The URL can be used to link to this page

Home My WebLink About206-1297. 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 C-35B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 206-129 50-029-21553-02-00 11330 Conductor Surface Intermediate Liner Liner 9009 80 2637 8763 325 2782 8925 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 8498 29 - 109 36 - 2673 35 - 8798 8550 - 8875 8548 - 11330 29 - 109 36 - 2672 35 - 8388 8178 - 8454 8176 - 9009 11280, 11282 2670 4760 7020 10530 8925 5380 6870 8160 10160 8829 - 11280 4-1/2" 12.6# 13cr80, L-80 33 - 8602 8415 - 9010 Structural 4-1/2" Baker S3 Packer 8401, 8051 8401, 8488 8051, 8125 Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 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 0028284, 0028285 33 - 8222 N/A N/A 47 69 6382 9496 0 0 1100 1100 200 295 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" TIW HBBP Packer 8488, 8125 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 No SSSV Installed By Grace Christianson at 1:19 pm, Apr 09, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.04.09 12:52:05 -08'00' Torin Roschinger (4662) DSR-4/12/24WCB 2024-07-09 RBDMS JSB 041024 ACTIVITY DATE SUMMARY 4/7/2024 ***WELL S/I ON ARRIVAL*** OBJECTIVE: PERFORATE INTERVAL W/2 3/8'' GEO LS GUN 5 spf 72 DEG PHASE RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH GUN#1 W/CH/1.69'' GR-CCL/22' OF 2 3/8'' GEO LS 5 spf TO PERFORATE INTERVAL 8849'-8871' CCL TO TOP SHOT 11.6' CCL STOP DEPTH 8837.4 GUN#2 W/CH/1.69'' GR-CCL/20' OF 2 3/8'' GEO LS 5 spf TO PERFORATE INTERVAL 8829'-8849' CCL TO TOP SHOT 8.6' CCL STOP DEPTH 8820.4' GR-CCL CORRELATE TO SLB MEMORY COMPENSATED NEUTRON LOG DATED 26-JAN-08 JOB COMPLETE ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU C-35B Adperfs are correctly shown on the new WBS, below. -WCB PERFORATE INTERVAL 8829'-8849' PERFORATE INTERVAL 8849'-8871' 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 C-35B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 206-129 50-029-21553-02-00 11330 Conductor Surface Intermediate Liner Liner 9009 80 2637 8763 325 2782 8925 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 8498 29 - 109 36 - 2673 35 - 8798 8550 - 8875 8548 - 11330 29 - 109 36 - 2672 35 - 8388 8178 - 8454 8176 - 9009 11280, 11282 2670 4760 7020 10530 8925 5380 6870 8160 10160 8835 - 11280 4-1/2" 12.6# 13cr80, L-80 33 - 8602 8420 - 9010 Structural 4-1/2" Baker S3 Packer 8401, 8051 8401, 8488 8051, 8125 Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 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 0028284, 0028285 33 - 8222 N/A N/A 423 47 44037 6382 17 0 425 1100 1120 200 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" TIW HBBP Packer 8488, 8125 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 No SSSV Installed By Grace Christianson at 12:13 pm, Mar 28, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.03.28 11:51:33 -08'00' Torin Roschinger (4662) DSR-3/12/24 ACTIVITY DATE SUMMARY 2/11/2024 *** WELL SHUT IN ON ARRIVAL *** RAN 2' 1-7/8" STEM, 2.77" GAUGE RING, SAT DOWN MULTIPLE SPOTS 8,532' SLM (8,548' MD) DEPLOYMENT SLEEVE, 8,615' (X-NIPPLE 8,630' MD, AND 8,833" SLM (XO 8,848' MD RAN 2' X 1-7/8" STEM, XO, 2.35" CENTRALIZER, BULLNOSE, DRIFTED DOWN TO 9,500' SLM **** WELL SHUT IN ON DEPARTURE **** 3/23/2024 ***WELL S/I ON ARRIVAL*** (SET2.5'' OD NS CIBP' ) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH RIH WCH/X2 1 11/16'' WB/1.69'' GR- CCL/ 2.50'' NS CIBP TO SET PLUG AT 8925' MD CCL TO MID ELEMENT 15.3' CCL STOP DEPTH 8909.7' MD GR-CCL CORRELATE TO SLB MEMORY COMPENSATED NEUTRON LOG DATED 26 JAN 2008 JOB COMPLETE ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations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y Anne Prysunka at 11:05 am, Nov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fish is correctly shown on the WBS below. -WCB Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:206-129 6.50-029-21553-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11330 8950 8521 8401, 8488 11282 8950, 10150 8051, 8125 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 36 - 116 36 - 116 Surface 2637 13-3/8" 36 - 2673 36 - 2672 2670 Intermediate 8763 9-5/8" 35 - 8798 35 - 8388 6870 4760 Production 325 7" 8550 - 8875 8178 - 8454 8160 7020 Perforation Depth: Measured depth: 8835 - 11280 feet True vertical depth:8420 - 9010 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13cr80 / L80 33 - 8602 33 - 8222 8401 8051Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S3 Packer Liner 2782 8548 - 11330 8176 - 9009 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 96430041204 2011773 500 34668 168 325 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Wyatt Rivard wrivard@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.777.8547 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9009 Sundry Number or N/A if C.O. Exempt: N/A 4-1/2" TIW HBBP Packer 8488 8125 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028305 PBU C-35B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 3-1/2" x 3-3/16" x 2-7/8" 4930 By Samantha Carlisle at 1:37 pm, Aug 05, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.08.05 13:09:10 -08'00' Stan Golis (880) MGR05AUG2021 DSR-8/6/21 RBDMS HEW 8/9/2021 ACTIVITY DATE SUMMARY 7/22/2021 ***WELL S/I ON ARRIVAL*** DRIFT TBG w/ 10' x 2.66" DMY GUN TO 8950' SLM / 8981' MD (no issues) DRIFT TBG & WORK THROUGH XO @ 8848' MD w/ 2.735" CENT, DRIFT TO 8950' SLM (xo is tight, have to jar 3-4 times to pass both ways) DRIFT TBG w/ 2.72" SWAGE TO 8950' SLM (no issues) ***JOB COMPLETE, WELL LEFT SI, DSO NOTIFIED OF STATUS*** 7/30/2021 ***WELL SHUT IN UPON ARRIVAL*** PT (LOW 300, HIGH 3000) SET 3-3/16" N. SOLUTIONS CIBP @ 8950' MD PERFORATED 10' INTERVAL @ 8835' - 8845' W/ 2.5" GUNS - GEO RZR CHARGES RELEASE WELL TO POP (JOB COMPLETE) Daily Report of Well Operations PBU C-35B STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI•N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations I ! Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate IZ Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Set CIBP l I 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-129 3. Address: P.O.Box 196612 Anchorage, Development m Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21553-02-00 7. Property Designation(Lease Number): ADL 0028305 8. Well Name and Number: PBU C-35B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL S, I V E D 11.Present Well Condition Summary: OCT 2 6 2017 Total Depth: measured 11330 feet Plugs measured 10150 feet true vertical 9009 feet Junk measured 11282 feet A®GCC Effective Depth: measured 10150 feet Packer measured See Attachment feet true vertical 9009 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 29-109 29-109 Surface 2637 13-3/8"72#L-80 36-2673 36-2672 4930 2670 Intermediate Production 8763 9-5/8"47#L-80 35-8798 35-8388 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9848-9880 feet feet 9900-9932 feet 9932-9964 feet 9964-9996 feet 10210-10240 feet 10434-10464 feet 10680-11280 feet True vertical depth: 9014-9014 feet feet 9013-9011 feet 9011-9010 feet 9010-9010 feet 9008-9008 feet 9012-9012 feet 9015-9010 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED Ti,f 2 , ,2n 17 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: 459 41023 52 940 924 Subsequent to operation: Shut-In 910 220 14.Attachments:(required per 20 Mc 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations m Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil IBJ Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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 Authorized Name: Boman,Wade Contact Name: Boman,Wade Authorized Title: Production Engineer,B&X pads Contact Email: Wade.Boman@bp.com Authorized Signature: ,f r Date: I - ( _ -) Contact Phone: +1 9075644674 Form 10-404 Revised 04/2017 f(.q 7 r n, / /1-/i7 RB Di S UL NCV - 2 2017 Submit Original Only • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary October 24, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Cast Iron Bridge Plug (CIBP) and Addition of Perforations for Well C-35B, PTD # 206-129. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • Packers and SSV's Attachment C-35B ADL0028305 SW Name Type MD TVD Depscription C-35B TBG PACKER 8401 8050.6 4-1/2" Baker S-3 Perm Packer C-35B TBG PACKER 8488 8124.74 4-1/2" TIW HBBP Packer • • a) t0N O O O cy)O O O O ti (D N O O O N t7' N- N- N- U N 0 0 0 0 0 0 i co N- CO co co co O) co (1 Ca d- CO CO c- CO CO CO O N 00 0) CO LO OD LO () CD N (V CO M O O N N CO CO CO O O) CO CO 00 I- N O) co Lf) N- CO M r- (O O) N CO CO CO O) CO 4-0C CD O co oo to co co O C` V MO 00 CO CO O c- CO t— 0o 00 CO N CO CO CO �. CO CO CO U p cCOI I I I I I I I I I QM a0 (fl 00 M O O Ln V LC) V O (O O) CO N M M00 OD 00 CO O N N CO C • m O 0 a O O O coco O Lco co co co „ L ` O CO O co co N a N CO *k �# 0 •� u) V N 00 O N N U - - - O M N 00 N M I N N c- Ch N V 4 COO M CO N N Lco SC) LNC) � C co (fl r- M d7 N N V r1 d (NJ 00 M N 00 00 J Z a)p O C w .0 o 0 U 0 u_ O cc cc cc ccZ Z Z Z 0 W w W w m m CO 0 J a Z Z_ Z_ Z_ j D D U (n d J J J J . 0 • I a5 co O co -cC 0) / '6 I CO \ & b ?0 I- \ / / CO - E - o0 « o c cc e f / 3 / \ / b \ E 0 / 0) / 2 E k c CO D D b _ _1 E I a. E0 e \ 2 \ & a b 2 m #CO / = 2 e n \ CO m ® o � � ® ƒ $ � \ t = t2 £ / a tf m / a o 0 a) \ a 0) < c ri / & & < E ■ _ - D C '� 7 2 _ » \ / / / / / \ � � \ f \ \ co cu c o _ - $ I y t \ % $ % o \ co 0 /U 7 /0 7 2 < 2 /2 3 \ ® 2 & � \ / � / \ / _0 _0 \ -0 L m U e f o m ƒ a H 2 U a £ 2 RU © ® r Ob f t oto 4- +Cr o A : C / b @ w P 2 R 2 o c o \ (Ni % 030 - \ L. - o / / I \ \ \ t % f % , - _% / 2 ID E _ J / § » / @ I O 2 O \ 8 / / 7 / / C /\ / • 7 ° // . o £ Z M m 2 ± / + £ ® % CNI-tr) 0 ® CO O • \ / % o .. -16 c.; 2 ¢ § / ƒ .z . / \ o \ ag / o \ / c ± do •® • D / D § - S § J. / / / § / / cf = \ / - / / C / o \ ) n n / f \ � E co \_ © (Dm / _ = - \ / _ / / \ / O .a/ \ \ / \ / / ® _ ® c a % 4 ¥ 4 ¥ _ # .4 ¥ _ y f D / 2 \ 2 E m b I 3 \ 2 I 0 \ + r R - Et o - R = '50 - 0 - 0 * R - O - $ O (..) 00 : U E o » I rr I : 0D_ : l- r ± < N. w w 0® \ r \ � C0 ® \ CO N \ / \ / F. a a a < CIW Wfl.L}�AD= ACTUATOR= BAKEFLIC R 4-1/6" • C 3 5 B S NOTES: WELL ANGLE>70' 9640'. *"4-1/2"CHROME TBG "* INITIAL WELL& C-35A NOT SHOWN BELOW WHIPSTOCK'"' OKB.B.D/= 66.15' ' BF:aEv= 36.75'KOP= 5200' Aixe 1988" --I4 1/7'FES HOLO SV LN,D=3.813" 0 Daum MD= 9394' GAS LFT MANDRELS DatumTVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH FORT DATE 4 3391 3390 1 MIG DOME RK 16 04/22112 3 5387 5381 16 MAG DONE RK 16 04/22/12 20'CONDUCTOR ? i L 2 7085 6896 29 MIG DAN RK 0 01/02/08 1 8244 7916 31 WS DMY RK 0 01/02/08 13-3/8"CSG,72#,L-80 BTRS,D=12.347' —1 2673' ' 8314' H4-1/2"BKR CMD SLD SLV,D=3.812" Minimum ID =2.387" @ 10076' I I 8380' H4-1/2"FES X NP,D=3.813" 3-3/16" X 2-7/8" XO Z 8401' —19-5/8"X 4-1/2"BKR S-3 PKR,D=3.875' I I 8425' —14-1/2"HES X NI,,,D=3.813" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, —I 8478' �+�''- ---I 9-5/8-x 4-1/2"DF2lfAASEAL ASSY,ID=3.958' .0152 bpf,ID=3.958' CA 8488' —19-58"X 4-112"Tial HBBP FKR,D=4.750" ' 8533' —14-1/2'OTIS x NAP,13=3.813' 8548' --I BTT DEPLOYMENT SLV,D=3.00' i ►f 8550' —{9-5/8'x 7"BOT LNR NGR VW TEBACK SLV I C 4-1/2'TBG-PC, 12.6#,L-80 BIFt), —I 8602' F 8568' 4-112"OTIS XN NF?WALLED TO 3.80' 0152 bpf,D=3.958" •r4 , BEHIND '• i♦ —{a-1 rz"wLEG,D=3.s58' CT LNR • • 9-5/8"CSG,47#,L-80 NSGC/BTRS,D=8.681" 8798' `♦4 8630' —13 112"HOMO X NIP =2-813" 3-1/2"LW,8.81#,L-80 STL, — 8848' *�•• •� ♦ 8848' H3-112"X 3-3116"XO,D=2.786" 0087 bpf,D=2.992' %4 %♦ 7'LFR,29#,L-80 BTRS,0371 bpf,,D=6.184" —I —8880 O♦4'4 0. Wt-tFSTOCK w/RA PP TAG(01/13/08) — 8882' `j4 �♦ 3.80'MLLOtJT WIDOW(C-358) 8875'-8882' 44 :♦♦ [3-3116'LIR,6.2#,L-80 TCI,.0076 bpf,13=2.80" l-- 10076' ii 10076' • PERFORATION SUMMARY I REF LOG:SLB MCNLJ GRI CCL ON 01/26/08 ANGLE AT TOP Pte:90'@ 9818' 10076' —3-3/16'X 2-7/8"XO,D=2.387" Note:Refer to Production DB for historical perf data 10150' I--I2-7/8"BKR CUP(09/24/17) SIZE SPF INTERVAL Opn/Sqz SHOT SCZ ' 2" 6 9848-9880 0 09/25/17 2" 6 9900-9996 0 09/24/17 ' 2" 6 10210-10240 C 01/09/14 2' 6 10434-10464 C 10/04/12 ' 2" 6 10680-11280 C 01/27/08 FWD — 11294' 11282' — CI BP FISH-CP PALLS)&RISFE)DH(05/13/15) 64 • 2-7/8"LFR,6.16#,L-80 STL,.0058 bpf,D=2.441" — 11330' •4 DATE REV BY COM ENTS DATE REV BY COMMENTS PF&U'OEBAY UNIT 04/20186 N22E ORIGINAL COMPLETION 11/10/12 PJC PERF CORRECTIONS(10/04/12) WELL C-35B 01/29/96 CTD SIDETRACK(C-35A) ,01/15/14 JTC/JMD ADFERFS(01/09/14) PB;1 T No:'2061290 01/27/08 0I'RWO&CTD SDTRI((C-358) 05/13/15 SRL)'PJC MILL&RJSH CUP DH AR No: 50-029-21553-02 , 03/23/12 TJHY PJC GLV 00 '09/27/17 AC/AID SET CEP&ADMIFS(09/24-25/17) SEC 19,T11M R14E, 1250'FM.&880'FEL 04/2611244.43M IMCrGLV Cl0(04/22/12) 10/23/12 SEr/JM ACFERF&CIBP(10/04/12) . BP Exploration(Alaska) • STATE OF ALASKA • 3KA OIL AND GAS CONSERVATION COMM._.iION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubin❑ Operations shutdown ❑ Performed Suspend ❑ Perforate Other Stimulate ❑ Alter Casini 1 I Change Approved Program ❑ Plug for Redd! ❑,erforate New Pool n Repair Well n Re-enter Susp Well ❑ Other Mill CIBP Q 2 Operator 4 Well Class Before Work- 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development ❑Q Exploratory ❑ 206-129-0 3 Address P 0 Box 196612 Stratigraphic E Service ❑ 6.API Number Anchorage,AK 99519-6612 50-029-21553-02-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028305 PBU C-35B 9 Logs(List logs and submit electronic and pnnted data per 20AAC25 071): 10 Field/Pool(s)- PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 11330 feet Plugs measured None feet true vertical 9008 96 feet Junk measured None feet i I 0 0 ), ;Ji7 Effective Depth measured 11282 feet Packer measured See Attachment feet r �"�`' true vertical 9009 66 feet true vertical See Attachment feet k V •• Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"Conductor 29-109 29-108 99 0 0 Surface 2637 13-3/8"72#L-80 36-2673 36-2672 34 4930 2670 Intermediate None None None None None None Production 8763 9-5/8"47#L-80 35-8798 35-8388 23 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10210-10240 feet 10434-10464 feet 10680-11280 feet True Vertical depth 9007 6-9007 58 feet 9012 34-9011 69 feet 9014-62-9009 68 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment 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 SCANNED 'JUL 0 9 '%01:'1 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 161 12965 16 0 313 Subsequent to operation 507 31417 49 0 944 14 Attachments(required per 20 AAC 25 070,25 071,&25 283) 15 Well Class after work Daily Report of Well Operations ❑✓ Exploratory❑ Development ❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16 Well Status after work Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 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 0 Exempt N/A Contact Nita Summerhays Email NIta.Summerhaysbp.com Printed Name Nita Summerha / Title Data Manager Signator_-��A�/��/ Phone 564-4035 Date 6/8/2015 vrt G//B ic / RBDM9' JUN 1 1 2015 ,A 7(/.s" Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028305 ACTIVITYDATE CTU 8 1. 5"coil CV=24.9bbl Objective: Mill CIBP and push to TD MIRU. Cellar full of water, MU BOT 2.34" 5 blade reverse opticut BHA. FP flowline with 49bbls 50/50. Lead w/50/50 and load well with 1%KCL w/SL while RIH. Well is very tight. Put 17bbl cap on well after load w/1%KCL w/SL. Displace coil to KCL while rih. Tag plug at 10632. Begin milling, milled and pushed plug to 11282'. POOH. 5/13/2015 ***Continued on WSR 5/14/14*** CTU 8 1.5" coil CV=24.9bbl Objective: Mill CIBP and push to TD ***Continued from WSR 5/13/14*** POOH, RDMO. Well is freeze protected with 40 bbls 50/50 methanol. Tree cap tested to 4000 psi. ***Job Completed*** 5/14/2015 FLUIDS PUMPED BBLS 148 50/50 METH 599 I% KCL W/SLICKLUBE 747 TOTAL Ci 1 U) CU O o� 00 C0 N- O o 0 U 1 0 O o o O o v mco • ( v cocco co CA CO CO CO CO ct c- 6:13 - O CO CO CO CA N V CO N I- L CO O O CL7 co O N Cfl -4 V O Ln co O co co N- c- N N V co co co (A CO N ,- CO CO C3) CA CO N- N CO CO CO jI I I I I I I I I I 1 H LU CO CO CA V CA OO O L Cp Co Co CA V NN_ oo co co M N N N c- 'Cr O CA CO CO C3) f- CO C in co co O CO CA co co CO N CA NM C) '- N- N- O O E (0 00 00 = CO CO V CO OD 00 00 N CSO C+O OO +' O M v CO 'Cl" CO Q ch rnvLn Vo Ln CO COCnCO Co N O CO CO M N N co ra N r- C O _ ▪ O mlof J CD O o I— ▪ Q p ' J . eD a) 00 U U 1-_,) J J J U1 J co co co co J J I# N I# CT(Ni % N � * 00 co - N- co Cfl Cfl CO• Cl) 0 O Op _ Co _ - - (N C\I CC O N CV CO _if: oO U) ,— N Co) O to\ co N A- CO r N co N N = i CA M CO N = V V 4 V t +-' 00 V CO 1"-- NCD CD O N N Ln CO CO Ln Ln .4- C C CO M O N CV N- in CO V V d M N A- A- CO N CO 00 J Z co 0 0 .- F- w (-) 012C C p w LL Z Z Z Z W W W W 0 w cC pp m m Q Z Z Z Z [tJ D J D D U J J J J d U) U) H H H Packers and SSV's Attachment ADL0028305 SW Name Type MD TVD Depscription C-35B PACKER 8401 8050.6 4-1/2" Baker S-3 Perm Packer C-35B PACKER 8488 8124.74 4-1/2"TIW Packer WELL ` Wall-FAD= 4 1/6"FMC C-35 B ***4-1/2NO RH S: E TBG AN NI >7 WELL& '. ACTUATOR= BAKER C C-35A NOT SHOWN BELOW WHIPSTOCK*** OKB.BEV= 66.15 F.B ( ' BE 3675' KOP= _ 5200' Max Angle= 93°@9929 1988' —14 1/2"I IM HOLO SVLN,D=3.813" 0 Datum MD= 9394' GAS UFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3391 3390 1 IMAG DONE RK 16 04/22/12 3 5387 5381 16 NMG DOME RK 16 04/22/12 20"CONDUCTOR ? L 2 7085 6896 29 NTNG DMY RK 0 01/02/08 1 8244 7916 31 MING MAY RK 0 101/02/08 13-3/8"CSG,72#,L-80 BTRS,13=12.347" — 2673' ( I 8314' H4-1/7 BKR CMD SLD SLV,D=3.812" Minimum ID =2.387" (_ad" 10076' I I 8380' —14-112"HES X t*,D=3.813" 3-3/16" X 2-7/8" XO 2' X' 8401' —19-5/8"X 4-1/2"BKR S-3 PIR,D=3.875" ' r8425' --14-1/2"HES X NP,D=3.813" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, H 8478' /^ $' H9 5/8"x 4-1/7 DRUM SEAL ASSY,D=3.958" .0152 bpf,D=3.958" �� X- 8488' —9-5/8"X 41/2"TM/HBBP PIR,D=4.750" 1 8533' H 4-1 i2'OTIS X NP,D=3.813' 8548' H BTT DEPLOYMENT SLV,D=3.00" P • 4 A 8550' _H 9-5/8'x 7"BOT LNC I-GR W/TRACK SLV 4-1/2'TBG-PC,12.6#,L-80 BTRS, -- • L 8568' —4-1/2"OTIS XN NP,MLLE?TO 3.80" BEHIND 04 0152 bpf,ID=3.958" '4 •4 8G01' --14-1/2"WLEG,D=3.958"• CT LNR 9-5/8"CSG,47#,L-80 NSCXJ BTRS,D=8.681" — 8798' i.-.A A t. lk ►••. 8630' —13-1/2"HOWCO X lam',D=2.813" 3-1/2'LNR 8.81#,L-80 STL, — 8848' 04 •� .0087 bpf,D=2.992" ......4. .` �� 8848' -{3 112"X 3-3/16"XO,D=2.786" ►•A4 ►off y 7"LNR,29#,L-80 B I Ib,0371 bpf,,D=6.184' ---1 -8880 L Vi ei WH STACK w I RA PP TAG(01/13/08) { 8882' II* •►� 3.80'NLLOUT WrJOW(C-358) 8875-8882' 114 PERFORATION SUMMARY •• REF LOG:SLB MCNJ GR/CCL ON 01/26/08 ANGLE AT TOP FEW.91"@ 10210' Note:Refer to Production DB for historical perf data 10076' H3-3/16"X 2-7/8"XO,ID=2.387' SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 2" 6 10210- 10240 0 01/09/14 2" 6 10434- 10464 0 10/04/12 I 2" 6 10680-11280 0 01/27/08 3-3/16"LNR,6.2#,L-80 TCI, .0076 bpf,D=2.80" H 10076' ' MID —I 11294' J 11282' --{FISH-CEP MLLEO&FUSHED DH(05/13/15) 2-7/8"LNR,6.16#,L-80 STL,.0058 bpf,D=2.441" —1 11330' Vi •1 DATE REV BY CONMBYTS DATE REV BY COMNBYTS PRUDHOE BAY UNIT 04/20186 N22E ORIGINAL COMPLETION 11/10/12 PJC PERF CORRECTIONS(10/04/12) WELL C-35B 01/29/96 CTD SIDETRACK(C-35A) 01/15/14 JTC/JND ADFERFS(01/09/14) PERMIT No: 2061290 01/27/08 NORDIC i RYYO&CTD SDTRK(C-35B) 05/13/15 SRCY PJGt NLL&PUSH 0BP DH AFI No: 50-029-21553-02 03/23/12 TJH/PJC GLV 00 SEC 19,T11N,R14E,1250'FM..&880'FEL 04/26/12 M3MJNDY GLV 00(04/22/12) 10/23/12 SET/JND ADPERF&CIBP(10/04/12) BP Exploration(Alaska) 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. p`~~.~ - ~ ~ q Well History File Identifier Organizing (done) ^ Two-sided III (VIII II III II III ^ Rescan Needed III II~III II II IIIIII RE AN Color Items: ~Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Project Proofing BY: Maria Scanning Preparation BY: _ Maria Production Scanning Stage 7 Page Count from Scanned File:.~°2- (Count does include cov sheet) Scanning is complete at this point unless rescanning is required.. Page Count Matches Number in Scanning Preparation: YES _ BY: Maria Date: 3 ' / Q Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: ,= v~ P "iiiumiimum ReScanned II I II II II (I I II I I I II BY: Maria Date: ~s~ Comments about this file: Quality Checked III I'll) III II'I III DIGIT DATA OVERSIZED (Scannable) iskettes, No. ( ^ Maps: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D ^ Other:: Date: ~ ~ /s~ Date: iiumiiimiiu~P ^ Logs of various kinds: =TOTAL PAGES j I (Count does not include cover sheet) /s/ 3 X 30 ~ q~ 1 Date: 10/6/2005 Well History File Cover Page.doc RECEIVED STATE OF ALASKA • AIL OIL AND GAS CONSERVATION COMM ON NOV 0 12012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate L( Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program p Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development CI Exploratory ❑ -' 206 -129 -0 3. Address: P.O. Box 196612 Stratigraphk0 Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21553 -02 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028305 i` PBU C -35B ' 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 11330 feet Plugs measured 10640 feet true vertical 9008.96 feet Junk measured None feet Effective Depth measured 10640 feet Packer measured See Attachment feet true vertical 9013.93 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 81 20" Conductor 29 - 110 29 - 109.99 0 0 Surface 2645 13 -3/8" 72# L -80 28 - 2673 28 - 2672.34 4930 2670 Intermediate None None None None None Production 8771 9 -5/8" 47# L -80 27 - 8798 27 - 8388.23 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10434 -10464 feet 10680 - 11280 feet True Vertical depth 9012.34 - 9011.69 feet 9014.62 - 9009.68 feet ��p�NN�C AN 2 3 2013 Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment 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: 457 26166 23 0 1200 Subsequent to operation: 446 26113 27 0 197 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorL❑ Development ID ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil i gs Gas ❑ WDSPLU 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 Email Nita.Summerhays(bp.com Printed Name Nita Sum 1 4 ay-1 Title Petrotechnical Data Technician ' Signatur Phone 564 -4035 Date 10/31/2012 xpr"„,,, . . ie (4 , ,...,,,,„ ,,,,,,,, 0, 2c,761F-n o pait-i-, e � /Tort !�'� ".'- �,��. ..a��,_,_ � Form 10 -404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028305 ACTIVITYDATE ' ' ` •: a -•∎ S -• GUN RUN 1: RIH WITH HEAD (4X3 WP / 1.38" FN) / ERS / MAXTRAC WITH CCL / GR / 2" PJ OMEGA 2006 GUNS. OAL = 60' / OAW = 275# / MAX OD = 2.125 ". 10' INTERVAL / 6 SPF / 60 DEG PHASE / PENETRATION DEPTH = 21.8" / ENTRANCE HOLE = 0.22" TOOL ZERO TO TOP SHOT = 6.8' / TOOL ZERO STOP DEPTH = 10447.2' / SHOT 10454'- 10464' GUN RUN 2: TOOL ZERO TO TOP SHOT = 6.8' / TOOL ZERO STOP DEPTH = 10437.2' / SHOT 10444'- 10454' GUN RUN 3: TOOL ZERO TO TOP SHOT = 6.8' / TOOL ZERO STOP DEPTH = 10427.2' / SHOT 10434'- 10444' FINAL T /I /O = 1120/0/0 PSI ** *JOB COMPLETED * ** 10/4/2012 ** *WELL S/I ON DEPARTURE * ** Casing / Tubing Attachment ADL0028305 Casing Length Size MD ND Burst Collapse CONDUCTOR 81 20" Conductor 29 - 110 29 - 109.99 LINER 300 3 -1/2" 8.81# L -80 8548 - 8848 8175.79 - 8430.81 LINER 332 7" 29# L -80 8550 - 8882 8177.5 - 8459.84 8160 7020 LINER 1228 3- 3/16" 6.2# L -80 8848 - 10076 8430.81 - 9010.67 LINER 1254 2 -7/8" 6.16# L -80 10076 - 11330 9010.67 - 9008.96 13450 13890 PRODUCTION 8771 9 -5/8" 47# L -80 27 - 8798 27 - 8388.23 6870 4760 SURFACE 2645 13 -3/8" 72# L -80 28 - 2673 28 - 2672.34 4930 2670 III TUBING 8452 4 -1/2" 12.6# 13Cr80 26 - 8478 26 - 8116.23 8430 7500 TUBING 123 4 -1/2" 12.6# L -80 8478 - 8601 8116.23 - 8220.86 8430 7500 • TREE 4-1/6 " aw = S NOTES: WELL ANGLE 70 9640'. ACTUATOR = BAKER C C -3 5 B ' "�" CHROME TBG „" INITIAL WELL & KB. REV = 66.15 C-35A NOT SHOWN BELOW WHIPSTOCK"' 1 BF. E-El/ = 36.75' 1 rk KOP= 5200' I 1988' H4 112" HES HXO SVLPI, D = 3.813" Max Angle = 93° ft 992g • Datum kV = 9394' GAS L PT MANDRILS t L un1VD _ 8800'SS ■ ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3391 3390 1 MMG DONE FE 16 04/22/12 3 5387 5381 16 MMG DONE RK 16 04/22/12 120" COPD JCTOR I ? L 2 7085 6896 29 MMG 01W RK 0 01/02/08 . 1 8244 7916 31 MMG OW FE 0 _ 01/02/08 113 -3/8" CSG, 72#, L-80 BTRS, I) = 12.347" H 2673' I 8314 I--I4 -1/2" BIa2 CNO SLD SLV, D = 3.812" I Minimum ID = 2.387" @ 10076' 8380' H4 -1/2" HES X NP, D= 3.813" I 3 -3/16" X 2 -7/8" XO I ► -. I 8401' ( � 9 5/8" X 4 -112" BK R S 3 PKR, D= 3.875" 8425' H 4- 1 /2"HESX NP,D= 3.813" I 4-1/2" TBG, 12.6#,13CR -80 VAM TOP, —I 8478' 9 5/8"x 4 112" DRISASEAL ASSY, D= 3.958" .0152 bpf, D = 3.958" ►in ► ∎,4 I 8488' H 9-�' X 4-1/2" TM/ IB R, D BP RC = 4.750" I • $533' HI4 - 12" OTIS X NP, D = 3.813" I I 5 — E' 854IBTT DLOY MINT SLV, D = 3.00" I !I II; : • 'I I I . i 4 8550' 9-5/8' x 7" BOT LW I- GR W TIEBACK SLV I 4-1/2" TBG PC, 12.6 #, 1-80 BTRS, —I 8602' I i I 8568' H4-1/2" Oils XN NP, P&L®TO 3.80' BEHIND .0152 bpf, D = 3.958" -. ■ ∎ 8601 H 4 -1 /2" WLEG, D = 3.958" I CT LNR ►4 01 19-5/8" CSG, 47 #, 1-80 1490(,/ BTRS, I) = 8.681" H 8795 •:4 • • �: � 8630' j--I3-1/2" I O' X NP, D = 2.813" I 3-1/2" LNR, 8.81 #, L-80 STL, 8848' • 4 4 ∎ i x • 41 8848' i--13-1/2" X 3- 3/16" XO, D = 2.786" I .0087 bpf, 13= 2.992" � 4� � i • . • • 7' LNR 29#, L-80 MRS, 0371 H • i i 0,4 I bpf, , D = 6.1 — 8880 I\ ∎ • X4.4 8882' I H • • *i i ii 3.80" 'ALLOW* WwOW (C -358) 8875' -8882 I WHPSTOCK w / RA PP TAG (01/13/08) I PERFORATION SUIMNIRY %i REF LOG:SLB MCNJ GR/ CCL ON 01/26/08 ' ANGLE AT TOP PELF: 90° m 10680' Note: Refer to Production DB for historical pert data SZE SW v M iAL: v -- Opr>/Sgr- -, 2" , 6 10434 -10464 0 10 10076' 3- 3/16' X 2 -7/8" XO, DIM 2.38r 2" 6 `- - 1280 G� /27 , —� = I 10638' I I2 -7/8" WFD CBP (10/04/12) I — ss� I3 -3/16" LNR 6.2#, L-80 TCI, .0076 bpf, D = 2.80" H 10076' ../•- I PBTD H 11294• 12-7/8" LNR, 6.16#, L -80 STI, .0058 bpf, D = 2.441" H 11330' 4 4 44 DATE REV BY °om nns DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/20/86 N22E ORIGINAL COMPLETION 05/16/11 AK/ PJC ANAL DRLG CORRECTIONS 1NE-L• C-35B 01/29/96 CTD SIDETRACK (C-35A) 03/23/12 TJW PJC GLV C/O FIT No: "2061290 01/27108 NOHOW 1 RWO & CTD SDTRK -35B) 04/26/12 I M'JMD GLV C/O (04/22112) AR ND: 50- 029 - 21553-02 02/15/08 KSBITLH GLV C/O (02/07/08) 10/23/12 SET /JMD ADFERF 8 SET CIBP(10/04/12) SEC 19, T11 N, R14E 1250' R& & 880' FB_ 03/01/10 JND DRLG DRAFT CORRECTIONS 04/01/11 PJC DRLG DRAFT CORRECTORS BP Exploration (Alaska) • C -35 8 Regg, James B (DOA) P ilJ 206, t 7-90 From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator @bp.com] z Sent: Saturday, March 24, 2012 7:47 AM ( 7 i r1 ' To: Reynolds, Charles (Alaska); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC3 &PCC OSM; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, OPS Prod Controllers; Glasheen, Brian P Cc: King, Whitney; Wills, Shane M Subject: OPERABLE: Producer C -35B (PTD #2061290) MIT -IA Passed All, Producer C -35B (PTD #2061290) passed an MIT -IA after dummy gas lift valves were set. The passing test confirms two competent barriers in the wellbore and the well is reclassified as Operable. Please be aware of the potential for thermal expansion when placing the well on production as the IA is liquid packed. Thank you, Mehreen Vazir (.'3liornate: G&'rrelc/ iAlrrr php j Well Integrity Coordinator # fYIH[� �� BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIllntegrityCoordinator @BP.com From: Reynolds, Charles (Alaska) Sent: Sunday, March 04, 2012 2:20 PM To: AK, D &C Well Integrity Coordinator; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC3 &PCC OSM; AK, OPS GC3 Facility & Field OTL; AK, • • GC3 Wellpad Lead; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Serv -s Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, OPS Prod Controllers; Glasheen, Brian P Cc: Walker, Greg (D &C); Olson, Andrew; Clingingsmi , Mike J Subject: UNDER EVALUATION: Producer C -35B (P D #2061290) Sustained Casing Pressure on IA All, Producer C -356 (PTD #2061290) has •nfirmed sustained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 2380/201 vac on 3/3/12. The well has been reclassified as Under Evaluation. The well may remain online while work is condu ed to attempt to restore integrity. Plan forward: 1. Slickline: Dummy gas lift Calves 2. Fullbore: MIT -IA to 30.. psi A TIO plot and well. are schematic have been included for reference. 