3/8" CSG. 72#, L-80, ID = 12.347" H 2547' ~ GAS LIFT MANDRELS DEV TYÆ VLV LATCH 16 KBG-2 DOME BK 28 KBG-2 SO BK 28 KBG-2 DMY BK 21 KBG-2 DMY BK PORT DATE 16 03/01/05 20 03/01/05 o 02/17105 o 02/17105 ST MD ìVD 4 3285 3278 3 5281 5060 2 6900 6471 1 8353 7783 Minimum ID = 3.725 @ XN L 8672' ~ 8716' 4-1/2" X NIP, ID=3.813" 7" x 4-1/2" Baker S3 Packer , 87/ ~ 4-1/2" X NIP, ID = 3.813" g ~ I TOP OF 7" LNR H 7" LNR, 29#, L-80. .0371 bpf. ID = 6.184" H H 8566' 8573' ~ 4-1/2" XN NIP, ID = 3.725" 4-1/2" LINER TOP / TBR 4-1/2" WLEG 1-1 7" Top of Window ~ ~g 9-5/8" CSG, 47#, L-80, ID = 8.681" H 8914' i_____~ 1 , H -8930' H -8940' H -9100' WHIPSTOCK TOP fish CIBP H 12470' I I 4 1/2" 12.6# L-80 Liner Shoe PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 94 @ 10100' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE ? 4 10100 - 10190 0 02/18/05 4 10250 - 10350 0 02/18/05 4 10390 - 10440 0 02/18/05 4 10920 - 10970 0 02/18/05 4 11100 - 11460 0 02/18/05 4 11590 - 11730 0 02/18/05 \ \eop- \'t.\50 \'Z.V0ð#\?~f) 7" LNR, 29#. L-80, .0371 bpf, ID = 6.184" H 9655' 2-3/8"LNR, 4,7# (abandoned) H 11373' DA TE REV BY COMMENTS I 02/25/05 /TLH CORRECTIONS TO DRLG DRAFT 03/02/05 RWL/TLH GL V C/O PRUDHOE BA Y UNrr WELL: 15-01B PERMrr No: 1982220 API No: 50-029-20696-02 SEC 22, T11 N, R15E, 2387.08' FEL & 3522.85' FNL DATE 1982 12/12/89 11/29/98 10/20/04 11/15/04 12/05/04 REV BY COMMENTS ORIGINAL COM PLETION COMPLETION CT SIDETRACK DA V /TLP DEPLOY SL V SZ CORRECTION CJ/TLH PATCH PULLED 10/24/04 PGS Proposed Rotary Sidetrack BP Exploration (Alaska) . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well 15-01 B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. 8,899.60' MD 8,924.00' MD 12,470.00' MD Tie-on Survey: Window / Kickoff Survey: Projected Survey: (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Å 9 f!Iovt ~ ð f'j- S. d ¡/) / j I; / ¡J / Igne ~v~ U~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 05-Mar-05 ~ 0 LI - Å s'-7 . . 05-Mar-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-01 B MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,899.60' MD 8,924.00' MD 12,470.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date À 9 Mall'! iú()} Signed tJ 6JlJ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) Â D0/-~~-7 I ~~:!Ä'\~" Œ'· [ i ! ¡ ¡ !: rü i I .. , ! ¡ : ¡ ¡..; L; . (ID~ ~~ . /l.ffi LrlJ FRANK H. MURKOWSK/, GOVERNOR AI',ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 15-01B BP Exploration (Alaska) Inc. Permit No: 204-257 Surface Location: 1557' SNL, 4968' WEL, SEC. 22, T11N, R14E, UM Bottomhole Location: 993' SNL, 934' WEL, SEC. 21, T11N, R14E, UM Dear Mr. Crane: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from 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 comply 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 permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commissio 6' 'tness any required test. Contact the Commission's petroleum field inspector at (907) 6 -36 ager). DATED this~day of January, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1\ . STATE OF ALASKA I ALAS~IL AND GAS CONSERVATION CO MISSION PERMIT TO DRILL 20 AAC 25.005 11 b. Current Well Class 0 Exploratory a DevÆøM'øntLåill¥b""~. ~iss '011 o Stratigraphic Test 0 Service 0 Development Gas ~t/~i8p:le Zone 5. Bond: 181 Blanket 0 Single Well 11. Well Name and ftÓm5KF Bond No. 2S100302630-277 P8U 15-018 "Í~I~o 6. Proposed Depth: 12. Field I Pool(s): MD 12142 TVD 8842 Prudhoe Bay Field I Prudhoe Bay 7. Property Designation: Pool ADL 028306 13. Approximate Spud Date: / January 20, 2005 14. Distance to Nearest Property: 33600' 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool (Height above GL): 61.9 feet 15-48A is 125' away at 11528' MD 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3150 Surface: 2370 / Setting. ~pth Top ·i> .......... .... .. · .. . .·Sdttdm Length MD TVD MD TVD (including stage data) 3362' 8780' 8200' 12142' 8842' 411 sx Class 'G' /' o Drill a Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1557' SNL, 4968' WEL, SEC. 22, T11 N, R14E, UM / Top of Productive Horizon: 2839' SNL, 739' WEL, SEC. 21, T11 N, R14E, UM Total Depth: 993' SNL, 934' WEL, SEC. 21, T11 N, R14E, UM / 4b. Location of Well (State Base Plane Coordinates): Surface: x- 676250 y- 5959930 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 8930 feet Maximum Hole Angle: 93 8. Land Use Permit: 9. Acres in Property: 2560 18. Casing Program: Size Casing 4-1/2" Weight 12.6# Specifications Grade Coupling L-80 IBT-M Hole 6" VJ (~ A- II ~/z...~5 REceIVED OEC 2 ~J 2004 PRESENT WELL CONDITION SUMMARY (To Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): 11392 8939 None 11339 Structural Conductor 110' 20" 1842# Poleset 110' 110' Surface 2547' 13-3/8" 2300 sx Fondu, 400 sx PF 'C' 2547' 2547' Intermediate 8914' 9-5/8" 500 sx Class 'G', 55 Bbls PF 'C' 8914' 8330' Production 9357' 7" 1220 sx Class 'G' 9357' 8760' Liner 2851' 2-3/8" 75 sx LARC 8523' - 11374' 7955' - 8937' perfOration Depth TVD (ft): 8923' - 8936' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program 181 20 AAC 25.050 Requirements Perforation Depth MD (ft): 9550' - 11341 ' 20. Attachments 181 Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Crane Title Senior Drilling Engineer IU~ Date: Contact Phil Smith, 564-4897 Phone Prepared By Name/Number: Terrie Hubble, 564-4628 Permit To Drill API Number: Number: 2.. ð 9- 2_. ~ ? 50- 029-20696-02-00 Conditions of Approval: Samples Required D Yes ~o yd ogen Sulfide Measures ""-ØYes D No p.... 'ŠS"oO rk.. ' /' ~ r-I. Permit APPiva'j' Date: 1:3 pç- Mud Log Required Directional Survey Required it. ¡ /..1 .~ .t \ ' APPROVED BY THE COMMISSION ~ See cover letter for other requirements D Yes ~No ~Yes tJ No Date I~~ 'lub1,~ Duplicate · . I Well Name: 115-01 B Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: Estimated Target Location: Ivishak Zone 1 A Bottom Hole Location: Ivishak Zone 1 B x = 676,249.8 Y = 5,959,929.7 1558' FNL 309' FWL Sec. 22, T11 N, R14E Umiat X = 675,235.0 Y = 5,958,625.0 TVDss 8874' 2839' FNL 739' FEL Sec. 21, T11 N, R14E Umiat X = 674,993.0 Y = 5,960,466.0 TVDss 8780' 993' FNL 934' FEL Sec. 21, T11 N, R14E Umiat ,/ ,/ I AFE Number: I PBD4P2275 I I Estimated Start Date: 101/20/05 I Rig: I Nabors 2ES / I Operating days to complete: 119.5 I MD: 112,142' II TVD: 18,842' 1/ I GL: 133.4' I I KB: 128.5' I I KBE: 161.9' I Well Design (conventional, slimhole, etc.): I Single String Horizontal Sidetrack I Objective: I Ivishak Zone 1 A/1 B Formation Markers Formation Tops (wp02) MD TVD TVDss Comments CM2 6711 -6649 ABOVE KICKOFF CM1 7373 -7311 r· '5"'" m~ ~ ~~ I LCU 7899 -7837 t T JD 7899 -7837 T JC 7996 -7934 T JB 8151 -8089 TJA 8240 -8178 SAG RIVER 8912 8331 -8269 SHUBLIK 8955 8369 -8307 TSAD 9031 8444 -8382 TCGL 9203 8611 -8549 BCGL 9267 8671 -8609 TZ1 B 9524 8875 -8813 3152 PSI @ 8800' TVD = 6.9 PPG EMW ,/ TDF 9625 8922 -8860 BSAD 8965 -8903 Not Penetrated TD 13,283 8836 TD Criteria: Reach planned TD unless drilling conditions deteriorate. Minimum of -800' perfable sand depending on rock quality. Polygon has been extended to allow for additional drilling if Zone 1 net to gross is lower than expected. 