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Home My WebLink About206-183 STATE OF ALASKA Ilk LASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATI RECEIVED ED 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operat lu10o$n 201? 0 Suspend 0 Perforate 0 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:A d 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 2 -1 3. Address: P.O.Box 196612 Anchorage, Development RI Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20581-01-00 7. Property Designation(Lease Number): ADL 028280,028304&028285 8. Well Name and Number: PBU G-08A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: 10610,12060,12586, Total Depth: measured 14004 feet Plugs measured 12950,13190 feet true vertical 9017 feet Junk measured None feet Effective Depth: measured 12060 feet Packer measured 10743 feet true vertical 8962 feet Packer true vertical 7968 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 33-113 33-113 Surface 2671 13-3/8" 32-2703 32-2703 4930 2670 Intermediate 11260 9-5/8" 29-11289 29-8344 6870 4760 Liner 829 7" 10790-11619 8000-8580 8160 7020 Liner 3218 3-1/2"x 3-3/16"x 2-7/8" 10786-14004 7998-9017 Perforation Depth: Measured depth: 12103-13830 feet True vertical depth: 8989-9017 feet Tubing(size,grade,measured and true vertical depth) 5-1/2"17#x 4-1/2"12.6#L-80 27-10853 27-8043 Packers and SSSV(type,measured and 5-1/2"Baker SAB Packer 10743 7968 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10400-10743'inIA,TOC in tubing at 10610'. SCANNED 1 92017 Treatment descriptions including volumes used and final pressure: �pSi� DECJ 12.5 Bbls 8.6 ppg cement. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 309 31004 3 0 1127 - Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations a Exploratory 0 Development I$ Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil RI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 i GSTOR ❑ 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 316-395 Authorized Name: Alatalo,Travis Contact Name: Alatalo,Travis Authorized Title: Productiono� Engineer Contact Email: Travis.Alatalot bp.com t2 Authorized Signature: -un Date: t l /2_/t"? Contact Phone: +1 9075645351 Form 10-404 Revised 04/2017 V.r` /z! / /! ,- yw Submit Original Only (2/i7 RBDKS k , L/ - 7217 • • 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 November 2, 2017 2/26/20 r7 To Whom it May Concern: 2,061`33 CbW Attached please find the Report of Sundry Well Operations for G-08A PTD#206- ,failed packer squeeze. G-08A has low remaining value (95 mbo remaining) and was being progressed as a CTD sidetrack.The well had active TxIA communication thought to be at the packer and behind the 5-1/2" patch. Current economics do not support a rig workover so an alternative integrity repair was proposed to maintain long term integrity/operability of the well.An IA cement squeeze was planned to mitigate the packer leak as well as the tubing leak that was behind the 5.5" patch. The proposed plan was to bring the TOC to '7300' MD in the IA. Calculated TOC in the IA after the squeeze was determined to be 10,400' MD while TOC in the tubing was determined to be 10,610' MD.Although cement in the IA was brought above the 5-1/2" patch, subsequent pressure tests still failed.The reserves associated with the proposed sidetrack G-08B do not support any further integrity work. 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 • • Daily Report of Well Operations G-08A ACTIVITYDATE SUMMARY ***WELL S/I ON ARRIVAL***(drlg screen (maint)) JAR FOR 1 HR ON HES DWP PATCH AT 10,590' MD ATTEMPT TO PULL PRT FROM 10590' MD - UNSUCCESSFUL 8/26/2016 ***CONT ON 8-27-16 WSR*** ***CONT FROM 8-26-16 WSR***(drlg screen (maint)) ATTEMPT TO SHEAR/ PULL 5-1/2" PRT PULLING TOOL FROM DWP PATCH @ 10,590' MD.(jarred 2hrs) PULLED 5-1/2" PRT PULLING TOOL FROM 5-1/2" HES DWP PATCH @ 10,590' MD. EQUALIZED & PULLED 3-1/2"XX PLUG FROM X-NIPPLE @ 10,805' MD. SET 5-1/2" PRT PULLING TOOL IN 5-1/2" HES DWP PATCH @ 10,590' MD.