1 • • P(3L4 C -3 3 Ark o lX90 Regg, James B (DOA) From: Reynolds, Charles (Alaska) [Charles.Reynolds @bp.com] Sent: Sunday, March 04, 2012 2:20 PM / To: AK, D &C Well Integrity Coordinator; Regg, James B (DOA); Maunder, Thomas E (DOA sponsored); Schwartz, Guy L (DOA); AK, OPS GC3 &PCC OSM; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, OPS Prod Controllers; Glasheen, Brian P Cc: Walker, Greg (D &C); Olson, Andrew; Clingingsmith, Mike J Subject: UNDER EVALUATION: Producer C -35B (PTD #2061290) Sustained Casing Pressure on IA Attachments: C- 35B.pdf; Producer C -35B (PTD #2061290) TIO.doc All, Producer C -35B (PTD #2061290) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 2380/2010/vac on 3/3/12. The well has been reclassified as Under Evaluation. The well may remain online while work is conduced to attempt to restore integrity. Plan forward: 1. Slickline: Dummy gas lift valves 2. Fullbore: MIT -IA to 3000 psi ScANNED MAR f 7 1 A TIO plot and wellbore schematic have been included for reference. Please call if you have any questions or concerns. SCE Thank you, • Charles Reynolds ] Ae v . Z( , 3 � Filling in for... c � Me/ireen Vazir n a,.}-, ray c�l� (Alter/ hire t; r,tl l 1.Icrr/ l t1 Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegritvCoordinator @BP.com 1 PBU C -35B PTD #2061290 3/4/2012 TIO Pressures Plot Well: C -35 4,000 - • 3,000 — Tbg —11111— IA OOA OA ZOO ' 000A On { 1,000 • j I 12/10111 12/17/11 12/24)11 12/31/11 01 /07)12 01/1012 01/21/12 01/28/12 02/04/12 02/11/1 2 02/18/12 02/25/12 03)03/12 • WELLHEAD = 4 FMC C _3 5 B SATES: WELL ANGLE> 70° @ 9640'. ***4-1/2" CHROME TBG ORIGINAL WELL & ACTUATOR = BAKER C I C -35A NOT SHOWN BELOW WHIPSTOCK * ** KB. ELEV = 66.1 BF. ELEV = 36. I 1988' H4 1/2" HES HXO SVLN, ID = 3.813" I KOP = 5200' Max Angle = 93° @ 9929' GAS LIFT MANDRELS Datum MD = 9394' ST MD TVD 1 DEV TYPE VLV LATCH PORT DATE Datum TVD = 8800' SS 4 3391 3390 1 MMG DOME RK 16 02/07/08 120" CONDUCTOR I 3 5387 5381 16 MMG SO RK 20 02/07/08 2 7085 6896 29 MMG DMY RK 0 01/02/08 113 -3/8" CSG, 72 #, L -80 BTRS, ID = 12.347" H 2673' 1 8244 7916 31 MMG DMY RK 0 01/02/08 ( I 8314' H4-1/2" BKR CMD SLD SLV, ID = 3.812" I Minimum ID = 2.387" @ 10076' 8380' I -14 -1/2" HES X NIP, ID = 3.813" 3- 3/16" X 2 -7/8" XO orb 4 8401' I- 1 9-5/8" X 4 -1/2" BKR S -3 PKR, ID = 3.875" I 8425' H4 -1/2" HES X NIP, ID = 3.813" I 8488' (-I9 5/8 "x 4 -1/2" DRUM SEAL ASSY, ID = 3.958" 4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, -I 8478' .0152 bpf, ID = 3.958" I►:/ 1 8488' H9.5/8" x4-1/2" TM/ HBBP PKR, ID = 4.750 "I I 8533' H4 -1/2 " OTIS X NIP, ID = 3.813" I 8548' HBTT DEPLOYMENT SLV, ID = 3.00" I • : ► • 8550' -19-5/8' x 7" BOT LNR HGR W/ TIEBACK SLV I • 4 -1/2" TBG -IPC, 12.6 #, L -80 BTRS, -I 8602' I , 8568' - I4 -1/2" OTIS XN NIP, MILLED TO 3.80' 1 .0152 bpf, ID = 3.958" �� - / • 8601' WLEG, ID = 3.9" 58" BE ♦ ►i CT LNR Di I9 -5/8" CSG, 47 #, L -80 NSCC/ BTRS, ID = 8.681" H 8798' ■ ►�i ■ 1 N 8630' I- I 3 -1/2" HOWCO X NIP, ID = 2.813" kAsw7= 6670 Fs; 3 -1/2" LNR, 8.81 #, L -80 STL, -I 8848' I-• 0 8848' H3-1/2" X 3- 3/16" XO, ID = 2.786" I • • ► H / � .0087 bpf, ID = 2.992" • • j ► � 17" LNR, 29 #, L -80 BTRS, 0371 bpf, , ID = 6.184" I-� 8880 I--__ ►., �� e_.. /�� 1~ 3.80" MILLOUT WINDOW (C -35B) 8875' - 8882' 'W il l HIPSTOCK (01/13/08) H 8882' I-' IRA PIP TAG (01/15/08) I 88$2'. ► R• PERFORATION SUMMARY REF LOG:SLB MCNL/ GR/ CCL ON 01/26/08 ANGLE AT TOP PERF: 90° @ 10680' Note: Refer to Production DB for historical perf data 10076' H3-3/16" X 2 -7/8" X0, ID = 2.387" s l SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 10680 - 11280 0 01/27/08 13-3/16" LNR, 6.2 #, L -80 TCII, .0076 bpf, ID = 2.80" H 10076' ( PBTD I 11294' ►�* 2 -7/8" LNR, 6.16 #, L -80 STL, .0058 bpf, ID = 2.441" H 11330' t ' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/20/86 N22E ORIGINAL COMPLETION 05/16/11 AK/ PJC FINAL DRLG CORRECTIONS WELL: C-35B 01/29/96 CTD SIDETRACK (C -35A) PERMIT No: " 01/27/08 NORDIC 2 RWO & CTD SIDETRACK (C -35B) API No: 50- 029 - 21553 -02 02/15/08 KSB /TLH GLV C/O (02/07/08) SEC 19, T11 N, R14E, 1250' FNL & 880' FEL 03/01/10 JMD DRLG DRAFT CORRECTIONS 04/01/11 PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 0 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 RECEIVED AUG 3 1 NMI Mr. Tom Maunder Alma CM & Gas Cam. Commis • Alaska Oil and Gas Conservation Commission s101t1 333 West 7 Avenue An C? 3r Anchorage, Alaska 99501 t y Subject: Corrosion Inhibitor Treatments of GPB C -Pad 36B Dear Mr. Maunder, �✓ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, 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, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C -01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -19B 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C -20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C -21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -27B 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -288 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -35B 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C -378 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C-41A 2041880 500292238501 Sealed NA NA NA NA NA C -42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 II ~~~ ~~~~ a -~_ .~4 J . ~ e ~ / ~ ~ ~ rtr _ aka ~+Wf ~ +r' MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL .UNDER THIS PAGE C:\temp\Temporary .Internet Files\OLK9\Microfilm_Marker.doc ~ ~ ~~~ ~~o DATA SUBMITTAL COMPLIANCE REPORT 1/25/2010 Permit to Drill 2061290 Well Name/No. PRUDHOE BAY UNIT C-35B Operator BP EXPLORATION (ALASKA INC API No. 50-029-21553-02-00 MD 11330 TVD 9009 Completion Date 1/29/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes "~- DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR, RES, MCNL / GR /CCL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments rLog Casing collar locator 5 Blu 1 7800 8650 Case 2/22/2008 MDD, GR, CCL 2-Jan-2008 ED~C Lis 16031 Neutron 8223 11208 Case 3/13/2008 LIS Veri, GR, CNT og Neutron 25 Blu 8300 11210 Case 3/13/2008 MCNL, GR, CCL, CNL 26- Jan-2008 ED D Asc Directional Survey 8800 11330 Open 3/10/2008 Rpt Directional Survey 8800 11330 Open 3/10/2008 ED'~C Las 16215 Induction/Resistivity 8820 11330 Open 4/11/2008 ATR, RPM, GR, RAM, ROP,RPD ti LIS V if 8224 11331 en O 12/15/2008 ROP RAD LIS Veri GR pt on er ica p , , , , RAS, RPD, RPS ~ ED 'f C Lis 17297 Induction/Resistivity 8224 11331 Open 12/15/2008 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS ~ Log "~ Induction/Resistivity 25 Col 8875 11330 Open 12/15/2008 MD MPR, GR 23-Jan-2008 / Log / Induction/Resistivity 25 Col 8875 11330 Open 12/15/2008 TVD MPR, GR 23-Jan-2008 Log~ Gamma Ray 25 Col 8875 11330 Open 12/15/2008 MD GR 23-Jan-2008 Log ^' See Notes 2 Col 8224 11331 Open 12/15/2008 Depth Shift Monitor Plot Well Cores/Samples Information: t~J Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 1/2512010 Permit to Drill 2061290 Well Name/No. PRUDHOE BAY UNIT C-35B MD 11330 TVD 9009 Completion Date 1/29/2008 ADDITIONAL INFORMATION WeII Cored? Y Chips Received? "4'7'1~- Analysis ~'-/-N-'` Received? Operator BP EXPLORATION (ALASKA INC Completion Status 1-OIL Current Status 1-OIL Daily History Received? 7" N Formation Tops API No. 50-029-21553-02-00 UIC N Comments: Compliance Reviewed By: Date: ,ass I BAKER F~V6F~E5 Baker Atlas PRINT DISTRIBUTION LIST COMPANY BY EXYLUKA'1'lUN (ALASKA) 1NC COUNTY NUR'1'H SLUYE BOKUUGH WELL NAME C-35B STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 12/11/2008 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 1718799 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 I Company EXXON MOBIL PRODUCTION CO Company Person FII,E ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: dv~ ~~~ Page 1 of 1 IloTTEQ Log ~ Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: C-35B Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 1718799 ~oC~ -ia9 l~~4 ~ Sent by: Catrina Guidry Date: 12/11/08 Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (~0 7) 267-6623 Baker Hughes INTEQ ~r 7260 Homer Drive ~ ~ Anchorage, Alaska 99518 Direct: (907) 267-6612 [NTEQ FAX: (907) 267-6623 ,~~A~Vk~.,L DATA TRANSMITTAL Enclosed are the rnatcrials listed' Below. (BPXA FIELD LOG DATA) t you have any questions, lease contact llougias llortch at trie YllC: at J64-4y /.5 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 05-13B ~U~'- I~16 ~ /~a(3 A-12A c~0'3--(3C~ ;` l Co ~ (~l C-35B c~iOC~-lc7q ~!(0 8( 5 Y-01APB1 a{j~-~~ d/~~1~ Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Date 04-11-2008 Transmittal Number:92955 03!06/08 ~D~i~~U~~ti~~~r~ NO.4621 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Pt.Mac,Milne Pt,Orion,Lisburne Well Job # Lo Descri lion Date BL Color CD C-41A 12021141 MEM LDL 02/25/08 1 1 MPS-01A 11970714 SCMT v"} _ C 02/21/08 1 1 P1-06 11975757 PROD PROFILE ~ 03/02/08 1 1 P1-05 11998992 PROD PROFILE ~' 02/29/08 1 1 Pi-O6 11975757 SCMT (~ ~-'n' 03/02/08 1 1 09-23A 12045070 USIT ~ ~ C ~ 03/02/08 1 1 LS-34 12057596 PROD PROFILE ~ ~ 02/28/08 1 1 W-40 11970816 PRODUCTION LOG -j 03/04/08 1 1 15-04B 12005202 MCNL '~d - 1~ G 12/28/07 1 1 C-356 12021139 MCNL ~ 01/26/08 1 1 X-20A 11661178 CH EDIT PDC GR (MEM CORRELATION) _I 10/26/07 a~- 1 L-219 12017479 CH EDIT PDC GR (IBC) - C /(p 01/02/08 1 PLEASE ACKNOWLEDGE RECEIPT BY31Gt~1ING'AND Ft~TURNIC~IG'ONE COPY EACH TO: BP Exploration (Alaska) Ina 1' Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~ ~ { i z , r ..l~,t, Anchorage, Alaska 99508 ~ ~~'~ ~~ ~~~)~a Date Delivered: r, ,,_ sYrsiv.+ i;~:- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ Received by: C: !/! I' I~ t3 ro.s BAKER NUGNES INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Te1907-267-6600 Fax 907-267-6623 To Whom It May Concern: March 7, 2008 Please find enclosed directional survey data for the following wells: A-12A OS-13B 15-45BPB 1 15-45B 18-32B C-35B f Enclosed for each well is: tea copies of directional survey reports lea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: ,State of Alaska AOGCC DATE: ~d ~ ~ Cc: State of Alaska, AOGCC 2ca~-r ~a \ ~` ~ STATE OF ALASKA ~'~'~~ ~~~~~~~ F~ ALAS~OIL AND GAS CONSERVATION CO ISSION * ~~~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~'~~ ~ ~ 200$ 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1b. Well Class:~~.~r 20AAC 25.105 2oAAC 2s.~,o ®DeveloprttBTf['"'ltploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aba 12. Permit to Drill Number BP Exploration (Alaska) Inc. 1/29/2008 206-129 3. Address: 6. Date Spudded ~ 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 1/8/2008 50-029-21553-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 1/22/2008 PBU C-35B 1250' FNL, 879' FEL, SEC. 19, T11 N, R14E, UM Top of Productive Horizon: 8. KB (ft above MSL): 66.19' r 15. Field /Pool(s): ~ 74' FSL, 2347' FEL, SEC. 18, T11 N, R14E, UM Ground (ft MSL): 36.25' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Pool 150' FSL, 4024' FEL, SEC. 18, T11 N, R14E, UM 11294 - 9009 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 664497 y- 5959971 Zone- ASP4 11330 9009 ADL 028305 - TPI: x- 662996 y- 5961263 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 661318 y- 5961303 Zone- ASP4 None 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): Submit el ctronic and rinted information er 20 AAC 25.050 N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printe information per 0 AAC 25.071): MWD DIR / GR, RES, MCNL / GR / CCL DOSJ C° ~i~6 /mod ~~S~~STI'd 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTM MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" Surface 110' Surface 110' 36" 8 cu ds Concre e 13-3/8" 72# L-80 Surface 2673' Surface 2673' 17-1/2" 3255 cu ft COldset III 465 cu ft CS II 9-5/8" 47# L-80 Surface 8798' Surface 8388' 12-1/4" 570 cu ft Class'G' 7" 29# L-80 8550' 7 ' 8177' 8450' 8-1/2" 432 cu ft Class'G' 3-1/2"x3-3116"x2-7/8" as~nis.zais.~sa L-80 8548' 11330' 8176' 9009' 4-1/8" 185 cu ft Class'G' 23. Open to production or injection? ®Yes ^ No 24. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET MD PACKER SET MD (MD+TVD of Top & Bottom; Perforation Size and Number): 2" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr & L-80 8601' 8401' & 8488' MD TVD MD TVD 10680' - 11280' 9015' - 9010' ~§. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protect w/ 40 BBIs Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): February 9, 2008 Flowing Date Of Test: HOUfS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 2/24/2008 6 TEST PERIOD 567 2,703 25 96 4,768 Flow Tubing CaSing PfeSS: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): Press. 260 460 24-HOUR RATE• 2,268 10,813 100 26 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewall Cores Ac wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. $ wG~ :I:Tii}i~ ~ None f- ,Q, Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ~ „'_ ~ G i 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS RKERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Teste ? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sadlerochit 8958' 8528' None Top CGL /Zone 3 9133' 8684' Base CGL /Zone 2C 9257' 8779' 23SB /Zone 2B 9323' 8823' 22TS 9429' 8886' 21 TS /Zone 2A 9548' 8945' Formation at Total Depth (Name): 21 TS /Zone 2A 9548' 8945' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoi is true and correct to the best of my knowledge. ^ ~~ ~ ~// Signed Sean McLaughlin Title CT Drilling Engineer Date PBU C-356 206-129 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITeM 1a: Class cation 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). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. 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: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information .required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only • BP EXPLORATION Page 1 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ~ Task Code NPT Phase Description of Operations ___ __ - 12/9/2007 18:00 - 20:00 2.00 RIGD P - PRE RD and make ready to move off DS18-13. Hold PJSM with all crews to discuss responsibilities while moving off well. Make multiple walk arounds of rig exterior. 20:00 - 21:30 1.50 RIGD P PRE Jack rig up. Back off well. Move down pad. Pick up rig mats and clean area around wellhead. Complete Pad inspection with DSO. 21:30 - 23:00 1.50 RIGD P PRE Nordic crew timed out due to late relief due to flight delays and changeout crew at airport. Standby and wait on relief. 23:00 - 0.00 RIGD P PRE Begin move from DS 18. 12/10/2007 00:00 - 10:00 10.00 MOB P PRE Continue to move rig from DS 18 to C-35. Weather is calm & clear. At 06:00 hrs, rig crew change 1 mile south on K-Pad road 10:00 - 14:00 4.00 RIGU P PRE Rig on C-Pad at 10:00 hrs Lay out herculite and rig mats 14:00 - 16:00 2.00 RIGD P PRE RU & troubleshoot power generation on the camp 16:00 - 16:30 0.50 RIGU P PRE Held PJSM on moving over the well. 16:30 - 17:00 0.50 RIGU P PRE Moved over well and set down Rig accepted at 17:00 hrs 17:00 - 20:00 3.00 RIGU P PRE RU handberm and spot associated equipment around the rig. Spot cuttings box. Take on rig water. Hook up office camp to rig power. 20:00 - 00:00 4.00 RIGU P PRE NU 7-1/16" BOPs to production tree. Install 7" lubricator. Measure BOP stack. MU kill and choke lines. Secure BOPs with chains. 12/11/2007 00:00 - 03:30 3.50 RIGU P PRE Continue to NU and secure BOPs. Tighen connection between annular and top double gate rams. Perform body pressure test. 03:30 - 12:00 8.50 BOPSU P PRE Pressure test BOP equipment. Test witness waived by J. Crisp. 12:00 - 14:00 2.00 BOPSU N PRE Two hrs of down time due to leaking annular flange and leaking graylock fittings. 14:00 - 16:00 2.00 BOPSU P PRE Hold PJSM to discuss pulling BPV. Rig up DSM lubricator. Engage and pull BPV. No pressure found on tubing under BPV. RD BPV lubricator. Release DSM crew. 16:00 - 19:00 3.00 DHB P DECOMP Spot and rig up slickline unit. Hold PJSM with crews to discuss retrieving down hole plug. Bring tools to rig floor. RU lubricator and PT 19:00 - 21:00 2.00 DHB P DECOMP RIH w/ equalizing prong to 8530' WLM and equalize pressure below 'X' plug. Well is stable 21:00 - 23:30 2.50 DHB P DECOMP RIH w/ GS and latch plug. Work out of nipple, then work thru all other 3.813" restrictions while POOH w/ plug 23:30 - 00:00 0.50 DHB P DECOMP Safety mtg. LD WL tools. LD lubricator. Load out tools and lubricator 12/12/2007 00:00 - 00:20 0.33 DHB P DECOMP Fin RDMO SWS slickline 00:20 - 01:15 0.92 KILL P DECOMP Safety mtg re: RU/bullhead Liquid pack wellbore and dispose of FP fluids to open perfs w/ 250 bbls 90 deg 1 % KCI water at AIR 4.5/2000 psi. FIR 4.0/2000. ISIP 1900 psi, 1 min 700, 5 min 0. SI SV 01:15 - 01:45 0.50 FISH P DECOMP Bring BTT tools to floor 01:45 - 02:30 0.75 FISH N SFAL DECOMP Open SV w/ 23.5 turns. Fill hole w/ 10 bbls. Function test MV Printed: 2/13/2008 2:42:09 PM BP EXPLORATION Operations Summary Report Page 2 of 36 Legal Well Name: C-35 [-35Y~ Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ;Code ~~ NPT I Phase Description of Operations 12/12/2007 01:45 - 02:30 0.75 FISH N SFAL DECOMP and locked up after 7 turns closed and could not reopen. FIII hole w/ 13 bbls. SI swab while WO grease crew 02:30 - 03:45 1.25 BOPSU P DECOMP PU injector. PT existing BTT CTC ~ 36k, 4000 psi. PT packoff and inner reel valve at 3500 psi as part of BOPE test Grease crew serviced MV but could not move MV either and deferred to higher authority 03:45 - 05:00 1.25 WHSUR N DECOMP Valve shop personnel arrive and are not able to move the valve. Open swab, fill well w/ 9 bbls. Visually inspect and see gate is about 1/3 closed. Remove valve handle and use pipewrench to open valve 05:00 - 08:00 3.00 WHSUR N DECOMP WO slickline unit Plan is to install two mechanical barriers (as before), ND and repair/replace the MV 08:00 - 09:00 1.00 WHSUR N SFAL DECOMP Discuss options with town. Decide to leave MV in place. Call DSM to discuss valve integrity and decide to leave MV as is 09:00 - 09:40 0.67 KILL P DECOMP Safety mtg re: RU/bullhead liquid pack wellbore and dispose of FP fluids to open perfs w/ 150 bbls 90 deg 1% KCL Water at IR 4.5bbls/min ~ 2100 psi. WHP bleed to zero in a few minutes. Well on a slight vac. 09:40 - 10:30 0.83 FISH P DECOMP Hold PJSM to discuss BHA make up. Feed well at 1.09 bpm while deploying BHA. Deployed BHA (GS Spear on 2 JTS of PH6) 10:30 - 12:00 1.50 FISH P DECOMP RIH with Fishing BHA, Filling well @.5 bbls/min. 35K # up weight & 22.2K # Down Weight. Tag fish with 4K # ~ 8567' Pick up Fish with 48K # pull. 12:00 - 14:40 2.67 FISH P DECOMP POH w/ Fish up Weight of 38K #. Tag at 8448' OP to 4950 Slack Off and continue to POH at 38K #. 14:40 - 16:00 1.33 FISH P DECOMP BHA at rig Floor. PJSM on LD of 2 7/8" FL4S 6.16 #/FT, L-80 Liner. LD BHA and Stand Back CT Injector LD 10 JTS 2 7/8" and Liner and Deployment sleeve. Total length: 331.23' 16:00 - 16:50 0.83 ZONISO P DECOMP PJSM on RU of Cementing Nozzle and Picking up the injector. MU Cementing BHA and PU Injector 16:50 - 18:45 1.92 ZONISO P DECOMP RIH with Cement Nozzle circ 0.8 bpm w/ 80% returns 18:45 - 19:15 0.50 ZONISO P DECOMP Park at 8600'. Inj test 0.5/1200 and whp was continuing to rise. RIH from 8600' 2.0/2000 holding 500 psi whp and jetting to TOL stub at 8900' ELMD. Tagged up at 8743' CTD 2.0/1.85/2120 46k. Jet on assumed cement sheath 2.75/2.50/2800 w/o by and made no progress. Discuss. Will UR first before cementing. Release SWS cementers, but left equipment rigged up 19:15 - 20:55 1.67 CLEAN P DECOMP POOH circ 1.1/300 20:55 - 21:10 0.25 CLEAN P DECOMP LD nozzle assy 21:10 - 21:35 0.42 CLEAN P DECOMP MU underreamer assy 21:35 - 23:10 1.58 CLEAN P DECOMP RIH w/ BHA #3 circ 0.27/110 to 8700' CTD. PUH 44k 23:10 - 00:00 0.83 CLEAN P DECOMP Start pump 2.42/2330 while PUH 43.5k Ream in hole from 8670' and stall twice at 8681.8'. Ease in hole 2.43/2.43/2095 at 60'/hr. UR to 8705' at midnite w/ no noticeable cement 12/13/2007 00:00 - 00:30 0.50 CLEAN P DECOMP Continue UR from 8705' 2.42/2090 w/full returns 00:30 - 04:35 4.08 CLEAN P DECOMP First MW at 8744' and stall at 8746.9'. Begin to make slow hole, but have lots of stalls. Spend 1.5 hrs at 8749.5' w/ no Printed: 2/13/2008 2:42:09 PM • BP EXPLORATION Page 3 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ~~ Code ; NPT Phase Description of Operations _- 12/13/2007 00:30 - 04:35 4.08 CLEAN P DECOMP further progress (26 total stalls) PVT 389 04:35 - 07:00 2.42 CLEAN P DECOMP POOH filling from BS 07:00 - 09:20 2.33 CLEAN P DECOMP Discuse options with Town, Baker, and Weatherford. WO Weatherford Undereamer. Decide to RIH w/ 3 3/4" PDC bit to open hole and evaluate cement strength. 09:20 - 10:10 0.83 CLEAN P DECOMP PJSM on RU of BHA and PU of Injector MU 3 3/4" PDC bit BHA PU Injector 10:10 - 11:45 1.58 CLEAN P DECOMP RIH w/ PDC bit BHA while pumping .3 bbls/min ~ 100fpm UP Weight 37.5K # Down Weight 20.5K # ~ .44bbls/min Free spin CP 2300psi ~ 2.6bbls/min Tag ~ 8752 11:45 - 13:45 2.00 CLEAN P DECOMP Mill ahead with very little motor work. CP of 2300 psi, initial ROP 1.6 ft/min drill 10 ft with final ROP of 2.3ft/min, started pumping 10bb1 pill of 1.51b biozan at 11:55 8762' PU and Circulate continue to mill 10 ft at a time Picking up to circulate each time 8772' -Continue Milling with CP Of 2100psi at 2.6 bbls/min, ROP of 2.5 fpm to 8783' PU and circulate. repeating to 8795- CP 2325 psi pump 2395psi ROP of 2.6fUmin, DN weight of 18K # 13:10 pump 10 bbls pill, milling C«3 8863 ft still very little motor work, CP 2340 PSI, PP 2380 psi ~ 2.6 bbls/min, 19K # DWN Weight ROP 2.4 Wmin 8899.5' - POH to 8897 circulating pill to bottom. 13:45 - 15:30 1.75 CLEAN P DECOMP POH while pumping 2.6 bbls/min at a CP of 2250 psi EOP Flag at 8800 FT. Hold PJSM in ops cab. 15:30 - 16:20 0.83 CLEAN P DECOMP AT surface . Get off well. Unstab coil. LD X-treme mtr and DS49 bit. MU Baker mtr with Weatherford Reeves undereamer. Blades dressed to cut 6.0' inside liner. 16:20 - 17:50 1.50 CLEAN P DECOMP RIH with Undereamer BHA Stop from 16:30 to 16:40 to tighten inside retaining bolts in the reel. Continue RIH. 17:50 - 21:00 3.17 CLEAN P DECOMP Begin UR from 8742' 2.52/3500 and ream cautiously by 8744-50' w/minor MW and one stall at 8749.4'. UR in hole at 60'/hr to 8896' CTD w/ <100 psi MW and no stalls over the entire interval. See flag on depth. Pump 31 bbl biozan pill before reaching TD 21:00 - 21:45 0.75 CLEAN P DECOMP Slow backream/ream 36.9k/17.3k 2.55/3530 w/full returns over 8865-8895' while circ pill to surface. Backream to 8630'. Dumped 50 bbls of pill that had 0.1 ppg max higher density than KCI 21:45 - 23:30 1.75 CLEAN P DECOMP POH filling from the BS 23:30 - 00:00 0.50 CLEAN P DECOMP LD UR'ing assy. UR teeth on bottom blades were chipped, but are satisfactory for another short run 12/14/2007 00:00 - 00:30 0.50 PXA P DECOMP Blow down kill line. MU 3" nozzle assy 00:30 - 02:20 1.83 PXA P DECOMP RIH w/ BHA #5 circ 0.71/175. See flag at 8815' and did not correct (-4'). Tag at 8897' Safety mtg re: cement plug 02:20 - 02:30 0.17 PXA P DECOMP PUH to 8850' 38.7k. Injection test at 0.5 bpm took 2.0 bbls to reach 1000 psi. IA rose from 170 to 535 psi and bled down Printed: 2/13/2008 2:42:09 PM • BP EXPLORATION Page 4 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code j NPT ; Phase Description of Operations ! --- 12/14/2007 02:20 - 02:30 0.17 PXA P _ _ DECOMP when whp was bled off. ISIP 950, two minutes 730 psi. Pump biozan to reel 02:30 - 03:00 0.50 PXA P DECOMP SWS cementers pump 5 bbls FW to reel. PT ~ 4000. SWS load CT w/ 9 bbls 17.0 ppg 'G' cement at 77.5E w/ 3:41 TT at 1.0/280 and displace w/ 10 bbls FW 03:00 - 03:30 0.50 PXA P DECOMP Rig fin displace cement 2.54/2.43/2400 w/ 20 bbls biozan followed by KCI while RIH from 8850'. Lay in cement at 1.5/300 from 8896' to 8660'. PUH to safety at 8500' CIP 0330 hrs 03:30 - 04:10 0.67 PXA P DECOMP Circ 0.43/120 and WOC for 15 min. IA 176, OA 0 PUH 3'/min, close choke and pressure up wellbore w/ 2.9 bbls. SD pump when whp reached 1180 psi. IA was tracking and was at 1290 psi. Park and monitor whp=930, IA=1080 for 10 min w/ less than 5 psi bleed off on each. Bleed off whp to zero 04:10 - 04:30 0.33 PXA P DECOMP PUH 40.2k and circ 0.5/140 while wo IA to bleed down and had 1/1 returns again at 175 psi. RIH diluting cement w/ 20 bbls biozan 1.0/400 to 8890' 04:30 - 06:45 2.25 PXA P DECOMP POH jetting 2.5/1830 while chase cement to surface. Dumped -60 bbls of cement (up to 11.3 ppg) contaminated KCI 06:45 - 07:15 0.50 PXA P DECOMP Hold PJSM. At surface. Get off well. LD nozzle assembly. 07:15 - 09:00 1.75 PXA N DECOMP Blowback reel from floor. Clean out reel house hard line manifold from cement plugs. 09:00 - 09:30 0.50 PXA P DECOMP SB Injector. Unstab coil. LD cement nozzle, RU swizzle stick to clean out BOP. PU Injector. 09:30 - 09:50 0.33 PXA N DECOMP PT Reel House hard lines to 500 psi low / 4500 psi high. Wet at 1000 psi. tighten hammer union and repeat. Test wet at same union. retighten, and PT joint, test good. 09:50 - 10:50 1.00 PXA P DECOMP BOP clean out, max rates of 3.6 bbls/min and CP 3200 psi. 8 passes at 1.5 ft/min. 100 psi on WH Pressure down and function BOP rams. Cirulate at 3.5 bbls/min Repeat. Get a lot of cement/material back over shaker. 10:50 - 11:05 0.25 PXA P DECOMP Stand Back injector, and LD Swizzle stick. 11:05 - 14:35 3.50 PXA N DECOMP Waiting on cement. 14:35 - 15:45 1.17 CLEAN P DECOMP PJSM on RU of Underreamer BHA and PU of injector. PU underreamer BHA. PU Injector. 15:45 - 17:10 1.42 CLEAN P DECOMP RIH with UR BHA to 8,000 ft and continue to WOC 17:10 - 17:30 0.33 CLEAN N DECOMP WOC 17:30 - 18:05 0.58 CLEAN P DECOMP Continue to RIH for Underreaming opps. Strat pumping at 8650 ft. free spin rates of CP 3430 and PP of 3490 C~3 2.6 bbls/min. pump 10 bbls Biozan pill ~ 8800 ft slow to 5 ft/min ROP. pump 2nd 10 bbl Biozan Pill 18:05 - 18:20 0.25 CLEAN P DECOMP 8885 CP 3800 psi spike slow down ROP to .5 ft/min, CP at 3400 psi. Stall at 8891'. UR hard cement to 8895.0' CTD while start final 15 bbl biozan pill 18:20 - 19:20 1.00 CLEAN P DECOMP Slow backream/ream 39.2k/17.3k 2.56/3470 w/full returns over 8865-8895' while chase pill to surface. Backream to 8730'. Minimal cement fines, no fluid needed to be dumped PVT 310 Printed: 2/13/2008 2:42:09 PM ` • z BP EXPLORATION Page 5 of 36 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To C-35 C-35 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Hours Task ~ Code NPT i 12/14/2007 18:20 - 19:20 1.00 CLEAN P 19:20 - 21:10 1.83 CLEAN P 21:10 - 21:50 0.67 CLEAN P 21:50 - 22:05 0.25 STWHIP P 22:05 - 23:30 1.42 STWHIP P 23:30 - 00:00 0.50 STWHIP P 12/15/2007 00:00 - 01:30 1.50 STWHIP P 01:30 - 03:00 1.50 STWHIP N 03:00 - 04:00 1.00 STWHIP N 04:00 - 05:00 1.00 STWHIP N 05:00 - 07:00 2.00 STWHIP P 07:00 - 07:50 I 0.831 STWHIPI P 07:50 - 08:40 0.83 STWHIP P 08:40 - 10:10 1.50 CASE P 10:10 - 12:20 I 2.171 PULL I P 12:20 - 13:20 I 1.00 PULL I P 13:20 - 14:35 I 1.25 I PULL I P 14:35 - 15:40 I 1.081 PULL I P 15:40 - 16:50 I 1.171 PULL I P 16:50 - 18:15 I 1.42 I PULL I N 18:15 - 20:30 2.25 PULL P 20:30 - 21:30 1.00 PULL P SFAL Spud Date: 2/15/1986 Start: 12/6/2007 End: 1/29/2007 Rig Release: 1/29/2008 Rig Number: .Phase Description of Operations DECOMP IA 198 DECOMP POOH filling from BS DECOMP LD UR assy and load out BTT tools IA 170 DECOMP Safety mtg re: RU slickline and run caliper log DECOMP RU SWS lubricator and PDS tool string DECOMP RIH w/ PDS GR/caliper tool on SWS slickline DECOMP Continue to RIH w/ PDS GR/caliper. SWS had a breakdown related to their mechanical depth counter. The PDS tool is preset to open the caliper arms after a planned delay (which was 1.5 hrs to RIH to PBD) Since it took approximately 30 minutes to fix the counter, the tool did not reach PBD in time, so had a misrun DECOMP Wait for arms to close. POOH w/ PDS caliper DECOMP Remove caliper tool and reprogram DECOMP RIH w/ PDS GR/caliper tool DECOMP Tag at 8898 ft SLM log to 7950 ft. POH DECOMP PJSM on unstabbing SL lubricator, wait on SL crew change, have PJSM with rig crew and SL crew about RD of SL tools and Move Out of SL. DECOMP RD SL tools and lubricator. DECOMP PJSM on PT of 9 5/8" casing. PT 9-5/8" casing (IA) and chart for 30 min. Initial SICP: 3028 psi start. 