15-01 B Permit to Drill Page 1 . . Directional - Sperry wp02 KOP: 18930' MD Maximum Hole Angle: Close Approach Wells: -930 in the 6" horizontal section All wells except DS15-48A pass major risk criteria for this well plan. DS15- 48A passes minor risk criteria at 125' ctr-ctr with 82' allowable deviation. MWD Standard + IFR/Cassandra 33,600' to the nearest PBU property line 15-48A at 125' center to center at 11,528' planned depth. Survey Program: Nearest Property Line: Nearest Well within Pool: CasinglTubing Program Hole Size Csg/Tbg Wt/Ft Grade Conn Length Top Btm O.D. / MDrrVD MDrrVD 6" 4-1/2" 12.6# L-80 IBT -M / 3362' 8,780'/8200' 12,142/8842' Tubing 4-1/2" 12.6# 13Cr-80 V AM Top -8750' GL 8,780'/8200' Mud Program Section Millinr Mud Properties: Flo Pro Density (ppg) YP I PV 8.4 - 8.5 30-38 8-15 I Whip Stock Window 7", 29# I LSVR I pH I API FI >40,000 9.0-9.5 6-7 produr¡;tio Mud Properties: Flo Pro Densit pp) I YP I PV 8.4 8. / 24-30 8-15 1 LSVR >25,000 pH 9.0-9.5 API FI 5-7 Logging Program 6" Production: Drilling: Open Hole: Cased Hole: Sample Catchers - over entire interval, samples described Dir/GR/Res/ABI (+Neu/Den in horizontal and MAD pass build section) None None Cement Program I Casing Size 14.5" 12.6#, L-80 Production Liner Basis: Lead: None Tail: Bas~...o 0' shoe. t.rack, 3212' of 4-1/2" X 6" open hole with 40% excess, 150' 4-1/2" X 7" Liner Lap, d 0' of 7" X 4" DP excess. Tail TOC"J. MD (TfP of Liner) 9 & -t (.If w;:; I Total Cement Volu: Tail 185 bbls, 477 ft3, 41 acks Class G @ 15.8 pp , 1.1. t3/sack Well Control 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. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. 15-01 B Permit to Drill Page 2 . . Production Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casingn" Liner Test Integrity Test - 6" hole Planned completion fluids 3150 psi @ 8800' TVDss (6.9ppg EMW) 237P'P§Y(.10 psi/ft gas gradient to surface) / I~~ with a 10.0 pp~ FIT . ./ Rams test to 3,500 pSl/250 pSI. Annular test to 2,500 psi/250 psi 3500 psi surface pressure / 10.0 ppg FIT after drilling 20' of new hole 8.5 ppg Seawater I 7.2 ppg Diesel Disposal . No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Sidetrack and Complete Procedure SUmmary Current Condition: ,¡' MITlA Passed 3000 psi 11/04/03 ,¡' Pulled tubing patch at :t6000' (found tight spot at 2.7" drift at 8450' MD) 10/25/04 ,¡' Set L ITP at 8450' top of production packer; CMIT TxlA passed 2500 psi 10/25/04 ,¡' MITOA passed 2000 psi 11/25/04 Scope Pre-Riq Work: 1. Completely purge the chemical injection line with diesel. 2. RU Slickline and pull the L TTP from the tubing at 8450'. Drift the 2 3/8" production liner to 9000' for abandonment CIBP. 3. RIH wI cast-iron bridge plug on e-line. Set plug at 9000' MD. Perform CMIT TxlA to 3500 psi. 4. Punch circulation holes in the tubing tail just below the packer. Chemical cut the 2 3/8" liner 5-10' above the TOC reference 10/31/03 SCMT/USIT (TOC = ±8945') 5. RU coiled tubing and spear the 2 3/8" liner top with a GS pulling tool. Pick up to confirm the liner top is free at the chemical cut. Release from the deployment sleeve. Repeat steps 3 and 4 as necessary. 6. Chemical cut the tubing in the first full joint above the packer. 7. Displace the well to clean seawater by circulating down the tubing through the chemical cut. Freeze protect to -2,100' MD with diesel. 8. Bleed casing and annulus pressures to zero. 9. Cycle the tubing hanger LDS and test the 7" pack-off. 10. Set a BPV and test to 1000 psi from tubing annulus. Secure the well. Level the pad as necessary. Riq Operations: 1. MI I RU Nabors rig 2ES 2. Pull BPV, circulate out diesel freeze protection and displace the well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull TWC. 4. R/U. Pull 3 W' tubing from the pre-rig cut. 15-01 B Permit to Drill Page 3 . . 5. RIH with overshot and latch the tubing stub. Pullljar the PBR from the seal bore extension (packer set on drillpipe prior to running tubing string on 12/11/89). 6. RIH with 2 3/8" GS pulling tool and latch the liner top 8523'. Pull and lay down ±400' of 23/8" liner. 7. RIH with packer mill and PRT; mill and recover the Baker FB-1 packer. 8. RIH wi 6" mill and GR-MWD. Drift the casing to the top of the 2 3/8" liner and confirm the whipstock setting depth with place the middle of the window at or below 8931' (original 12 1fi¡" hole TO). Mill 2 3/8" liner if required as required. Pressure test the casing to 3500 psi. POH. ~. P/U and RIH with 7" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on cut liner stub. Shear off of whip stock. 10. Displace the well to 8.4 ppg Flo-Pro milling I drilling fluid. Completely displace the well prior to .,/ V ~O\ beginning milling operations. ~ '> lO'( 11. Mill window in 7" casing at ± 8935' MD, plus approximately 20' beyond middle of window. Circulate y(JJ ()\,o . well bore clean. Off' 12. Pull up into 9 5/8" casing and conduct an FIT to 10.0 ppg EMW. POOH. ~/ 13. M/U 6" Dir/GR/Res/ABI assembly. 14. RIH, drill build section through zone 3 to land base Zone 1A. 15. Trip for PDC bit and pick up Neu/Den. MAD pass open-hole section and drill horizontal section to planned TD, short trip andlor bit trip as necessary. 16. Circulate, short trip, spot liner running pill, POOH. / 17. Run and cement a 4 W', 12.6#, L-80 solid production liner. POOH UD all drill pipe. 18. RIH with 2 7/8" perf guns and perforate ±1000'. 19. R/U and run 4 1/2",12.6#, 13Cr-80 completion tubing. Land the tubing RILDS. ./ 20. Set a TWC and test to 1000 psi 21. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. 