2993 psi after 15 min 2978 psi after 30 min Summary: 50 psi pressure drop in 30 minutes 35 psi pressure drop in first 15 minutes 14 psi pressure drop in last 15 minutes Pressure drop in last 15 min is < one half that of the first 15 min. Test passed. Slowly bleed down tbg and IA pressures to zero. DECOMP PJSM on rig up of E line tools. RU E Line tools and Lubricator for 4 1/2" tubing hole punch. DECOMP RIH with E Line punch tool and corelate depth to ccl log to hole punch depth of 8424 ft. DECOMP Fire E Line Punch tool. POH and RD punch tools. DECOMP PJSM & RU to flow test down IA into 4 12" tubing through new punch holes. establish circulation at 1 bbls/min. pump press 1050 psi IA press 1040 psi. f~ 2 bbls/min PP 1400 psi DECOMP PJSM & RU to run string shoot. RIH with String Shot. DECOMP POH with String shott due to problems with electical faulting in e line. Rehead a-line DECOMP RIH w/ string shot. Log into position and shoot string shot centered across 8449' IA 148 DECOMP Safety mtg LD string shot. MU chemical cutter Printed: 2/13/2008 2:42:09 PM L • BP EXPLORATION Page 6 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/15/2007 21:30 - 00:00 2.50 PULL P DECOMP RIH w/ chemical cutter and cut 4-1/2" tubing in the middle of the first jt above the packer at 8449'. Good indication. Release slips, POH w/ chemical cutter 12/16/2007 00:00 - 01:00 1.00 PULL P DECOMP Safety mtg re: LD chemical cutter LD chemical cutter. RDMO SWS a-line 01:00 - 01.:30 0.50 PULL P DECOMP Pull mousehole. RU to circ 01:30 - 01:45 0.25 PULL P DECOMP Safety mtg re: displace wellbore 01:45 - 02:30 0.75 PULL P DECOMP Blow CT back w/air Spot vac trucks 02:30 - 07:45 5.25 PULL P DECOMP Bleed off 130 psi IAP to tiger tank. Begin circ 1 %KCI at 90 deg down the tubing taking returns from the IA. Initial rate 4.9 bpm ~ 2000 psi. Out densiometer showed 6.3 ppg initial returns, increasing to 6.8 ppg after 50 bbls and 8.5 ppg after 150 bbls. Red rate to 2.2 bpm to keep pump pressure under 3000 psi. Further reduced pump rate to 1.5 bpm after 250 bbls pumped. Pumped 150 bbls fresh 1 % KCL followed by 580 bbls 1 %KCI w/ Safe Surf-O followed by 150 bbls fresh 1 %KCI 07:45 - 12:00 4.25 PULL P DECOMP Continue to circulate KCL w/ Safe Surf-O at 3090 psi at 1.61 in/out. Displace tbg with neat KCL. Leave Safe-Surf-O in IA. 12:00 - 14:45 2.75 PULL P DECOMP Hold PJSM with N2 crew. RU N2 unit. Pump 60 bbls fresh water, 10 gals MI corrosion inhabiter (KI-3882), 10 bbls 60/40 McOH to flush and inhibit reel. Blow down reel with N2. Finish emptying tiger tank and pits. 14:45 - 15:00 0.25 PULL P DECOMP Hold PJSM to discuss unstabing coil. Get of well. Install stabing grapple. 15:00 - 15:30 0.50 BOPSU P DECOMP Hold PJSM. Set two way check valve (dry rod) wtih DSM crew. 15:30 - 17:00 1.50 PULL P DECOMP Rig up to unstab coil from injector. Install and pull test grapple. Spool coil back onto reel. Instal shipping bar and secure coil. Leave grapple in place. 17:00 - 18:00 1.00 BOPSU P DECOMP Rig up to test two way check from below and above. Test to 500 psi from below. Held solid. Would not hold pressure from above 18:00 - 20:30 2.50 BOPSU N DECOMP WO DSM Valve Crew Remove gooseneck, legs, set injector on floor Fin vac pits, warm up moving system 20:30 - 22:30 2.00 BOPSU N DECOMP Safety mtg. RU and PT DSM lubricator. Pull BPV. No pressure on well, hole is full. Dryrod TWC. PT from below at 500 psi. PT from above at 3500 psi. RDMO DSM 22:30 - 00:00 1.50 BOPSU P DECOMP Safety mtg ND 7-1/16" BOPE 12/17/2007 00:00 - 01:30 1.50 BOPSU P DECOMP Continue ND 7-1/16" BOPE 01:30 - 01:45 0.25 BOPSU P DECOMP Safety mtg re: move off well, set 13-5/8" BOPE 01:45 - 05:30 3.75 MOB P DECOMP Move rig off well leaving enough room for crane to work Lower 7-1/16" BOPE onto rig mats and set on traveling skid w/ loader. Set shooting flange in cellar and PU w/ tugger Meanwhile, VECO 140T crane pick 13-5/8" BOPE off traveling skid and set behind well Move rig back over well and set down 05:30 - 06:30 1.00 BOPSU P DECOMP RU lines to satellite camp. Berm up cellar. Spot cuttings box 06:30 - 09:30 3.00 BOPSU P DECOMP Remove IA valve from wellhead to allow clearance for 13-5/8" BOPs. Printed: 2/13/2008 2:42:09 PM • BP EXPLORATION Page 7 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations 12/17/2007 06:30 - 09:30 3.00 BOPSU P DECOMP Continue to rig up equipment after moving rig back on well. Replace mouse hole. 09:30 - 12:30 3.00 BOPSU P DECOMP Thaw tree valves with steam hose. Remove valves and tubing head adapter. Verifty landing thread with landing joint crossover. Remove tree from cellar. 12:30 - 14:30 2.00 BOPSU P DECOMP Skid 13-5/8" BOPs into cellar. Lift and place BOPs on wellhead. 14:30 - 18:30 4.00 BOPSU P DECOMP NU BOPS. 18:30 - 21:00 2.50 BOPSU P DECOMP NU shooting flange, NU lubricator Offload 290 bbls SW in pits 21:00 - 22:30 1.50 BOPSU P DECOMP Function test BOPE. Have trouble w/ hydraulics/valves. Steam Load first row of tubing in pipeshed 22:30 - 00:00 1.50 BOPSU P DECOMP Perform shell test. Had leak on shooting flange (will need to change it out before pulling TWC). Install test joint. Test BOPE. Chuck Scheve waived the State's right to witness the test Begin loading jewelry into pipeshed 12/18/2007 00:00 - 04:00 4.00 BOPSU P DECOMP Finish BOPE test Fin load completion jewelry into pipeshed and rack up on ODS of catwalk 04:00 - 05:30 1.50 BOPSU P DECOMP Attempt to get shooting flange to hold pressure w/o success Safety mtg. ND shooting flange 05:30 - 08:45 3.25 BOPSU P DECOMP NU replacement shooting flange from Tool Sercie. This is a one piece design with out the seal assembly that leaked on the first flange. Install 7-1/16" lubricator up through floor. Pressure test lubricator and flange. 08:45 - 09:15 0.50 BOPSU P DECOMP Wait on DSM valve crew to arrive. 09:15 - 12:15 3.00 BOPSU P DECOMP PJSM with DSM crew. PU lubricator. MU on floor. Pressure test to 500 psi. Engage and pull two way check from tbg hanger profile. RD DSM lubricator and tools. 12:15 - 14:30 2.25 BOPSU P DECOMP ND shooting flange and load out 14:30 - 16:15 1.75 BOPSU P DECOMP NU riser, fill w/ SW 16:15 - 17:00 0.75 PULL P DECOMP MU landing jt w/ BTC XO. Screw into hanger Safety mtg FMC BOLDS 17:00 - 17:45 0.75 PULL P DECOMP Pull hanger to rig floor. Started moving at 82k. Pulled to 110k where assumed chemical cut finished parting. Pull to floor w/ 92k. Find encapsulated SSSV lines looks to be in good shape 17:45 - 18:00 0.25 PULL P DECOMP RU to circ while crews change out 18:00 - 18:20 0.33 PULL P DECOMP PJSM & C/O with day crew. 18:20 - 19:00 0.67 PULL P DECOMP Wait for water. Bring 9-5/8" casing packoffs into welding shop & warm it up. 19:00 - 19:50 0.83 PULL P DECOMP Back in vac truck. Fill out fluid transfer paper work. C/O day with night crew for vac truck operator. 19:50 - 00:00 4.17 PULL P DECOMP Begin pumping down the tubing & verify circulation while taking returns to the tiger tank. Increase rate to 4 bpm ~ 3800 psi on the tubing & 60 psi on the backside. At 3800 psi the tubing started to hydraulic out of the ground, thereby scaring the entire rig crew. Stop pumping & open the Baker choke to Printed: 2/13/2008 2:42:09 PM • BP EXPLORATION Page 8 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code ~ NPT ~ Phase Description of Operations 12/18/2007 19:50 - 00:00 4.17 PULL P DECOMP relieve the tubing pressure, -aft of travel. Continue to circulate at 1.8bpm C~ 3000psi, discuss with engineer. Bring returns inside & inspect for debris, recovered pieces of encapsulated rubber. At 140bb1s away, stop pumping. Bleed off pressure, flow check. PU on tubing, 106k to move & -Eft of travel. Circulate down tubing to confirm pressures (before reverse circulating), 1.8bpm & stable at 1500psi. Increase rate 2.25bpm & continue to pump the long way taking returns to the tiger tank. Plan forward is to circulate out Safe-Surf-o & then recipricate pipe while taking returns to the pits in an attempt to clean up backside debris. 12/19/2007 00:00 - 02:00 2.00 PULL P DECOMP Pumped 585bb1s & returns have cleaned up. Bring returns inside. Try to move pipe down. Won't move, stacking out. PU ~ 60k (40k less than previous). Try to get connection lower to floor to working level. Try to reciprocate pipe up & down while trying to vary pump rate (limit to 2500psi due to hydraulic forces on tubing). Call out Halliburton hand to rig. 02:00 - 04:20 2.33 PULL P DECOMP RU spooler & equipment. Achieve 6 bpm @ 1300psi. Returns are long large rubber pieces and FCO material (scale, schmoo, fine sand & paraffin). Not able to maintain 6bpm (5min max), slowly increases to 2500psi while reducing rate, once 2500psi is achieved the tubing hydraulics OOH then falls down in a violent jar like activity. Slowly reciprocate pipe up & down while pumping & get the tubing hanger connection to a workable level. Not able to maintain sufficient AV's & FCO material is falling back downhole. 04:20 - 04:35 0.25 PULL P DECOMP Flow check well & PJSM regarding handling tubing. 04:35 - 07:15 2.67 PULL P DECOMP Break off SSSV control line & cap it. Let balance line u-tube (due to down hole leak) & cap it. LD landing joint and hanger. Break off 4-1/2" butress by 3-1/2" IF x-over on tubing hanger & MU floor valve. 07:15 - 07:25 0.17 PULL P DECOMP Safety mtg re: Pull completion 07:25 - 09:00 1.58 PULL P DECOMP Start puling tubing. Hook up control line to spooler. Have to pull slow due to swabbing. Weight varies between 92-110k. Remove control line clamps. LD 10 jts 09:00 - 10:00 1.00 PULL P DECOMP CL started bunching up. RU tugger to pull CL. Got a good wad of CL at the bottom of jt 12. Lost most of the clamp (and the pin) off of jt 12. Take an hour to remove CL 10:00 - 11:15 1.25 PULL P DECOMP Resume pulling tubing using tugger on CL. No more clamps are being recovered (clamps were installed on top of every other collar) 11:15 - 12:20 1.08 PULL P DECOMP On jt #19, lost one control line. Still pullling at a normal wt of 78k. Pulling on tugger at max. Spend some time trying to get centered up in stack. Lost the second CL at the bottom of #19 12:20 - 13:10 0.83 PULL P DECOMP POH from joint #20 and did not recover any control line or clamps, etc. Look frequently to see if anything is visible in the stack 13:10 - 14:00 0.83 PULL P DECOMP Got joint #29 completely OOH, but had to go to 40k over (112k). Able to go back in hole. Install head pin and circ while discuss. After wellbore pressured up to 2000 psi, red rate and circ 2.0/1640 and get small pieces of CL rubber back 14:00 - 15:30 1.50 PULL P DECOMP Load out 28 jts of used 4-1/2" tubing which was in good shape externally. The bottom of each pin end was corroding Printed: 2/13/2008 2:42:09 PM BP EXPLORATION Operations Summary Report Page 9 of 36 Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task j Code NPT Phase Description of Operations 12/19/2007 14:00 - 15:30 1.50 PULL P DECOMP 15:30 - 20:45 5.25 PULL P DECOMP 20:45 - 00:00 3.25 PULL P DECOMP 12/20/2007 00:00 - 01:40 1.67 PULL P DECOMP 01:40 - 02:30 0.83 PULL P DECOMP 02:30 - 03:30 1.00 PULL P DECOMP 03:30 - 04:00 0.50 PULL P DECOMP 04:00 - 07:30 3.50 PULL P DECOMP 07:30 - 09:00 1.50 PULL C DECOMP 09:00 - 11:00 2.00 PULL C DECOMP 11:00 - 14:50 3.83 PULL C DECOMP 14:50 - 15:05 0.25 PULL C DECOMP 15:05 - 17:45 2.67 PULL C DECOMP 17:45 - 18:20 0.58 PULL C DECOMP 18:20 - 22:00 3.67 PULL C DECOMP 22:00 - 22:20 0.33 PULL C DECOMP 22:20 - 00:00 1.67 PULL C DECOMP Load out 2nd row of 4-1/2" new completion to allow better working conditions while using the catwalk (assuming we will need to pick up DP if we get the completion out of the hole) Fin circ 260 bbls Drain stack and look for debris. Can see a wad about 30' below the floor in the wellhead Begin working pipe and look for movement of the wad-none. Begin laying down singles after reciprocating each 3-4 times. Max up wt is 40k over or 110k LD SSSV, no control line recovered. Can still see a wad of debris below the RF. Continue to LD tubing. Pulling slower starting at jt # 57 & having to work each joint, taking - 30min per jt. Continue to pull 4-1/2" tubing from well - 30 to 45 min per jt. On jt # 66 & very little movement. RU to circulate down tubing. Recovered rubber pieces. Work pipe while circulating at 0.5 bpm, 800-1000psi. Continue to pull 4-1/2" tubing. Pull jts 66,67,68 - 5min perjt. Slow pulling & working every joint on jts 69 & 70. RU to circulate down tubing. Recovered rubber pieces. Work pipe while circulating. Continue to pull 4-1/2" tubing. Work jt 71. Set tubing in slips & turn 3 times -rotates fine, no backlash. Attempt to circ and get minimal returns. After 6 bbls the wellbore pressures up to 1800 psi where the tubing tries to hydraulic out of the hole. Work to -50k over or 120k max and getting no movement. Can get jt #71 connection to the floor, but no futher. The first GLM is just below jt #74. It is assumed that there is a wad of -1600' of dual encapsulated control line plus -20 control line clamps/pins between the top of the GLM and the wellhead which is preventing any further uphole movement Work occassionally while discuss in AM call and in subsequent conference call Plan forward will be to RBIH with the completion, set it on the 4-1/2" stub at 8449', chemical cut the pup above the top GLM (-3000'), then pull the tubing back out of the hole. This will allow room for fishing 'the wad' in the 9-5/8" with DP. Will use a reconditioned string of 4-1/2" BTC tubing rather than the 4-1/2" tubing pulled from the well due to the corroded pins. This will also allow the largest OD (3-5/8") chemical cutter to be run (vs 3-1/2 DP) Order tubulars, prepare pipeshed Load pipeshed w/ 90 jts 4-1/2" 12.6# L-80 IBT R3 Cond B tubing. Steam, drift and strap Safety mtg re: run tubing RD TIW valve and circ equipment. Run 42 jts 4-1/2" tubing. Lose 8k midway down on each jt and tubing overflows KWTdrlll-discuss. SD for crew change Continue to run 4-1/2" tubing. Add in 2-10ft & 1-5ft pup joint & space out with full joint below RF. 83k up wt, 72k down wt. PU to 20k & set in slips. PJSM regarding RU a-line. RU a-line unit consisting of x-over,puping sub, line wiper. MU Printed: 2/13/2008 2:42:09 PM • i BP EXPLORATION Page 10 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date j From - To Hours j Task Code NPT Phase Description of Operations 12/20/2007 22:20 - 00:00 1.67 PULL C DECOMP ccl & string shot tool string & stab onto 4-1/2" tubing. 12/21/2007 00:00 - 01:15 1.25 PULL C DECOMP RIH w/ a-line. Correlate to pup jts & GLM ~ 2976ft. String shot C~ 2966ft to 2976ft (10ft pup above GLM). Good indication of firing. 01:15 - 01:45 0.50 PULL C DECOMP POH w/ a-line. 01:45 - 02:00 0.25 PULL C DECOMP RD string shot tool string (all shot fired). 02:00 - 03:00 1.00 PULL X DFAL DECOMP RU 3-5/8" chem cutter. MU ccl &chem cut string & stab onto 4-1/2" tubing. 03:00 - 04:00 1.00 PULL X DFAL DECOMP RIH w/ a-line. Correlate to pup jts & GLM ~ 2976ft. Attempt to chem cut with no luck. 04:00 - 04:45 0.75 PULL X DFAL DECOMP POH w/ a-line. 04:45 - 04:55 0.17 PULL X DFAL DECOMP Stop at 300ft & perform PJSM regarding miss fire of chem cutter. 04:55 - 05:45 0.83 PULL X DFAL DECOMP Suit up in PPE gear. Pop off well & clear RF. Continue to POH w/ a-line. Inspect chem cutter. 05:45 - 06:00 0.25 PULL X DFAL DECOMP Chem cutter not fired. Break off tool string & dog collar chem cutter in mouse hole. Lower down upper portion of tool string & inspect on the ground. Appears to be an electrical connection. Test tools -good test. (Igniter'thru-rod' was missing-see Scorecard) 06:00 - 06:30 0.50 PULL X DFAL DECOMP Crew change/safety mtg before MU chem cutter 06:30 - 08:30 2.00 PULL C DECOMP MU 3-5/8" chemical cutter. RIH and cut tubing at 2973' which is 2' below the collar above the pup on GLM #6. POOH w/ cutter 08:30 - 08:45 0.25 PULL C DECOMP Safety mtg before LD cutter 08:45 - 09:15 0.50 PULL C DECOMP LD a-line tools. Rig back SWS floor tools 09:15 - 09:30 0.25 PULL C DECOMP Check to see if pipe was cut and still had 82k. Work pipe several times until losing 50k with bottom about 3' above the stub (may not be as round as it was ...) 09:30 - 10:00 0.50 PULL C DECOMP RD SWS Fish out several floating pieces of rubber debris. Thaw frozen kill line (-43F ambient) 10:00 - 10:15 0.25 PULL C DECOMP Attempt to remove excess 4-1/2" tubing workstring from pipeshed, but SWS unit quit running as they attempted to leave. Get heater off of main camp and assist in getting equipment running 10:15 - 12:00 1.75 PULL C DECOMP LD space out pups. LD 4-1/2" BTC workstring. See 5k overpull midway on each joint starting out. By 10 joints out were having 18k overpulls. LD 11 jts. KWT drill 12:00 - 13:15 1.25 PULL C DECOMP Unload pipeshed of 30 jts of BTC workstring and 39 jts of Vam Top completion 13:15 - 15:00 1.75 PULL C DECOMP Resume pulling tubing and see 10-18k over midway on each joint. Load out of pipeshed when ODS row is full 15:00 - 18:00 3.00 PULL C DECOMP Finish pulling all 69 jts of 4-1/2" workstring and 4 jts of old completion along with the 2' stub of the pup jt above GLM 6. Chemical cutter had fully cut thru 90% of the circumference leaving about 1 "+ that was still attached Unload pipeshed of all 4-1/2" tubulars. Load in 6 jts 3-1/2 DP and 2 Dc's 18:00 - 18:20 0.33 FISH C DECOMP C/O with day crew. PJSM regarding handling Kelly & BHA. 18:20 - 20:55 2.58 FISH C DECOMP Load Kelly into pipe shed. Steam & strap 6 jts of DP & 2 DC's. Hang weight bucket on tong line. RU spinners. RU snub lines. MU floor valve. Bring Baker BHA to RF & steam connections. Printed: 2/13/2008 2:42:09 PM BP EXPLORATION Page 11 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ~; Hours Task ~ Code NPT Phase Description of Operations 12/21/2007 20:55 - 21:10 0.25 FISH C 21:10 - 22:00 0.83 FISH C 22:00 - 22:35 I 0.581 FISH I C 22:35 - 22:45 0.17 FISH C 22:45 - 00:00 1.25 FISH C 12/22/2007 00:00 - 00:20 0.33 FISH C 00:20 - 00:35 0.25 FISH C 00:35 - 00:50 0.25 FISH C 00:50 - 01:30 0.67 FISH C 01:30 - 03:10 I 1.67 I FISH I C 03:10 - 05:20 I 2.17 FISH C 05:20 - 07:30 2.17 FISH C 07:30 - 09:00 1.50 FISH C 09:00 - 09:30 0.50 FISH C 09:30 - 18:00 I 8.501 FISH I C 18:00 - 18:20 0.33 FISH C 18:20 - 19:00 0.67 FISH C 19:00 - 19:15 0.25 FISH C 19:15 - 19:40 0.42 FISH C 19:40 - 20:40 1.00 FISH C 20:40 - 21:00 0.33 FISH C 21:00 - 00:00 3.00 FISH C 12/23/2007 00:00 - 00:50 0.83 FISH C 00:50 - 04:20 3.50 FISH C 04:20 - 04:45 0.42 FISH C 04:45 - 05:40 0.92 FISH C 05:40 - 06:00 ~ 0.331 FISH ~ C 06:00 - 06:30 0.50 FISH C 06:30 - 08:30 2.00 FISH C 08:30 - 10:00 1.50 FISH C DECOMP PJSM regarding handling 3-1/2" DP & MU BHA. DECOMP MU BHA consisting of rope spear, stop ring, top sub, bumper sub, pump out sub. DECOMP PU & drift 3-1/2" DP. PU 1 jt & reciprocate across tubing hanger & POH to inspect spear - no wire. RIH w/ 3-1/2" DP. DECOMP Tag up on the 3rd joint of DP - 96ft below RF. POH. DECOMP Recovered - 200ft of wire, -4 clamps, 1 clamp pin. Use wire clamp to tie off to remaining wire & use tugger to fish out 100ft wire. Clean up rope spear & clear RF of debris. DECOMP Continue to clean up rope spear. DECOMP Place BHA in hole & MU 3-1/2" DP. Tag up on 2nd jt. DECOMP POH DECOMP Recovered - 200ft of wire, -2 clamps. Clean rope spear & clear RF of debris. DECOMP RIH w/ DP. Tag up on 2nd jt, sliding down hole, push on it, spin it. POH, popped off ~ tubing hanger. RIH w/ single DC & DP. Tag up on 2nd jt & push on it, spin it. POH, popped off @ tubing hanger. RIH w/ 2 DC's & DP. Tag up on 3rd jt. Push on it, can go no further. Spin it, can't spin it. POH - 6k over. DECOMP Stand back DP & DC's in the derrick. Recovered _ 200ft of wire, ~2 clamps, 7 clamp pins. Clean rope spear & clear RF of debris. Bring in 9 more DC & steam/strap them. DECOMP MU BHA #11. Tag up at -120' DECOMP POH. Recover another -200' of wire w/ 2 clamps DECOMP LD spear assy and DC. Move stand of DC in derrick to other side Environmental advisor, Laura Barlow, okays disposal of CL to metal dumpster DECOMP RU kelly. Break all connections and redope. PT upper and lower kelly cock. Blow down kelly. DECOMP C/O with day crew. PJSM for putting Kelly into shuck. DECOMP Put Kelly into shuck. DECOMP PJSM for MU BHA. DECOMP MU BHA #12. PU spear assy and DC's. Tag up at 100ft. PU - nofish, push on it. DECOMP Continue to PU DC's. DECOMP RIH with DP. RIH with 6 jts of DP (all that is in the pipe shed). DECOMP Kick while tripping drill. RU to CBU. CBU ~ 5bpm, recovering substantial amounts of rubber. Simultaneously conduct PJSM loading pipeshed w/ DP. Clean pipe shed of control line. Load pipeshed w/ 3-1/2" DP, steam & strap each jt. DECOMP Continue to steam & strap 3-1/2" DP. DECOMP RU air slips. Continue to RIH w/ 3-1/2" DP. DECOMP PU wt = 48k. Tag up on the last 15 ft of jt # 83, 2990ft. Clean PU of 48k. Spin RT 1 turn, torqued up. LD single. DECOMP RU &CBU C~ 6bpm / 840psi. Simultaneously load more DP into pipeshed, steam & strap same. DECOMP Break off circulating hose. Spin RT - 4 turns & no torque (assume tip of spear inside tubing stub). Flow check well. DECOMP Crew chg/safety mtg DECOMP POOH w/ DP DECOMP Stand back DC's Printed: 2/13/2008 2:42:09 PM BP EXPLORATION Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Event Name: REENTER+COMPLETE Start: 12/6/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date I From - To I Hours I Task ! Code I NPT I Phase 12/23/2007 10:00 - 10:30 0.50 FISH C 10:30 - 12:00 1.50 FISH C 12:00 - 12:15 0.25 FISH C 12:15 - 13:00 0.75 FISH C 13:00 - 14:45 1.75 FISH C 14:45 - 17:00 2.25 FISH C 17:00 - 18:00 1.00 FISH C 18:00 - 18:20 0.33 FISH C 18:20 - 19:00 0.67 FISH C 19:00 - 21:00 2.00 FISH C 21:00 - 21:35 I 0.581 FISH I C 21:35 - 22:00 0.42 FISH C 22:00 - 22:30 0.50 FISH C 22:30 - 00:00 1.50 FISH C 12/24/2007 00:00 - 01:00 1.00 FISH C 01:00 - 03:00 I 2.001 FISH I C 03:00 - 06:00 3.00 FISH C 06:00 - 06:15 0.25 FISH C 06:15 - 07:00 0.75 FISH C 07:00 - 08:20 1.33 FISH C 08:20 - 10:20 2.00 FISH C 10:20 - 11:30 1.17 FISH C 11:30 - 15:15 3.75 FISH C 15:15 - 16:30 1.25 FISH C 16:30 - 18:00 1.50 FISH C 18:00 - 18:30 0.50 FISH C 18:30 - 19:30 1.00 FISH C 19:30 - 00:00 4.501 FISH ~ C Page 12 of 36 Spud Date: 2/15/1986 End: 1 /29/2007 Description of Operations DECOMP LD spear assy after having no recovery DECOMP Bring burnover tools to floor DECOMP Nordic crew change/safety mtg DECOMP Finish MU BHA #13 DECOMP MU DC's DECOMP TIH w/ DP DECOMP Tag at w/ jt #83. LD 3 singles. PU kelly and retighten upper connections. PU 2 singles DECOMP Circ during crew change. DECOMP PJSM. Mix up 70bb1 Bio pill. DECOMP PU 2 jts of DP. Circ 40 bbl Bio pill at 4 bpm/400psi while tagging up at 2986ft, 52k up. LD single jt. Pump C~ 4bpm/325psi, spin RT & tag up at 2986ft, work down to 2995ft & set down 4k, torquing up (good indication that we are over the 4-1/2" stub). Stop turning RT & set down 2k. Kelly down. Stop pumping & PU single jt. Resume pumping/turning RT. Tag up & set 5 k down ~ 2995ft, torquing up again. Stop turning RT. DECOMP CBU ~ 6bpm/835 psi. Recovered large pieces of rubber & debris. DECOMP Flow check &PJSM for setting Kelly into shuck & TOH. DECOMP Bring BOT overshot to RF. Blow down Kelly. Set Kelly into shuck. DECOMP TOH, fill hole every 10 stds. DECOMP Continue to TOH. Stand bank 40 stds of DP in derrick. Flow check at 30 stds - (Safe-surf-o suds giving incorrect hole fill). Bring on more SW, vac out cuttings box. RU to slip & cut drill line. DECOMP Stab floor valve. PJSM for slip & cutting drill line. Hang blocks. Release dead man clamp. Remove weight cells. Slip & cut 50ft of drill line. Put back together same. DECOMP Continue to TOH. Stand back 1 std of DP, LD pump out sub & intensifier & 5 stds of collars. Inspect burnover shoe, good indications of tubing stub (metal scarring on inside of burnover shoe). Boot baskets empty. Put together grapple overshot. Fill hole - 5bbls. Clear RF of BOT boot baskets, XO's &burnover shoe. DECOMP Crew change/safety mtg DECOMP MU OS assy BHA #14 DECOMP MU DC's DECOMP TIH w/ 41 stds DP DECOMP PU kelly. Get parameters 52k, 50k circ 1.6/60 RIH and see top at 2987'. Bury extension to 2995'. PUH w/fish on. Set grapple w/ one jar hit at 110k. Blow down and set back kelly DECOMP LD single. TOH (slow) w/ DP. Tite connections DECOMP Stand back DC's DECOMP Fish is at surface. LD fishing BHA. No additional CL's etc recovered DECOMP C/O w/ day crew. PJSM regarding handling tubing. DECOMP Grease blocks/service rig. RD 3-1/2" DP elevators. RU 4-1/2" YT elevators. Install donut/stripping rubber. RU air slips. RU eckels. RD DP spinners. DECOMP Pull 4-1/2" tubing, LD singles in pipeshed. Fill hole every 10 jts Printed: 2/13/2008 2:42:09 PM i • BP EXPLORATION Page 13 of 36 ~ Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/24/2007 19:30 - 00:00 4.50 FISH C 12/25/2007 00:00 - 04:30 4.50 FISH C 04:30 - 06:00 1.50 FISH C 06:00 - 08:30 2.50 CLEAN C 08:30 - 15:00 6.501 BOPSUFjC 15:00 - 16:00 1.00 BOPSUFjC 16:00 - 18:00 2.00 BOPSU C 18:00 - 18:20 0.33 BOPSU C 18:20 - 19:20 1.00 BOPSU C 19:20 - 19:35 0.25 BOPSU C 19:35 - 22:30 2.92 BOPSU C 22:30 - 00:00 1.50 BOPSU C 12/26/2007 00:00 - 05:50 5.83 FISH C 05:50 - 06:00 I 0.171 FISH I C 06:00 - 08:30 I 2.501 FISH I C 08:30 - 10:15 I 1.751 FISH I C 10:15 - 10:20 0.08 FISH C 10:20 - 14:30 4.17 FISH C 14:30 - 15:15 I 0.75 I FISH I C 15:15 - 17:00 1.751 FISH C DECOMP & simultaneously remove tubing from pipe shed. DECOMP Continue to TOH w/ 4-1/2" tubing. Slow going due to having to hammer each connection prior to breaking it out. LD singles in pipeshed. Fill hole every 10 jts & simultaneously remove tubing from pipe shed. DECOMP OOH w/ 4-1/2" tubing. End of tubing (~ chem cut is egged shaped. 2.5" ID, 6" OD. 5ft long twisted split on one side & 1' long split on the other side. RD Eckel tongs. RU DP spinners. Clean RF. Remove tubing from pipe shed. DECOMP Suck down stack. Function test BOP's. Set test plug in tubing hanger. Get body test Strap first row of DP in pipeshed. Load out misc fishing tools from pipeshed DECOMP Test BOPE 3500/300. No call back from AOGCC after several tries Load pipeshed w/ 3-1/2 DP DECOMP Rig Services, PJSM on replacing breaker on Gen #2 DECOMP SD rig power and install newly reconditioned breaker on generator #2 DECOMP C/O w/day crew. DECOMP Set wear ring & secure w/ 2 lock down screws. Hoist boot baskets, xo's, wash pipe, casing elevators to RF & steam same. Inspect easy torque lines & system under RF. Breakout jars & xo's from previous overshot run. DECOMP PJSM for MU BHA, PU pipe in derrick, PU singles from pipeshed. DECOMP MU wash pipe BHA. DECOMP TIH w/ 3-1/2" DP stands in derrick. DECOMP Continue to TIH w/ 3-1/2" DP. PU singles from pipeshed. Stop at jt # 221 of 253. DECOMP Conduct kick while tripping drill. Clean RF for day crew. Service/grease rig accordingly. DECOMP RIH with 253 jts of 3-1/2" DP, PU PJ and Jt 254. PU kelly and PT as per AOGCC DECOMP Fluid pack surface lines and PT upper and lower Kelly as per AOGCC DECOMP RIH and tagged the top of the stump at 8450 ft DECOMP Milling on 4-1/2" stump Op = 180-190 spm at 1800 -2080 psi. Torque at 220 amps RPM at 80 rpm Wt up at 112k and 98k down Milled from 8450 ft to 8453ft from 10:40 hrs to 13:40 hrs WO mill at 1 k to 1.5k DECOMP Dressing up 4-1/2" Stump at 8,453 ft. Pumped 40 bl biozan pill #2 Op = 190 spm at 2080 psi. Torque at 215 amps RPM at 80 rpm WO mill at 1 k Keeping everything I milling Milled from 8,450 ft 8,454 ft and then washed down without much effort to 8,467 ft and the 4.5" ID tagged the 5.5" OD collar (PJ above the Latch/seal assy. PU and found the top again at 8,449.8 ft and rotated over and tagged again at 8,467 ft DECOMP Cir 40 bbl 2.OOppb biozan pill around Printed: 2/13/2008 2:42:09 PM BP EXPLORATION Page 14 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code i NPT ~ Phase Description of Operations 12/26/2007 17:00 - 17:30 0.50 FISH C DECOMP Blow Kelly down and LD 1 single, pup jt 17:30 - 18:00 0.50 FISH C DECOMP POOH standing back DP 18:00 - 19:00 1.00 FISH C DECOMP C/O w/ day crew. Perform daily walk around of rig. Service rig, inspect equipment - install C clip on air slips. 19:00 - 19:10 0.17 FISH C DECOMP PJSM regarding standing back pipe in derrick. 19:10 - 23:25 4.25 FISH C DECOMP TOH standing back DP. Fill hole every 5 stands. 23:25 - 00:00 0.58 FISH C DECOMP TOH standing back DC's, torque up lifting subs & use dog collar on each connection. 12/27/2007 00:00 - 00:30 0.50 FISH C DECOMP Continue to TOH. 00:30 - 02:00 1.50 FISH C DECOMP OOH. Break out BHA, change out tong heads as required. Clean boot baskets -all 3 were full of control tubing, wire, cable clamp pins & scale - 5 gal recovered. RD DP elevators & RU casing elevators to handle 8-1/8" wash pipe. LD 30ft wash pipe. Lower boot baskets to end of beaver slide. Hoist up overshot, barrel extension & xo. Steam same. C/O casing elevators for DP elevators. 02:00 - 04:20 2.33 FISH C DECOMP MU overshot BHA. RU snub line as needed. PU 5 stands of DC's, dog collar each connection & break out lifting subs. LD single 3-1/2" DP. PU accelerators & pump out sub. PU single 3-1/2" DP. Pull bushings & install stripping rubber, install bushings. RU air slips, replace air fitting on air slips. 04:20 - 05:50 1.50 FISH C DECOMP TIH w/ 3-1/2" DP stands from the derrick. Stop at stand #47. 05:50 - 06:00 0.17 FISH C DECOMP Conduct kick while tripping drill. Flow check well. Clean RF for day crew. Service/grease rig accordingly. 06:00 - 11:10 5.17 FISH C DECOMP RIH with DP 9126x DP in derrick) 11:10 - 12:30 1.33 FISH C DECOMP PU and washed over top of stub at 8,449 ft and set grappled on 4-1/2" tubing at 8,461 ft PU 10 k and put 12 rounds torque in DP at 420 amps. Tried this several times at different string wts without results. PU and jarred 10 times at 60k over without much results. After 4 cycles of jarring and using torque at 430 amp finally backed off the anchor and lost torque, PUH and pulled smooth. Pumped 40 bbl 2 ppb biozan around 12:30 - 13:30 1.00 FISH C DECOMP Circulate wellbore 13:30 - 14:00 0.50 FISH C DECOMP Stand kelly back and blow down same. Place in shuck 14:00 - 18:00 4.00 FISH C DECOMP TOH w/ DP, stand back in derrick. 18:00 - 18:25 0.42 FISH C DECOMP C/O w/ day crew. PJSM regarding TOH w/ DP. 18:25 - 21:00 2.58 FISH C DECOMP Continue to TOH. Fill hole every 5 stands. 21:00 - 21:45 0.75 FISH C DECOMP TOH standing back DC's, torque up lifting subs & use dog collar on each connection. 21:45 - 22:50 1.08 FISH C DECOMP OOH. Service break BHA on barrel extension. Break 4-1/2" tubing pup & LD SBR & K anchor assembly on catwalk (call Tool services for NORM testing). Change out tong heads as required, use sunb line as required. 22:50 - 00:00 1.17 FISH C DECOMP Fill out man rider permit. PJSM for slip & cutting drill line. Hang blocks in derrick. Release dead man clamp. Remove weight cells. Slip & cut 100ft of drill line. Put together same. 12/28/2007 00:00 - 02:30 2.50 FISH C DECOMP Continue to slip & cut drill line. Simultaneously bring in 20 jts of 2-3/8 PH6 tubing, 3 joints of 8-1/8" wash pipe & VACS tool into pipeshed. Steam same. Drift & tally 20 jts of 2-3/8" PH6 tubing. RD DP elevators & RU 2-3/8" elevators. MU floor valve for 2-3/8" tubing. Hoist 2-3/8" muleshoe, XO's to RF. Steam same. PU little jerk tongs & dial in hydraulics. 02:30 - 02:40 0.17 FISH C DECOMP PJSM for handling BHA. Printed: 2/13/2008 2:42:09 PM BP EXPLORATION Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Event Name: REENTER+COMPLETE Start: 12/6/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date !From - To ! Hours I Task I Code I NPT I Phase ~ 12/28/2007 ~ 02:40 - 04:00 04:00 - 06:00 1.331 FISH C 2.001 FISH I C 06:00 - 07:00 1.00 FISH C 07:00 - 13:15 6.25 FISH C 13:15 - 15:30 2.25 FISH C 15:30 - 15:50 0.33 FISH C 15:50 - 17:30 1.67 FISH C 17:30 - 18:00 0.50 FISH C 18:00 - 18:30 0.50 FISH C 18:30 - 22:45 4.25 FISH C 22:45 - 00:00 I 1.251 FISH I C 12/29/2007 00:00 - 01:45 1.75 FISH I C 01:45 - 03:30 I 1.751 FISH I C 03:30 - 03:45 0.25 FISH C 03:45 - 04:10 0.42 FISH C 04:10 - 05:00 0.83 FISH C 05:00 - 06:00 I 1.001 FISH I C 06:00 - 08:45 2.75 ~ FISH C 08:45 - 16:10 I 7.421 FISH I C 16:10 - 17:30 1.331 FISH ~ C Page 15 of 36 Spud Date: 2/15/1986 End: 1 /29/2007 Description of Operations DECOMP PU bushing inserts & slip bowl. MU BHA. PU 20 jts of 2-3/8" tubing from pipeshed using dog collar on each connection. DECOMP RD little jerk tongs. RD 2-7/8" elevators. RU casing elevators. C/O tong heads as required. RU snub line. MU Vacs tool. RD slip bowl & bushing inserts. RD casing elevators & RU DP elevators. Mu rest of BHA. PU 5 stands of DC's, dog collar each connection & break out lifting subs. PU pump out sub. Pull bushings & install stripping rubber, install bushings. RU air slips, replace air fitting on air slips. DECOMP Crew change and rig service DECOMP RIH with VACS BHA System. RIH wit 113 stands and LD 6 jts DECOMP Vac at O 5.25 bpm and 1600 psi from 8443 ft to 8630 ft. DECOMP RIH to 8819 ft with DP out of derrick DECOMP Washed from 8819 ft to 8885 ft at 5.25 bpm and a Pp of 1700 psi. tagged hard at 8,885 ft, turned drill string 180 deg and tried it again. PBTD still at 8,885 ft DD. DECOMP SD pump and PUH laying down 3 jts of drill pipe. DECOMP C/O with day crew. PJSM regarding tripping drill pipe. DECOMP TOH, stand back DP. Fill hole every 5 stands. Pull bushings & pull stripping rubber, install bushings. DECOMP Stand back DC's, use dog collar on each connection. Service break entire BHA. LD pump out sub, jars. Drain each 30ft section of wash pipe. DECOMP LD bumper sub, rotary sub. C/O tong head as required. Wait for each 8-1/8" wash pipe to drain. - 1/2 cup of solids recovered. The BOT Vacs tool really does suck. LD wash pipe in pipe shed. DECOMP LD 2-3/8" PH6 singles in pipeshed (wet trip). Plugged joint # 11. Clean RF. Prep to RU slickline. DECOMP PJSM regarding RU slickline. DECOMP RU slickline junk basket run. DECOMP RIH w/ 8.5"junk basket. Set down at 7960ft, 8246ft. Tag up twice at 8481 ft. DECOMP POH w/junk basket. Pressure up on OA w/diesel to confirm there is no ice plug, pumped for 5 min with no pressure increase. DECOMP Recovered 1 8 in wire rope. Reran 8.5" JB/GR and tagged at 8494 ft. POOH and no recovery. Crew conducted Table top drills while running wireline Open OA and OAP = 0 psi. Open to bleed trailer and watch DECOMP PU and RIH wit 3.5" Pump Bailer Tagged at 8875 ft aned worked down to 8891 ft. Solid at 8891 ft. POOH and recovered some parts of clamp pins and small pieces of control lines and rubber. Rerun Tagged hard again at 8891 ft. Stroked bailer 15 min and POOH. Recovered same as before, clamp pins, control line segments and small pieces of rubber. Reran bailer and washed down to 8,893 ft. Recovered more metal, clamps and a rock. Run #4 tagged hard again at 8,893 ft WLMD, bailed 20 min POOH, recovered metal but quantity is reducing, Run # 5 Tagged at 8893 ft WLMD and bailed for 20 min then POOH. Recovered a couple of small) pieces of control lines. DECOMP Run 3.7" 19 ft long Dummy WS and tagged PBTD at 8893 ft POOH Printed: 2/13/2008 2:42:09 PM BP EXPLORATION Page 16 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code j NPT j Phase Description of Operations 12/29/2007 17:30 - 18:00 0.50 FISH C DECOMP RD wireline 18:00 - 18:30 0.50 WHSUR P DECOMP C/O w/ day crew. PJSM regarding tripping pipe. 18:30 - 21:30 3.00 WHSUR P DECOMP Pull wear ring (8.75" I.D.). Run 30 stds 3-1/2" DP. PU RTTS storm packer. PU 1 stands of DP & set RTTS packer 60ft below RF. Pressure test 500 psi above & 500 psi below. 21:30 - 21:45 0.25 WHSUR P DECOMP PJSM regarding pulling casing packoffs. 21:45 - 23:00 1.25 WHSUR P DECOMP Suck down stack. MU casing running tool on 1 jt of DP. Tag packoff & J latch into it. Back out lock down screws. Close annular bag w/ 400 psi. Pull 20 k to release packoff. 23:00 - 00:00 1.00 WHSUR P DECOMP Attempt to set new casing packoff through BOPE. 12/30/2007 00:00 - 06:00 6.00 WHSUR P DECOMP Attempt several times to set casing packoff through the BOPE's. Nipple down riser. Install lifting plate. Disconnect IA pumping flange. Hot bolt tubing spool & BOPE riser spool. Hoist BOPE & tubing spool off of well. Clean up casing adaptor. Set new casing packoff, secure with lock down screws. Unbolt & remove old tubing spool. Hoist in new tubing spool. 06:00 - 10:30 4.50 WHSUR P DECOMP Installed new tubing spool and pack-off. Lower BOP and MU tubing spool studs. PT to 5000 psi for 30 min. (OK) NU 13-5/8" BOP and surface lines 10:30 - 14:00 3.50 WHSUR P DECOMP NU riser and remove fishing tools from pipe shed. make ready to PT the BOP body PT the BOP body to 3500 psi 15 min OK 14:00 - 15:00 1.00 WHSUR P DECOMP Pull test plug and load RTTS #2 packer in the pipe shed 15:00 - 16:30 1.50 WHSUR C DECOMP RIH with 1 std DP and upset and POOH RTTS and circulating valve. LD same. POOH standing 3-1/2" DP back in the derrick 16:30 - 18:00 1.50 CASE C DECOMP PU 9-5/8" RTTS Packer with cir valve (open) and RIH to PT casing. 18:00 - 18:30 0.50 CASE C DECOMP C/O with day crew. PJSM regarding handling drill pipe. 18:30 - 00:00 5.50 CASE C DECOMP Continue to TIH w/ DP. Packer accidentally set at 5716ft. Set packer back into run position & continue to TIH. 12/31/2007 00:00 - 02:15 2.25 CASE C DECOMP Continue to TIH w/ DP. 02:15 - 03:20 1.08 CASE C DECOMP 128 stands in the hole, 102k up wt. Hook up circulating hose & circulate 20 bbls at 3 bpm ~ 400 psi. Center of element is at 8415ft, set RTTS packer w/ 16k down. Close annular. 03:20 - 04:00 0.67 CASE C DECOMP Pressure test 9-5/8" casing to 3000psi -FAIL. 0 min = 3000psi 15 min = 2950psi 30 min = 2900psi Leakage over floor valve, close floor valve. Bump up pressure. 04:00 - 04:30 0.50 CASE C DECOMP Pressure test 9-5/8" casing to 3000psi -FAIL. 0 min = 2950psi 15 min = 2900psi 30 min = 2985psi 04:30 - 05:00 0.50 CASE C DECOMP Unseat packer & PU 10ft, set packer again w/ 25k down. Middle element is at 8404ft. 05:00 - 05:20 0.33 CASE C DECOMP Pressure test 9-5/8" casing to 3000psi -FAIL. 0 min = 3150psi 15 min=3100 psi Leakage over floor valve (either a slow leak in the DP or slow leak at the packer). Bleed off pressure. 05:20 - 05:35 0.25 CASE C DECOMP Set more weight down on packer - 50k down. 05:35 - 06:45 1.17 CASE C DECOMP Pressure test 9-5/8" casing to 3000psi -PASS. 0 min = 3200psi Printed: 2/13/2008 2:42:09 PM i BP EXPLORATION Page 17 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code; NPT ' Phase Description of Operations 12/31/2007 05:35 - 06:45 1.17 CASE C DECOMP 15 min = 3170psi 30 min = 3150psi Bleed off pressure. 06:45 - 08:45 2.00 CASE C DECOMP Unset RTTS and open Circulating Valve Circulating 50 bbl biozan at 6.00 bpm and 1350 psi 17000 stroke, full circulation. Not much solids recovered at surface. Unloading pipe shed of unused DP 08:45 - 09:15 0.50 CASE C DECOMP PJSM on LD DP 09:15 - 18:00 8.75 CASE C DECOMP POOH laying down DP 18:00 - 18:30 0.50 CASE C DECOMP C/O w/ day crew. PJSM regarding handling Kelly. 18:30 - 21:30 3.00 CASE C DECOMP Rig down Kelly for the last time this year. 21:30 - 00:00 2.50 CASE C DECOMP Continue to TOH laying down DP. 1/1/2008 00:00 - 03:30 3.50 RIGD C DECOMP Recovered RTTS packer & both rubber elements. Empty pipe shed of DP, DC's & RTTS packer. Pull Kelly shuck & LD on the ground. LD Kelly swivel onto the ground. Clean RF. Put away tongs, pipe spinners, DC lifters. 03:30 - 14:30 11.00 BUNCO RUNCMP Load pipe shed with 4-1/2" Vam Top tubulars. Remove thread protectors, steam, strap & drift same. Prep reel for change out 14:30 - 16:30 2.00 BUNCO RUNCMP MU Bottom completion assembly 16:30 - 18:15 1.75 BUNCO RUNCMP RU Doyon torque torn equipment. Running 4-1/2 completion. 18:15 - 18:30 0.25 BUNCO RUNCMP Crew change. At jt# 186. 18:30 - 00:00 5.50 BUNCO RUNCMP Continue to run 4-1/2 completion. MU jewelry as per completion detail. 1/2/2008 00:00 - 05:00 5.00 BUNCO RUNCMP Continue to run 4-1/2" completion tbg and jewelry. 05:00 - 11:30 6.50 BUNCO RUNCMP Ran 198 jts and tagged no/go and spaced out. PU circulating system and washed down and seen a small increase in pressure working down inside of the packer. PUH layed down 3 jts, added 4-4-1 /2" pup jts and changed out jt 194 ft to longer one. PU 13-5/8" X 4-1/2" TCII hanger and landed . No Go presently at 3.28 ft above top of packer which willl allow 1.5 ft to 2.00 ft for packer stroke when setting. The bottom of the mule shoe will then be located aprroximately 2.39 ft to 2.89 ft from the packer Landed hanger in tubing spool and FMC confirmed hanger setting location. 11:30 - 13:15 1.75 BUNCO RUNCMP Back off landing joint. RU to run MCCUGR and clean pits 13:15 - 14:40 1.42 BUNCO RUNCMP RIH to pull RHC plug. Pull same 14:40 - 16:45 2.08 BUNCO RUNCMP RU MCCL logging tools and RIH to 7800 ft Located the NoGo on the stinger at 8488 ft and the mule shoe at 8492 ft. This places the the mule shoe approximately 2 ft inside the TIW packer with a top at 8890 ft. This 2 ft inside they packer places the bottom of the mule shoe inside the 4-3/4" body of the packer 16:45 - 18:15 1.50 BUNCO RUNCMP RIH with 3.75" TS and 3.80 TS on top (2 ft apart) 3.8" TS tagged at 8571 ft 18:15 - 20:30 2.25 BUNCO RUNCMP RIH with 3.80" drift to 8650'. 20:30 - 23:00 2.50 BUNCO RUNCMP RIH with dummy whipstock to 8750'. 23:00 - 00:00 1.00 BUNCO RUNCMP Run and set RHC plug in X nipple at 8429'. 1/3/2008 00:00 - 02:30 2.50 BUNCO RUNCMP Run and set RHC plug in X nipple at 8468'. Hold PJSM. Rig down SLB slickline unit. 02:30 - 06:00 3.50 BUNCO RUNCMP Reverse circulate 150 bbls neat 1%KCL followed by 450 bbls inhibited KCL water down IA. Take rtns up the tubing. 175 psi at 2.89 bpm. Printed: 2/13/2008 2:42:09 PM BP EXPLORATION Page 18 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date ~ From - To Hours Task Code NPT Phase ~, Description of Operations 1/3/2008 06:00 - 06:30 0.50 BUNCO RUNCMP Crew change and PJSM 06:30 - 07:10 0.67 BUNCO RUNCMP Dropped rod and ball and RU to PT and set the 4-1/2" completion Installed 07:10 - 11:45 4.58 BUNCO DFAL RUNCMP PT and set packer 3800 psi Straight line on chart recorder. LowTorque valve started to Leak, SD and replaces and retested. Finally tested and recorded 40 minutes and lost 100 psi. Test past, retested to confirm with all of the problems, Test failed as before. No confidence with test. Conduct leak hunt 11:45 - 13:00 1.25 BUNCO DFAL RUNCMP Called WL for a leak hunt. Held PJSM with WL crew and discussed the hazards associated with rigging up on the rig. SLB installed a new reel and removed the one with 400,000 running ft in 13Cr tubing 13:00 - 14:15 1.25 BUNCO DFAL RUNCMP RU WL to pull 1-1/2" DCK valve at 3,391 ft and replace it with a 1-1/2" DGLV. Set short stop below 3391 ft as catcher sub 14:15 - 17:20 3.08 BUNCO DFAL RUNCMP RIH and set slip stop below DCK valve at 3390 ft. RIH, retrieve the 1-1/2" DCK valve. POOH, RIH and set DGLV in pocket at 3,39 ft. POOH, RIH and pulled slip stop from below the mandel, POOH 17:20 - 18:00 0.67 BUNCO RUNCMP RU and PT the tubing as per procedure Test failed Tried 3 times and same results. 200 psi in 10 minutes 18:00 - 18:30 0.50 BUNCO RUNCMP Crew change for SLB and Nordic 2. 18:30 - 21:30 3.00 BUNCO RUNCMP Run in hole. with SLB slickline. Engage and shift sliding sleeve at 9318' open. POOH. 21:30 - 00:00 2.50 BUNCO RUNCMP Redress SL sliding sleeve tool. RIH. Engage and shift sliding sleeve closed. POH. 1/4/2008 00:00 - 00:30 0.50 DHEOP N RUNCMP Pull out of hole with slickline after shifting sleeve closed. 00:30 - 02:45 2.25 BUNCO RUNCMP Make up 4-1/2" test joint. Pressure tbg to 3500 psi. Held solid fo 30 min. Pass. Bleed tbg pressure to 1500 psi. Pressure test IA to 3000 psi for 30 min. Both tests recorded on circular chart recorder. 02:45 - 04:00 1.25 BUNCO RUNCMP RIH with slickline. Pull ball & rod. 04:00 - 09:00 5.00 BUNCO RUNCMP RIH to engage and pull RHC plug. POOH. RIH with slip stop prior to pulling DGLV and set below DGLV. POOH and RIH and pulled DGLV. LRS is RU to FP the IA with diesel 09:00 - 14:30 5.50 BUNCO RUNCMP Pumping 130 bbl 90 deg diesel down IA with LRS. Installed DGLV and PT IA to 1000 psi with diesel RIH and recovered the slip stop below the GLM. RIH to 8650 ft with 3.75' / 3.80' TS configuration. POOH and RD wireline 14:30 - 14:45 0.25 BOPSU P WEXIT Blow stack down and set TWC. PT from top to 1000 psi 14:45 - 20:00 5.25 BOPSU P WEXIT Hold PJSM. Blow down BOPs. ND riser and remove from cellar. Remove hydraulics, kill & choke lines. 20:00 - 00:00 4.00 BOPSU P WEXIT Hold PJSM. Open doors and remove rams. Clean and lubricate ram bodies. ND BOPs from wellhead. Secure on trolley skid. 1/5/2008 00:00 - 02:00 2.00 BOPSU P WEXIT Continue to ND 13-5/8" BOPs. Secure on trolley. Skid out of cellar. 02:00 - 05:00 3.00 BOPSU P WEXIT Spot in cellar. NU THA and 4-1/2" tree. Pressure test same. Printed: 2/13/2008 2:42:09 PM • ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: C-35 Page 19 of 36 ~ Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date ~ From - To Hours ~ Task Gode NPT Phase Description of Operations 1/5/2008 05:00 - 12:00 7.00 BOPSU P 12:00 - 12:15 0.25 BOPSU P 12:15 - 15:00 2.75 BOPSU P 15:00 - 17:00 2.00 BOPSU P 17:00 - 00:00 7.00 BOPSU P 1/6/2008 00:00 - 02:30 2.50 BOPSU P 02:30 - 10:15 7.75 BOPSU P 10:15 - 11:45 1.50 BOPSU P 11:45 - 12:15 0.50 STWHIP P 12:15 - 12:30 0.25 STWHIP P 12:30 - 16:30 4.00 STWHIP P 16:30 - 18:30 2.00 STWHIP P 18:30 - 19:30 1.00 STWHIP P 19:30 - 20:45 1.25 STWHIP N 20:45 - 22:15 1.50 STWHIP N 22:15 - 22:30 0.25 STWHIP N 22:30 - 00:00 1.50 STWHIP P 1/7/2008 00:00 - 00:30 0.50 STW H I P P 00:30 - 01:30 1.00 STWHIP P WEXIT Prep to back rig off well. Wait on Crane to demob the 13-5/8" BOP from behind the well WEXIT MI Peak Crane. Held PJSM with crews on moving off well, WEXIT Move off well, level out 13-5/8" BOP's, place 7-1/16" BOP in cellar area RU Peak Crane .Pick the BOP out from behind well and place on shipping skid. PU 7-1/16" BOP's with blocks. RD Peak crane and move off. WEXIT Move rig back over well. Rig up and spot supprot equipment. Re-seal berm around cellar. WEXIT MU adapter flange to tree. Lift and set 7-1/16" BOPs on tree. NU same. MU choke and kill lines. MU hydraulic lines to BOP components. Install lubricator sections through rig floor. Repair test pump. Conducted Spud Meeting with Night crew on the Plan Foward on the well using the CTD and WILD Systems at crew change WEXIT Continue to NU BOPS. Replace failed o-ring on lubricator below rig floor. Complete satisfactory body pressure test. WEXIT Pressure test BOP equipment as per Drilling Permit. Called AOGCC to witness. No response. Conducted Spud Meeting with day crew on the Plan Foward on the well using the CTD and WILD Systems at crew change. WEXIT RU and PT lubricator to 700 psi .pull TWC. RD lubricator WEXIT Weekly crew change with Nordic RU to pull CT across pipe shed WEXIT Held PJSM and discussed the HAZARDS with pulling CT across to injector and conducting slack management WEXIT Pull CT across pipe shed Prep eline cable Reverse circulate in 10 bbl MEOH followed by 2% KCL Pumped conventionally at 2.5 bpm Moved 10 ft WEXIT Installing CTC, pull test Megged line (OK) Pull tested CTC to 35k, OK Behead BHI UOC WEXIT MU BHA #1 (3.8" DSM clean out assembly w/ string reamer) SFAL WEXIT Unable to get BHA past master valve/tbg hanger neck. Stand back BHA. Pump out BOPs. Master appears to be open. PU 1 joint of CSH. RIH. Tag at same depth (top of hanger). Feels like ice. WEXIT PJSM to discuss steps in removing plug. LD Inteq BHA. MU nozzle & stinger on coil. Get on well. Jey through ice with warm KCL water. Get off well. LD nozzle assembly. WEXIT PU BHA #1 again. WEXIT Test Inteq tools. Run in hole. WEXIT Continue to run in hole. Circulate at min rate. WEXIT Log CCL down from 8300' to 8889'. New and old jewelry on depth with 3/8/86 SWS CBL log. Log GR from 8850' to 8889'. Add 1' correction to Top of Sag Printed: 2/13/2008 2:42:09 PM i • BP EXPLORATION Page 20 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: i, Date ;From - To Hours Task Code NPT Phase Description of Operations 1/7/2008 00:30 - 01:30 1.00 STWHIP P WEXIT marker at 8832'. ' 01:30 - 04:00 2.50 STWHIP P WEXIT Pump 40 bbl hi viscosity sweep. Clean out 7" liner. 2.59 bpm at 2515 psi. Open EDC and circulate out of hole. 04:00 - 07:17 3.28 STWHIP P WEXIT Bring Baker Tools to the rig floor. Make up Baker whipstock. Install PIP tags in tray. PT the stripper and inner reel valve as per AOGCC, charted 07:17 - 08:24 1.12 STWHIP P WEXIT PU and scribed WS 08:24 - 10:18 1.90 STWHIP P WEXIT RIH to 8520 ft 10:18 - 10:50 0.53 STWHIP P WEXIT Log down with CCL to Tie-in to old 4-1/2" tubing tail nipples at 8535 ft 8571 ft and stopped att 8690 ft. Corrected -2 ft. Switch to logging with GR 10:50 - 12:15 1.42 STWHIP P WEXIT RIH and lightly tag bottom at 8,889 ft. PUH and line out to log GR PUH logging with GR, seen the GR spike at 8831 ft in the up log mode Logged down and tagged at 8889 ft. PU off bottom and corrected +2 ft Bottom of WS at 8,889.11 ft and the top is 8,871.58 ft TF at 180 deg Set WS at 2700 psi and stacked wt and PU clean 12:15 - 14:25 2.17 STWHIP P WEXIT POOH 14:25 - 15:35 1.17 STWHIP P WEXIT Changed out tools, install new packoff Starting to MIRU the WILD Bunch equipment 15:35 - 17:30 1.92 STWHIP P WEXIT RIH with window milling BHA. Dry tag WS at 8876.5'. Pick up. 17:30 - 00:00 6.50 STWHIP P WEXIT Begin milling window at 8875.6'. 2720 psi fs at 2.51 bpm in/out. 200-300 psi mtr work. Initial DHWOB: 0.84k#. Average DHWOB: 3.5k#. ECD: 9.18 ppg. Mill to 8880'. Time milling at 0.1' per six minutes. 1/8/2008 00:00 - 02:15 2.25 STWHIP P WEXIT Continue to mill window from 8880' to 8882'. Appear to be into formation. Estimted TOW: 8875'. BOW: 8882'. 02:15 - 04:15 2.00 STWHIP P WEXIT Drill ahead in formation to 8893'. Displace well to flo pro mud. 3250 psi fs at 2.7 bpm. 04:15 - 05:15 1.00 STWHIP P WEXIT Dress window with several up and down passes. Dry drift window. Smooth up and down. 05:15 - 07:10 1.92 STWHIP P WEXIT Open EDC. Circulate out of hole. Held PJSM on final TOH OOH closed EDC and power down tool 07:10 - 07:45 0.58 STWHIP P WEXIT Changed out BHA. Mill gauged 3.8" go and 3.79 no/go 07:45 - 10:55 3.17 DRILL P PROD1 RIH to 8850 ft Had Rig evaluation, and pin hole /parted coiled tubing, kick while drilling table top with all of the crews 10:55 - 11:10 0.25 DRILL P PROD1 Log GR spike at 8,832 ft Stopped at 8,867 ft and corrected +1 ft SD pump and closed EDC. 11:10 - 11:32 0.37 DRILL P PROD1 RIH tagged bottom at 8,894. Work CT to get pattern started 11:32 - 17:35 6.05 DRILL P PROD1 Drilling Shublik drop section from 8,894 ft to 8973 ft Free spin 3250.psi at 2.4 bpm Op 2.60 /2.63 bpm at 3263 psi Vp = 365 bbl Printed: 2/13/2008 2:42:09 PM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date i From - To Hours Task Code NPT 1/8/2008 111:32 - 17:35 6.051 DRILL P 17:35 - 18:00 ~ 0.42 ~ DRILL ~ P 18:00 - 20:15 I 2.251 DRILL I P 20:15 - 20:30 0.25 DRILL P 20:30 - 22:20 1.83 DRILL P 22:20 - 23:00 0.67 DRILL P 23:00 - 23:30 0.50 DRILL P 23:30 - 00:00 0.501 DRILL P 1/9/2008 100:00 - 02:00 I 2.001 DRILL I P 02:00 - 02:30 I 0.501 DRILL I P 02:30 - 04:30 2.00 DRILL P 04:30 - 05:15 0.75 DRILL P 05:15 - 05:40 0.42 DRILL P 05:40 - 08:10 2.50 DRILL P 08:10 - 10:12 2.03 DRILL P 10:12 - 10:45 0.55 DRILL P 10:45 - 11:30 0.75 DRILL P 11:30 - 11:40 0.17 DRILL P 11:40 - 13:50 2.17 DRILL P 13:50 - 14:45 0.92 DRILL P 14:45 - 18:30 I 3.751 DRILL I P 18:30 - 22:30 4.00 I DRILL P Start: 12/6/2007 Rig Release: 1 /29/2008 Rig Number: Page 21 of 36 Spud Date: 2/15/1986 End: 1 /29/2007 Phase Description of Operations PROD1 WOB 0.5 to 2 k ROP's range 2 to 20 fph ECD = 9.85 ppg While drilling at 8,922 ft, took a hard stall of 2,300 psi differential Seen some rubber coming across the shaker Limping along to get the hole TD for the WILD TD at 8973 ft Started cost tracking WILD project charges on AFE PBD4P9317 at 1730 hrs PROD1 PUH, SD pump at base of WS and pull through. PUH to 8650 ft with HS TF PROD1 RIH logging to tie-in the GR spike at 8832 ft as per PDC Log. Spend 30 min working to move TF to LS (short in tool string). Log thru window 0.6/1800. Wiper to TD 2.56/3120 while finish tie-in to mother wellbore. Correct +1', tagged TD at 8972.7', PU 33.9k, PVT 116 PROD1 Wiper to window, clean PROD1 POOH circ 3.0/2800 circ thru EDC PRODi LD build assy and reconfigure PRODi Safety mtg MU custom BTT venturi assy onto BHI mwd assy PROD1 RIH w/ BHA #23 circ 0.5/1800 Repair leak on hardline in reel house (replace 3 hardline gaskets) PROD1 Continue RIH w/ venturi circ 0.5 bpm / 1800 psi. Fin repair leak in reelhouse and PT Hoover 2.52 bpm / 3750 psi from 8,450 ft at 20'/min to TD tagged at 8973.6' CTD PROD1 Hoover thru open hole and recip in 7" while start 25k LSRV mud down CT PRODi POOH 2.51/3060 while finish displacement to 25k LSRV mud PROD1 LD BTT Venturi assy. Recovered several thin slivers of metal up to 2" long. Had one thin sliver that was 0.5" wide x 5". Also recovered about a cup of large Shublik shale chunks up to 1" OD PROD1 MU BTT Venturi assy for rerun PROD1 RIH w/ BHA #24 circ 0.30 bpm / 498 psi Tagged bottom and circulated PROD1 POOH with Venturi Basker Run #2 PROD1 LD BHA, recovered shublik shale, no metal was seen PROD1 Cut off CTC and blow back coiled tubing . Won't blow back, need to rehead with CTC PROD1 PJSM on cutting CT and reheading. PROD1 Cut off CTC and installed CTC and pull tested to 35k. BHI tested wire and reheading UOC and test. PT to 3500 psi (OK) PROD1 Held PJSM with wireline crew and discussed the hazards assocaiated with the wireline RU and running same. RU WL with 42 BO tool too open sliding sleeve PROD1 RIH with wireline. Open sliding sleeve ~ 8314'. RD WL tools. Kept SWS on standby until full returns established PROD1 RU to circ. Safety mtg. Stab on lub w/ injector. Displace IA of diesel and KCI while pumping 25k LSRV mud thru the CT down the production tubing taking returns from the IA to the tiger tank at initial 2.54/1800 w/ 110 psi whp due to hardline restrictions. Had 1/1 returns. Pumped 450 bbls of 25k LSRV 67F mud at final 2.48/1990 psi w/ 140 psi induced by at 79F Printed: 2/13/2008 2:42:09 PM BP EXPLORATION Page 22 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date ~ From - To .Hours Task Code NPT Phase Description of Operations ~, 1/9/2008 22:30 - 23:15 0.75 DRILL P PROD1 Blow down and RD all circ lines 23:15 - 23:30 0.25 DRILL P PROD1 Safety mtg re: RU WILD drift 23:30 - 00:00 0.50 DRILL P PROD1 MU BHA #25 w/ 3.75" OD WILD drift assy w/ 4 jts CSH and BHI MWD assy 1/10/2008 00:00 - 00:30 0.50 DRILL P PROD1 Fin MU WILD drift assy 00:30 - 02:40 2.17 DRILL P PROD1 RIH w/ BHA #25 circ 0.45/550 thru swizzle stick. Hole was clean to TD tagged at 8975.1' CTD 37.Ok, 24.9k 02:40 - 04:30 1.83 DRILL P PROD1 POH w/drift and was clean thru window, EOT 04:30 - 05:35 1.08 DRILL P PROD1 LD WiLD drift assy, CSH and MWD. SI swab 05:35 - 10:30 4.92 DRILL P PROD1 Set injector over bung hole and circ. Prep to ND riser Pumped water in CT and RU to blow back prio to NU wireline BOPs. Pumped 150 bbl of 25k LSRV down IA and heated up the mud. RU to install wireline BOP's 10:30 - 14:30 4.00 DRILL P PROD1 RD riser and install Wireline BOP with china hat and high pressure duct tape on the China Hat. Sent MOJ to go get the lunches for the crews Load out BHI's Tool for repair. RU to PT the Eline BOP body to 3500 psi. Pumped open SSV and remove shipping cap and installed fuseable cap 14:30 - 15:30 1.00 DRILL P PRODi Tried to PT BOP body with Eline BOP. Line froze up with all the traffic coming and going out of the pump room. Working to unthraw to PT. PT the Eline BOP's body to 3500 psi, 10 min (ok). 