22. Reverse circulate inhibited seawater to the packer depth. Set packer and individually test the tubing / and annulus to 3,500psi 30 minutes. Record each test. 23. Shear the DCK valve and freeze protect the well to -2,100'. Secure the well. 24. Rig down and move off. Post-RiQ Work: 1. Install well house and instrumentation 2. MI I RU slick-line. Pull the ball and rod I RHC plug from landing nipple below the production packer. Install gas lift valves. 3. POP well to test unit until cleaned up. 15-01 B Drilling Program Job 1: MIRU Hazards and Contingencies Þ> Adjacent well 15-02 is on 120' center to the north and well 15-24 is on 60' center to the south. No well houses will require removal or shut-in for the rig move onto 15-01A. Þ> D515 is not designated as an HzS site. Recent H2S data from the pad is as follows: - #1 Closest SHL #2 Closest SHL #1 Closest BHL #2 Closest BHL Well Name 15-24 15-47 15-48A 07 -28AL 1 H2S Reading No data 4ppm 15 ppm 20 ppm Date 3/5/2001 12/8/2003 8/22/2004 /' Most wells have more than 10 - 20 ppm H2S recorded. The maximum on the pad is DS15- 21A at 50 ppm ).- Post Permit to Drill in the dog house and camp prior to spud 15-01 B Permit to Drill Page 4 . . Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP =''''_W»h",",,_~'''_'''' 4..... .==_="''''''',=.,."_~,,,_,-''',_,_w,,,''__,__A_' ',"" Job 2: De-complete Well Hazards and Contingencies ~ A caliper log dated 10/31/02 indicates fair to poor tubing with extensive line corrosion between GLMs 2 and 4. More sever corrosion in the pup joints at each gas lift mandrel may also be expected. ~ The chemical injection line will be purged during the pre-rig work. Anticipate that there will be traces of chemical in the line and ensure all personnel handling it wear the proper PPE. ~ NORM test all retrieved well head and completion equipment. The recovered tubing may be junked after the NORM inspection. ~ Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP ,,-.,-=-,""".=------', "' Job 4: Window Mill Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP Job 7: Drill 6" Production Hole Hazards and Contingencies ~ The well is not expected to cross any faults. Polygon hardlines reflect small «20' throw) faults to the east and west of the planned trajectory. ~ Watch for indications of magnetic interference after 11,000 MD for indications of nearby well 15- 48A. Stop drilling immediately and contact the Drilling Manager if a close approach issue is suspected. ~ Ensure the close approach analysis has been re-run after drilling DS15-14A to identify a potential intersection with the new wellbore. ~ In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a .5 ppg at the 7" casing shoe, and 8.5 ppg mud in the hole, the kick Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP 15-01 B Permit to Drill Page 5 . . Job 9: Install 4-112" Solid Production Liner Hazards and Contingencies ~ Differential sticking is a concern. The 8.5 ppg mud will be -750psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Reduce losses as much as feasible prior to cement job and pump excess cement as per loss rate. Evaluate alternative cement options based upon conditions. Hydraulic set packer may be required if losses exist prior to runninø liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. ~ Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" .:. Schlumberger Cement Program Job 10: DPC Perforate Production Casiinq Hazards and Contingencies ~ Observe Schlumberger's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs .:. Follow Schlumberger perforating practices and recommendations. .:. "OPC Perforating" RP ~< !~, »"M Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Job 13: ND/NUlRelease Riq HazardsandConUngencres ~ No wells will require well house removal or shut-in for the rig move off of 15-01 B. See MIRU section for nearest well. Reference RP .:. "Freeze Protecting an Inner Annulus" ={P 15-01 B Permit to Drill Page 6 TREE = .WELLHE.A,.D = ACTUATOR = KB, ELEV = BF. ELEV = KOP= Max Angle = Datum MD = ,...........-------.-..., ,~. " Datum NO = FMC GEN 2 FMC AXELSON 63' ? 3100' 97 @ 10672' . O~,W~H< ..___, 9470' 8800' SS . 113-3/8" CSG, 72#, L-80, 10 = 12347" H 2547' ~ Minimum ID = 1.97" @ 8523' 2-3/8" DEPLOYMENT SLV TOP OF 2-3/8" LNR H I TOP OF 7" LNR H 7" LNR, 29#, L-80, .0371 bpf,ID=6184" H 8523' 8566' 8573' 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" H 8615' 15-01A av NOTES: 70° @ 9599' AND 90° @ 9815' . 2102' H A V A TBG RETRIEVABLE, ID = 2.812" I CHEMICAL INJECTION MANDRELS ~ IST MD I ND DEV TYÆVLVILATCH PORT DATE c L 1 8381 7821 20 KBUG BK-2 GAS LIFT MANDRELS ST MD NO DEV TYÆ VLV LATCH PORT DATE L 1 2862 2862 5 MMG2 DMY RK 0 08/13/02 2 4685 4534 27 MMG2 DMY RK 0 08/13/02 3 5965 5662 30 MMG2 DMY RK 0 08/13/02 4 6931 6507 28 MMG2 DMY RK 0 08/13/02 5 7534 7045 26 MMG2 DMY RK 0 08/13/02 6 8292 7738 22 MMG2 DMY RKP 0 08/13/02 8 8' 8450' H 7" X 3-1/2" BAKER FB-1 PKR I 8523' H 2-718" DEPLOYMENTSLV,ID= 1.97" ~ 1 8598' 1-f3-1/2" OTIX XN NIP BEHIND CT LNR, 10 = 2.80" ~ 8614' 11 BAKER SOLID NOSE SHEA ROUT SUB I (BB-iIND CT LNR) 8615' H 3-1/2" TUBING TAIL (BB-iIND CT LNR) 1 .. I 8623' H ELMO TT LOGGED 04/11/90 (BB-iIND CT LNR) I H 9-5/8" CSG, 47#, L-80, ID = 8.681" H 8914' I----" ÆRFORA TION SUMMA RY REF LOG: SWS MEMORY CNL ON 11/23/98 ANGLEATTOPÆRF: 52 @ 9550' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 1-11/16" 4 9550 - 9570 0 05/02/01 1-11/16" 4 9595-9615 0 05/02/01 1-11/16" 4 9725 - 10144 0 11/24/98 1-11/16" 4 10214 - 10396 0 11/24/98 1-11/16" 4 10460-10476 0 11/24/98 1-11/16" 4 10802 -10906 0 11/24/98 1-11/16" 4 10994 - 11185 C 11/24/98 1-11/16" 4 11228 -11341 C 11/24/98 7" LNR, 29#, L-80, .0371 bpf, ID = 6,184" H 9655' DATE 1982 12/12/89 11/29/98 10/20/04 11/15/04 REV BY COMMENTS ORIGINAL COM PLETION COM PLETION CT SIDETRACK DA V ITLP DEPLOY SL V S2 CORRECTION CJITLH PATCH PULLED 10/24/04 DATE CTD SLIM HOLE HORIZONTAL SIDETRACK WINDOW AT 9357' I 1 1 11133' /1 2-3/8" CIBP SET 11/10/991 FAILED 11/15/99 ~ I PBTO H 11339' I 2-3/8" LNR, 4.7#, L-80, .00387 bpf, ID = 1.995" H 11373' ITO 1 H 11392' REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 15-01A ÆRMIT No: 1982220 API No: 50-029-20696-01 SEC 22, T11N, R15E, 2387.08' FEL & 3522.85' FNL BP Exploration (Alaska) 4It5-01 B Proposed ~NDTES TREE = , WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Woo, ,'w".<.",____... ,.....~.." , Datum MD = DatumTVD= FMC GEN 2 FMC AXELSON 63' ? 3100' 8800'55 . 