15:30 - 16:00 0.50 DRILL P PROD1 Safety and operational meeting with the rig crew and the WILD Bunch, 16:00 - 18:00 2.00 DRILL P PROD1 RU the well control air and gease hoses on the second level RU safety joint and elevator. Unloaded sheave with loader and PU on floor. Function test eline BOP's Circilate the IA while waiting on WILD rig up 1.37/180 18:00 - 18:20 0.33 DRILL P PROD1 Crew change/safety mtg 18:20 - 20:30 2.17 DRILL P PROD1 Attach WL and raise sheave w/ blocks. PU top of BHA (one jt of 1-1/4 CSH + top of WILD) and tie off on derrick leg. SD pump, blow down lines. Install packoff assy. MU bottom three sections of WILD venturi assy (a little difficult to MU fine threads with knuckle jts above connection). Zero at top of packoff at top of tool 20:30 - 22:00 1.50 DRILL P PROD1 Power up tool and surface check. Realign bottom sheave Install packoff 22:00 - 23:40 1.67 DRILL P PROD1 RIH w/ WILD BHA #1 (Venturi/JB) on a-line at 10k fph Start rig pump down the IA and stage up to 2.7/250 w/ 50 psi whp at 74F PVT 300 Get up wt before window at 6500#. RIH and tag TD at 8967' uncorr ELMD 23:40 - 00:00 0.33 DRILL P PROD1 Hoover open hole w/WILD Venturi 1/11/2008 00:00 - 02:00 2.00 DRILL P PROD1 Continue to Hoover the open hole. Log tie-in. Hoover some more and SWS try to figure out why the WILD pump is not acting as planned 02:00 - 05:30 3.50 DRILL P PROD1 POOH w/ a-line at 6k fph. Stop at various spots and do WILD pump checks. Assuming that JB is full of solids 05:30 - 06:00 0.50 DRILL P PROD1 At surface w/WILD assy. SD pump operations after pumping 730 bbls at 2.7/260 w/ 50 psi whp. OA 200 PVT 300 06:00 - 08:00 2.00 DRILL P PROD1 Check tool at surface. Unable to get cutting out of junk basket. WILD changed out pump and installed same junk basket 08:00 - 08:45 0.75 DRILL P PROD1 PJSM on PU and running junk basket BHA again Printed: 2/13/2008 2:42:09 PM • • BP EXPLORATION Page 23 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/11/2008 08:45 - 10:00 1.25 DRILL P PROD1 10:00 - 10:50 0.83 DRILL P PRODi 10:50 - 12:15 1.42 DRILL P PRODi 12:15 - 13:30 1.25 DRILL P PROD1 13:30 - 18:00 4.50 DRILL P PROD1 18:00 - 21:30 3.50 DRILL P PROD1 21:30 - 22:30 1.00 DRILL P PRODi 22:30 - 23:00 0.50 DRILL P PRODi 23:00 - 00:00 1.00 DRILL N PRODi 1/12/2008 00:00 - 00:30 0.50 DRILL N PROD1 00:30 - 00:40 0.17 DRILL N PROD1 00:40 - 01:30 0.83 DRILL N PROD1 01:30 - 02:00 0.50 DRILL N PROD1 02:00 - 04:00 2.00 DRILL N PROD1 04:00 - 04:10 0.17 DRILL N PROD1 04:10 - 05:15 1.08 DRILL N PROD1 05:15 - 07:10 1.92 DRILL N PROD1 07:10 - 07:30 0.33 DRILL N PROD1 07:30 - 11:30 4.00 DRILL N PROD1 09:30 - 11:30 2.00 DRILL N PROD1 RIH ,zero BHA at 87 ft insatlled packoff and megged line and tested tool RIH and conducted wt check above WS at 6900 Ibf RIH and tagged bottom at 8967 ft Hoovering bottom of the hole POOH with junk basket run # 2 Seemed to work OK OOH, release packoff, pulll 1 jt 1-1/4" tubing out of hole. LA top section with joint. Pull BHA out of hole and removed junk basket. Unable to look at recovery due to welding up the sleeve. Install 3-3/4" WILD bit (gauaged 3-3/4") and RIH with BHA. WILD is reheading the cable /weak point for the drilling phase. Make ready to PU 1-1/4" CSH. Brought umbilical cable to rig floor and install spooler wireline cable splice connection. Pulled umbilical cable onto eline truck. Behead HLS Hydraulic Latch Sub to umbilical cable and tested. RIH w/ a-line to -2000'. Pull back to splice point at 846' and hang off w/ T-bar. Disconnect a-line at splice. RU to run CSH. Connect a-line to and install HLS to the first jt of CSH and MU. Remove the T-bar MU 27 jts 1-1/4 CSH + 11.7' pup Install guide assy on top of last jt. RIH w/ WL GS spear and latch the a-line at the bottom of the CSH. Pull a-line to surface and had about 8' extra eline Work to latch the BHA to the receiver at the bottom of the CSH w/o success Work to latch BHA to CSH w/o success Safety mtg re: strip OOH Surface cut a-line. POOH and standback CSH (wet). Cut e-line after breaking each stand and dispose Pull the last jt of CSH to floor with the HLS. Install clamp and RD HLS WILD reps determine latch problem to be a sleeve on the HLS that shifted down prematurely on the first attempt to latch up. Rebuild tool Tabletop parted CT discussion Safety mtg Connect a-line to and install HLS to the first jt of CSH and MU. Remove the T-bar. MU 13 stds CSH plus two 7.8' pups Install guide assy on top of last pup jt. RIH w/ WL GS spear and latch the a-line at the bottom of the CSH. Pull a-line to surface and had about 6' extra eline when BHA reached the HLS. Unable to latch up to the HLS and secure the umbilical cable Held PJSM on POOH with umbilical pipe and cable. Run the umbilical and engaged the nogo at the bottom of the 1-1/4" tubing, cut off cable. PU on the 1-1/4" tubing. RU to pull umbilical pipe and stand in the derrick. Cut umbilical cable every 60 ft Installed Tbar and clamps, removed connector, stop. Changed elevators and RU to pull umbilical to surface Pull to surfacve and checked OK, RIH and RU packoff to circulated IA and tubing Circulated wellbore at 3.00 bpm, with packoff on well while the Wild Bunch is reheading their tools Printed: 2/13/2008 2:42:09 PM • • BP EXPLORATION Page 24 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ,Code NPT ~ Phase Description of Operations 1/12/2008 111:30 - 12:30 12:30 - 15:30 15:30 - 00:00 1 /13/2008 00:00 - 01:00 01:00 - 01:10 01:10 - 03:15 03:15 - 05:30 05:30 - 07:00 07:00 - 07:30 07:30 - 08:45 08:45 - 12:30 12:30 - 12:45 12:45 - 21:30 1.00 DRILL N PROD1 SD Pump,blowed down surface lines, removed packoff, insdtalled Tbar /clamp. PU upper sheave and route cable through it to the eline truck 3.00 DRILL N PROD1 POOH to look at the upper tool section, checked tool, looked good, power up tool and RIH below surface. SLB working on drilling tool Pull tool to hole and set C-plate on tools. Having trouble with brakes on eline truck due to cold temperature. Lower the blocks, close the eline truck back cover. WILD checking the tool for electrical short 8.50 DRILL N PROD1 Wild troubleshooting electrical problem in umbrical cable and drilling head. Find short at top of BHA. Recheck all connections. Rewire splice connector 1.00 DRILL N PROD1 Finish fixing a-line shorts 0.17 DRILL N PROD1 Safety mtg 2.08 DRILL N PROD1 RIH w/ BHA on a-line to splice point and hang off on T-bar. Install HLS on one jt of CSH. RIH w/ 13 stds of CSH and two 7.8' pups. Install WL guide. RIH w/ spear on a-line and latch up to wire at HLS. Pull to surface 2.25 DRILL N PROD1 Work to latch up BHA to HLS. Close annular on CSH to get more hold down wt and appeared to get tool to latch. Work BHA up and down just to be sure. Remove one 7.80' CSH pup and add a 6.05' pup 1.50 DRILL N PROD1 Wired up top sub. Tested the tool and located a short in the head or in the connection downhole. This occurred following the latching up with the HLS sub. There isn't much confidence in the latch of HLS at this time 0.50 DRILL N PROD1 Held a operational and PJSM on how to PULL out of the hole with the tubing and umbilical cable with little confidence in the latch up of the BHA. Will need to use to twoT-bars and 1 clamp to accomplished this task. Disscussed the hazards and how to midigation of same. 1.25 DRILL N PROD1 PU umbilical and BHA with wire secured by T-Bar. Set slips. Move W iLD tech box out of rig enroute to SLB deadhorse. Need to build new umbilical at SLB's shop. Rehead both ends of approximately 845 ft umbilical cable. 3.75 DRILL N PROD1 POOH, cutting 60 ft of 1/2" cable using 2 T-Bars and 1 WL clamp. 0.25 DRILL N PROD1 Set C-Plate on drilling tool and conducted crew change with Nordic. Held PJSM with new crew Temp is -47 f with WC at -73ft at Deadhorse airport 8.75 DRILL N PROD1 Backed off control head and HLS was securly latched. Checked electrical pin connect on the top of the tool. Pulled tool out of the hole and conducted function test on BOP's. Set WILD BHA in mouse hole and try to circulate IA. Put steam hose on IA valve. Check valve frozen. Circulating IA at 3.00 bpm for 1.75 hrs Ti = 58 deg and Tf = 85 deg Meeting with WILD Rig team and Town team on the plan forward. SLB delivered new umbilical cable to rig. Looking at the electrical connection to see if the setting of the latch is the reason of the elctrical short .Placed WILD BHA in the well. This failure is the same as the 1st failure, the electrical short Printed: 2/13/2008 2:42:09 PM ~ ~ BP EXPLORATION Page 25 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: I ; NPT Phase Description of Operations Date From - To Hours Task i Code 1/13/2008 12:45 - 21:30 8.75 DRILL N PRODi occurs when latching up the HLS. Make ready to rerun the BHA ,but this time latch up on surface and thread the 1/2" cable through the umbilical tubing as its RIH. 21:30 - 22:45 1.25 DRILL N PRODi Prep pipeshed to LD CSH from the derrick. LD 13 stds 1-1/4 CSH while SWS writes procedure for threading the a-line thru each joint (rather than stands) 22:45 - 00:00 1.25 DRILL N PROD1 WO WILD to fin prep a-line for threading 1/14/2008 00:00 - 00:15 0.25 DRILL N PROD1 Safety mtg re: unconventional MU of eline inside CSH 00:15 - 02:30 2.25 DRILL N PROD1 BHA is hanging on C plate w/ HLS and 850' of eline umbillical attached and laying inside and outside of pipeshed. Thread opposite end of the 850' of 0.505" eline thru each joint of CSH from the pin end. Use T clamp on tugger to keep line tight. Use clamp on eline on the top of each joint set in the slips when threading. MU three joints 02:30 - 02:50 0.33 DRILL N PROD1 Fill CSH w/ FW and test eline connection for continuity and not 02:50 - 03:40 0.83 DRILL N PROD1 POOH and LD one single w/ eline still threaded thru it. Use T clamp and tugger to pull eline into derrick. Pull one stand and set BHA in C-plate below the HLS 03:40 - 12:00 8.33 DRILL N PRODi WILD work to determine short in head/line. Disconnect the top part of the BHA Checking all bulk heads for continuity Found some inpedence problem with the pump and problem between the head and telemerty modular. Changed out and found some electrical proble with the head and rehead same. PU BHA and suspened in the well and attached the HLS and tested tool. Tool tested ok 12:00 - 13:00 1.00 DRILL N PROD1 RIH with 3 jts and it tested ok. 13:00 - 15:00 2.00 DRILL N PROD1 Ran 7 jts and tested continuity and tested OK. Ran pump and it worked good. SD and off load tools from pipe shed and take to SWS shop. Running in the hole with umbilical cable/tubing at the same time. 15:00 - 15:30 0.50 DRILL N PRODi With 16 jts in and due to the cable twisting up, decided to test the tool again. Test ed OK 15:30 - 18:00 2.50 DRILL N PROD1 RIH with WILD with all of the umbilical cable 18:00 - 18:45 0.75 DRILL N PROD1 After 27 jts of CSH in hole, test continuity again and was okay! 18:45 - 19:45 1.00 DRILL N PROD1 Strip over eline with four CSH pups totalling 23.3'. Spear top of eline and pull 3' of slack. Install clamp on WL guide and release spear 19:45 - 21:45 2.00 DRILL N PROD1 Expose conductors on umbillical. RU sheave in derrick. Make connections. Install cover plate and hoisting device. Hanging string wt is 4400#. Zero at 951'. Remove C-plate. Install packoff 21:45 - 00:00 2.25 DRILL P PROD1 RIH w/WILD assy on eline. Start pumping down the IA 2.7/320 w/ intial out temp at 52F PVT 287 1/15/2008 00:00 - 04:00 4.00 DRILL P PRODi Finish RIH w/WILD drilling BHA on eline. Sync primary and backup PC's. Tag TD. Pull back up hole 9k and tie-in to RA pip at 8881' and corr <10'. RIH and tag TD at 8972' ELMD. Drill 2' to 8974' 04:00 - 07:00 3.00 DRILL P PROD1 Switch to backup system. Doing pump tests and tension tests. "Top secret", can't reveal too much 07:00 - 10:35 3.58 DRILL P PROD1 Test WILD Drilling bit and BHA as per Schlumberger Op = 3.00 bpm at 293 psi T = 88.3 deg F at out micro motion 10:35 - 12:00 1.42 DRILL P PROD1 WILD BHA failed in the lower drilling section, POOH with Printed: 2/13/2008 2:42:09 PM BP EXPLORATION Page 26 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: 1 ,Phase Description of Operations Date From - To Hours Task I Code i NPT 1/15/2008 10:35 - 12:00 1.421 DRILL P 12:00 - 13:45 1.751 DRILL ~ N 13:45 - 14:00 I 0.251 DRILL N 14:00 - 19:00 I 5.001 DRILL I N 19:00 - 20:50 1.831 DRILL ~ N 20:50 - 00:00 I 3.171 DRILL I N 11/16/2008 100:00 - 05:40 I 5.671 DRILL I N 05:40 - 06:30 0.831 DRILL ~ N 06:30 - 06:40 0.17 DRILL N 06:40 - 08:00 1.33 DRILL N 08:00 - 16:00 8.00 DRILL N 16:00 - 17:20 I 1.331 DRILL I N 17:20 - 18:00 0.67 DRILL N 18:00 - 19:30 1.50 DRILL N 19:30 - 00:00 I 4.501 DRILL I N PROD1 wireline. Drilled a total of 4 ft with the WILD BHA. Cuttings were small and samples were nonrealistic of the present bit depth. The sand grains were well round due to either deposition or mechanical issues with the low flow rates of WILD. PROD1 At surface w/ top of CSH. SD pumping down the IA after moving 2350 bbls at 3.0/265 w/final return temp -89F and PVT 292, OA 190. Remove circ head from eline connector. Check continuity, okay (before doing a pull test before redoing continuity test). Use clamp on the 3' of slack. Attach spear and do pull tests on eline up to 6000# w/ annular closed. Continuity test showed a short PROD1 Safety mtg re: POOH w/ eline and CSH. Will need to pull out of weak point so that eline doesn't have to be cut in 30' lengths. W II need to set BOP slips on safety jt to pull out of weak point PROD1 Use clamp and spear and LD the 4 CSH pups and one single. MU 2-3/8 PH6 safety jt w/ XO to CSH in the hole. Insert spear and find that the CSH XO has too small of ID to pass the 1.125" spear. WO XO from BTT PROD1 MU single joint of 2-3/8" PH6 w/ XO's. Set in slips rams. MU T-bar assembly & pull out of disconnect ~ 6k. Splice together e-line, a la Torpedo. Spool out a-line from BHA onto a-line unit. PROD1 LD CSH in singles in pipe shed. MU new a-line anchor assembly. LD broken drilling BHA. Remove bit - 3 plugged jets, slight clay balling - claystone, sandstone, cement & pyrite (presumably from higher above in the hole). Fill hole - 1 bbl. PROD1 Spool off - 850ft of a-line cable from a-line unit. MU new drilling BHA. Test BHA at surface, shorting issues in the "secret part of the tool". Continue to rehead a-line cable. Partially break down current BHA. Mix & match parts from previous BHA w/ present BHA. String a-line cable through 2 jts of CSH. Work on latch assembly. PROD1 Test BHA okay Determined that the problem in the BHA was in the 'driller' and was not a short, but a hardware issue. Can't pinpoint the problem until the tool is been broken down PROD1 Safety mtg re: RU to run CSH PROD1 MU one jt of CSH prethreaded w/ eline to the top of the BHA. RIH, fill w/ FW and test okay PROD1 MU prethreaded CSH singles using T bar on a tugger to pull slack and use clamp to hold wire when CSH is in the slips. Test continuity every 9 jts PROD1 Install circ head and hang off eline. Install splice and check continuity. Install packoff assy and prep a-line to RIH Rig spend 20 min thawing IA valves before circ can be established PROD1 RIH w/ a-line Begin circ down IA at 3.0/360 w/ 56F and PVT 284 initial PROD1 POH w/ a-line from 5100' ... 'tool problems'. Blow down pump line & kill /choke line. PROD1 LD 2 single jts of CSH. Inspect a-line anchor at umbilical junction. A short exist here at one of the connectors. Cut off 2 ft Printed: 2/13/2008 2:42:09 PM ~ ~ BP EXPLORATION Page 27 of 36 Operations Summary Report Legal Well Name: C-35 Common W ell Name: C-35 Spud Date: 2/15/1986 Event Nam e: REENTE R+COM PLET E Start : 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALIST A Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours i Task Code NPT Phase j Description of Operations 1/16/2008 19:30 - 00:00 4.50 DRILL N PROD1 of a-line & test wire. Another short exists downhole. MU new rope socket. 1/17/2008 00:00 - 01:50 1.83 DRILL N PROD1 MU single joint of 2-3/8" PH6 w/ XO's. Set in slips rams. MU T-bar assembly & pull out of disconnect ~ 5k. Splice together e-line, via Torpedo. Spool out a-line from BHA onto a-line unit. 01:50 - 03:00 1.17 DRILL N PRODi LD CSH in singles in pipe shed, use mud bucket on each connection. MU new a-line anchor assembly. 03:00 - 04:10 1.17 DRILL N PROD1 Pin check tool at upper connection. Remove 3 pieces, found visible short in connection -possible crack in insulation of electrical connector. 04:10 - 08:00 3.83 DRILL N PROD1 MU new BHA. Cut off -30' from umbilical and rehead 08:00 - 09:00 1.00 DRILL N PRODi MU one jt of CSH prethreaded w/ eline to the top of the BHA. RIH, fill w/ FW and test okay 09:00 - 15:00 6.00 DRILL N PROD1 MU prethreaded CSH singles using T-bar on a tugger to pull slack and use clamp to hold wire when CSH is in the slips. Test continuity after 13 jts. MU a total of 26 jts of CSH plus two 7.8' pups. MU a-line head and test again. MU packoff 15:00 - 16:45 1.75 DRILL N PROD1 RIH w/WILD on a-line into open hole Pump down the IA 3.0/360 w/ 54F returns C~ PVT 282 initial 16:45 - 20:00 3.25 DRILL N PROD1 PUH to window to log tie-in and tool shorted. POOH. Stop pumping & blow down IA line & kill/choke line. 20:00 - 22:00 2.00 DRILL P PROD1 MU single joint of 2-3/8" PH6 w/ XO's. Set in slips rams. MU T-bar assembly & pull out of disconnect ~ 5k.Tie knot in a-line & spool off - 850ft of a-line cable to a-line unit. LD CSH. 22:00 - 00:00 2.00 DRILL P PROD1 LD BHA. Off load WILD tools from pipeshed. Clean RF. RD e-line unit & equipment. 1/18/2008 00:00 - 03:30 3.50 DRILL P PROD1 Offload WILD tools & equipment from RF. MU BHI toolstring on catwalk & test same. ND a-line BOPE. NU 7" Otis lubricator. 03:30 - 04:00 0.50 WHSUR P PROD1 P.T. lubricator to 3500 psi -good test. Back up vac truck to rig & fill out fluid transfer. 04:00 - 05:00 1.00 DRILL P PROD1 Leak from hose in pump room coming from vac truck. See remarks. 05:00 - 06:30 1.50 DRILL P PROD1 Begin pumping KCL down IA, 4.75 bpm ~ 135psi WHP and pump 290 bbls. Recover 25k LSRV mud and send to MI to recondition for drilling 06:30 - 08:00 1.50 DRILL P PROD1 Swap to 1 %KCI w/ Nalco EC1124A corrosion inhibitor 4.7/540 and pump 290 bbls Safety mtg re: RU SWS slickline ROPE 08:00 - 10:30 2.50 DRILL P PRODi MIRU LRS. PT ~ 3000 psi. FP the IA to 2200' with 120 bbls 50F diesel down the IA w/ KCI returns from the tubing at avg 1.3/300 10:30 - 12:30 2.00 DRILL P PROD1 Finish RU slickline. RIH and close BOT CMD sliding sleeve at 8314'. POOH w/ tool string. Install cap on WL BOP's 12:30 - 13:50 1.33 DRILL P PROD1 LRS PT IA to 3000 psi w/ 5.9 bbls diesel for 10 min and lost 30 psi w/ no flow from tubing. OA rose from -20 to 140 psi. Bleed off IAP to zero and recover 6 bbls while OA returned to -20 RDMO LRS. RDMO SWS slickline 13:50 - 15:15 1.42 DRILL P PROD1 Safety mtg re: MU BHA MU BHI MWD assy w/ 1.2 deg motor and bi bit 15:15 - 17:00 1.75 DRILL P PRODi RIH w/ BHA #26 circ KCI thru bit 0.5/300. Swap to 70k LSRV mud 0.6/570 while displace from CT and circ out 1 %KCI 17:00 - 17:20 0.33 DRILL P PROD1 Log tie-in down from 8830'. Corr -16' 17:20 - 17:30 0.17 DRILL P PROD1 Take a few tries to get thru window at min rate, but got thru w/ Printed: 2/13/2008 2:42:09 PM . ~ ~ BP EXPLORATION Page 28 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task i Code ! NPT ; Phase Description of Operations 1/18/2008 117:20 - 17:30 I 0.171 DRILL I P 17:30 - 18:00 I 0.501 DRILL I P 18:00 - 22:40 I 4.671 DRILL I P 22:40 - 23:00 I 0.33) DRILL I P 23:00 - 00:00 I 1.001 DRILL I P 1/19/2008 100:00 - 04:10 I 4.171 DRILL I P 04:10 - 04:15 I 0.081 DRILL I P 04:15 - 06:00 I 1.751 DRILL I P 06:00 - 06:50 0.831 DRILL P 06:50 - 07:20 0.50 DRILL P 07:20 - 11:25 4.08 DRILL P 11:25 - 11:45 0.33 DRILL P 11:45 - 13:20 1.58 DRILL P 13:20 - 14:30 1.17 DRILL P 14:30 - 22:40 8.17 BOPSU P PROD1 no pump. Precautionary ream to TD 2.4/2450 at 20'/min and hole was clean. Stall at 8979' PROD1 End WILD charges at 1730 hrs 1/18/07 Resume drilling from 8979' 2.42/2460/175L Have several stalls getting started PROD1 Drilling build section from 8,979 ft to 9078 ft 45-30L Free spin 2750 psi at 2.5 bpm Op 2.51/2.50 bpm at 2900 psi Vp = 196 bbl (turn on centrifuges at 21:15) WOB 0.5 to 1 k ROP's range 20 to 30 fph ECD = 9.57 ppg PROD1 Reboot BHI computer. Wiper to window -clean. Wiper to TD - clean. PRODi Drilling build section in Zone 4 from 9,078 ft to 9,090 ft 45-30L Free spin 2700 psi at 2.55 bpm Op 2.55/2.55 bpm at 2920 psi Vp = 198 bbl WOB 0.5 to 1 k ROP's range 20 to 30 fph ECD = 9.57 ppg DHT = 120 deg. ST = 83 deg. PROD1 Drilling build section in Zone 4 from 9,090 ft to 9,170 ft 60-30L Free spin 2700 psi at 2.55 bpm Op 2.55/2.55 bpm at 2920 psi Vp = 200 bbl WOB 0.5 to 1 k ROP's range 15 to 25 fph ECD = 9.61 ppg DHT = 120 deg. ST = 83 deg. PROD1 Slight stall & starting to have slight losses -slowly starting from 0.05bpm and increasing to 0.15bpm, continued to have losses for - 10 min (possible cross over into higher porosity of Zone 3 ). Bled off IA from 600psi to Opsi in 5 min (all diesel) to slop trailer. PROD1 Drilling build section in Zone 3 from 9,160 ft to 9,208 ft 60-30L Free spin 2670 psi at 2.54 bpm Op 2.56/2.52 bpm at 2780 psi Vp = 191 bbl WOB 0.25 to 0.75 k ROP's range 10 to 20 fph ECD = 9.58 ppg DHT = 122 deg. ST = 87 deg. PROD1 "'"NOTE"' Geologst has called the top of Zone 3 at 9160ft. Drilling build section in Zone 3 from 9,208 ft to 9,230 ft 60-30L Free spin 2670 psi at 2.49 bpm Op 2.49/2.44 bpm at 2780 psi Vp = 190 bbl WOB 1 to 2.25 k ROP's range 20 to 35 fph ECD = 9.68 ppg DHT = 122 deg. ST = 88 deg. PROD1 Wiper to window was clean both directions PVT 184 PROD1 Drill from 9230' 2.52/2710/45L w/ 150-400 psi dill, 1-2k wob, ECD 9.62 at 15-40'/hr while continuing the build in Z3 at 42 deg. Drill to 9300' and penetration has slowed to 10'/hr, but are thru Z3 PVT 180 PROD1 Wiper to window was clean PROD1 POOH circ thru EDC 2.6/2600. Swap to water PROD1 LD drilling BHA. Bit was 3-4-I and starting to core. Blow CT back w/ air PROD1 Biweekly ROPE test witnessed by AOGCC Chuck Scheve. Test #1. Upper 2-3/8", choke HCR, Kill HCR Test #2. Upper Printed: 2/13/2008 2:42:09 PM ~ ~ BP EXPLORATION Page 29 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: i Date From - To Hours Task Code j NPT Phase '~, Description of Operations 1/19/2008 114:30 - 22:40 I 8.171 BOPSURP 22:40 - 00:00 1.331 DRILL P 1/20/2008 100:00 - 02:00 2.00 DRILL P 02:00 - 02:30 0.50 DRILL P 02:30 - 02:50 0.33 DRILL P 02:50 - 05:55 3.08 DRILL P 05:55 - 06:30 0.58 DRILL P 06:30 - 07:30 1.00 DRILL P 07:30 - 09:40 2.17 DRILL P 09:40 - 10:30 0.83 DRILL P 10:30 - 12:45 2.25 DRILL P 12:45 - 13:15 0.50 DRILL P 13:15 - 13:40 0.42 DRILL P 13:40 - 14:10 0.50 DRILL P 14:10 - 16:05 1.92 DRILL P 16:05 - 17:05 1.00 DRILL P 17:05 - 19:40 2.58 DRILL P PROD1 2-3/8", Man Kill, Man Choke Test #3. 2-3/8"x3-1/2" VBR Test #4. Lower 2-3/8" Combi Test #5. Annular, Kill HCR Test #6. Blinds, Kill HCR, Choke, Valves-9,10,11,13 Test #7. Blinds, Kill HCR, Choke, Valves-7,8,3,4,11,13 Test #8. Blinds, Kill HCR, Choke, Valves-1,2,6,12 (Had to grease valve #1,2,6,12 & retest) Test #9. Blinds, Kill HCR, Choke, Valves-1,2,5,12 Test #10. Inner Reel Valve Test #11. Injector Packoffs & coil check valves Test #12. Floor Valve Accumulator Draw Down Full System = 3000psi After Function = 2150psi First 200psi Build Up = 20 sec Full System Build Up = 1 min 30 sec N2 = 2100psi avg. PROD1 PJSM regarding handling BHA. Pop off well & place injector over bung and circ at min rate. Check grub screws on coil connector -good. Open swab & master valve -can't see fluid level. MU 4-1/4" HYC BC bit to mud motor & place in well. PU & attach BHI MWD tools to mud motor. MU coil to tools & stab onto well. Test tool & open EDC. PRODi RIH w/ coil circ (~ .4bpm/950psi. 4 bbls to catch fluid & - 6 bbls until it cleaned up = 0.5 bph static losses. PVT = 124bb1s. PRODi Log down for tie-in from 8830ft (-ift corr. PROD1 Start mud swap. Wiper to TD -clean. Tag bottom at 9300ft. PROD1 ***NOTE*** Geologst has called the top of Zone 2 at 9260ft. Drilling build section in Zone 2 from 9,300 ft to 9,450 ft 70-60L Free spin 3000 psi at 2.48 bpm Op 2.48/2.49 bpm at 3275 psi Vp = 147 bbl WOB 1 to 2 k (24k surface wt). NBI 50deg. ROP's range 40 to 60 fph. ECD = 9.80 ppg DHT = 134 deg. ST = 81 deg. CTW up = 39k. PROD1 Wiper to window -clean. Finish mud swap PRODi Resistivity MAD pass from 8900' to TD PVT 323 PROD1 Drill from 9450' 2.48/3000/70L w/ 200-400 psi dill, 1-3k wob, 9.83 ECD at 80-110'/hr while continuing the build/turn in Z2 from 8820' TVD and 57 deg. Swap to right at 9550'. Drill to 9600' PVT 321 PROD1 Wiper to window 37k was clean PVT 319 PROD1 Drill from 9600' 2.50/3020/458 w/ 200-500 psi dill, 1-3.5k wob, 9.87 ECD at 100'/hr at 67 deg Drill to 9750' PVT 314 PROD1 Wiper to window was clean Ambient temp is 38F, that's +38F! PROD1 log tie-in down to RA pip from 8925' and missed it. Relog from 8920', Corr +2' PROD1 Wiper to TD tagged at 9752' PVT 310 PROD1 Drill from 9752' 2.60/3130/308 w/ 200-500 psi dill, 1.3-3.5k wob, 9.96 ECD at 80-110'/hr at 81 deg while finishing the build by 9825'. Swap to left at 9890' and drill to 9900' PROD1 Wiper to window was clean both directions PVT 302 PROD1 Drill from 9900' 2.59/3180/85L w/ 200-500 psi dill, 1.2-3.4k Printed: 2/13/2008 2:42:09 PM ~ ~ BP EXPLORATION Page 30 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code ~ NPT Phase Description of Operations 1/20/2008 117:05 - 19:40 I 2.581 DRILL I P 19:40 - 21:20 I 1.671 DRILL I P 21:20 - 00:00 I 2.671 DRILL f P 1/21/2008 100:00 - 00:15 I 0.251 DRILL I P 00:15 - 01:45 I 1.501 DRILL I P 01:45 - 02:00 0.25 DRILL P 02:00 - 02:50 0.83 DRILL P 02:50 - 05:30 2.67 DRILL P 05:30 - 07:10 1.67 DRILL P 07:10 - 09:55 2.75 DRILL P 09:55 - 11:30 1.58 DRILL P 11:30 - 13:45 2.25 DRILL P PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 wob, 10.04 ECD at 80-110'/hr at 92 deg while finish the turn and set up for the lateral. DHT=138 deg. Wiper to window w/ 2.75bpm ~ 3600psi -clean. Losses are 4.5bbls/hr while drilling. Bleed off IA & OA from 500psi to Opsi to a slop trailer in 5 min each. Drilling lateral section in Zone 2 from 10,050 ft to 10,200 ft 90L Free spin 3190 psi at 2.50 bpm Op 2.51/2.46 bpm at 3567 psi Vp = 290 bbl (centrifuge 'A' is runing) WOB 1 to 2 k (22-19k surface wt). ROP's range 60 to 100 fph. ECD = 10.04 ppg DHT = 140 deg. ST = 98 deg. CTW up = 39k, (46k to get it moving). Continue drilling lateral section in Zone 2 from 10,200 ft to 10,250 ft 120E Free spin 3190 psi at 2.50 bpm Op 2.51/2.46 bpm at 3567 psi Vp = 290 bbl (centrifuge 'A' is runing) WOB 1 to 2 k (22-19k surface wt). ROP's range 60 to 100 fph. ECD = 10.04 ppg DHT = 140 deg. ST = 98 deg. CTW up = 39k, (46k to get it moving). Wiper to window w/ 2.75bpm ~ 3530psi -clean. Open EDC & PUH to 8,500ft C~ 3.8bpm/4100psi. Close EDC. Log down for tie-in from 8,830ft (+4ft corr. Wiper to TD, 2.55bpm ~ 3300psi -clean. Conduct mud swap. Drilling lateral section in Zone 2 from 10,250 ft to 10,450 ft 110-90L Free spin 3060 psi at 2.50 bpm Op 2.50/2.53 bpm at 3525 psi Vp = 200 bbl (conducting mud swap) WOB 1 to 1.5 k (22-19k surface wt). ROP's range 80 to 110 fph. ECD = 9.88 ppg DHT = 144 deg. ST = 98 deg. Wiper to window. Clean PU off bottom @ 37k up wt. PVT 276 Drill from 10450' 2.6/3150/90L w/ 200-400 psi dill, 0.5-2.Ok wob, 9.91 ECD at 100'/hr holding 90 deg at 8945' TVD. Swap to right at 10472'. Occasional diff sticking in the faster drilling. Ran into a rubble zone? at 10535'. Spend 40 min w/ stalls and OP's while drilling to 10560'-no losses. Resume drilling sand at 100'/hr. Drill to 10600' PVT 272 Wiper to window was clean both directions Drill from 10600' 2.60/3250/908 w/ 200-300 psi diff, 1.0-2.5k wob, 10.0 ECD at 60-100'/hr holding 90 deg at 8945'-8947' TVD Drill to 10750' Wiper to window, clean PVT 256 Log tie-in down from 8905', corr +4' Wiper to TD was clean PVT 247 Drill from tag at 10751' 2.62/3350/708 w/ 200-400 psi diff, 2.5-5.Ok wob, 10.13 ECD at 10-50'/hr holding 90 deg at 8947' TVD Wiper trip to window -slight motor work at 10,525' & 10,583', otherwise clean. PROD1 PROD1 13:45 - 14:35 0.83 DRILL P PROD1 14:35 - 14:55 0.33 DRILL P PROD1 14:55 - 15:50 0.92 DRILL P PROD1 15:50 - 18:15 2.42 DRILL P PRODi 18:15 - 21:15 I 3.001 DRILL P PROD1 Printed: 2/13/2008 2:42:09 PM BP EXPLORATION Page 31 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code ! NPT ; Phase Description of Operations 1/21/2008 121:15 - 00:00 I 2.751 DRILL I P PROD1 1/22/2008 00:00 - 01:45 1.75 DRILL P PROD1 01:45 - 02:35 0.83 DRILL P PROD1 02:35 - 05:00 2.42 DRILL P PROD1 05:00 - 06:40 1.67 DRILL P PRODi 06:40 - 08:30 1.83 DRILL P PROD1 08:30 - 10:10 I 1.671 DRILL I P I I PRODi 10:10 - 11:55 1.75 DRILL P PROD1 11:55 - 12:10 0.25 DRILL P PROD1 12:10 - 13:35 1.42 DRILL P PROD1 13:35 - 15:25 1.83 DRILL P PROD1 15:25 - 17:00 1.58 DRILL P PROD1 17:00 - 18:40 1.67 DRILL P PRODi 18:40 - 19:25 I 0.751 DRILL P PROD1 19:25 - 22:45 3.33 DRILL P PROD1 22:45 - 00:00 1.25 DRILL P PROD1 1/23/2008 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 02:30 2.00 DRILL P PROD1 02:30 - 02:45 I 0.25 ~ DRILL ~ P ~ ~ PROD1 Drilling lateral section in Zone 2 from 10,900 ft to 11,050 ft 110-90L Free spin 3250 psi at 2.75 bpm Op 2.50/2.48 bpm at 3350 psi Vp = 229 bbl (centrifuge 'A' & 'B' are running) (losses are 2bbl/hr while drilling) WOB 1 to 1.75 k (20-17k surface wt). ROP's range 20 to 80 fph. ECD = 10.23 ppg DHT = 152 deg. ST = 100 deg. Wiper to window, 2.77bpm ~ 3680psi -clean. Wiper to TD, 2.77bpm ~ 3680psi -clean. Drilling lateral section in Zone 2 from 11,050 ft to 11,200 ft` " 110-90L Free spin 3400 psi at 2.50 bpm Op 2.48/2.45 bpm at 3450 psi Vp = 207 bbl (centrifuge 'A' & 'B' are running) (losses are 3.6bb1/hr while drilling) WOB 1 to 2 k (19-15k surface wt). ROP's range 20 to 80 fph. ECD = 10.31 ppg DHT = 156 deg. ST = 101 deg. Wiper to window, 2.6bpm C~ 3850psi. Pull thru window, clean. Open EDC. POOH thru 7"jetting solids 2.7/3400 POOH for motor, orientor. Inspect final 50' of CT for wear and find a few flat spots within tolerance LD drilling BHA. Bit was 5-4-I and cored, motor tile. Change bit and orientor RIH w/ BHA #27 circ thru EDC 0.6/1425. Close EDC & log down from 8835ft (-0.5ft corr. Wiper to TD 2.6bpm @ 3600psi. Set down at 10,025ft. Drilling lateral section in Zone 2 from 11,200 ft to 11,330 ft ~ 110-90L Free spin 3600 psi at 2.50 bpm Op 2./2.45 bpm at 3450 psi Vp = 173 bbl (centrifuge'A' are running) (losses are 3.6bb1/hr while drilling) WOB 1 to 2 k (19-15k surface wt). ROP's range 20 to 80 fph. ECD = 10.17 ppg DHT = 156 deg. ST = 94 deg. W iper trip to tie in Log tie-in down at 150 ft (2.5 ft correction) RIH to 9,600 ft to conduct MAD pass. Log from 9,600 ft to 9875ft. Tag twice at 9875ft. Wiper to TD, 2.7bpm (~ 3800psi -clean. Replace swabs & liners on pump #1. Tag TD C~3 11,330ft. MAD pass to 9875ft, 1.5bpm ~ 2665psi. RIH to TD. Lay in 50bb1 100k LSRV liner pill with 2ppb alpine beads from TD. Continue to lay in liner pill from TD, 1 for 1 to the window. Open EDC ~ 8848ft. Pump ~ 2.9bpm to clean up 7" casing. POH to surface. Tag up. Stop pumping. Flow check. PJSM regarding handling BHA, discuss working in phase II weather in windy conditions. Printed: 2/13/2008 2:42:09 PM .~ BP EXPLORATION Page 32 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ' Task Code NPT Phase ! Description of Operations 1/23/2008 02:45 - 04:35 1.83 RIGU P RUNPRD Pop off well. Break off BHI tools from coil. Set injector on legs over bung hole & circ ~ min rate. Blow down BHI tools, bit was 2-2 & starting to core. RU Eckel tongs. RU 2-7/8" elevators. Prep floor to run liner. Clear catwalk of BHI tools. Hoist BOT liner running equipment to RF. Prep 2-3/8" PH6 safety joint w/ XO's. Fill hole - 1 bbl. 04:35 - 04:45 0.17 CASE P RUNPRD PJSM regarding handling liner. Discuss hazards such as pinch points, proper torque, windy conditions. 04:45 - 06:00 1.25 CASE P RUNPRD MU liner per program. 06:00 - 07:00 1.00 CASE P RUNPRD Crew change, Spill Champion Wakabout. Held PJSM and discussed the SOP for handling and running CTD liner 07:00 - 07:15 0.25 CASE P RUNPRD Run 2-7/8" Liner 07:15 - 18:00 10.75 CASE N WAIT RUNPRD Phase III called at 07:15 hrs Notified ADW HSE advisor on present situtation Presently 23 jts 2/7/8" liner in the hole 12,000 gal fuel on rig and 3,100 gal fuel at camp. Water OK. Sent 3rd Party Vendors to Mancamp to rest during Phase Ill weather conditions. SLB and Nordic working on job procedures and SOP's Sent Mud engineer and BHI MWD personnel to man camp. 18:00 - 00:00 6.00 CASE N WAIT RUNPRD Still in Phase III weather. Continue to monitor hole, fill hole/break circulation as needed. Continue to work on SOP's & table top drills. 