2100' H 41/2" X Landing Nipple (3.813" ID) 113-3/8" CSG, 72#, L-80, ID = 12.347" H 2547' ~ Minimum ID = 3.725 @ XN I TOP OF 7" LNR H 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" H 8566' 8573' 9-5/8" CSG, 47#, L-80. ID = 8.681" H 8914' WHIPSTOCK TOP fish CIBP H -8930' H -8940' H -91 DO' ÆRFORA TION SUMMARY REF LOG: ANGLEATTOPÆRF: ' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" H 9655' DATE 1982 12/12/89 11/29/98 10/20/04 11/15/04 12/05/04 REV BY COMMENTS ORIGINAL COMPLETION COM PLETION CT SIDETRACK DA V ITLP DEPLOY SL V SZ CORRECTION CJITLH PATCH PULLED 10/24/04 PGS Proposed Rotary Sidetrack ~ GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 4 3 2 1 L g 8410' 8425' 8440' H 4-1/2" X NIP, ID = 3.813" I-J 7" x 4-1/2" Baker 53 Packer H 4-1/2" X NIP, ID = 3.813" g H ~ ~ ~g I 8!1ß) H 4-1/2" XN NIP, ID = 3.725" I ¡f.7pf H 4-1/2" LlNERTOPITBR I ~84' H 4-1/2" WLEG I 8930' I-J 7" Top of Window :----~ 1 ~ H 12,142' I I 4 1/2" 12.6# L-80 Liner Shoe 2-3/8" LNR, 4.7# (abandoned) H 11373' DATE PRUDHOE BA Y UNIT WELL: 15-01B ÆRMIT No: 1982220 API No: 50-029-20696-02 SEC 22, T11 N, R15E, 2387.08' FEL & 3522.85' FNL REV BY COMMENTS BP Exploration <Alaska) Ê § 8400 ~ fi ¡r :::> -¡¡ 1~ " > g f-o 8700 COMPANY VET AILS SURVEY PRÜGRAM pJan: !5~01B wp02 (l5-OliPhw !:5-0IB) CrC'dted By Digital Business Client User Dale: 12/?i2004 REFERENCE: INFQRJ.1ATJON BP Amü£o Date Depth Fm Depth T,' Survey/Plan 89JeH)O 12!4n¡ Planned: !S...()1B wpÜ2 \i12 Too] MWD·'·IFR~·MS Cheçked Date Reviewed ~--~.- CASING DETAILS WELL DETAILS N¡¡n¡e Nrnihíng [:"~stíng UJ1Ítude Longitude Slo{ 1S..(I1 IOH20 .21.55 5959929.68 676249.80 70~!7'45.988N J48~34'2¡,842W N!A SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TLace VSec Target I 217.19 8344_99 -2058,63 -1432.41 0_00 0_00 -2424,39 2 207_98 836432 -2062.95 -1435_17 12,00 -85_00 -2429.40 3 n50 8608.52 -2082-72 -1406,59 13_00 -150,00 -2438-19 4 77 .50 8671.20 -2077.60 -1383-48 0,00 0_00 -2425.48 5 16,99 8943,30 -1772-56 -1195.33 -16,50 -61.86 -2074.49 6 16,99 8935_99 -128634 -1046_79 0.00 0_00 -1566_79 7 16_70 8935_90 -1280.95 -1045.16 6,00 -58,52 -156U7 15-018 Tl 8 350.91 8920.17 -854.92 -1016.75 6.00 -84.92 -115Ul 9 350.91 8841.90 565_68 -1243.96 0,00 0,00 106.11 15-OlB T2 No, TVD Size MD Name 8841.92 12142_00 41/2" 4.500 TARGET DETAILS Name TVD +N/-S +FJ-W Northing Easting Shape 15·OlB T2 8841.90 565,68 5960466,00 674993,00 Point 15-018 TI 8935,90 -1280,95 5958624,65 675235,03 Point 780Q- TAILS 8100 , FORMATION TOP DE \ \ ~~fftf~ i No, TVDPath MOPath I 1 8368.90 [; 2 8443,90 3 8610.90 ¡~ 4 8670,90 5 8874,90 ,.5 I 6 892 1. 90 1.4 i i - -- D -. -- t' ~If I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I -- I i I i I I I I I Ii i i i : I I I-·~ -- i ~- ;~~ f---~ . --- n _ i2€ 1---' -- - .- 1---- " -- .- -- -- - <-- --- ~- ::: / I I I I I \ : /1 \, : \, i Ii" i ! I i i I .- 1 I I -- It I - «< 1- : t-- -- - t-- f--- '-,- -~ <- - .. -- I I I ! - \ ! i I ! ! I ¡ I 11 11 ¡ !I \ , , ! j I···¡ ¡ , \ \ \ \ \ ! II·!.! , , , , \ , ¡ \ ; , \ , , , , , , , , , , , \ , , , I -1500 -900 -600 ..300 0 Formation Shub1ik TSAO TCGL BCGL TZIB TOL 9000 V ertic~lSeçtîon at [300ft/in] I Plan: 15..[1lB wpÜ2 (15 Created By: DjgÜa! Business C!iml Us Checked \\'ELL DETA!U SURVEY PROGRAM Too! 8930.00 j5..íJIB "þ(JZ v¡ MWD""fFR.o-MS REFERENCE JNFORJ\'lATtoN I Name Núrtbmg LongittKì, 15-ú! 1093.20 -21 14S"34'21.842W TARGET DETAILS Easting Shape +E/-W Northmg 00 TVD SECTION DETAILS +N/-S Name 15-01B 1'2 3 2 Target CASING DETAILS MD Name Size 2142,00 41/2" 4.500 , ! ik FORMATION TOP DETAILS TVDPath VSec MDPath TFace -6 I -5: -8, DLeg ( I- I, ( Ii ° No. I 2 3 4 5 6 No. TVD 8841.92 , +N/-S +E/-W 1.63 -14 -14 -14 -I TVD ¡ Azi o 9 9 ° ¡ I Iue 3: 3: , MD Ii Ii II I: See I 2 3 4 5 6 7 8 9 jj J 500 .., ..... - f·· ° ! f-- - - ¡ þ £i -500 ! ¡ '" '" ::::., +' ~ 0 ~ ~ 0 <IJ -1000 ~.+ ..-----1 - -1500 VI b': - I ..... -2000 , . . Sperry-Sun BP Planning Report Plan: 15-01B wp02 Date Composed: Version: Tied-to: 10/27/2004 12 From: Definitive Path Principal: No Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft 676296.98 ft Latitude: 70 17 Longitude: 148 34 North Reference: Grid Convergence: 35.236 N 21.213 W True 1.34 deg Well: 15-01 Slot Name: 15-01 Well Position: +N/-S 1093.20 ft Northing: 5959929.68 ft Latitude: +E/-W -21.55 ft Easting: 676249.80 ft Longitude: Position Uncertainty: 0.00 ft 70 17 45.988 N 148 34 21.842 W Casing Points 12142.00 8841.92 4.500 6.000 41/2" Formations 0.00 CM2 0.00 0.00 0.00 CM1 0.00 0.00 0.00 THRZ 0.00 0.00 0.00 LeU 0.00 0.00 0.00 TJD 0.00 0.00 0.00 TJC 0.00 0.00 0.00 TJB 0.00 0.00 0.00 TJA 0.00 0.00 0.00 Sag River 0.00 0.00 8954.74 8368.90 Shublik 0.00 0.00 9031.15 8443.90 TSAD 0.00 0.00 9202.54 8610.90 TCGL 0.00 0.00 9266.68 8670.90 BCGL 0.00 0.00 9523.57 8874.90 TZ1B 0.00 0.00 9625.42 8921.90 TDF 0.00 0.00 0.00 BSAD 0.00 0.00 0.00 Formation 18 0.00 0.00 0.00 Formation 19 0.00 0.00 0.00 Formation 20 0.00 0.00 0.00 Formation 21 0.00 0.00 Targets 15-01B T2 8841.90 565.68 -1243.96 5960466.00 674993.00 70 17 51.550 N 148 34 58.103 W 15-01 B Fault 3 8918.90 -583.96 -1275.93 5959316.00 674988.00 70 17 40.244 N 148 34 59.029 W -Polygon 1 8918.90 -583.96 -1275.93 5959316.00 674988.00 70 17 40.244 N 148 34 59.029 W -Polygon 2 8918.90 -123.28 -1298.13 5959776.00 674955.00 70 17 44.774 N 148 34 59.678 W 15-01BT1 8935.90 -1280.95 -1045.16 5958624.65 675235.03 70 17 33.389 N 148 34 52.300 W . Sperry-Sun BP Planning Report . Targets 15-018 Poly 8935.90 78.36 -1237.38 5959979.00 675011.00 70 17 46.758 N 148 34 57.909 W -Polygon 1 8935.90 78.36 -1237.38 5959979.00 675011.00 70 17 46.758 N 148 34 57.909 W -Polygon 2 8935.90 -700.97 -1106.61 5959203.00 675160.00 70 17 39.093 N 148 34 54.094 W -Polygon 3 8935.90 -1069.67 -1082.25 5958835.00 675193.00 70 17 35.467 N 148 34 53.382 W -Polygon 4 8935.90 -1362.90 -1119.14 5958541.00 675163.00 70 17 32.583 N 148 34 54.456 W -Polygon 5 8935.90 -1590.75 -1171.50 5958312.00 675116.00 70 17 30.342 N 148 34 55.981 W -Polygon 6 8935.90 -1625.72 -960.25 5958282.00 675328.00 70 17 29.999 N 148 34 49.824 W -Polygon 7 8935.90 -1347.97 -902.72 5958561.00 675379.00 70 17 32.730 N 148 34 48.149 W -Polygon 8 8935.90 -1083.57 -873.51 5958826.00 675402.00 70 17 35.331 N 148 34 47.298 W -Polygon 9 8935.90 -869.49 -873.49 5959040.00 675397.00 70 17 37.436 N 148 34 47.298 W -Polygon 10 8935.90 -668.55 -910.79 5959240.00 675355.00 70 17 39.412 N 148 34 48.386 W -Polygon 11 8935.90 73.44 -1027.43 5959979.00 675221.00 70 17 46.710 N 148 34 51.789 W -Polygon 12 8935.90 93827 -1221.21 5960839.00 675007.00 70 17 55.215 N 148 34 57.441 W -Polygon 13 8935.90 920.09 -1426.71 5960816.00 674802.00 70 17 55.036 N 148 35 3.432 W -Polygon 14 8935.90 78.36 -1237.38 5959979.00 675011.00 70 17 46.758 N 148 34 57.909 W 15-01B Fault 2 8936.90 -1326.27 -719.14 5958587.00 675562.00 70 17 32.944 N 148 34 42.799 W -Polygon 1 8936.90 -1326.27 -719.14 5958587.00 675562.00 70 17 32.944 N 148 34 42.799 W -Polygon 2 8936.90 -843.53 -828.86 5959067.00 675441.00 70 17 37.691 N 148 34 45.998 W 15-018 Fault 1 8976.90 -2105.53 -1486.68 5957790.00 674813.00 70 17 25.279 N 148 35 5.162 W -Polygon 1 8976.90 -2105.53 -1486.68 5957790.00 674813.00 70 17 25.279 N 148 35 5.162 W -Polygon 2 8976.90 -1777.93 -1336.94 5958121.00 674955.00 70 17 28.501 N 148 35 0.801 W Plan Section Information 8930.00 14.72 217.19 8344.99 -2058.63 -1432.41 0.00 0.00 0.00 0.00 8950.00 15.12 207.98 8364.32 -2062.95 -1435.17 12.00 1.98 -46.03 -85.00 9200.00 20.68 77.50 8608.52 -2082.72 -1406.59 13.00 2.23 -52.19 -150.00 9267.00 20.68 77.50 8671.20 -2077.60 -1383.48 0.00 0.00 0.00 0.00 9756.52 90.82 16.99 8943.30 -1772.56 -1195.33 16.50 14.33 -12.36 -61.86 10264.98 90.82 16.99 8935.99 -1286.34 -1046.79 0.00 0.00 0.00 0.00 10270.61 91.00 16.70 8935.90 -1280.95 -1045.16 6.00 3.13 -5.12 -58.52 15-018 T1 10701.53 93.11 350.91 8920.17 -854.92 -1016.75 6.00 0.49 -5.98 -84.92 12142.31 93.11 350.91 8841.90 565.68 -1243.96 0.00 0.00 0.00 0.00 15-018 T2 Survey 8930.00 14.72 217.19 8344.99 8283.09 -2058.63 -1432.41 0.00 5957838.16 674866.15 Start Dir 12/10 8950.00 15.12 207.98 8364.32 8302.42 -2062.95 -1435.17 12.00 5957833.77 674863.50 Start Dir 13/10 8954.74 14.58 206.76 8368.90 8307.00 -2064.03 -1435.72 13.00 5957832.68 674862.96 Shublik 9000.00 10.02 188.99 8413.12 8351.22 -2073.02 -1438.91 13.00 5957823.63 674859.99 MWD+IFR+MS 9031.15 7.93 166.43 8443.90 8382.00 -2077.78 -1438.83 13.00 5957818.86 674860.18 TSAD 9100.00 9.80 106.71 8512.06 8450.16 -2084.10 -1432.09 13.00 5957812.71 674867.07 MWD+IFR+MS 9200.00 20.68 77.50 8608.52 8546.62 -2082.72 -1406.59 13.00 5957814.69 674892.53 End Dir : 9200 9202,54 20.68 77.50 8610.90 8549.00 -2082.52 -1405.71 0.00 5957814.90 674893.40 TCGL 9266.68 20.68 77.50 8670.90 8609.00 -2077.62 -1383.59 0.00 5957820.32 674915.39 8CGL 9267.00 20.68 77.50 8671.20 8609.30 -2077.60 -1383.48 0.00 5957820.35 674915.50 Start Dir 16.5/ 9300.00 23.72 65.50 8701.77 8639.87 -2073.58 -1371.74 16.50 5957824.64 674927.15 MWD+IFR+MS 9400.00 36.34 43.72 8788.42 8726.52 -2043.62 -1332.70 16.50 5957855.51 674965.48 MWD+IFR+MS 9500.00 51.01 32.64 8860.65 8798.75 -1989.10 -1290.97 16.50 5957910.99 675005.91 MWD+IFR+MS 9523.57 54.59 30.73 8874.90 8813.00 -1973.12 -1281.12 16.50 5957927.19 675015.39 TZ18 9600.00 66.36 25.51 8912.52 8850.62 -1914.52 -1250.00 16.50 5957986.50 675045.12 MWD+IFR+MS 9616.79 68.97 24.50 8918.90 8857.00 -1900.44 -1243.43 16.50 5958000.73 675051.35 15-018 Fault 3 . . Sperry-Sun BP Planning Report Survey 9625.42 70.31 23.99 8921.90 8860.00 -1893.07 -1240.11 16.50 5958008.17 675054.50 TDF 9700.00 81.96 19.91 8939.75 8877.85 -1826.01 -1213.16 16.50 5958075.84 675079.87 MWD+IFR+MS 9756.52 90.82 16.99 8943.30 8881.40 -1772.56 -1195.33 16.50 5958129.69 675096.44 End Dir : 9756 9800.00 90.82 16.99 8942.67 8880.77 -1730.98 -1182.63 0.00 5958171.55 675108.16 MWD+IFR+MS 9900.00 90.82 16.99 8941.24 8879.34 -1635.36 -1153.42 0.00 5958267.83 675135.12 MWD+IFR+MS 10000.00 90.82 16.99 8939.80 8877.90 -1539.73 -1124.20 0.00 5958364.11 675162.08 MWD+IFR+MS 10100.00 90.82 16.99 8938.36 8876.46 -1444.10 -1094.99 0.00 5958460.39 675189.05 MWD+IFR+MS 10200.00 90.82 16.99 8936.92 8875.02 -1348.48 -1065.77 0.00 5958556.67 675216.01 MWD+IFR+MS 10264.98 90.82 16.99 8935.99 8874.09 -1286.34 -1046.79 0.00 5958619.23 675233.53 Start Dir 6/100 10270.61 91.00 16.70 8935.90 8874.00 -1280.95 -1045.16 6.00 5958624.65 675235.03 15-018T1 10300.00 91.16 14.94 8935.35 8873.45 -1252.68 -1037.15 6.00 5958653.10 675242.38 MWD+IFR+MS 10400.00 91.68 8.96 8932.87 8870.97 -1154.92 -1016.45 6.00 5958751.31 675260.78 MWD+IFR+MS 10500.00 92.18 2.98 8929.51 8867.61 -1055.57 -1006.06 6.00 5958850.88 675268.84 MWD+IFR+MS 10600.00 92.66 357.00 8925.28 8863.38 -955,70 -1006.07 6.00 5958950.71 675266.48 MWD+IFR+MS 10700.00 93.11 351.00 8920.25 8858.35 -856.42 -1016.51 6.00 5959049.71 675253.72 MWD+IFR+MS 10701.53 93.11 350.91 8920.17 8858.27 -854.92 -1016.75 6.00 5959051.21 675253.44 End Dir : 1070 10800.00 93.11 350.91 8914.82 8852.92 -757.82 -1032.28 0.00 5959147.91 675235.64 MWD+IFR+MS 10900.00 93.11 350.91 8909.39 8847.49 -659.23 -1048.05 0.00 5959246.10 675217.57 MWD+IFR+MS 11000.00 93.11 350.91 8903.95 8842.05 -560.63 -1063.82 0.00 5959344.30 675199.49 MWD+IFR+MS 11100.00 93.11 350.91 8898.52 8836.62 -462.03 -1079.59 0.00 5959442.49 675181.41 MWD+IFR+MS 11200.00 93.11 350.91 8893.09 8831.19 -363.43 -1095.36 0.00 5959540.69 675163.34 MWD+IFR+MS 11300.00 93.11 350.91 8887.66 8825.76 -264.83 -1111.13 0.00 5959638.89 675145.26 MWD+IFR+MS 11400.00 93.11 350.91 8882.22 8820.32 -166.23 -1126.90 0.00 5959737.08 675127.18 MWD+IFR+MS 11500.00 93.11 350.91 8876.79 8814.89 -67.63 -1142.67 0.00 5959835.28 675109.11 MWD+IFR+MS 11600.00 93.11 350.91 8871.36 8809.46 30.97 -1158.44 0.00 5959933.47 675091.03 MWD+IFR+MS 11700.00 93.11 350.91 8865.93 8804.03 129.57 -1174.21 0.00 5960031.67 675072.95 MWD+IFR+MS 11800.00 93.11 350.91 8860.50 8798.60 228.17 -1189.98 0.00 5960129.87 675054.88 MWD+IFR+MS 11900.00 93,11 350.91 8855.06 8793.16 326.77 -1205.75 0.00 5960228.06 675036.80 MWD+IFR+MS 12000.00 93.11 350.91 8849.63 8787.73 425.37 -1221.52 0.00 5960326.26 675018.72 MWD+IFR+MS 12100.00 93.11 350.91 8844.20 8782,30 523.97 -1237.29 0.00 5960424.45 675000.65 MWD+IFR+MS 12142.00 93.11 350.91 8841.92 8780.02 565.38 -1243.91 0.00 5960465.70 674993.06 41/2" 12142.31 / 93.11 350.91 8841.90 8780.00 565.68 -1243.96 0.00 5960466.00 674993.00 15-018 T2 TERRIEL HUBBLE BP EXPLORAtIONAKINC"Mastercard Check" PO BOX196612 MB7-5 ANCHORAGE,AK 99519-66.12 89-6/1252 169 DAIEl Ç)...,2..9-ot¡ ~~~lNt" .~.i.i<...~...~...... ·.(t/.·....·. ....... Ao......>.ffi.... .<3,. $/()ù.·<Jb.·...... O¡\Q ,fuÆ'(#{@~lt11ÐB . . DOLLARS- First National Bank Alaska .. .. ::::'T5btß ~.pŠ¿.(/¡~ .~ -: ~ 25 2000bO-: qq ~1.."lb2 2 ?"I~ 55 bU· 0 ~ b q . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME fJ6~ /5-n/-8 PTD# 2-ot¡- ¿.