1/24/2008 00:00 - 00:50 0.83 CASE N WAIT RUNPRD Continue to standby for weather. Fill hole every hour. Heavy equipment is cleaning out access to medical facilities. Rig loader has cleared the pad & to the twin towers road. 00:50 - 01:30 0.67 CASE N WAIT RUNPRD Phase II on roads, level III on pads. Contact IMT, C pad Op & get ok to go back to work. Clear out entryways & stairs of snow. Conduct spill champion paperwork. Take on precious rig water! PJSM regarding MU liner, discuss pinch points, STF,over head loads, possible ice in the derrick. 01:30 - 02:00 0.50 CASE P RUNPRD Continue to MU liner per program. 02:00 - 02:20 0.33 CASE P RUNPRD Fill liner. Swap to 3-3/16" elevators. MU XO on 2-3/8" PH6 safety joint. C/O dies in Eckel tongs. 02:20 - 04:25 2.08 CASE P RUNPRD Continue to MU liner per program. 04:25 - 04:35 0.17 CASE P RUNPRD Swap to 3-1/2" elevators & C/O dies in Eckel tongs. 04:35 - 05:25 0.83 CASE P RUNPRD Continue to MU liner per program. 05:25 - 06:00 0.58 CASE P RUNPRD Fill liner. Clean RF. PU & MU BHI tools to liner. PU injector & stab coil onto BHA. Stab onto well. 06:00 - 06:45 0.75 CASE P RUNPRD Crew change, held pJSM and talked about hazards on PU the BHI BHA and SLB injector 06:45 - 07:50 1.08 CASE P RUNPRD PU BHA with EDC closed. PU injector and megged cable connect. 07:50 - 10:15 2.42 CASE P RUNPRD Set counters and RIH with liner Op = 0.22 bpm at 2275 psi, (Flo-Pro a little thick this morning) Wt check 8800 ft = 37k up and 22.5 k down at 22 fpm RIH and tagged bottom at 11330 ft corrected 10:15 - 12:15 2.00 CASE P RUNPRD Released from liner TOL 8548 ft and PBTD at 11294 ft POOH with LRT 12:15 - 13:30 1.25 CASE P RUNPRD OOH, LD BHA and LRT 13:30 - 16:45 3.25 CEMT P RUNPRD Pumped in pickle fluids and held PJSM with N2 Pumpers Blow down reel to TT. Un-thaw cement line (iced up) 16:45 - 19:45 3.00 CEMT P RUNPRD PT N2 lines, fix leak. SLB had to go to the BOC to find a Printed: 2/13/2008 2:42:09 PM • BP EXPLORATION Page 33 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ! Task Code NPT Phase I, Description of Operations - - ~ 1/24/2008 16:45 - 19:45 3.00 - CEMT P - RUNPRD replacement check valve. PT surface lines to 4000 psi. Pump pickle fluid and followed by blowing down with N2. Let coil bleed off & RD N2 unit. 19:45 - 23:00 3.25 CEMT P RUNPRD Circulate across the top to keep the hole full - 1 bbl/hr losses. Cut off coil connector. Prep end of a-line cable. RU internal grapple connector & cable for unstabbing coil. PJSM regarding pulling coil across. Pull coil across & secure coil w/ shipping bar. Remove inner hardline from a-line reel. RU lifting slings to reel. 23:00 - 00:00 1.00 CEMT P RUNPRD PJSM regarding lowering coil -discuss cold temps, STF's, overhead loads, buddy system, proper communication. Lower e-coil to low boy trailer & PU a-less coil & secure in reel house. 1/25/2008 00:00 - 02:50 2.83 CEMT P RUNPRD Continue to secure a-less coil in reel house. RU hardline inside reel. Remove & secure lifting slings. RU internal grapple connector. Pull coil across & stab into injector. 02:50 - 03:30 0.67 CEMT P RUNPRD Dress end of coil. Install BOT slip/set screw CTC. Pull test to 35k -good. Install dart catcher. Stop fill across the top & shut swab valve. Stab onto well. 03:30 - 04:20 0.83 CEMT P RUNPRD Fill coil with methanol _ 2 bbls, 5bbls of water followed by flo-pro ~ 2.5 bpm. 04:20 - 08:45 4.42 CEMT N RUNPRD Load dart into coil & launch w/ flo-pro. Dart landed at 59.6 bbls away. Retrieve dart. Load another dart to verify coil volumes. Second dart landed at 58.6 bbls. Pumped 3rd dart to confirm due to 1 bbl volume differential. SLB Hayden Electrician checked the power pack traction motor. OK 08:45 - 09:45 1.00 CEMT P RUNPRD Installed 4th dart (new one) and found some restriction in the reel house 2" iron. Took apart to conduct visual inspection. Changed out 2" ball valve. Dart landed at 59.3 bbl. Good 09:45 - 10:45 1.00 CEMT P RUNPRD PU cementing BHA with 2 jts of 2-3/8" PH6 10:45 - 12:20 1.58 CEMT P RUNPRD Set counters and RIH. Wt check at 8500 ft . RIH and tagged at 8546 ft. Set 5k down and PU and have the liner 37.8k PU wt. 12:20 - 12:45 0.42 CEMT P RUNPRD Circulate and reduce the gel streenght on the mud prio to dropping ball Qi = 1.59 bpm at 3600 psi. 02 = 2.10 bpm at 3500 psi. 12:45 - 14:15 1.50 CEMT P RUNPRD Confirmed and dropped 1/2" steel ball to release Displace ball at 2.20 bpm and 3,772 psi Slowed down at 49 bbl to 1.25 bpm and at 58 slowed down to 1.00 bpm. Can't get ball on seat. Vct = 59.5 bbl's Tried several flowrates from 0 to 1.6 bpm and worked the ct/liner and still unable to get ball on seat. PU on CT, liner moves at 48 k up. 14:15 - 15:34 1.32 CEMT P RUNPRD SD, drop 5/8" AI ball. Pumped ball down CT at 1.00 bpm Pumped 79 bbl and no AI ball on seat. SD pump and PU and liner is moving at 48k. SD and pumping at 1.00 bpm and PU and looks like we are off the liner 15:34 - 18:15 2.68 CEMT N RUNPRD Unable to release from liner, POOH with liner weighting 38.7k same wt as before landing on 10:15 hrs 1/24/08 18:15 - 18:25 0.17 CEMT N RUNPRD PJSM regarding handling BHA. Flow check well. 18:25 - 20:20 1.92 CEMT N RUNPRD Pop off well, install XO & ball catcher nozzle & place injector in bung hole. Break off 2jts of 2-3/8" PH6 tubing & LD in pipeshed. LD 2-3/8 PH6 XO's. Release CTLRT from liner & LD Printed: 2/13/2008 2:42:09 PM • • BP EXPLORATION Page 34 of 36 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: C-35 C-35 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Spud Date: 2/15/1986 Start: 12/6/2007 End: 1/29/2007 Rig Release: 1 /29/2008 Rig Number: Phase ~'; Description of Operations RUNPRD on catwalk, recovered 1 steel ball & 1 aluminum ball. PU new RUNPRD Tag up. Set counters. Fill liner. RIH. WT check ~ 8800ft = 32k. RIH w/liner in OH section (~ 100Wmin, set downs ~ 10900ft & 11085ft. Tag bottom at 11,330ft, RIW = 12k, PU wt = 36.8k ~ 1bpm. Repeat w/out pumps, PU wt = 54k, RIW = 17k. RUNPRD PU to ball drop position. Launch 5/8" aluminum ball w/ 500psi using flo-pro. Circulate ball ~ 2.Obpm, 3480psi. Listen for ball in reel -can hear zinging around! RIH & tag bottom w/ liner. Reduce rate to 0.75bpm C~ 50bbls away. Ball landed C~3 52.8bbls away & sheared at 4200psi as the pump tripped. PU 31 k, released from liner. RUNPRD Call for cementers. Line up & swap well bore to 2% KCL 2.17bpm in ~ 3400psi / 2.14bpm out ~ 41 psi. RUNPRD Continue to swap well to 2% KCL. Final rates/pressure are 2.31 bpm in ~ 1366psi, 2.20bpm out ~ 33psi. Spot cementers. Spot vac trucks. RUNPRD PJSM regarding cementing ops. Discuss working in cold temps, high winds, STF's, high pressure pumping, pinch points, caustic fluids, vehicle ops & vehicle hazards, mustar point. RUNPRD Continue to circulate ~ 2.3bpm ~ 1350psi. RU cement truck. Prime up cement truck. Purge cement line from reel house to ensure it's clear -good. Rig up new hose for rig water for cement clean up. Begin batching up cement ~ 3:OOam. RUNPRD 40bbls of 15.8ppg class 'G' cement is up to weight ~ 03:20. Thickening time is 3hr & 40 min. RUNPRD Pump 5.2 bbls of Bio to fill lines w/ rig pump to reel hardline. Attempt to pump from cement truck -frozen valve, replace valve. Warm up & PT cement lines to 4000 psi -good test. RUNPRD Start pumping cement, zero when 11 ppg at MM. Pumped 33 bbls of 15.8ppg class 'G' cement, 2.10bpm ~ 2875psi. RUNPRD Stop pumping, isolate inner reel valve & clean up cement lines with Bio & vac out. Load Pee Wee dart into coil past tee on inner reel manifold. Launch w/ 500 psi. Simultaneously, clean up cement truck to vac truck. RUNPRD Zero MM's. Pump Pee Wee dart downhole w/ Bio, 2.75bpm @ 2900psi. Reduce rate to lbpm 300psi. RUNPRD Pump LWP to latch collar. 13 bbls of cement behind pipe & lost out MM. By-pass out MM & blow it down w/air. Minimum of 19.4 bbls of cement behind pipe according to out MM. LWP landed at the calculated volume. Pressure up to 2500psi - holding. Bleed off & check flow -checks are holding. Pressure up to 500psi & unsting from liner, 31 k up. RUNPRD POH pumping displacement. PJSM prior to being out of hole RUNPRD LD Cementing BHA and PU FCL mill and motor with 2 jts 1-1/4" CSH RUNPRD PJSM on handling radioactive source in MGR/CCL LOWERI PU FCO BHA LOWERi RIH with FCO /MGR /CCL BHA Wt check at 8200 ft = 28k up LOWERI Logging down from 8300 ft at 30 fpm down Op = 1.25 bpm at 1500 psi Sent 95 bbl of cement contaimintion to the cutting box. Tagged at 11271 ft Date ,From - To ~ Hours '. Task Code NPT __ 1/25/2008 18:25 - 20:20 1.92 CEMT N 20:20 - 22:20 2.00 CEMT N 22:20 - 22:55 I 0.581 CEMT I N 22:55 - 00:00 I 1.081 CEMT I P 1/26/2008 100:00 - 01:50 I 1.831 CEMT I P 01:50 - 02:00 0.17 ~ CEMT P 02:00 - 03:05 I 1.081 CEMT I P 03:05 - 03:35 I 0.501 CEMT I P 03:35 - 04:00 I 0.421 CEMT I P 04:00 - 04:15 0.25 CEMT P 04:15 - 04:30 0.25 CEMT P 04:30 - 05:00 0.50 CEMT P 05:00 - 05:20 0.33 CEMT P 05:20 - 07:04 1.73 CEMT P 07:04 - 08:15 1.18 CEMT P 08:15 - 08:30 0.25 CEMT P 08:30 - 13:30 5.00 EVAL P 13:30 - 15:00 1.50 EVAL P 15:00 - 16:45 I 1.75 I EVAL I P Printed: 2/13/2008 2:42:09 PM • BP EXPLORATION Page 35 of 36 ~ Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task ~ Code NPT Phase Description of Operations 1/26/2008 16:45 - 19:00 2.25 EVAL P LOWERI POOH logging MCNUGR/CCL and laying in pert pill at 60 fpm 19:00 - 22:45 3.75 EVAL P LOWERI Tag up & flow check. PJSM regarding handling BHA. Pop off well & place injector over bung hole & circulate. Drop 5/8" ball to open circ sub, 3000psi to open circ sub. Stand back 1-1/4" CSH in derrick. Recoverd 5/8" ball. Remove source & LD logging tools -check for data. Fill hole _ 1 bbl. 22:45 - 00:00 1.25 EVAL P LOW ER1 MU swizel stick & jet stack. Clean out all lines on choke manifold. Flow thru & PT Swaco choke to 3400psi -good test. 1/27/2008 00:00 - 06:00 6.00 EVAL N LOWERi Cement is at 1550psi compressive strength at midnight. Wait for cement to harden to 2000 psi compressive strength before testing liner lap. Perform weekly function test of BOPE per AOGCC regs. Clean RF. MU safety joint for running guns. Pertorm derrick inspection. 06:00 - 10:10 4.17 EVAL N LOWERI Cement compressive strength at 06:15 hrs = 1857 psi 2 24 hrs at Tested at 157 deg F cir and 190 deg F static temperature. +After 25 hrs. the compressibilty is 1920 psi. 2000 psi should be reached at 14:00 hrs the afternoon 10:10 - 11:03 0.88 EVAL P LOWERI Test liner Lap with reported compressive strength at 1900 psi 0500 psi (ok) 1011 psi (ok) 1500 psi (ok) 2144 psi. T1 = 10:33 hrs T2 = 2060 psi at 11:03 hrs 4% loss in 30 minutes Charted the 2000 psi interval for 30 minutes 11:03 - 11:15 0.20 EVAL P LOWERI Bleed wellhead pressure off and held PJSM on handling pert guns 11:15 - 12:30 1.25 EVAL P LOWERI RU to PU perf guns, Crew change for Nordic 12:30 - 14:00 1.50 EVAL P LOWERI PU Perf guns 14:00 - 15:45 1.75 EVAL P LOWERI RIH with 36 stds 1-1/4" CSH PU upper BHA and stab injector 15:45 - 17:45 2.00 EVAL P LOWERI RIH and tagged at 11296.4 ft 17:45 - 18:40 0.92 EVAL P LOWERI Pump 10 bbl biozan, SD and dropped 1/2" ball Pressured up to 500 psi and launched ball. Pumped 35 bbl biozan. Reduce rate at 40bbls away. Ball on seat at 53.8bbls away. Perform drive by perforating, guns fired at 3300psi. Perforate from 10,680ft to 11,280ft. 18:40 - 20:40 2.00 EVAL P LOW ER1 POH pumping across the top. PJSM while POH regarding handling BHA. 20:40 - 22:30 1.83 EVAL P LOWERI Tag up. Flow check well. Pop off well & place injector over bung hole to circulate. Stand back CSH in the derrick & fill hole every 5 stands. 22:30 - 22:40 0.17 EVAL P LOW ER1 Fill hole & flow check. PJSM regarding handling perf guns, discussed STF's, pinch points, trapped pressure in guns, mustar point, overhead loads, using Eckel rig tongs, burs on guns, handling warped guns. 22:40 - 00:00 1.33 EVAL P LOWERI RU Eckel tongs. LD perf guns (fired), fill hole every 5 guns. 1/28/2008 00:00 - 01:00 1.00 EVAL P LOWERI Continue to LD perf guns, fill hole every 5 guns, all guns fired. 01:00 - 01:45 0.75 EVAL P LOWERI Fill hole. RD Eckel tongs. Remove guns from pipeshed. Hoist SLB lifting equipment down the beaver slide. Clean RF. 01:45 - 02:00 0.25 RIGD P POST PJSM regarding PU CSH & LD in singles. 02:00 - 04:00 2.00 RIGD P POST MU 2.5" o.d. JSN w/ XO to CSH. PU &RIH w/ 44 stands of 1-1/4" CSH from derrick. 04:00 - 07:00 3.00 RIGD P POST POH w/ 1-1/4" CSH in singles. Fill hole every 10 jts. 07:00 - 09:15 2.25 RIGD P POST RIH to 2500 ft and pumped 42 bbl of diesel down coiled tubing Printed: 2/13/2008 2:42:09 PM • • BP EXPLORATION Page 36 of 36 Operations Summary Report Legal Well Name: C-35 Common Well Name: C-35 Spud Date: 2/15/1986 Event Name: REENTER+COMPLETE Start: 12/6/2007 End: 1/29/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/29/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ~ Code NPT` Phase Description of Operations 1/28/2008 09:15 - 09:45 0.50 RIGD P POST POOH laying in 40 bbl diesel freeze protect. Clean diesel at i the tree and circulated to the cutting box. 09:45 - 10:00 0.25 RIGD P POST Popped off well and rig up to set BPV. 10:00 - 13:00 3.00 RIGD P POST Pumped in corrosion inhibitor and blew down CT with N2 13:00 - 16:00 3.00 RIGD P POST Instabbed CT from injector and installed grabble and pull tested. Pull CT to reel and secured to reel Secured injector on the floor for rig move. Lower reeel and hauled to Deadhorse 16:00 - 18:00 2.00 RIGD P POST Collect all RAA and oily waste material and get off rig before going to Kupuark. Sucked out tiger tank and knocked off2 in line. Put top back on cutting box. Clean pits and haul off for fluid for disposal. 18:00 - 18:20 0.33 RIGD P POST C/O w/ day crew. PJSM reagarding rigging down Nordic 2. Discuss pinch points, STF's, overhead loads, working in cold temps, buddy system 18:20 - 00:00 5.67 RIGD P POST SLB swapped out stuffing box brass & packoffs to 2", swap gripper blocks to 2" on the injector, inspect gooseneck rollers. Warm up rig moving system ~ 21:30. Roll tires at 22:30. Rig down wiring to office camp. CH2MHILL rigged down 2" hardline to tiger tank. Swap out BOP rams to 2", having great difficulties with the lower set (closed on tool joint or XO & rolled the edge of the ram prevent removal). Continue to load equipment onto trailers & haul to Kuparuk. 1/29/2008 00:00 - 04:00 4.00 RIGD P POST ND BOPE & hang in cellar. Scope down derrick. NU tree cap & PT to 5000psi. Release Rig 04:00 Printetl: 2/13/2008 2:4Z:Oy PM a ' ~ • by BP Alaska Baker Hughes INTEQ Survey Report ~~~ sus INTEQ Company: BP Amoco Field: Prudhoe Bay Site: PB C Pad Well: G35 Wellpath: G356 Date: 1 /23!2008 Time: 08:35:19 Page: ] Co-ordinate(NE) Reference: WeA: G35, True North Vertical (TVD) Reference: 43:35 5/31/1996 09:59 66.2 Section (VS) Reference: Wefl (O.OON,O.OOE,293.98Azi) Survev Calculation Method: Minimum Curvature Db: Orade Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB C Pad TR-11-14 UNITED STATES :North Slope Site Position: Northiug: 5957218.72 ft Latitude: 70 17 22.367 N From: Map Easting: 662550.03 ft Longitude: 148 41 2.797 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.24 deg Well: G35 Slot Name: 35 G35 Well Position: +N/-S 2710.66 ft Northing: 5959971.94 ft Latitude: 70 17 49.024 N +E/-W 2007.06 ft Easting : 664497.88 ft Longitude: 148 40 4.294 W Position Uncertainty: 0.00 ft Wellpath: G35B Drilled From: G35 500292155302 Tie-on Depth: 8800.00 ft Current Datum: 43:35 5/31/1996 09:59 Height 66.19 ft Above System Datum: Mean Sea Level Magnetic Data: 8/3/2007 Declination: 23.67 deg Field Strength: 57654 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.19 0.00 0.00 293.98 Survey Program for Definitive Wellpath Date: 8/3!2007 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 100.04 8800.00 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 8871.00 11330.00 MWD (8871.00-11330.00) MWD MWD -Standard Annotation NID TVD ft ft 8800.00 8389.93 TIP 8871.00 8450.40 KOP 11330.00 9008.96 TD Survey: MWD Start Date: 1/21/2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD ft Intl deg Azim deg TVD ft Sys TVD ft N/S ft E/W ft MapN ft MapE ft VS ft DLS Tool deg/100ft 8800.00 31.62 331.70 8389.93 8323.74 1166.65 -1071.54 5961114.78 663401.14 1453.16 0.00 MWD 8871.00 31.61 331.84 8450.40 8384.21 1199.44 -1089.14 5961147.17 663382.82 1482.57 0.10 MWD 8909.73 26.47 325.62 8484.25 8418.06 1215.53 -1098.82 5961163.04 663372.80 1497.94 15.38 MWD 8935.61 23.91 323.87 8507.67 8441.48 1224.52 -1105.17 5961171.90 663366.25 1507.40 10.30 MWD 8971.30 21.39 321.21 8540.61 8474.42 1235.44 -1113.51 5961182.63 663357.67 1519.46 7.62 MWD 8999.82 22.79 318.85 8567.03 8500.84 1243.66 -1120.40 5961190.69 663350.60 1529.10 5.81 MWD 9032.69 25.65 314.51 8597.01 8530.82 1253.44 -1129.67 5961200.27 663341.12 1541,54 10.24 MWD 9061.84 28.25 312.51 8622.99 8556.80 1262.53 -1139.25 5961209.14 663331.34 1553.99 9.44 MWD 9091.41 31.26 310.63 8648.66 8582.47 1272.25 -1150.24 5961218.63 663320.15 1567.98 10.66 MWD 9121.66 33.29 305.94 8674.24 8608.05 1282.24 -1162.92 5961228.33 663307.25 1583.62 10.65 MWD 9151.18 35.80 302.57 8698.55 8632.36 1291.64 -1176.76 5961237.43 663293.21 1600.09 10.68 MWD • by BP Alaska $ Baker Hughes INTEQ Survey Report INTEQ ~ Company: BP Amoco Date: 1/23/2008 Time: 08:35:19 Page: 2 Field: Prudhoe Bay Co-0rdinate(NE) Reference: Well: C-35, True North Site: PB C Pad Vertical (TVD) Reference: 43:35 5/31/1996 09:59 66.2 Well: C-35 Section (VS) Reference: Well (O.OON,O.OOE,293.98Azi) ~I Wellpath: G356 Survey Calculation Method: Minimum Curvature Db: Orade Survey MD lncl Azim TVD Sys TVD N/S E/W ft deg deg ft ft ft ft 9181.42 37.98 297.74 8722.74 8656.55 1300.74 -1192.45 9209.04 40.29 294.67 8744.17 8677.98 1308.42 -1208.09 9238.82 43.54 292.33 8766.33 8700.14 1316.34 -1226.34 9266.48 46.89 289.79 8785.81 8719.62 1323.38 -1244.66 9294.36 48.88 283.61 8804.52 8738.33 1329.30 -1264.45 9330.25 51.20 279.14 8827.57 8761.38 1334.71 -1291.41 9361.00 52.77 276.08 8846.51 8780.32 1337.91 -1315.42 9392.95 54.33 271.94 8865.50 8799.31 1339.70 -1341.05 9426.55 56.43 268.13 8884.59 8818.40 1339.70 -1368.69 9455.27 57.65 265.44 8900.22 8834.03 1338.35 -1392.74 9484.77 59.25 261.81 8915.66 8849.47 1335.55 -1417.72 9517.35 62.29 258.69 8931.57 8865.38 1330.72 -1445.73 9549.88 65.81 256.71 8945.80 8879.61 1324.49 -1474.30 9580.28 66.56 262.79 8958.09 8891.90 1319.55 -1501.65 9608.08 67.49 266.41 8968.94 8902.75 1317.14 -1527.13 9635.36 69.11 270.83 8979.03 8912.84 1316.54 -1552.46 9666.17 72.23 274.12 8989.23 8923.04 1317.80 -1581.49 9696.18 75.62 277.19 8997.54 8931.35 1320.65 -1610.18 9731.41 79.55 280.34 9005.12 8938.93 1325.89 -1644.17 9761.99 82.74 282.53 9009.82 8943.63 1331.89 -1673.78 9797.11 86.83 284.44 9013.01 8946.82 1340.04 -1707.78 9827.59 90.43 288.01 9013.74 8947.55 1348.55 -1737.03 9864.28 89.85 293.39 9013.65 8947.46 1361.52 -1771.34 9898.31 92.71 295.86 9012.89 8946.70 1375.69 -1802.26 9929.28 93.04 293.78 9011.34 8945.15 1388.67 -1830.33 9963.26 90.64 290.84 9010.25 8944.06 1401.56 -1861.75 9996.35 89.51 286.60 9010.21 8944.02 1412.18 -1893.08 10027.42 89.85 283.43 9010.38 8944.19 1420.23 -1923.09 10057.31 89.35 279.77 9010.59 8944.40 1426.24 -1952.36 10096.28 90.95 275.67 9010.49 8944.30 1431.47 -1990.97 10125.61 91.78 272.55 9009.79 8943.60 1433.57 -2020.21 10158.44 90.83 267.55 9009.04 8942.85 1433.60 -2053.02 10195.95 92.27 263.71 9008.02 8941.83 1430.75 -2090.40 10230.67 89.57 261.21 9007.47 8941.28 1426.19 -2124.81 10258.46 87.94 257.76 9008.07 8941.88 1421.12 -2152.12 10292.60 86.98 253.28 9009.58 8943.39 1412.60 -2185.13 10322.42 86.96 248.78 9011.16 8944.97 1402.92 -2213.29 10352.00 89.20 245.83 9012.15 8945.96 1391.51 -2240.56 10380.62 89.42 242.25 9012.50 8946.31 1378.99 -2266.28 10415.93 90.37 237.12 9012.56 8946.37 1361.17 -2296.75 10445.74 91.41 233.80 9012.10 8945.91 1344.27 -2321.30 10475.26 90.95 232.50 9011.49 8945.30 1326.58 -2344.92 10508.93 90.89 237.35 9010.95 8944.76 1307.24 -2372.46 10537.78 90.09 243.08 9010.70 8944.51 1292.91 -2397.49 10565.69 88.50 247.19 9011.05 8944.86 1281.18 -2422.81 10601.30 87.88 252.46 9012.17 8945.98 1268.91 -2456.20 10632.93 86.96 254.89 9013.60 8947.41 1260.03 -2486.52 10662.14 89.48 259.04 9014.50 8948.31 1253.44 -2514.96 10693.87 90.00 263.05 9014.65 8948.46 1248.51 -2546.30 10727.71 89.91 266.96 9014.67 8948.48 1245.56 -2580.00 10757.01 91.32 270.04 9014.36 8948.17 1244.79 -2609.28 10785.05 91.41 275.32 9013.69 8947.50 1246.10 -2637.28 10820.69 89.88 279.60 9013.29 8947.10 1250.73 -2672.60 AiapN NIapE ft ft 5961246.18 663277.32 5961253.52 663261.52 5961261.04 663243.11 5961267.68 663224.64 5961273.16 663204.72 5961277.97 663177.65 5961280.65 663153.58 5961281.87 663127.92 5961281.27 663100.29 5961279.39 663076.27 5961276.05 663051.37 5961270.61 663023.47 5961263.75 662995.04 5961258.21 662967.81 5961255.25 662942.39 5961254.09 662917.09 5961254.72 662888.03 5961256.94 662859.29 5961261.44 662825.19 5961266.78 662795.46 5961274.19 662761.29 5961282.06 662731.87 5961294.27 662697.28 5961307.76 662666.06 5961320.13 662637.71 5961332.33 662606.03 5961342.25 662574.47 5961349.64 662544.30 5961355.01 662514.90 5961359.40 662476.19 5961360.86 662446.92 5961360.17 662414.11 5961356.49 662376.81 5961351.19 662342.51 5961345.52 662315.32 5961336.28 662282.50 5961325.99 662254.57 5961313.99 662227.56 5961300.90 662202.11 5961282.43 662172.04 5961265.00 662147.87 5961246.79 662124.65 5961226.85 662097.53 5961211.98 662072.83 5961199.70 662047.78 5961186.70 662014.66 5961177.16 661984.54 5961169.95 661956.26 5961164.33 661925.04 5961160.65 661891.41 5961159.24 661862.15 5961159.94 661834.14 5961163.79 661798.72 VS D1S Tool ft deg/100ft 1618.13 11.99 MWD 1635.54 10.91 MWD 1655.43 12.11 MWD 1675.03 13.75 MWD 1695.52 17.92 MWD 1722.35 11.53 MWD 1745.59 9.36 MWD 1769.73 11.51 MWD 1794.99 11.23 MWD 1816.41 8.93 MWD 1838.10 11.80 MWD 1861.73 12.52 MWD 1885.30 12.13 MWD 1908.29 18.46 MWD 1930.59 12.45 MWD 1953.48 16.18 MWD 1980.53 14.28 MWD 2007.90 14.97 MWD 2041.09 14.17 MWD 2070.58 12.60 MWD 2104.96 12.84 MWD 2135.14 16.63 MWD 2171.76 14.75 MWD 2205.77 11.10 MWD 2236.70 6.79 MWD 2270.64 11.16 MWD 2303.58 13.26 MWD 2334.27 10.26 MWD 2363.46 12.36 MWD 2400.86 11.29 MWD 2428.44 11.00 MWD 2458.43 15.50 MWD 2491.42 10.93 MWD 2521.01 10.60 MWD 2543.91 13.73 MWD 2570.61 13.41 MWD 2592.40 15.07 MWD 2612.68 12.52 MWD 2631.10 12.53 MWD 2651.70 14.78 MWD 2667.26 11.67 MWD 2681.65 4.67 MWD 2698.96 14.40 MWD 2716.01 20.05 MWD 2734.37 15.79 MWD 2759.90 14.89 MWD 2783.99 8.21 MWD 2807.30 16.61 MWD 2833.93 12.74 MWD 2863.53 11.56 MWD 2889.97 11.56 MWD 2916.08 18.83 MWD 2950.24 12.75 MWD ~. # i by BP Alaska sus Baker Hughes INTEQ Survey Report 1NTEQ Company: BP Amoco Date: 1/23/2008 Time: 08:35:19 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: G35, True North Site: PB C Pad Vertical (TVD) Reference: 43:35 5/31/1996 09:59 66.2 Well: G35 Section (VS) Reference: Well (O.OON,O.OOE,293.98Azi) Wellpath: G356 Survey Calculation Me[hod: Minimum Curvature Db: Orade Survey MD ft Incl deg Azim deg TVD ft Sys TVD ft N/S ft E/W ft MapN ft MapE ft VS ft DLS Tool deg/100ft 10851.75 89.02 284.03 9013.59 8947.40 1257.09 -2702.99 5961169.48 661768.20 2980.59 14.53 MWD 10882.69 89.94 288.20 9013.87 8947.68 1265.67 -2732.71 5961177.41 661738.31 3011.23 13.80 MWD 10915.15 90.86 293.81 9013.64 8947.45 1277.30 -2763.00 5961188.38 661707.77 3043.63 17.51 MWD 10947.62 90.12 299.00 9013.36 8947.17 1291.74 -2792.07 5961202.17 661678.39 3076.06 16.14 MWD 10979.25 91.38 303.92 9012.95 8946.76 1308.24 -2819.04 5961218.08 661651.07 3107.41 16.06 MWD 11015.46 91.07 303.11 9012.18 8945.99 1328.23 -2849.22 5961237.40 661620.46 3143.11 2.39 MWD 11045.28 90.98 299.13 9011.64 8945.45 1343.63 -2874.74 5961252.24 661594.61 3172.69 13.35 MWD 11080.67 90.40 294.35 9011.22 8945.03 1359.55 -2906.34 5961267.46 661562.68 3208.03 13.60 MWD 11110.10 90.58 289.34 9010.96 8944.77 1370.50 -2933.64 5961277.81 661535.14 3237.42 17.03 MWD 11143.99 91.57 285.44 9010.33 8944.14 1380.62 -2965.97 5961287.22 661502.60 3271.08 11.87 MWD 11175.11 91.11 281.84 9009.60 8943.41 1387.96 -2996.20 5961293.89 661472.22 3301.68 11.66 MWD 11204.97 89.05 277.15 9009.56 8943.37 1392.88 -3025.64 5961298.17 661442.68 3330.58 17.15 MWD 11234.93 89.54 274.83 9009.93 8943.74 1396.01 -3055.44 5961300.65 661412.83 3359.07 7.91 MWD 11264.00 90.58 271.80 9009.90 8943.71 1397.69 -3084.45 5961301.69 661383.79 3386.27 11.02 MWD 11273.64 90.83 273.02 9009.78 8943.59 1398.09 -3094.08 5961301.89 661374.15 3395.23 12.92 MWD 11330.00 90.83 273.02 9008.96 8942.77 1401.06 -3150.36 5961303.62 661317.83 3447.86 0.00 MWD TB~ 4-1 /6" CM! N LHEAD = FMC /~;TUA TOR = AXELSON KB. ELEV = 66.15' BF. ELEV = 36.75' KOP = 5200' Max Angle = 93 @ 9898' Datum MD = 9394' Datum TV D = 8800' SS DRLG DRAFT ~ 13-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" ~~ 2673' 4-1/2" TBG, 12.6#, 13CR, ID = 3.958" ~--~ 8478' Minimum ID = 2.372" @ ? TOP OF 2-7/8" LINER 4-1/2" TBG, 12.6#, L-80 BTRS, ID = 3.958" I 8601' 9-5/8" CSG, 47# L-80 BTRS, ID = 8.681" 879$' SAFETY NOES: WELL EXCEEDS 70° @ 9550' AND GOES C -3 5 B HORIZONTAL @ 9794'. ** CAUTION -TOP OF 2-7/8" LNR @ 8566' 3.75" OD BKR DEP SLV, ID = 3.000". EXACT DEPTH OF 2.372" MIN ID @ XO FROM 3-112" TO 2-718" UNKNOWN. SDTRK LNR DETAIL NOT IN FILE 1978' 4-1 /2" OTIS X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3391 3390 1 MMG SHEA RK 0 01/02/08 3 5387 5381 16 MMG DMY RK 0 01/02/08 2 7085 6896 29 MMG DMY RK 0 01/02/08 1 8244 7916 31 MMG DMY RK 0 01 /02/08 8314' ~ BOT SLIDING SLV, ID = 3.183" 8380' 4-112" HES X NIP, ID = 3.813" 8401' 9-518"x 4-1/2" BAKER S-3 PKR, ID = 4.750" 8425' 4-1 /2" HES X NIP, ID = 3.813" 8489' BOT 8-25" Fluted No/Go 8490' 9-5/8"x 4-1 /2" TIW HBBP PKR, ID = 4.750" 8494' 4-V2" Mule Shoe WLEG 8533' 4-1/2" OTIS X NIP, ID = 3.813" $rj4$' Top of 3-1/2" Liner. TOC 8550' 7" BOT LNR HGR W/TIEBACK SLV 8630' 3-1!2" X NIP. ID = 2.813" 8568' 4-1/2" OTIS XN NIP, ID MILLED FROM 3.725" to 3.80" 8601' 4-1/2" WLEG 8605' ELMD TT LOG NOT AVAILABLE 10077' I-13-3/16 x 2-7/8 X-over PERFORATION SUMMARY REF LOG: GEARHART -BRCS ON 02/27186 A NGLE AT TOP PERF: 90 @ 10680' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10680 - 1 1280 O 01 /27/08 3-3/16" cmted X 2-7/8" Liner 11330' 8874' Mechanical Whipstock 89~ Chem cut 2-7/8" Inr 7" MARKER JOINT 10115' I-j FISH-IBP RUBBERS (3/27 ~- PBTD 10272' 9275' TOP OF WHIPSTO K roc 9322' 10318' 2-7/8" LNR, 6.16#, L-80 FLRS, .0057 bpf, ID = 2.372" 7" LNR, 29# L-80 IJ4S, ID = 6.184" I-~ 9700' DATE REV BY COMMEMS DATE REV BY COMMENTS 04120/86 ORIGINAL COMPLETION 01/29/96 CTD SIDETRACK 01/27/08 NORDIC1 RWO &CTD SIDETRACK PRUDHOE BAY UNIT WELL: G35A PERMIT No: 1952000 API No: 50-029-21553-01 SEC 19, T11 N, R14E 1250' FNL & 879' FEL BP Exploration (Alaska) oz/zo/os Schlumb~rer NO. 4590 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Milne Pt,Endicott,Borealis,Polaris,Lisburne Wall .Inh tt l_nn Daccrintinn Date BL Coler CD 18-32A 11968923 SCMT / - ~ 02112/08 1 MPE-12 11978438 MEM INJ PROFILE lU= L' o~US - C3Co 02108108 1 4-14/R-34 11996383 USIT (, 02!12/08 1 V-07 40016096 OH MWDILWD EDIT "~ - C j Lfc 12/04/07 2 1 L1~14 11626482 RST ~ "- / 1 Sr9~l3 05/09/07 1 1 L2-18A 11657124 RST ~ 05!10/07 1 1 L2-33 11626484 RST j (p - j `~` [ / 05/11/07 1 1 G-31A 11962778 RST - US ~( ~~ 01/01/08 1 1 V-111 11978439 MEM GLS ~ 02/10/08 1 W-216 12031441 CH EDIT PDC GR (USIT) - 9 01/11/08 1 W-214 40016055 OH MWDILWD EDIT V=, _ j 11115/07 2 1 Y-07A 11962576 USIT 12/18/07 1 C-356 11978432 _ MEM DDL ~ j 01/02/08 1 PLEASE AGKNUWLEDGE KEGEIP I E3Y SIGNING AND Kt I IJKNIryta-U t,GUPY tAGM I V: t', BP Exploration (Alaska) Inc. _ Petrotechnical Data Center LRZ-1 900 E. Benson Blvd. Anchorage, Alaska 99508 d s-~ ~ t~", Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN Beth Received by: ry r STATE OF ALASKA 11/13/07 O IL AND GAS CONSERVATION COMMISSION ROPE Test Report Submit to: Contractor: Nordic Rig No.; 2 DATE: 1/19/08 Rig Rep.: MckeirnaNPederson Rig Phone: 659-439$ Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: SevciklRoss E-Mail Weii Name: PBU C-356 PTD # 206-1 Z9 Operation: Drig: XX W©rkover: Explor.; Test: Initial: Weekly: Bi-Weekly xx Test Pressure: Rams: 250/35 Annular. 25012500 Naives: 250/3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Wel! Sign P Up~r Kelly NA Housekeeping: P Dr1. Rig P Lower Kelly NA PTD On Location P Hazard Sec. P BaH Type 2 P Standing Order Posted P Inside BOP NA BOP STACK: Quantity Sizelfype Test ResutE MUD SYSTEM: Visual Alarm Stripper 1 23!8" P Trip Tank P P Annular Preventer 1 71116" P Pit Level indicators P P #1 Rams 1 B1nd/Shear P Fiow indicator NA NA #2 Rams 1 Z 318" Combi P Meth Gas Detector P P #3 Rams 1 2318"x31/2" P H2S Gas Detector P P #4 Rams 1 2 3/8" ComtH P #5 Rams NA Quantity Test Result Ghoke Ln. Valves 1 3118" P inside Beet valves 1 P HCR Valves 2 3118" P Kill Line Valves 1 31/8" P ACCUMULATOR SYSTEM: Check Valve 2 21/16" P TimelPressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2100 P Quantity Test Result 200 psi Attained 20 sec. P No. Valves 14 P Fu11 Pressure Attained 90 sec. P Manual Chokes 1 P Blind Switch Covers: Ali stations Yes Hydraulic Chokes 1 P Nitgn. Bottles (avg}: 4 2100 Test Results Number of Failures: 0 Test Time: 7 Hours Components tested 31 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, foiiow with written confirmation to Su wiser at: Remarks: 24 HOUR NOTICE GIVEN YES XX NO Waived By Date 1/18/08 Time 1200 Witness Chuck Scheve Test start 1500 Finish 2300 BOP Coil for Rigs BFL 11/13/07 Nordic 2 BOP 01-19-08.x1s a STATE OF ALASKA 11/13/07 OIL AND GAS CONSERVATION COMMISSION BO PE Test Report Submit to: fir~3.E'e{~c;_;t~~~c~S~t~_~~E?SI t3~~1'~,fl{:f,kc'r:,5t~;3r:@~~~5~~.~~~?fir Contractor: Nordic Rig No.: 2 DATE: 1/6/08 Rig Rep.: Sloan / Holmes Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Hildreth /Goodrich E-Mail ~~~~t~;~lc~rlcrE.~:~3c~~E?U~~?~E5~3E'E_ 7~?:f_~<I Well Name: PBU C-356 PTD # 206-129 Operation: Drlg: XX Workover: Explor.: Test: Initial: XX Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular: 250/3500 Valves: 250/3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NA Housekeeping: P Drl. Rig P Lower Kelly NA PTD On Location P Hazard Sec. P Balt Type 2 P Standing Order Posted P Inside BOP NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2 3/8" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind/Shear P Flow Indicator NA NA #2 Rams 1 2 3/8" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8"x3 1/2" P H2S Gas Detector P P #4 Rams 1 2 3/8" Combi P #5 Rams NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 1 P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve 2 2 1/16" P Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2100 P Quantity Test Result 200 psi Attained 25 sec. P No. Valves 14 P Full Pressure Attained 105 sec. P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 @ 2200 Test Results Number of Failures: 0 Test Time: 7.5 Hours Components tested 31 Repair or replacement of equipment will be made within NA days. Notify the N orth Slope Inspector 659-3607, follow with written confirmation to Superviser at: ,~3E~3,r~c~~,:c~,~~~sk~_~~~?~s Remarks: 24 HOUR NOTICE GIVEN YES XX NO Waived By John Crisp Date 1/4/07 Time 1400 Witness Goodrich /Hildreth Test start 03:00 Finish 10:30 BOP Coil for Rigs BFL 11 /13/07 Nordic 2 BOP 01-06-08.x1s Change to BOP stack on C-35 detrack (PTD 206-129) during field toperations Page 1 of 4 Maunder, Thomas E (DOA) From: Johnson, Mark O [Mark.Johnson@bp.com] Sent: Tuesday, December 18, 2007 10:25 AM To: Maunder, Thomas E {DOA) Cc: Regg, James B {DOA) Subjec#: RE: Change to BOP stack on C-35B sidetrack (PTD 206-129) during field trial operations OK Tom, will get with you sooner. Thanks, Mark O. Johnson BP Advisor -Low Cost Reservoir Access johnsomo@bp.com 907-564-5666 (office) 907-240-8034 (cell) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.govj Sent: Tuesday, December 18, 2007 8:51 AM To: Johnson, Mark 0 Cc: Jim Regg Subject: RE: Change to BOP stack on C-35B sidetrack (PTD 206-129) during field trial operations Mark, One item on this trial. There obviously has been a lot of planning that has gone into this effort probably over some months/years. It appears, from this side of the fence, that your original notification/request regarding the well control equipment addition and start-up of actual operations on this specific well was one of the final actions. In this case, I don't think there was anything really controversial. I had a question regarding the umbilical which you answered satisfactorily. However, if there is a case where a proposed field trial does result in a controversial issue, there is the very real possibility that any Commission approval will not be as swift as was possible here. It is also entirely possible that an approval may not be given without some modifications to an original plan. We do appreciate having time to examine/analyze proposals. Goad luck with the trial. As 1 messaged previously, it will be interesting to read the operations reports. Call or message with any questions. Tom Maunder, PE AOGCC From: Johnson, Mark O [maiilto:Mark.Johnson@bp.com] Sent: Monday, December i7, 2007 4:26 PM To: Maunder, Thomas E (DOA) Subject: RE: Change to BOP stack on C-35B sidetrack (PTD 206-i29) during field trial operations Thanks Tom. Thanks, ~< ~~~ ~~~`~~~~ 2!1312008 Change to BOP stack on C-35 detrack (PTD 206-129) during field toperations Page 2 of 4 Mark O. Johnson BP Advisor -Low Cost Reservoir Access johnsomo@bp.com 907-564-5666 (office) 907-240-8034 (cell) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, December i7, 2007 4:24 PM To: Johnson, Mark O Cc: Hubble, Terrie L; Rixse, Mel G Subject: RE: Change to BOP stack on C-35B sidetrack (PTD 206-129) during field trial operations Mark, et al, Further to the information you provided for the WILD field trial, it appears that employing the new equipment will not compromise well control capability. It may complicate it, but not compromise it. The circulation path to surface is independent of the deployed tools. Good luck with the trial. It will be interesting to read the operations reports. Tom Maunder, PE AOGCC From: Johnson, Mark 0 [mailto:Mark.Johnson@bp.com] Sent: friday, December 07, 2007 8:41 AM To: Maunder, Thomas E (DOA) Cc: Hubble, Terrie L; Rixse, Mel G Subject: RE: Change to BOP stack on C-356 sidetrack (PTD 206-129) during field trial operations Hi Tom, The WILD field trial portion of C-35B will start on about Dec 23. We actually move to C-35B on Dec 9 with Nordic 2, but do a workover on the well with Nordic 2 before the sidetrack is conducted. Thanks, Mark O. Johnson BP Advisor -Low Cost Reservoir Access johnsomo@bp.com 907-564-5666 (office) 907-240-8034 (cell) From: Maunder, Thomas E (DOA) [rnailto:tom.maunder@alaska.gov] Sent: Thursday, December ~, 2007 4: i5 PM To: Johnson, Mark O Cc: Hubble, Terrie L; Rixse, Mel G Subject: RE: Change to BOP stack on C-35B sidetrack (PTD 206-129) during field trial operations Mark, et al, Thanks for all the info (I think!). When will operations start? Tom 2/13/2008 Change to BOP stack on C-35detrack (PTD 20b-129) during field t perations Page 3 of 4 From: Johnson, Mark O [mailto:Mark.Johnson@bp.com] Sent: Thursday, December 06, 2007 2:45 PM To: Maunder, Thomas E (DOA) Cc: Hubble, Terris L; Rixse, Mel G Subject: RE: Change to BOP stack on C-356 sidetrack (PTD 206-129) during field trial operations Importance: High Hi Tom, The umbilical is either 1 1/4" CSH pipe or 2 3/8" fiberglass pipe. The umbilical is part of the BHA and will be 800` long for the CSH or 1500' long for the fiberglass. The CSH will we used for drilling Zone 4 and the fiberglass for drilling zone 2 with the WILD BHA. The BHA and umbilical are conveyed into the hole on EL cable Attached is a diagram that describes make-up of the BHA with RIH being the last step (WILD deployment process). In the unlikely event of a well kick during deployment of the BHA/umbilical we will stab a 2 3!8" joint and TIW valve onto the umbilical, RIH and close the 2 3/8" pipe/slip combination rams on that joint for full well control. Very similar to how we handle slotted liner deployment. We believe that this field trial will be a safe and fully controlled operation. If you are interested I would be happy to go over this will you either on the phone or in person. Thanks, Mark O. Johnson BP Advisor -Low Cost Reservoir Access johnsomo@bp.com 907-564-5666 (office) 907-240-8034 (cell) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, December 04, 2007 3:08 PM To: Johnson, Mark O Cc: Hubble, Terris L; Rixse, Mel G Subject: RE: Change to BOP stack on C-35B sidetrack (PTD 206-i29) during field trial operations Mark, et at, Interesting application. A question, in the drawing there is some "umbilical pipe" above the wild BHA. Is that conveyed in by EL or run with coil prior to deploying the EL? Could you send in the operational steps planned for the WILD trial? Thanks in advance. Tom Maunder, PE AOGCC From: Johnson, Mark O [mailto:MarkJohnson@bp.com] Sent: Tuesday, December 04, 2007 2:56 PM To: Maunder, Thomas E (DOA) Cc: Hubble, Terris L; Rinse, Mel G Subject: Change to BOP stack on C-35B sidetrack (PTD 206-129) during field trial operations Hi Tom, We request a slight change to the 80P stack on C-356 permit to drill 206-929 to add a 5k dual wireline ram on top of the normal CTD BOP stack when testing a new wireNne lateral drilling BHA. 2/13/2008 Change to BOP stack on C-35B•sidetraek (PTD 206-12~} during field trial orations Page 4 of 4 During the C-35B CTD sidetrack with Nordic 2 we will be testing a new drilling technology that is called Wireline Lateral Drilling (WILD). After CTD mills the window and drills down to PBU zone 4 we will switch to the WILD BHA and drift about 400' using Nordic 2 as a base platform during the field trial of this technology. After the field trial is complete, we will switch back to CTD to finish the sketradc and complete the well. During the field trial the CTD BOP static will include a 5k dual wireline ram flanged to the top of the annular preventor (picture attached). This wirefine BOP will be tested to the same pressures as the rest of the CTD BOP stack as fisted in the permit to drill. The wire6ne BOPs viii only be on the CTD stack during field trial operat~ns. Attached is a diagram of the BOP stack change, a description of the new drilling technology, well schematic, and our weft control procedure. I will be glad to review any of this with you at your convenience if needed. «C-35B BOP stack for WILD field trial.ppt» «y~ryLD f=ield Trial Operations Rev 1.doc» «C-35B rev2 final fi~or weft con#rof.jpg» «WLD well control.doc» Thanks, Mark O. Johnson BP Advisor -Low Cost Reservoir Access johnsomo@bp.com 907-564-5666 (office) 907-240-8034 (cell) 2/13/2008 Wireline Lateral Drilling (WILD) field trial on C-35B sidetrack Permit to Drill 206-129 Will add dual 7 1/16" 5k BOP wireline rams on top of CTD BOP stack during field trial of WILD drilling BHA. Wireline rams are flanged to annular preventor. All BOP stack below wireline rams is normal CTD stack as permitted. MOJ - 907-564-5666 -35B Christmas tree • • WILD Field Trial Operations and Procedures Introduction Wireline Lateral Drilling (WILD) is a new drilling technology jointly developed by BP and Schlumberger that utilizes an electric line conveyed bottomhole drilling assembly to drill sidetracks. This technology is expected to reduce the cost of sidetracks on the North Slope and globally through a reduction in surface equipment and personnel. The drilling service will be available commercially through Schlumberger. The drilling assembly is powered via wireline and consists of an electric motor to rotate the bit, crawler to move in and out of the hole, and a downhole pump. The pump reverse circulates mud and drill cuttings up an umbilical where they exit into the tubing string and are carried out of hole via mud circulation from the inner annulus. Gas lift can also be used to carry cuttings to surface. Cable to surface Cuttings exit Gas lift valve Umbilical to parent well Electrical BHA r ~~y -1- Procedure This will be the first field trial of the Wireline Lateral Drilling (WILD) technology in a hydrocarbon bearing reservoir. PBU C-35B is an excellent candidate well since the Sadlerochit formation is relatively stable and the distance between bit and GLM is relatively short (reduces umbilical length). The well is scheduled for a coiled tubing drilling (CTD) sidetrack in November 2007. Ten additional days are planned for this well to field trial WILD during the drilling phase of the sidetrack. The plan is to switch from CTD to WILD and drill approximately 400' of the planned directional with the WILD bottomhole assembly (BHA). After the workover to replace leaking tubing, CTD will mill the sidetrack window and start drilling the build section down to Zone 4. WILD will then be picked up to drill a portion of the build section and the early part of the lateral section utilizing Nordic 2 rig & personnel for support. All operational expenses associated with the WILD field trial will be charged 100% to BP as described in the WILD Field Trial Ballot. After the WILD drilling is complete, CTD will resume operations and complete the sidetrack. Field Trial Objectives 1. No Accidents, No Harm to People, No Damage to the Environment. 2. Return the well to Prudhoe Bay operations at the end of the field trial with no impairment to well productivitye 3. Prove proper function of WILD concept with experimental prototype tools prior to progression to engineering prototype tool development. This includes 3 specific field trial demonstration objectives: a. Safely drill in true downhole conditions (within the PBU Sadlerochit reservoir). b. Directionally drill with WILD BHA c. Successfully remove cuttings from openhole through umbilical into 4'/2" tubing and then bring cuttings to surface via drilling mud circulated from the bottom GLM. Planned Drilling Intervals -2- • C-35B Wellplan #3 -CTD and WILD Drilling Intervals Sections highlighted in yellow are drilled with WILD Base plan for top of umbilical to go no deeper than: 8275 ft MD Comment -Bottom GLM at 8300 ft MD Drilling Intervals IJmbilical Interval MD SS Inclination required Comments CTD start 8865 CTD mills window in Sag and drills Shublik to top of zone 4 CTD end 8956 WILD section 1 start 8956 8460 21 Top of Zone 4 nice sand. Some fairly high GR shales cut on way down, but nearly vertical so do not expect shale trouble. end 9120 8617 13 845 End at start of Z3 conglomerate (river rocks), PU coil. WILD drill 164 CTD start 9120 CTD drills conglomerate in Zone 3 and upper Zone 2 CTD end 9506 WILD section 2 start 9506 8890 72 Likely will have to tractor down to TD. Thin shale of 45 GR at 8925' SS cut at 9655'md at 80 incl. end 9742 8937 84 1467 WILD drill 236 Total WILD drill 400 CTD start 9742 Land horizontal in polygon, zone 2A above 14N shale and continue to TD. CTD end 11325 -3- TREE- i-1~' GUU ~ ~ ~ SAFETY NaT ES ~ SELL E~ CEEDS 7G° ~ 9550' A ND GC UUELLHEAD- FMG HaRIZaNTALt~979~1'. ** C4UTIaN- TaP aF2-~~" Lh RGTURIDR- ~. R~CEIS4N Proposed CTG~+ ~Idetrack 8566' 3.75" aDBKR DEF SLII, Id= 3A00".E}~ACT DEP' I~ . ~ B! - 66.15' ___.__ ~.~._w_. aF2,372" A11h11D~ xa FRaM 3-1~" Ta 2-7~" Ulvl~lva 9F. ELEV 36.75' kDF .__. _ _~__ ..._ _ nom; ~ SDTRK LNR DETAIL NaT IIV FILE. iu~ ~~91~-__ ~~ imss~ ~,t,~`i!~, ~-i..~, a.5" ELta surface Datwm MD- 9357' I<! D~3~m 1'•1 D - ~ 8;3~Q ss ~'t~ Mud circulation IA to tubing 13~'G9G,72~4},L-~ BTRS, D-tz.3~7• 2673 $~~Q' BST sliding sleeve 3.183" l~ 19-5`6'x ~l-t ll PFiR, ID -1..7 ~' I Itr-tom' Tat;, tz~R, c~rome, w- a.~zr ~ Giem ~ittlClg { ~-1t1' TBG,12.6ip, L~ 9TRS, D - 3958' 9-68' CMG, ~7t? L~0 BTRS, ID- 8.681' e r. gQ$g 9~'x ir1fi~' TUU HBBP PIGR, ID- IG.75Q ~t~I' OTI~X NIP, D-313' ~55a' 7' BOT LNR HGR UltrTl®RGICSLI! $~' Jr1f~ OTIS~N NIP, D MLLEDFROM3.725' b3,8 $6a9' 86x1' ~] 2 UUL ~ $ EL LID TT LOG NDTR5fR1LR9LE Urrlbilical pipe 1 1 ~~" ASH ar 2 3!8" fibergls . , ~ V~liLD BHA 8~' long r 7' FAA R IcH~ J O NT Pre~riaustap perf~t 9~~0' P&Ad laP OF J I -7~8' LNR, 6.1 f~ , L~ F LRS , X057 bpY, ID - 2.3 ' LNR,29Ip L~ II~S,ID-6.18' ~ J71DC~ DATE R Ed 8 Y GO LILIEHTS DRTE R EJ B Y GO MMEN15 Ob~0~66 QRIGINAL COM PLETION 031'16f13 DAI~FPJG GL~! G1O 01~5fJ6 GTDS I^ETRAGK 07A1A3 JJFKAK GL~! GrO OPEN STR 5& 6) PRUDHOE BRIE UNIT QUELL: G~5R PERMIT Na: "195~m RP1Na: SQ-0~-21553-0t SBG 1 ~, T1 1 N, R1 ~E,125Q FN L & 87 9r • • Wireline Lateral Drilling (WILD) Well Kick Procedure Scenario -WILD BHA and umbilical in hole, electric line to surface. An influx is detected. Notes: a. Throughout the WILD field trial rig team will monitor in and out micro motions and PVT equipment closely, as usual. b. Reservoir pressure is estimated to be 3320 psi @8800'ss. Therefore drilling with a 8.6 ppg flo pro mud provides a 615 psi static overbalance (kick is very unlikely). c. BOP stack is normal CTD configuration with dual Sk wireline BOP rams added on top. d. The well has production tubing and casing down to the window in the Sag River at 8774' and (838Tss) 1) If influx is detected, pull WILD BHA into casing. 2) Open HCR and choke. Close wireline rams on electric line. 3) Shut in well with choke to prevent further influx. Monitor well pressure and verify kick influx volume with PVT equipment. 4) Circulate kick out of well via drillers method from sliding sleeve at 8270' and (7872'ss). Confirm dead well. POOH. 5) If well is not dead after driller method, circulate KWF brine surface to surface via sliding sleeve. Ensure no solids in KWF. Monitor well for 1 hour to confirm dead. POOH. 6) If well not dead, bullhead KWF down tubing into formation. POOH. 7) If well locks up (not expected since solids free mud), will use the volumetric method to get influx above sliding sleeve, then circulate influx out of hole. Notes: The drillers method in step 4 is not circulating from the bottom of the hole since the sliding sleeve is at 8300' and (7872'ss). The WILD drilling will be done in two intervals that TD at 9120' and (8617'ss) at 13 degrees inclination and the deepest TD at 9742' and (8937'ss) at 84 degrees inclination. As such a gas influx will migrate up hole and can be controlled with the volumetric method until the influx is above the sliding sleeve. Once it is above the sleeve it can be circulated OOH. In addition to Sk wireline BOPS the additional contingency rams include the CTD BOP 7 1/16" annular preventor and the blind/shear rams. MOJ 12/3/07 • WILD Deployment Process 85' long electronic BHA Run BHA on Attach to EL 800' bottom of CSH, C~ J Latch and pull EL back to surface Attach EL to EL, RIH r STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COiI~MiSS10N BOPS Test Report Submit to: Contractor: Nordic Rig No.: Z DATE: 12/11/07 Rig Rep.: Sloan / Holmes R~ Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Hildreth /Goodrich E-Mai{ nsuadwcirkfnaniic2toalpusher~ bp.coin Well Name: C-356 PTD # 206-129 Operation: Dtig: Worlcover. ~7C Exptor.: Test: InitiaL• XX Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular. 250/3500 Valves: 250/3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NA Housekeeping: P Drt. Rig P Lower KeNy NA PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP NA BOP STACK: Quantity Sizetf'ype Test ResulE MUD SYSTEM: Visual Alarm Stripper 1 23/8" P Trip Tank P P Annular Preventer 1 71116" P Pit Level Indicators P P #1 Rams 1 Blind/Shear P Flow Irrtlic:ator NA NA #2 Rams 1 23/8" Combi P Meth Gas Detector P P #3 Rams 1 23!8"x31/2" F H2S Gas Detector P P #4 Rams 1 23!8" Combi P #5 Rams NA Quantity Test Result Choke Ln. Valves 1 31/8" P Inside Reel valves 1 P HCR Valves 2 31/8" P Kitt Line Valves 1 3118" P ACCUMULATOR SYSTEM: Check Valve 2 21/16" P Time/Pressure Test Result System Pressure 3000.... P CHOKE MANIFOLD: Pressure After Closure 2100 P Quantity Test Result 200 psi Attained 16 sec. P No. Valves 14 P Full Pressure Attained 95 sec. P Manual Chokes 1 P Blirai Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2200 Test Results Number of Failures: Test Trine: 10.5 Hours Comaonents tested 30 Repair or replacement of equipment vHil be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Su wiser at: Remarks: As per the 10.5 hrs test time the bottom. flange on annular preventer failed the initial shell test ~ the 2 3/8" test jt had worn out 8 a newlt had to be source 8 assembled 24 HOUR NOT{CE GIVEN YES XX NO Waived By John Crisp Date 12!9147 Time 14;(10 Witness Goodrich /Hildreth Test start 03:30 Finish 14:00 BOP Coil for Rigs BFL 11114/07 Nordic 2 BOP 12-11-07p.xls r ~7~~ OIL ~ va47 CO1~T5ERQATIOI~T COriMI5SIOIQ Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-35B BP Exploration (Alaska) Inc. Permit No: 206-129 Surface Location: 1250' FNL, 879' FEL, SEC. 19, T 11 N, R 14E, UM Bottomhole Location: 170' FSL, 4018' FEL, SEC. 18, Tl 1N, R14E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907Y6~9-3607 (pager). K. N DATED this day of September, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ..11 STATE OF ALASKA ' NU ~~ ~ ALASI~IL AND GAS CONSERVATION COMMI~N ~~~ !~ PERMIT TO DRILL 20 AAC 25.005 $(zoo(Q SEP 0 6 2006 Alaska 011 & Gas Cons. Commission 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is p ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU C-35B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11325 TVD 8945 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 879' FEL 1250' FNL SEC 19 T11N R14E UM 7. Property Designation.: ADL 028305 Pool , , . , , , Top of Productive Horizon: 282' FSL, 2168' FEL, SEC. 18, T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: December 1, 2006 Total Depth: 170' FSL, 4018' FEL, SEC. 18, T11 N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 18,300' 4b. Location of Well (State Base Plane Coordinates): Surface: x-664497 y-5959971 Zone-ASP4 10. KB Elevation (Height above GL): 66.19 feet 15. Distance to Nearest Well Within Pool: 8 16. Deviated Wells: Kickoff Depth: ggg5 feet Maximum Hole An le: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 25 35) Downhole: 3200 Surface: 32 18. Casin. P ram: S `catio ns T -Settin De th -Bo ttom uantit of ent c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1 /8" 33/16" X zaie~' 6.2# / 6.16# L-80 TCII / STL 2785' 8540' 8169' 11325' 8945' 197 cu ft Class 'G' 1 g. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 10318 Total Depth TVD (ft): 8gg4 Plugs (measured): None Effective Depth MD (ft): 10272 Effective Depth TVD (ft): 8997 Junk (measured): 10115 .:Casing Length ~ Size Cement Volume MD D Conductor /Structural 110' 20" 8 cu ds Concrete 110' 110' Surface 2673' 13-3/8" 3255 cu ft Coldset II 465 cu ft CS II 2673' 2673' Intermediate 8798' 9-5/8" 570 cu ft Class'G' 8798' 8388' Produ i n Liner 729' 7" 432 cu ft Class'G' 8550' - 9279' 8177' - 8801' Liner 1750' 2-7/8" 77 cu ft Class'G' 8566' - 10318' 8191' - 8994' Perforation Depth MD (ft): 9670' - 9730' Perforation Depth TVD (ft): 9004' - 9008' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Sean McLaughlin, 564-4387 Printed Name can McLaughlin Title CT Drilling Engineer Prepared By Name/Number: Si nature ,/~ Phone 564-4387 Date ~ ~ !~ ~ Terrie Hubble, 564-4628 'Commission Use Onl Permit To Drill Number: API Number: 50-029-21553-02-00 Permit A prov I See cover letter for Date: other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, s contained shales: Samples Req'd: ^ Yes ~tJo M Log Req'd: ^ Yes ~No 2 S~ ~ ~ I7 ~ ~o ~ S'p p ~ L%t, HZS Measures: `,,Yes o n Survey Req'd: ~ Yes ^ No Other: t~ APPROVED BY THE COMMISSION Date ~ 0~ ,COMMISSIONER Form 10-401 Revised 12/2005 v ~ Submit In Duplicate ORIGINAL BP Prudhoe Bay C-35B CTD Sidetrack CTD Sidetrack Summary Pre-Rig Work: 1. E 2-7/8 liner cut at 8900' 2. C Pull test of liner cut-off 3. S Set DGLV's 4. O MIT-IA/OA test 5. S Pull Dummy SSSV '~ Rig Work: (scheduled to begin on Dec 1, 2006) ~ 1. MIRU and test BOPE to 250 psi low and 3500 psi high. ~' 2. Pull 334' section of 2 7/8" liner 3. Run caliper log. 4. Cleanout/underream cement from 8566' down to 8900'. 5. Run dummy WS to 8900' 6. Set 4-1/2X7" WS @ 8865 with LS orientation. _ 7. Down squeeze cement past whipstock. 16 bbls of 15.8 ppg cement ~ 8. Mill 3.8" window at 8865' and 10' of rathole. Swap the well to Flo-Pro. 9. Drill Build and Lateral: 4.125" OH, 2460' (12 de 100 Tanned) with resistivity (res in lateral, not in build) ~ P ~ 10. MAD pass entire lateral in memory mode 11. Run 3-3/16" x 2-7/8" solid liner leaving TOL a 54 ' ~ 12. Pump primary cement leaving TOC at 8540', 5 s of 15.8 ppg liner cmt planned ~ __., 13. Cleanout liner and MCNL/GR/CCL log `~` 14. Test liner lap to 2000 psi. 15. Perforate liner per asset instructions (-600') 16. Freeze protect well, RDMO Ir Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Test separator (600' of prefs) 3. Rerun SSSV dummy when running GLVs. Well back side may be plugged. Be prepared to kick off well with nitrogen. Mud Program: • Well kill: 8.6 pp rme • Milling/drillin : 8.f ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: // • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4-1/8" Casing Program: fully cemented liner • 3-3/16", L-80 6.2# TCII 8540' and - 9850' and • 2-7/8", L-80 6.16# STL 9850'md - 11325'md j • A minimum of 35 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 8540' (top of liner) Existing casing/tubing Information 13-3/8", L-80 72#, Burst 5380, collapse 2670 psi 9 5/8", L-80 47#, Burst 6870, collapse 4750 psi 4-1/2", L-80 12.6#, Burst 8430, collapse 7500 psi Well Control: ! • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 90 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 18,300 ft. (North) • Distance to nearest well within pool - 875 ft. (C-15) Logging • MWD directional, Gamma Ray, will be run over all of the open hole section. Resistivity will be run over all the lateral section. • A cased hole MCNL/GR/CCL log will be run. Hazards • The maximum recorded H2S level on C Pad is 20 ppm. ~ • Lost circulation risk is average. • Leak at SSSV -monitor IA throughout job. Double valve the IA. Rerun dummy valve when running GLV s. • HOT penetration not planned, geosteer to 5 feet above if encountered. • Zone 3 Conglomerate -plan for extra bit trips. • Pu112-7/8" liner, kickoff in Sag -cement underream may be required Reservoir Pressure • The max res. press. is estimated to be 3200 psi at 8800'ss (7.0 ppg EMW). • Max. surface pressure with gas (0.10 psi/ft) to surface is 2320 psi. TREE = a-1 /s° cM/ WELLHEAD= FMC ACTUATOR = AXELSON KB. ELEV = 66.15' BF. ELEV = 36.75' KOP = 5200' Max Angle = 96 @ 10058' Datum MD = 9357 Datum TV D = 8800' SS C 113-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" I-i 2673' Minimum ID = 2.372" TOP OF 2-7/8" LINER 4-1/2" TBG, 12.6#, L-80 BTRS, ID = 3.958" i 8601' 9-5/8" CSG, 47# L-80 BTRS, ID = 8.681" $79$' .PERFORATION SUMMARY REF LOG: GEARHART- BHCS ON 02/27/86 A NGLE AT TOP PERF: 84 @ 9670' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 9670 - 9700 O 02/23/01 1-11/16" 4 9710 - 9730 O 05/13/98 2" 4 9700 - 9730 O 02/23/01 2" 4 9670 - 9700 S 05/07/98 2" 4 9700 - 9730 S 05/07/98 2" 4 9805 - 9835 S 05/07/98 2" 4 9835 - 9865 S 05/07/98 2" 4 9865 - 9895 S 05/07/98 2" 4 10041 - 10071 S 05/07/98 2" 4 10074 - 10104 S 05/07/98 2" 4 10107 - 10137 S 05/07/98 2" 4 10140 - 10170 S 05/07/98 2" 4 10173 - 10203 S 05/07/98 2" 4 10206 - 10236 S 05/07/98 2" 4 10239 - 10269 S 05/07/98 7" LNR, 29# L-80 U4S, ID = 6.184" I-i 9700' I I 17' 1~4 1/2" OTIS DBESSSVN, ID= 3.813" ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 2985 2918 0 OTIS DMY RM 0 04/24/06 5 4885 4818 1 OTIS DMY RM 0 04/24/06 4 6272 6128 31 OTIS DMY RA 0 04/19/86 3 7265 6987 29 OTIS DMY RA 0 04/19/86 2 7961 7603 28 OTIS DMY RA 0 04!19/86 1 8269 7871 30 OTIS DMY RA 0 04/19/86 I 8414' -~4-1/2" OTIS XA SLIDING SLEEVE, ID = 3.813" i 8473' TM/ PBR W/ LATCH ASSY ID = 4 750" 8488' 9-5/8"x 4-1/2" TMJ HBBP PKR , . 813" 1/2" OTIS X NIP ID = 3 8533' 4 - , . 