~ 7 Y Development Service CHECK WHAT APPLJES ADD-ONS (OPTIONS) M1JLTI LATERAL (If API num ber last two. (2) digits ne between 60-69) PILOT (PH) Exploration Stratigraphic ~'CLUEn Tbe permit is for a new wellboresegment of existing wen·. . Permit No, . API No. Production. should continue to be reponed as a function 'of the original API number. stated above. . HOLE In accordance witb 20 AAC 25.005(1), aU records, data and logs aCCJuired for tbe pilot bole must be clearly differentiated In both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTJON DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance witb 20 AAC 25.,055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spa dng e:J ception. (Company Name) assumes tbe liability of any protest to tbe spacing .exception tbat may occur. All dry ditcb sample sets submitted to tbe Commission must be in no greater 1han 30' sample intervals from below tbe permafrost or from wbere samples are fiTSt caught and ] 0' sample h:iter:vals through target zones. . . D D Well bore seg Annular Disposal Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 15-018 Program DEV PTD#: 2042570 Company BP EXPLORATION (ALASKA) INC_ nitial Classrrype DEV /1-0IL _ GeoArea 890 Unit 11650 On/Off Shore On Administration 11 P_e(mit fee attache_d _ - - - - - - - - - - Yes - - - - - I~ Leas~number _appropriate_ - - - - - - - - - Yes - - - - - _U_nique wel[n_am_e_and lJumQe( _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y_es - - - - - - - - - - - - - - - - - - ~ - 4 WelllQcated in a define_dppol_ _ - - - - - - - - - - - - _Y_es - - - - - 5 Well JQcate<! prpperdistance_ from drilling uoit bouodal'Y_ Yes - - - - - 6 WelUQcated proper _distance f(om Qther welJs_ - - - - - - - - - - - - Yes - - - - - '7 S_utf;c;entacreageaYaìtable jn_dJillilJg unjL _ _ _ _ _ _ _ Yes - - - - - - 8 Ifd_eviated, js_ wellbQre platincJu_ded _ Y~s - - - - - - - - - 9 Qperator ooly affected party_ - - - - _Y_es - - - - - - 10 _Qper_ator has_apprJ:>priate_ Qond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes ~ - - - - - - - - - - - - - - - - - - - - - 11 P_e(mit can be issued withQut coMervation order _ _ Y_es - - - - Appr Date 12 P_e(mit can be issued withQut admioist(atille appr_oval _ _ _ _ Yes - - - - - - - - - - - RPC 12/30/2004 13 Can permit be approved before 15-day wait Yes 14 WeJUQcated withio area aod_strataauthorized by_lnjectiplJ Ord_er # (put 10# jn_comments)_ (For_ NA - - - - - - - - - - - 15 _All welJs_withinJl4JIJi[e_area_of (eyiew id_elJtjfied (Fp( servj~well çmlYL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA - - - - - - - - - - -- - - - - - - - - - ,16 Pre-produced injector; _duratiQn_of pre-productiol3 less than 3 mootbs_ (FoLservice well only) _ J~A 17 ACMP_ findjngof Consistency has been issued for this project _ - - - - - NA Engineering 18 _Conductor string_PJQvided _ _ _ _ - - - - - - - - - - - - - - - NA 19 _Sulia~_casiog_pJotects all_known_ USDWs _ _ - - - - NA 20 _CMT v_ol adequate to circ_u[ate on _conductor 8. SUJf <;$g _ NA '21 _CMT v_of adeQuate_ to tie-inJQngstring tOSJ.1I1 çsg _ NA - - - - 22 _CMTwill coyeraJl kl3ow_npr<~duGtiYe hQrizon_s_ _ _ _ _ _ _ _ _ Yes 23 _C_asing designs adequa_te for C,_ T, B&_ permafr_ost - - - - - - - - - - Y_es 24 Adequaletankage_or re_serve pit _ _ _ - - - - - - - - - - _Yes _ Nabws2ES, _ _ 25 Ifa re-d(ilt, has a_ to,.403 for abandonment be~11 apPJoved . . . . - _Y~s 12f30!2004. - - - - - 26 AdequateJlIlellbore ~eparatio_n_propose_d_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _____yes - - - - - ~ - - - - - - - - - - - - - - - - 27 Jtdjv~rter JectuiJed~ dQes itJTleet reguJatiol3s - - - - - - - - - - - _ _NA · _ Sidet(ack. . Appr Date 28 DJillil1g fluid_program sGhematjc_& ectuiplistadequale_ _ - - - - - ... - Y~s · _ Max MW8.5 ppg. WGA 1/3/2005 29 _B_QP_Es, do they meet reguJation _ . . - - - - - - - - - - - - - - - Yes ,30 _BØPEpress ratil1g ¡¡pproprîate;test to_(put psig in_commel1ts)_ _ . . _ _ _ . ... _ Yes · _ Test to 350Q psi.MS~ 2370 psi. 31 _Chokemanjfold complies w/API R~-53 (May 84)_ - - - - - - - - - Y_es 32 WQrk will OGCU( withoutoperatjonshutdQwn_ Yes 33 Js presence Qf H2S gas_ prQb.able _ _ . _ - - - - - - _No_ . Notan H2S pad. 34 _Mechanicalcondjtion _of wells within AOR yerified (For_ s_e(Vice w~1J ooly) _ . NA - Geology 35 P_e(mit can be issueçJ w/Q hyçJrogen sulfide meas_uœs _ _ . _ _ No 36 D_ata_pJes~nted on pote_ntial pveJpressure_zones_ - - - - - NA Appr Date 37 S_eismicanalysjs of shallow gaszol1es_ NA - - - - - - - - - - RPC 12/30/2004 38 SeabedcondjtiplJ surve_y -Of off-sh9(e} . _ NA - - - - - - - - - - - - - 39 _ Contact oamelphQoefor_weelsly prpgressreports [e¡cploratpl'Yonlyl _ NA Geologic Engineering Public Date Commissioner: Date: Commissioner: Date ~"e' NS 1/ ~ )u fS¡~ . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ¥ . . Sperry-Sun Drilling Services LIS Scan Utility RECEIVED $Revision: 3 $ LisLib $Revision: 4 $ Fri Nov 17 11:13:06 2006 JAN 2 9 Z007 I\Iaska on & Gas eons· eomm\SSiOR An<:h<Jr8ge Reel Header Service name.......... ...LISTPE Date....... ............. .06/11/17 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name........ .....LISTPE Date.................... .06/11/17 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.... . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Previous Tape Name..... ..UNKNOWN Comments.... ............ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PBU MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 15-01B 50029206960200 BP Exploration (Alaska), Inc. Sperry Drilling Services 17-NOV-06 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 W-0003514716 . RICHARDSON J. RALL MWDRUN 4 W-0003514716 . RICHARDSON J. RALL MWD RUN 5 W-0003514716 . RICHARDSON J. RALL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 6 W-0003514716 N. WHITE M. MONNIN MWD RUN 7 W- 0003514 716 N. WHITE M. MONNIN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 22 llN 14E 1558 309 MSL 0) 62.60 33.40 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 7.000 8924.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. ao~ -QS"? ¡t: 1'-I3~D File Header . . THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE EXITS 15-01 BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 8924'MD/8326'TVD. 4. MWD RUN 1 WAS A MILLING RUN. MWD RUN 2 WAS A FAILED ATTEMPT TO POSITION THE WHIPSTOCK - COULD NOT GET TO BOTTOM. NO DATA ARE PRESENTED. 5. MWD RUN 3 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. ONLY SROP DATA ARE PRESENTED. 