8550' 7" BOT LNR HGR W/ TIEBACK SLV 8566' 3-3/4" BAKER DEPLOYMENT SLV, ID = 3.000" 8568' 4-1/2" OTIS XN NIP, ID MILLED FROM 3.725" to 3.80" 8601' 4-1/2" WLEG 8605' ELMD TT LOG NOT AVAILABLE n _,_~ 9253' ~ 7" MARKER JOINT 9275' TOP OF WHIPSTOCK 92$4' RA TAG 7" MILLOUT WINDOW 9279' - 9286' _ 10115' FISH-IBP RUBBERS (3/2. PBTD I---I 10272' I TOC I 10318' I-{ 2-7/8" LNR, 6.16#, L-80 FLRS, .0057 bpf, ID = 2.372" DATE REV BY COMMENTS DATE REV BY COMMENTS 04/20/86 ORIGINAL COMPLETION 03/16/13 DAV/PJC GLV GO 01/29/96 CTD SIDETRACK 07/01/03 JJ/KAK GLV GO (OPEN STA 5 8~ 6) 01/16/06 RCGPAG GLV GO (01/13/06) 03/27/06 DBM/PJC PULL IBP @ 9770' 03/27/06 DBM/PJC FISH (IBP RUBBERS) @ 10115' PRUDHOE BAY UNff WELL: G35A PERMfI• No: 1952000 API No: 50-029-21553-01 SEC 19, T11 N, R14E, 1250' FNL & 879' FEL BP Exploration (Alaska) 'TREE= 4-1/6" CNV WELLHEAD= FMC ACTUATOR = AXELSON KB. ELEV = 66.15' BF. ELEV = 36.75' KOP = 5200' Max Angle = 96 ~ 10058' Datum MD = 9357' Datum TV D = 8800' SS 113-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" C -3 5 B SAFETY NOT : WELL E7(C®S 70° @ 9550' AND GOES HORIZONTAL @ 9794'. "CAUTION -TOP OF 2-718" LNR @ Proposed CTD Sidetrack Ssss' 3.75° OD BKR DEP SLV, ID= 3.000°. EXACT DEPTH OF 2.372" MIN ID @ XO FROM 3-112" TO 2-718" UNKNOWN. SDTRK LNR DETAIL NOT IN FILE 2117' 4 1!2" OTIS DBE SSSVN. ID = 3.813" Minimum ID = 2.372" @ ? TOP OF 2-7/8" LINER 8533' 4-1 /2" OTIS X NIP, ID = 3.813" 8540' Top of 3-,;2„ ~in•;: ~ CC 8550' 7" BOT LNR HGR W/ T~BACK SLV ~k' 8550' 3-112" X ~d1P 'D = 2.313° 8568' 4-1/2" OTIS XN NIP, ID MILLED FROM 3.725" to 3.80" 8601' 4-1/2" WLEG 8605' ELMD TT LOG NOT AVAILABLE 9850' 3-3116 x 2-7/8 X-over 8414' -{4-1/2" OTIS XA SLIDING SLEEVE, ID= 3.813" 8473' TNV PBR W! LATCH ASSY $4$$' 9-5/8"x 4-112" TNV HBBP PKR, ~ = 4.750" 1 /2" TBG, 12.6#, L-80 BTRS, ID = 3.958" ~ 8601' 9-5/8" CSG, 47# L-80 BTRS, ID = 8.681" 8798' PERFORATION SIAMM RY REF LOG: GEARHART- BHCS ON 02/27/86 ANGLEATTOP PERF: 84 @9670' Note: Refer to Roduction DB for historical perf data SQE SPF IIYTEIT/AL Opn/Sqz DOTE 2" 4 9670 - 9700 ~ ,' : ~ ~ ~~:osed 1-11/16" 4 9710 - 9730 isolated proposed 2" 4 9700 - 9730 isolated proposed 2" 4 9670 - 9700 isolated proposed 2" 4 9700 - 9730 isolated proposed 2" 4 9805 - 9835 isolated proposed 2" 4 9835 -9865 isolated proposed 2" 4 9865 -9895 isolated proposed 2" 4 10041 - 10071 isolated proposed 2" 4 10074 - 10104 isolated proposed 2" 4 10107 - 10137 isolated proposed 2" 4 10140 - 10170 isolated proposed 2" 4 10173 - 10203 isolated proposed 2" 4 10206 - 10236 isolated proposed 2" 4 10239-10269 isolated proposed LIVf[, G51F L-OU W9J, IV - O. 109 I', -~/ {/V 3-3.16" carted X 2-7/8" pre-drilled 11325' '~ 8865' Mechanical Whipstock g{~ 90~ Chem cut 2-7/8" Inr 17" MARKER JOINT I (FISH-IBP RUBBERS (3/27/06) I - PBTD 1~7Z' ~ ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 2985 2918 0 OTIS DMY RM 0 04/24/06 5 4885 4818 1 OTIS DMY RM 0 04/24/06 4 6272 6128 31 OTIS DMY RA 0 04/19/86 3 7265 6987 29 OTIS DMY RA 0 04/19/86 2 7961 7603 28 OTIS DMY RA 0 04!19/86 1 8269 7871 30 OT1S DMY RA 0 04/19/86 TOC 12-7/8" LNR, 6.16#, L-80 FLRS, .0057 bpf, ID= 2.372" I DATE REV BY COMMENTS DATE REV BY COMMENTS 04120186 ORIGINAL COMPLETION 03/16/13 DAV/PJC GLV GO 01129!96 CTD SIDETRACK 07/01/03 JJ/KAK GLV GO (OPEN STA 5 & 6) 01/16/06 RCGPAG GLV GO (01/13/06) 03/27/06 DBMIPJC PULL IBP @ 9770' 03/27/06 DBIWPJC FISH (IBP RUBBERS) I~ 10115' PRUDHOE BAY UNIT WELL: G35A PERMff No: 1952000 API No: 50-029-21553-01 SEC 19, T11 N, R14E, 1250' FNL 8 879' FEL BP Exploration (Alaska) by ~ BP Alaska Baker Hu hes INTEQ Plannin Re ort g g P ~.r ~c~s INTEQ Company: BP Amoco Date: 8/17/2006 Time: 16:05:28 Page: t Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: C-35, True North Site: PB C Pad Vertical ('I'VD) Reference: 43 :35 5/31/1996 09:59 66.2 Well: C-35 5eedon (VS) Reference: Well (O.OON,O.OOE,275.OOAzi) Wellpath: Plan 2, C-35B Survey Calealation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB C Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5957218. 72 ft Latitude: 70 17 22.367 N From: Map Easting: 662550. 03 ft Longitude: 148 41 2.797 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.24 deg Well: C-35 Slot Name: 35 C-35 Well Position: +N/-S 2710.66 ft Northing: 5959971. 94 ft Latitude: 70 17 49.024 N +E/-W 2007.06 ft Easting : 664497. 88 ft Longitude: 148 40 4.294 W Position Uncertainty: 0.00 ft Wellpath: Plan 2, C-356 Drilled From: C-35 Tie-on Depth: 8800.00 ft Current Datum: 43:35 5/31/1996 09 :59 Height 66 .19 ft Above System Datum: Mean Sea Level Magnetic Data: 8/17/2006 Declination: 24.43 deg Field Strength: 57606 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.19 0.00 0.00 275.00 Plan: Plan t'i`2 Date Composed: 8/17/2006 Copy Lamar's plan 2 Version: 3 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <-_ Latitude -_> <- Longitude. ---> Name Deseription TVD +N/-S +E/-W Northing., Fasting Deg Min Sec Deg Min Sec Dip. Dir. `ft ft ft ft ft C-35A Polygon 66.19 1082.86 -1574.66 5961020.00 662900.00 70 17 59.672 N 148 40 50.200 W -Polygon 1 66.19 1082.86 -1574.66 5961020.00 662900.00 70 17 59.672 N 148 40 50.200 W -Polygon 2 66.19 1076.94 -1989.92 5961005.00 662485.00 70 17 59.613 N 148 41 2.306 W -Polygon 3 66.19 1221.80 -3352.17 5961120.00 661120.00 70 18 1.033 N 148 41 42.022 W -Polygon 4 66.19 1600.97 -3308.86 5961500.00 661155.00 70 18 4.762 N 148 41 40.764 W -Polygon 5 66.19 1473.92 -2531.40 5961390.00 661935.00 70 18 3.515 N 148 41 18.096 W -Polygon 6 66.19 1387.81 -1567.99 5961325.00 662900.00 70 18 2.671 N 148 40 50.008 W C-35A Faultl 66.19 1178.53 -1832.65 5961110.00 662640.00 70 18 0.612 N 148 40 57.722 W -Polygon 1 66.19 1178.53 -1832.65 5961110.00 662640.00 70 18 0.612 N 148 40 57.722 W -Polygon 2 66.19 946.16 -1727.70 5960880.00 662750.00 70 17 58.327 N 148 40 54.661 W -Polygon 3 66.19 636.00 -1724.49 5960570.00 662760.00 70 17 55.277 N 148 40 54.565 W -Polygon 4 66.19 946.16 -1727.70 5960880.00 662750.00 70 17 58.327 N 148 40 54.661 W C-35A Fault3 66.19 1598.83 -2068.52 5961525.00 662395.00 70 18 4.745 N 148 41 4.602 W -Polygon 1 66.19 1598.83 -2068.52 5961525.00 662395.00 70 18 4.745 N 148 41 4.602 W -Polygon 2 66.19 1516.51 -1735.22 5961450.00 662730.00 70 18 3.937 N 148 40 54.884 W C-35A Faultl 66.19 1493.81 -2525.96 5961410.00 661940.00 70 18 3.711 N 148 41 17.937 W -Polygon 1 66.19 1493.81 -2525.96 5961410.00 661940.00 70 18 3.711 N 148 41 17.937 W -Polygon 2 66.19 2179.64 -2325.89 5962100.00 662125.00 70 18 10.457 N 148 41 12.111 W C-35A Targetl 9011.19 1284.34 -1548.25 5961222.00 662922.00 70 18 1.654 N 148 40 49.431 W C-35A Targetl 9011.19 1324.00 -1897.49 5961254.00 662572.00 70 18 2.043 N 148 40 59.613 W C-35A Target3 9011.19 1220.88 -2578.95 5961136.00 661893.00 70 18 1.027 N 148 41 19.480 W by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P s~Rltr Nucsli~s INTEQ Company: BP Amoco Date: 8/17/2006 Time: 16: 05:28 Page: 2 Field: Prudhoe ;Bay Co-ordinate(NE}.Reference: WeIL C-35, True North Site: PB C Pad Vertical (TVI)) Reference: 43:35 5/31!1 996 09:59 66. 2 Welt: C -35 Section (VS) Reference: Well (O.OON,O .OOE,275.OOAzi) Wellpath: Pian 2, C-35B Survey Calcalstion Method: Minim um Curvature Db: OraGe Targets Map Map <-- Latitude ----> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Fasting Deg Afia Sec Deg hlin Sec Dip. Dii-. ft ft $ ft ft C-35A Target4 9011.19 1429.24 -3140.57 5961332.00 661327.00 70 18 3.074 N 148 41 35. 855 W Annotation MD TVD ft ft 8800.00 8389.93 TIP 8865.00 8445.29 KOP 8885.00 8462.48 End of 9 Deg/100' DLS 8985.00 8553.80 4 9025.00 8592.28 5 9525.00 8965.16 6 9761.11 9011.17 7 10261.11 9011.17 8 10961.11 9011.17 9 11325.00 0.00 TD Plan Section Information MD Incl. Azim TVD +NFS +E/-W DLS Build Turn TFO -Target ft deg:. deg ft ft ft deg/1OOft deg/100ft deg/100ft deg 8800.00 31.62 331.70 8389.93 1166.65 -1071.54 0.00 0.00 0.00 0.00 8865.00 31.61 331.83 8445.29 1196.67 -1087.66 0.11 -0.02 0.20 98.46 8885.00 29.81 331.83 8462.48 1205.67 -1092.48 9.00 -9.00 0.00 180.00 8985.00 17.81 331.83 8553.80 1241.20 -1111.50 12.00 -12.00 0.00 180.00 9025.00 13.86 321.77 8592.28 1250.36 -1117.36 12.00 -9.89 -25.15 210.00 9525.00 67.56 267.53 8965.16 1291.23 -1412.76 12.00 10.74 -10.85 300.00 9761.11 90.00 285.29 9011.17 1318.21 -1640.30 12.00 9.51 7.52 40.00 10261.11 90.00 245.29 9011.17 1278.00 -2128.56 8.00 0.00 -8.00 270.00 10961.11 90.00 301.29 9011.17 1316.61 -2799.91 8.00 0.00 8.00 90.00 11325.00 90.00 272.18 9011.17 1420.27 -3144.65 8.00 0.00 -8.00 270.00 Survey -MD Intl Azim SysTW N/S E/W' MapN MspE DLS VS TFO Tool'. ft deg. ..deg ft ft ft- ft ft degl100ft ft deg ___ 8800.00 31.62 331.70 8323.74 1166.65 -1071.54 5961114.78 663401.14 0.00 1169.14 0.00 MWD 8865.00 31.61 331.83 8379.10 1196.67 -1087.66 5961144.44 663384.36 0.11 1187.82 98.46 MWD 8885.00 29.81 331.83 8396.29 1205.67 -1092.48 5961153.33 663379.35 9.00 1193.40 180.00 MWD 8900.00 28.01 331.83 8409.42 1212.06 -1095.90 5961159.65 663375.78 12.00 1197.37 180.00 MWD 8925.00 25.01 331.83 8431.79 1221.90 -1101.17 5961169.36 663370.30 12.00 1203.47 180.00 MWD 8950.00 22.01 331.83 8454.71 1230.69 -1105.88 5961178.05 663365.40 12.00 1208.93 180.00 MWD 8975.00 19.01 331.83 8478.12 1238.41 -1110.01 5961185.68 663361.10 12.00 1213.72 180.00 MWD 8985.00 17.81 331.83 8487.61 1241.20 -1111.50 5961188.43 663359.55 12.00 1215.45 180.00 MWD 9000.00 16.28 328.62 8501.95 1245.01 -1113.68 5961192.19 663357.29 12.00 1217.95 210.00 MWD 9025.00 13.86 321.77 8526.09 1250.36 -1117.36 5961197.46 663353.50 12.00 1222.08 213.07 MWD 9050.00 15.57 312.05 8550.28 1254.96 -1121.70 5961201.96 663349.05 12.00 1226.81 300.00 MWD 9075.00 17.62 304.37 8574.24 1259.34 -1127.32 5961206.22 663343.34 12.00 1232.79 309.41 MWD 9100.00 19.91 298.33 8597.91 1263.50 -1134.19 5961210.23 663336.38 12.00 1240.00 316.76 MWD 9125.00 22.36 293.52 8621.23 1267.42 -1142.30 5961213.97 663328.19 12.00 1248.42 322.49 MWD 9150.00 24.93 289.64 8644.13 1271.09 -1151.63 5961217.43 663318.78 12.00 1258.03 326.97 MWD 9175.00 27.58 286.45 8666.55 1274.50 -1162.14 5961220.61 663308.20 12.00 1268.80 330.53 MWD 9200.00 30.29 283.79 8688.43 1277.64 -1173.82 5961223.50 663296.46 12.00 1280.70 333.39 MWD 9225.00 33.04 281.53 8709.70 1280.51 -1186.62 5961226.08 663283.60 12.00 1293.71 335.72 MWD 9250.00 35.83 279.58 8730.32 1283.09 -1200.52 5961228.36 663269.65 12.00 1307.78 337.64 MWD 9275.00 38.65 277.88 8750.22 1285.37 -1215.47 5961230.32 663254.65 12.00 1322.87 339.25 MWD 9300.00 41.49 276.37 8769.35 1287.36 -1231.44 5961231.96 663238.64 12.00 1338.95 340.61 MWD 9325.00 44.35 275.03 8787.66 1289.05 -1248.38 5961233.27 663221.67 12.00 1355.97 341.76 MWD • by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P s~ ~r s INTEQ Company: BP Amoco Date: 8/17/2006 Time: 16 :05:28 Page: 3 Field: Prudhoe. Bay Co-ordinate(NE) Reference: Well: C-35, True North Site: PB C Pad Vertical (T'VD) Reference:. 43:3 5 5/31/1996 09:59 66. 2 Weil: C-35 Section (VS) Reference: Well ( O.OON,O.OOE,275.OOAzi) Wellpath: Plan 2, C-35B Snrvey Catculstioo Method:- Minimum Curvature Db: Oracle Survey MD Incl Azim Sys TVD N/S - E/R' MapN MapE DLS VS TFO Tool ft deg , deg ft ft ft ft ft deg/100ft ft deg 9350.00 47.22 273.82 8805.09 1290.43 -1266.24 5961234.26 663203.78 12.00 1373.89 342.74 MWD 9375.00 50.10 272.72 8821.60 1291.49 -1284.98 5961234.91 663185.03 12.00 1392.65 343.59 MWD 9400.00 53.00 271.70 8837.14 1292.25 -1304.54 5961235.24 663165.46 12.00 1412.20 344.32 MWD 9425.00 55.90 270.76 8851.68 1292.68 -1324.87 5961235.22 663145.12 12.00 1432.49 344.95 MWD 9450.00 58.80 269.88 8865.16 1292.79 -1345.92 5961234.88 663124.08 12.00 1453.47 345.49 MWD 9475.00 61.72 269.06 8877.56 1292.59 -1367.62 5961234.20 663102.39 12.00 1475.07 345.97 MWD 9500.00 64.64 268.27 8888.84 1292.07 -1389.92 5961233.19 663080.10 12.00 1497.25 346.38 MWD 9525.00 67.56 267.53 8898.97 1291.23 -1412.76 5961231.85 663057.29 12.00 1519.92 346.73 MWD 9550.00 69.87 269.58 8908.05 1290.65 -1436.05 5961230.76 663034.03 12.00 1543.07 40.00 MWD 9575.00 72.20 271.58 8916.17 1290.89 -1459.68 5961230.48 663010.39 12.00 1566.64 39.25 MWD 9600.00 74.56 273.52 8923.33 1291.96 -1483.61 5961231.03 662986.45 12.00 1590.57 38.61 MWD 9625.00 76.93 275.42 8929.48 1293.84 -1507.77 5961232.39 662962.26 12.00 1614.79 38.05 MWD 9650.00 79.31 277.28 8934.63 1296.55 -1532.08 5961234.56 662937.90 12.00 1639.25 37.58 MWD 9675.00 81.70 279.11 8938.75 1300.07 -1556.48 5961237.54 662913.42 12.00 1663.87 37.20 MWD 9700.00 84.11 280.92 8941.84 1304.38 -1580.91 5961241.32 662888.91 12.00 1688.58 36.90 MWD 9725.00 86.52 282.71 8943.88 1309.48 -1605.29 5961245.89 662864.42 12.00 1713.31 36.67 MWD 9750.00 88.93 284.50 8944.88 1315.36 -1629.57 5961251.23 662840.02 12.00 1738.01 36.53 MWD 9761.11 90.00 285.29 8944.98 1318.21 -1640.30 5961253.85 662829.23 12.00 1748.95 36.46 MWD 9800.00 90.00 282.18 8944.98 1327.45 -1678.08 5961262.25 662791.26 8.00 1787.39 270.00 MWD 9850.00 90.00 278.18 8944.98 1336.28 -1727.28 5961270.01 662741.88 8.00 1837.17 270.00 MWD 9900.00 90.00 274.18 8944.98 1341.66 -1776.98 5961274.30 662692.08 8.00 1887.15 270.00 MWD 9950.00 90.00 270.18 8944.98 1343.57 -1826.93 5961275.11 662642.10 8.00 1937.08 270.00 MWD 10000.00 90.00 266.18 8944.98 1341.98 -1876.90 5961272.43 662592.19 8.00 1986.72 270.00 MWD 10050.00 90.00 262.18 8944.98 1336.91 -1926.63 5961266.27 662542.58 8.00 2035.82 270.00 MWD 10100.00 90.00 258.18 8944.98 1328.38 -1975.89 5961256.67 662493.52 8.00 2084.15 270.00 MWD 10150.00 90.00 254.18 8944.98 1316.44 -2024.43 5961243.67 662445.26 8.00 2131.46 270.00 MWD 10200.00 90.00 250.18 8944.98 1301.14 -2072.02 5961227.33 662398.02 8.00 2177.54 270.00 MWD 10250.00 90.00 246.18 8944.98 1282.56 -2118.43 5961207.74 662352.03 8.00 2222.15 270.00 MWD 10261.11 90.00 245.29 8944.98 1278.00 -2128.56 5961202.96 662342.01 8.00 2231.84 270.00 MWD 10300.00 90.00 248.40 8944.98 1262.71 -2164.31 5961186.89 662306.60 8.00 2266.13 90.00 MWD 10350.00 90.00 252.40 8944.98 1245.94 -2211.41 5961169.10 662259.88 8.00 2311.58 90.00 MWD 10400.00 90.00 256.40 8944.98 1232.50 -2259.56 5961154.61 662212.04 8.00 2358.38 90.00 MWD 10450.00 90.00 260.40 8944.98 1222.45 -2308.53 5961143.49 662163.31 8.00 2406.28 90.00 MWD 10500.00 90.00 264.40 8944.98 1215.84 -2358.08 5961135.80 662113.92 8.00 2455.07 90.00 MWD 10550.00 90.00 268.40 8944.98 1212.71 -2407.97 5961131.57 662064.11 8.00 2504.50 90.00 MWD 10600.00 90.00 272.40 8944.98 1213.06 -2457.96 5961130.83 662014.13 8.00 2554.33 90.00 MWD 10650.00 90.00 276.40 8944.98 1216.90 -2507.80 5961133.58 661964.22 8.00 2604.32 90.00 MWD 10700.00 90.00 280.40 8944.98 1224.20 -2557.25 5961139.80 661914.62 8.00 2654.22 90.00 MWD 10750.00 90.00 284.40 8944.98 1234.94 -2606.08 5961149.46 661865.58 8.00 2703.79 90.00 MWD 10800.00 90.00 288.40 8944.98 1249.06 -2654.03 5961162.53 661817.33 8.00 2752.79 90.00. MWD 10850.00 90.00 292.40 8944.98 1266.48 -2700.88 5961178.92 661770.11 8.00 2800.99 90.00 MWD 10900.00 90.00 296.40 8944.98 1287.14 -2746.41 5961198.57 661724.15 8.00 2848.14 90.00 MWD 10950.00 90.00 300.40 8944.98 1310.92 -2790.38 5961221.38 661679.67 8.00 2894.02 90.00 MWD 10961.11 90.00 301.29 8944.98 1316.61 -2799.91 5961226.87 661670.01 8.00 2904.01 90.00 MWD 11000.00 90.00 298.18 8944.98 1335.90 -2833.68 5961245.41 661635.83 8.00 2939.33 270.00 MWD 11050.00 90.00 294.18 8944.98 1357.96 -2878.54 5961266.48 661590.50 8.00 2985.94 270.00 MWD 11100.00 90.00 290.18 8944.98 1376.83 -2924.84 5961284.33 661543.81 8.00 3033.70 270.00 MWD 11150.00 90.00 286.18 8944.98 1392.43 -2972.33 5961298.88 661495.99 8.00 3082.38 270.00 .MWD 11200.00 90.00 282.18 8944.98 1404.67 -3020.80 5961310.06 661447.27 8.00 3131.73 270.00 MWD 11250.00 90.00 278.18 8944.98 1413.51 -3070.00 5961317.82 661397.89 8.00 3181.51 270.00 MWD 11300.00 90.00 274.18 8944.98 1418.89 -3119.70 5961322.11 661348.09 8.00 3231.49 270.00 MWD 11325.00 90.00 272.18 8944.98 1420.27 -3144.65 5961322.95 661323.11 8.00 3256.47 270.00 4 1 /8" BP Alaska wt~tPaT~ ot,A~t= Pb~z ~35a P&r T a~IOn Mel, 8900.00 Ruf. On[RUm9~: i9:355rJln 9%09:59 66.19fl V.Sectan Dr~an Cridn Surt~rq 8 KER I ~ ; "'°~`~""'°~'° ~~s t'~t? I i • Vertical Section at 275.00° ~100fuin~ AM • • ents are i ~_ ~ C-35B BAG 71/16" 5000 psi. fiddle middle of pipes fiddle of pi cross Blind/Shears _ TOTs ~' 2 3/8" combi ram/slips ~ ~ x/16" 5ooopsi Mud Cross I I Mud Cross 7 1/16" 5000psi variable bore pipe 3 1/2"-2 3/8" TOTs 2 3/8" combi ram/slips ~ ~ 1/16" 5000psi Flow Tee • Terri Hubble BP Exploration AK Inc PO Box 196612 MB 7-5 Anchorage, AK 995T9 PAY TO THE ORDER OF "Mastercard Check" First National Bank Alaska w Anchorange.,~AK 99501 MEMO-- V • as-siizsz 299 DATE ° ~./~ ~ `° ~/ $ l0~ • °~' ~:L25200060~:99L46227L556~~' 0299 • • TRANSMITTAL LETTER CHECKLIS'T' WELL NA~tiTE ~~(~ -- ,~ j ~~~ PTD# 2©~ /2 g' ~7~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-ONS WHAT I (OPTIONS) APPLIES TEXT FOR APPROVAL LETTER I MULTI LATERAL ~ The permit is for a new wellbore segment of existing j well (If last two digits i API numb in ' Permit No. , API No. 50- - - er between 60-69) are ~ j Production should continue to be reported as a function of the ' i original API number stated above. i PILOT HOLE j In accordance with 20 AAC 25.005(f), all records, data and logs i ;acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (~0- - -_) from records, data and logs acquired for well SPACING ~ The permit is approved subject to full compliance with 20 AAC EXCEPTION ~ 2.055. Approval to perforate and produce r' inject is contingent upon issuance of a conservation order approving a spacing I exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH j All dry ditch sample sets submitted to the Commission must be in ' SAMPLE , I no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals I through target zones. ! i Non-Conventional j Please note the following special condition of this permit: Well ~ production or production testing of coal bed methane is not allowed ~ for (name of well) until after (Company Name) has designed and I implemented a water well testing program to provide baseline data i on water quality and quantity. (Company Name) must contact the j Commission to obtain advance approval of such water well testing j Rev: 1 /25/06 C:\jody\transmitta( checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY,. PRUDHOE Oll. - 640150_ _ __Well Name: PRUDHOE BAY. UNIT C-356 _ ___Program DEV__ _._ Well bore seg ' PTD~:2061290 C ompany BP EXPLORATION_(ALASKA~NC _ Initial ClasslType _ _DEV/ 1-O1L_ GeoArea 890 ___ _ __ Unit 11650__ __ On/Off Shore On Annular Disposal '__', Administration '1 Permit feeattached_ _ Yes ',2 Lease number appropriate Yes 3 .Unique well name and number Yes '4 Well located in a defined-pool Yes 15 Well located proper distance from drilling unit boundary_ Yes X16 Well located proper distance-from other wells. Yes J Sufficient acreage available in drilling unit Yes 8 )f deviated, is wellbore plat included _ _ _ Yes _ 9 Operator only affected party _ Yes 10 Operator has_appropriate_bond in force Yes -.- 111 Permit can be issued wthout conservation order_ _ _ Yes _ 112 Permit can be issued without administrativ_e_approval Yes _ - Appr Date 13 Can permit be approved before 15-day wait Yes - RPC 9!1!2006 14 Well located within area and strata authorized by Injection Orde[# (put)O# in comments)_(For NA_ 15 All wells-within 114_mile area of review identified (For service well only) NA II16 Pre-produced injector; duration of preproduction less than 3 months_(For service well_only) NA I17 Nonconvert, gas conforms to AS31,05,030(~.1_.A),(j,2.A-D) _ - _ NA- _ _ - _ - __ ~18 - - -- __ - Conductorstnng_provided _ _ NA- - - Engineering I19 Surface casing_protectsoll known USDWs NA_ 20 CMT vol adequateto circulate onconductor_& surf csg NA 21 CMT vol adequate_to tie-in long string to-surf csg NA ',22 CMT_will cover all knownproductive horizons.. Yes Adequate excess.- 23 Casing designs adequate for C, T, B &. permafrost_ Yes '~24 Adequate.tankage-or reserve pit _ _ _ _ - Yes CTDU. ~125 If a re-drill, has a 10-403 for abandonment been approved _ _ _ Yes _ _ - - 26 Adequate wellbore separation proposed Yes !27 If dmerter required, does it meet_ regulations_ - - NA Sidetrack. _ _ j28 Drilling fluid- program schematic & equip list_adequate Yes - Max MW 8,6 ppg, Appr Date X29 BOPEs, do they meet_ regulation Yes _ WGA 9!8/2006 '~30 BOPE-press rating appropriate; test t_o-(put prig in comments) Yes Test to 3500. psi. MSP 2320 psi, '31 Choke manifold complies_wlAPl RP-53 (May 84) Yes ~i32 Work will occur without operation shutdow_n_ _ _ _ _ Yes _ x',33 Is presence of H2S gas probable No_ Max_ on_pad 20 ppm. i34 Mechanical condition of wells within AOR verified (For service well only) -- --- NA_ - -- __ _- __ 1 - 35 - - ___ Permit_can be issued wlo hydrogen sulfide measures No Geology ~',36 Data_presented on_ potential overpressure zones. NA 37 Seismic analysis_of shallow gas_zones --------- -------- ~ Appr Date X38 Seabed condition survey (if off_-shore) _ NA - RPC 917!2006 39 Contact namelphone for weekly progress reports_[explora_toryon/y] NA_ - - - - Geologic Engineering ~ Commissioner: Date: Commissioner: Date m r Date ors ~ f ~'/~ _ ___ _- ~ ~~.~ __ • Welt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 08/11/27 BHI Ol LIS Customer Format Tape **** TAPE HEADER **** MWD 23/01/08 1718799 01 3" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract .File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 8224.5000: Starting Depth STOP.FT 11331.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: C35-B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 17' 49.024"N 148 deg 40' 4.294"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 23 Jan 2008 API API NUMBER: 50029215530200 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 19 TOWN.N 11N RANG. 14E PDAT. MSL EPD . F - . LMF KB . FAPD.F 66.2 DMF DF EKB .F 66.2 EDF . F - . EGL .F 0 CASE.F 9279 OS1 DIRECTIONAL Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 ~~ OS2 PRESSTEQ I Other Services Line 2 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor and an Ultra Slim .Resistivity Sub. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated per Mike McTeague with BP Exploration (Alaska), Inc. (8) Tied to PBU C-35A at 8832 feet MD (8351 feet TVDSS). (9) Baker Hughes INTEQ runs 1 and 2 were used to mill through 7 in. liner and set a permanent whipstock. (10) Baker Hughes INTEQ runs 5, 6 and 7 were Venturi clean out and drift runs. (11) The sidetrack was drilled from PBU C-35A off the whipstock set at 8871 ft. MD (8384 ft. TVDSS) through the 7 in. liner. Top of window 8875 ft.MD (8388 ft.TVDSS) Bottom of window 8883 ft.MD (8395 ft.TVDS5) (12) The interval from 11299 ft to 11330 ft. MD (8943 ft. to 8942 ft. TVDSS) was not logged due to sensor bit offset at TD. (13) The resistivity interval from 8883 ft. to 9300ft. MD (8387ft to 8720 ft. TVDSS) was ream logged in Run 9, 291.8 hrs. after drilling. (14) The resistivity data presented from 9575 ft. MD to 11300 ft. MD (8890 ft. to 8943 ft. TVDSS) was ream logged after reaching TD per client request. was ream logged after reaching TD per client request. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACHX -> Resistivity (AT)(LS) 2MHz-Compensated Borehole Corrected, ohm.m RACLX -> Resistivity (AT)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCLX -> Resistivity (PD)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, ohm.m TVD -> True Vertical Depth (Subsea) TVD -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 8836.67, 8835.43, ! -1.24316 8872.94, 8871.08, ! -1.86523 8881.65, 8879.99, ! -1.65918 8900.56, 8898.91, ! -1.6582 8907.56, 8906.73, ! -0.830078 8921.92, 8920.46, ! -1.45117 8940.1, 8938.44, ! -1.6582 8954.14, 8951.86, ! -2.28027 8967.61, 8965.54, ! -2.07324 8976.11, 8974.04, ! -2.07324 8988.55, 8986.27, ! -2.28027 C~ 9030.21, 9028.34, ! -1.86523 9034.97, 9033.11, ! -1.86523 9050.15, 9048.91, ! -1.24414 9081.11, 9080.08, ! -1.03613 9092.1, 9090.86, ! -1.24414 9106.37, 9105.33, ! -1.03613 9177.13, 9176.51, ! -0.621094 9190.2, 9188.96, ! -1.24414 9323.52, 9321.86, ! -1.6582 9329.94, 9327.04, ! -2.90137 9401.7, 9400.66, ! -1.03711 9417.04, 9416.62, ! -0.415039 9594.14, 9593.93, ! -0.207031 9680.61, 9679.37, ! -1.24316 9693.87, 9693.45, ! -0.415039 9703.21, 9703.21, ! 0 9803.55, 9801.69, ! -1.86523 9824.97, 9823.31, ! -1.6582 9891.03, 9889.37, ! -1.6582 9966.21, 9964.96, ! -1.24316 10018.9, 10017.8, ! -1.03613 10032, 1 0032.2, ! 0.207031 10094.5, 10094.3, ! -0.207031 10113, 1 0113.6, ! 0.621094 10148.5, 10148.3, ! -0.207031 10158.2, 10158.6, ! 0.415039 10248.3, 10246.4, ! -1.86621 10281.6, 10277.6, ! -3.93848 10306.8, 10303.3, ! -3.52344 10326.1, 10321.3, ! -4.76855 10362, 1 0357.6, ! -4.35352 10487.9, 10485, ! -2.90234 10523.2, 10519.5, ! -3.73145 10539.6, 10537.5, ! -2.07227 10558, 1 0554.9, ! -3.10938 10599.5, 10597.4, ! -2.07227 10667, 1 0664.3, ! -2.69434 10751.1, 10746.6, ! -4.56055 10780.4, 10775.8, ! -4.56055 10951.4, 10946.6, ! -4.76758 10965.7, 10961.1, ! -4.55957 11002, 1 0998.4, ! -3.52441 11031, 1 1029.1, ! -1.86523 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 141 records... Minimum record length: 8 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------ WDFN c35b 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN C35-B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!~!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL from Schlumberger GR CNL per Mike McTeague with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: CIFO MNEM ----- CHAN DIMT ------------------ CNAM -------- ODEP GR GR ---- GRAX ----------------- 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 173 Tape File Start Depth = 8224.500000 Tape File End Depth = 11331.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 186 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN c35b.xtf LCC 150 CN BP Exploration (Alaska) WN C35-B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw unedited field data. *** INFORMATION TABLE: CIFO MNEM ----- CHAN DIMT --- CNAM ODEP GR --------------- GR ------------ GRAX ----------------- 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 280 Tape File Start Depth = 8820.000000 Tape File End Depth = 11331.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 293 records... Minimum record length: 34 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 23/01/08 1718799 01 **** REEL TRAILER **** MWD 08/11/27 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subfile 1 is type: LIS • • Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 8224.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8225.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8400.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8500.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8600.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8700.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8800.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999 2500 8900.0000 160.5157 13.5614 1073.9436 16.7921 -999.2500 -999.2500 9000.0000 51.7719 25.7149 49.2820 2000.0000 -999.2500 -999.2500 9100.0000 83.1221 39.5773 32.4882 70.3611 -999.2500 -999.2500 9200.0000 35.3550 31.4650 30.3437 55.7944 -999.2500 -999.2500 9300.0000 19.2264 1131.2683 35.4440 69.9914 41.7897 34.7818 9400.0000 35.6189 106.8958 24.2430 71.0662 50.5103 49.9228 9500.0000 19.9424 87.0873 19.1443 23.7274 18.5734 15.8351 9600.0000 25.3398 64.4061 15.6290 24.0839 21.8044 21.8615 9700.0000 26.7066 77.8926 15.6960 20.2545 13.5655 10.6724 9800.0000 32.4458 97.0169 10.1008 11.0730 10.8629 10.6981 9900.0000 24.6721 114.2180 10.5660 11.8767 9.3313 7.8572 10000.0000 30.5283 60.6147 11.7542 12.2381 10.2216 8.5613 10100.0000 27.8576 64.0179 12.0580 12.9458 11.2467 10.1720 10200.0000 21.5905 111.5877 9.0408 7.0297 10300.0000 36.1156 104.3195 7.4211 6.0920 10400.0000 26.8861 103.5454 10.4704 10.2863 10500.0000 36.4429 70.1656 10.8498 9.8726 10600.0000 24.3229 60.2476 9.6881 9.4971 10700.0000 23.8809 78.1000 16.0474 15.9042 10800.0000 50.1136 109.5874 16.7143 14.1560 10900.0000 25.9354 102.3661 8.2425 6.8481 11000.0000 35.4491 29.5037 10.4444 8.6632 11100.0000 24.2223 106.6824 9.0636 7.8479 11200.0000 43.8789 82.2258 7.0700 5.5914 11300.0000 -999.2500 94.1992 -999.2500 -999.2500 11331.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 8224.500000 Tape File End Depth = 11331.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • 12.2404 9.6430 9.9193 10.8364 9.4765 13.4449 17.1937 10.2624 12.0315 9.8819 9.7225 -999.2500 -999.2500 12.1993 8.6928 11.0895 13.0186 10.5029 16.7350 21.5410 10.0889 12.5730 10.8575 8.0515 -999.2500 -999.2500 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 8820.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8820.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8900.0000 193.3000 13.3000 47.8700 16.0570 12.0910 10.5000 9000.0000 56.1000 33.0000 48.9590 3863.1558 51.4920 38.8180 9100.0000 28.0000 40.4000 32.8470 81.0030 53.9360 50.2690 9200.0000 27.7000 30.9000 30.5890 63.0530 53.0720 52.4940 9300.0000 18.2000 12.0000 35.4440 73.4760 43.9230 36.4290 9400.0000 20.6000 107.0000 24.7420 73.3160 57.3540 58.1620 9500.0000 19.3000 79.7000 19.0820 23.0580 18.5060 15.7760 9600.0000 25.0000 63.5000 15.6080 24.1700 21.9890 22.1690 9700.0000 26.9000 75.6000 15.6910 20.2120 13.6000 10.6970 9800.0000 27.0000 97.6000 10.0670 11.1520 10.2280 9.5960 9900.0000 23.0000 102.5000 10.4680 11.8610 9.3120 7.8920 10000.0000 39.1000 71.1000 11.8800 12.1980 10.5050 8.9290 10100.0000 27.8000 63.6000 12.0580 12.9480 11.2680 10.2000 10200.0000 20.6000 127.3000 12.2980 12.2100 9.0560 7.0260 10300.0000 36.1000 112.8000 9.7820 8.7250 7.2080 5.7630 10400.0000 30.7000 90.6000 10.0790 11.2270 10.4150 9.9440 10500.0000 30.5000 80.6000 10.6260 12.6230 11.1680 10.7140 10600.0000 29.9000 90.0000 9.3350 10.2380 9.1850 8.6860 10700.0000 25.6000 78.0000 13.1970 16.3830 15.2600 14.6960 10800.0000 48.9000 110.8000 15.6550 13.0820 10900.0000 28.8000 93.8000 7.6700 6.1590 11000.0000 50.8000 58.7000 9.5130 7.8150 11100.0000 26.8000 90.9000 9.4580 8.2670 11200.0000 38.8000 95.2000 7.1540 5.6110 11300.0000 -999.2500 99.6000 -999.2500 -999.2500 11331.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 8820.000000 Tape File End Depth = 11331.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • 16.4890 10.1680 11.3280 10.0510 9.8940 -999.2500 -999.2500 19.7590 9.6980 11.6770 11.2310 8.3510 -999.2500 -999.2500 Tape Subfile 4 is type: LIS