6. MWD RUNS 4-7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4),AND AT-BIT INCLINATION (ABI). RUN 5 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO-DENSITY (SLD). 7. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER OPEN -HOLE GAMMA RAY LOG RUN ON 6 FEBRUARY 1982 IN THE 15-01 WELLBORE. THESE DIGITAL DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) VIA E-MAIL ON 14 NOVEMBER 2006. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 8. MWD RUNS 1-7 REPRESENT WELL 15-01B WITH API#: 50-029-20696-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12470'MD/8834'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP : SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP : SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP : SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE : SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS : SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA : SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 : SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 : SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 : SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE: NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE : NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.0" BIT MUD WEIGHT: 8.5 PPG MUD SALINITY: 2800-4500 PPM CHLORIDES FORMATION WATER SALINITY: 10,994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ . . Service name.. ..... ......STSLIB.OOl Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .06/11/17 Maximum Physical Record. .65535 File Type..... . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPX RPM RPS ROP FET NCNT NPHI FCNT RHOB DRHO PEF $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 8892.5 8917.0 891 7.0 8917.0 891 7.0 8934.5 8958.5 9250.5 9251.0 9251.0 9264.0 9264.0 9264.0 STOP DEPTH 12426.0 12433.0 12433.0 12433.0 12433.0 12477.5 12433.0 10830.5 10830.5 10831.0 10844.0 10844.0 10844.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 8892.5 8885.0 8908.0 8900.5 891 7.0 8910.0 8922.0 8915.0 8932.5 8925.0 8942.0 8935.5 8950.5 8944.0 8958.0 8950.0 8960.0 8952.0 12477.5 12469.5 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 8927.5 8950.0 MWD 4 8885.0 9843.0 MWD 5 9242.5 10910.0 MWD 6 10849.5 11104.0 MWD 7 11053.0 12469.5 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type. ....0 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point....... ...... .Undefined Frame Spacing..................... 60 .1IN Max frames per record.... ..... ... .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT FCNT MWD NCNT MWD Units FT CNTS CNTS Size 4 4 4 Nsam 1 1 1 Rep 68 68 68 Code offset o 4 8 Channel 1 2 3 . . RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8892.5 12477.5 10685 7171 8892.5 12477.5 FCNT MWD CNTS 293.4 1483.4 655.982 3161 9251 10831 NCNT MWD CNTS 17924.7 411 75.5 29129.9 3161 9250.5 10830.5 RHOB MWD G/CM 2.113 4.962 2.85652 3161 9264 10844 DRHO MWD G/CM -0.083 2.413 0.261434 3161 9264 10844 RPD MWD OHMM 1. 68 2000 150.756 7033 8917 12433 RPM MWD OHMM 1. 06 2000 103.548 7033 8917 12433 RPS MWD OHMM 1. 39 1885.67 81.7359 7033 8917 12433 RPX MWD OHMM 1. 08 1443.04 68.9377 7033 8917 12433 FET MWD HOUR 0.32 44.67 2.83944 6950 8958.5 12433 GR MWD API 14.94 579.4 63.5072 7068 8892.5 12426 PEF MWD BARN 1. 31 5.73 2.28738 3161 9264 10844 ROP MWD FT/H 0.19 788.19 81.0549 7087 8934.5 12477.5 NPHI MWD PU-S 12.35 45.71 23.6482 3160 9251 10830.5 First Reading For Entire File..........8892.5 Last Reading For Entire File.......... .12477.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation... ....06/11/17 Maximum Physical Record. .65535 File Type. .... . . . . " . . . . .LO Next File Name... ....... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .06/11/17 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name. ......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 2 header data for each bit run in separate files. 3 .5000 START DEPTH 8927.5 STOP DEPTH 8950.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 05-FEB-05 Insite 66.37 . DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.... ........ .... .Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing..................... 60 .1IN Max frames per record. . . . ........ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD030 Memory 8950.0 8924.0 8950.0 .0 .0 TOOL NUMBER 149843 6.000 8924.0 Flo Pro 8.40 46.0 8.8 4000 .0 .000 .000 .000 .000 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD030 FT/H Min 8927.5 1.12 Max 8950 40.33 First Reading For Entire File... .., ....8927.5 Last Reading For Entire File.......... .8950 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/11/17 Maximum Physical Record. .65535 Mean 8938.75 7.90065 Nsam 46 46 . .0 118.0 .0 .0 First Reading 8927.5 8927.5 Last Reading 8950 8950 . File Type.. . . . . . . . . . . . .. .LO Next File Name......... ..STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation... ....06/11/17 Maximum Physical Record. .65535 File Type. .... .. . . . . . . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPX RPS RPM ROP FET $ 3 . header data for each bit run in separate files. 4 .5000 START DEPTH 8885.0 8910.0 8910.0 8910.0 8910.0 8950.5 8950.5 STOP DEPTH 9780.0 9787.0 9787.0 9787.0 9787.0 9843.0 9787.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 07-FEB-05 Insite 66.37 Memory 9843.0 8950.0 9843.0 9.4 89.7 TOOL NUMBER 64004 59475 6.000 8924.0 Flo Pro SF 8.40 50.0 9.7 4500 9.5 .950 .540 2.700 .750 80.0 147.0 80.0 80.0 . . # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction... ............. .Down Optical log depth units....... ... .Feet Data Reference Point..... ....... ..Undefined Frame Spacing..................... 60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8885 9843 9364 1917 8885 9843 RPD MWD040 OHMM 1. 68 2000 123.357 1755 8910 9787 RPM MWD040 OHMM 1. 06 2000 91.6167 1755 8910 9787 RPS MWD040 OHMM 1. 39 1443.32 60.9203 1755 8910 9787 RPX MWD040 OHMM 1. 08 1443.04 42.2337 1755 8910 9787 FET MWD040 HOUR 1. 29 4.16 2.16643 1674 8950.5 9787 GR MWD040 API 14.94 559.62 49.74 1791 8885 9780 ROP MWD040 FT/H 1.19 11 7.91 38.8175 1786 8950.5 9843 First Reading For Entire File......... .8885 Last Reading For Entire File.......... .9843 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation. ......06/11/17 Maximum Physical Record..65535 File Type. .... . . . . . . . . . . .LO Next File Name... ....... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .06/11/17 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . . LO Previous File Name..... ..STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: 4 header data for each bit run in separate files. 5 .5000 # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI RHOB DRHO PEF GR RPS FET RPX RPM RPD ROP $ . START DEPTH 9242.5 9243.0 9243.0 9256.0 9256.0 9256.0 9780.5 9787.5 9787.5 9787.5 9787.5 9787.5 9843.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ # STOP DEPTH 10822.5 10823.0 10822.5 10836.0 10836.0 10836.0 10849.0 10856.0 10856.0 10856.0 10856.0 10856.0 10910.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............ ......0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units..... ..... .Feet Data Reference Point............. . Undefined Frame Spacing........... ....... ...60 .1IN Max frames per record............ . Undefined . 10-FEB-05 Insite 66.37 Memory 10910.0 9843.0 10910.0 88.2 93.5 TOOL NUMBER 64004 162905 116332 59475 6.000 8924.0 Flo Pro SF 8.40 45.0 9.3 2750 5.0 .950 .520 2.700 .750 80.0 152.0 80.0 80.0 . . Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD050 CNTS 4 1 68 4 2 NCNT MWD050 CNTS 4 1 68 8 3 RHOB MWD050 G/CM 4 1 68 12 4 DRHO MWD050 G/CM 4 1 68 16 5 RPD MWD050 OHMM 4 1 68 20 6 RPM MWD050 OHMM 4 1 68 24 7 RPS MWD050 OHMM 4 1 68 28 8 RPX MWD050 OHMM 4 1 68 32 9 FET MWD050 HOUR 4 1 68 36 10 GR MWD050 API 4 1 68 40 11 PEF MWD050 BARN 4 1 68 44 12 ROP MWD050 FT/H 4 1 68 48 13 NPHI MWD050 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9242.5 10910 10076.3 3336 9242.5 10910 FCNT MWD050 CNTS 293.4 1483.4 655.982 3161 9243 10823 NCNT MWD050 CNTS 17924.7 41175.5 29129.9 3161 9242.5 10822.5 RHOB MWD050 G/CM 2.113 4.962 2.85652 3161 9256 10836 DRHO MWD050 G/CM -0.083 2.413 0.261434 3161 9256 10836 RPD MWD050 OHMM 24.1 2000 124.332 2138 9787.5 10856 RPM MWD050 OHMM 17.31 2000 93.6129 2138 9787.5 10856 RPS MWD050 OHMM 14.26 1885.67 56.6886 2138 9787.5 10856 RPX MWD050 OHMM 12.47 488.68 47.4188 2138 9787.5 10856 FET MWD050 HOUR 0.32 21.17 3.1056 2138 9787.5 10856 GR MWD050 API 21.96 579.4 76.5675 2138 9780.5 10849 PEF MWD050 BARN 1. 31 5.73 2.28738 3161 9256 10836 ROP MWD050 FT/H 0.2 788.19 108.539 2134 9843.5 10910 NPHI MWD050 PU-S 12.35 45.71 23.6482 3160 9243 10822.5 First Reading For Entire File......... .9242.5 Last Reading For Entire File.. ....... ..10910 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .....06/11/17 Maximum Physical Record. .65535 File Type................ LO Next File Name.... ...... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/11/17 Maximum Physical Record. .65535 File Type..... . . . . . . . . . . .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 5 header data for each bit run in separate files. 6 .5000 START DEPTH STOP DEPTH . GR RPX FET RPS RPM RPD ROP $ 10849.5 10856.5 10856.5 10856.5 10856.5 10856.5 10910.5 11052.5 11059.5 11059.5 11059.5 11059.5 11059.5 11104.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ...............0 Data Specification Block Type.....O Logging Direction........ .... .... .Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing....... ............. .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth units. . . . . . . . . . . . . . . . . , . . . . . Datum Specification Block sub-type...O . 11-FEB-05 Insite 66.37 Memory 11104.0 10910.0 11104.0 90.3 97.9 TOOL NUMBER 64004 59475 6.000 8924.0 Flo Pro SF 8.60 45.0 9.0 2200 5.8 .950 .580 2.700 .750 80.0 136.4 80.0 80.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 . . GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10849.5 11104 10976.8 510 10849.5 11104 RPD MWD060 OHMM 13.57 186.29 41.3379 407 10856.5 11059.5 RPM MWD060 OHMM 11.34 104.32 30.7726 407 10856 . 5 11059.5 RPS MWD060 OHMM 11.45 84.46 27.5213 407 10856.5 11059.5 RPX MWD060 OHMM 11.38 89.23 26.5854 407 10856.5 11059.5 FET MWD060 HOUR 1. 09 25.48 8.57447 407 10856.5 11059.5 GR MWD060 API 38.78 130.89 86.4668 407 10849.5 11052.5 ROP MWD060 FT/H 0.19 114.28 38.5004 388 10910.5 11104 First Reading For Entire File. ........ .10849.5 Last Reading For Entire File.......... .11104 File Trailer Service name............ .STSLIB.005 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......06/11/17 Maximum Physical Record..65535 File Type..... . . . . . . . . . . . LO Next File Name.. ...... ...STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ....06/11/17 Maximum Physical Record. .65535 File Type. . . ........... . .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX FET RPM RPS RPD ROP $ 6 header data for each bit run in separate files. 7 .5000 START DEPTH 11053.0 11060.0 11060.0 11060.0 11060.0 11060.0 11104.5 STOP DEPTH 12418.0 12425.0 12425.0 12425.0 12425.0 12425.0 12469.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 15-FEB-05 Insite 66.37 Memory 12470.0 11104.0 12470.0 89.2 95.1 # . . TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... .......... .....0 Data Specification Block Type.....O Logging Direction................ .Down Optical log depth units...... .....Feet Data Reference Point....... ...... . Undefined Frame Spacing..................... 60 .1IN Max frames per record... ..........Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . TOOL NUMBER 64004 59475 6.000 8924.0 Flo Pro SF 8.60 46.0 8.9 2400 6.0 1. 200 .460 1. 300 1.000 69.0 189.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 11053 12469.5 11 761. 3 2834 11053 12469.5 RPD MWD070 OHMM 18.52 2000 205.331 2731 11060 12425 RPM MWD070 OHMM 14.51 377.31 129.467 2731 11060 12425 RPS MWD070 OHMM 13.75 626.51 122.85 2731 11060 12425 RPX MWD070 OHMM 12.93 579.54 109.297 2731 11060 12425 FET MWD070 HOUR 0.35 44.67 2.18892 2731 11060 12425 GR MWD070 API 21.11 201.9 58.7822 2731 11053 12418 ROP MWD070 FT/H 0.91 354.95 94.538 2731 11104.5 12469.5 First Reading For Entire File......... .11053 Last Reading For Entire File.......... .12469.5 File Trailer Service name...... ...... .STSLIB.006 . . . Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/11/17 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . . LO Next File Name......... ..STSLIB.007 Physical EOF Tape Trailer Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/11/17 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments. ........ ....... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. ............LISTPE Date.................... .06/11/17 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............. ...UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File