(4 x 5/16" brass screws, shear value-13,190#) PULL 5-1/2" PRT FROM HES DWP PATCH AT 10,590' MD (PRTsheared before GS) SET 5-1/2" PRT PULLING TOOL IN HES DWP PATCH AT 10,590' MD 8/27/2016 ***CONT ON 8-28-16 WSR*** ***CONT FROM 8-27-16 WSR*** (drlg screen (maint)) RIG DOWN SWCP 4522 8/28/2016 ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** CTU 9 w/2.0" CT CV=43.2bbI Job Objective: Fish Patch, CMT IA MIRU. Pump 1.375" drift ball. Begin BOP test. 8/28/2016 ***Job Continued on 8/29/2016*** CTU 9 w/2.0" CT CV=43.2bbI ***Continued from 8/28/2016*** Job Objective: Fish Patch, CMT IA Pump 1.375" drift ball. Finish BOP test. MU fishing toolstring with up only jars and 4" G- spear. RIH and tag fish @ 10580'. Latch fish and hit one small jar lick. RBIH to re-cock jars. PU to hit another jar lick and realized we are no longer latched to fish. Tried multiple time to relatch with no success. Suspecting we sheared the PRT we decided to trip OOH and re-pin. Unstab and discover one dog on G-spear is very loose which is why we cant latch back up to fish. PRT is still baited on patch. MU new G-spear and RBIH with fishing toolstring. Had trouble latching FN again. Suspecting plastic coating from tubing may be fouling pulling tool. Jet FN and latched up with no problem, start jarring in fish. Hit 50 licks, pump off fish and POOH to trim pipe. RBIH with same BHA. 8/29/2016 ***Job Continued on 8/30/2016*** CTU 9 w/2.0" CT CV=43.2bbl ***Continued from 8/29/2016*** Job Objective: Fish Patch, CMT IA Continue in hole with 4" GS BHA and up only jar BHA. Latch fish at 10586CTMD and begin jarring. Jar 50 licks, no movement. POOH. LD fishing BHA and trim pipe. MU new fishing BHA with agitator above 4" GS. Latch fish and alternate jar licks with overpulls while agitating. After 38 licks the jars stopped firing. Trip OOH. Talk to town and they don't want to try 4th run. Trip OOH. Cut off tools and trim 50' of pipe. MU & RIH with up/down jar, 2 wt bars, and accelerator. Not able to get a down jar lick. Pump off and POOH. 8/30/2016 ***Job Continued on 8/31/2016*** CTU 9 w/2.0" CT CV=43.2bbl ***Continued from 8/30/2016*** Job Objective: Fish Patch, CMT IA RIH with sigle-acting (down) Bakke hammer. Tag at 10589 and begin hammering. Have good indication of hammering for a total of 92 minutes. 68 taking all returns to formation and 24 flowing the well. PRT still not sheared. POOH to check tools. MU BOT bidi hipp tripper and RIH. Tag fish @ 10600'. Could not latch fish. Try to clean out FN by jetting. Still could not latch fish. POH. GS looks normal. FP well. Turn well over to SL to retrieve 8/31/2016 PRT. • S Daily Report of Well Operations G-08A ***WELL SHUT IN ON ARRIVAL*** RAN 2.50" P. BAILER TO 10,573' SLM...RECOVERED HAND FULL OF METAL SHAVINGS PULLED PRT FROM 10,573' SLM 9/1/2016 ***JOB COMPLETE, WELL LEFT S/I, PAD OP NOTIFIED*** CTU#6 1.75" CT Job Scope: GR CCL log /set CBP/ tubing punch / Packer squeeze. MU and RIH with 2.60" nozzle and GR/CCL logging tool, drift to 12,202' and tag 2-7/8" liner x-over. PU to 12,180' and paint flag (white and green). RIH w/ baker CBP 2.55" OD/Set CBP at 12060' set 5k down on plug POOH 9/4/2016 CTU#6 1.75" CT Job Scope: GR CCL log /set CBP/ tubing punch / Packer squeeze. RIH w/2"x 10' tubing punch 5' of shots perforate from 10659' to10664' POOH. LD tbg punch guns, all guns fired. MU 2.5" BDJSN. CMIT x IA to 3500 psi. Good test. RIH with nozzle and circulate 17 bbls of 9.8 ppg NaCI @ 12040' down the CT and up the backside. Pump 240 bbls of hot diesel @ 10610' down the CT and up the backside. Pump 470 bbls of hot diesel down CT and up IA. Pumped 777 bbls of diesel total 9/5/2016 **** Job in progress **** T/I/O=0/470/0, Temp=S/I, Assist CTU with Hot Oil Treatment (Packer Squeeze) Pumped 242 bbls of HOT 160* DSL down coil and up backside of coil. Pumped 473 bbls of 160* DSL down coil and up IA. Pumped 20 bbls of 50* DSL down coil and up backside of coil. 9/5/2016 CTD in control of well per LRS departure. FWHP's=180/380/480 CTU#6 1.75" CT Job Scope: GR CCL log /set CBP/ tubing punch / Packer squeeze. Pumped 12.5 bbls of 8.6 ppg cement into the IA for a packed squeeze POOH keeping hole full pumping diesel down coil. TOC in tubing 10610. TOC in IA 10400. 9/6/2016 ****Job complete **** T/I/O = 150/Vac/Vac. Temp = SI. MIT-T **FAILED**, CMIT-TxIA**PASSED**on second attempt to 2708/2718 psi, Max = 2750 psi, Target= 2500 psi (Post PKR SQZ). Tbg & IA FL near surface. Attempted MIT-T, IAP tracked TP. CMIT-TxIA used 12 bbls diesel to pressure Tbg/IA from 150/Vac psi to 2747/2748 psi. Tbg/IA lost 24/24 psi in 1st 15 min, and 15/6 psi in 2nd 15 min for a total loss of 39/30 psi in 30 min. Bled TBG from 2708 psi to 3 psi in 5 min, while bleeding TP, IAP tracked. Leak was to big to obtain a LLR with the triplex pump. Hung tags. Final WHPs = 0/50Nac. SV, WV, SSV = C. MV= O. IA, OA= OTG. 15:50 9/10/2016 T/I/O= 180/13/vac Temp= Shut in. Establish LLR Pumping into IA, taking returns up the 9/29/2016 TBG. ***Job continued to 9/30/2016. ***WSR continued from 9/29/2016. Pumped 50 bblls of ambient diesel down IA taking returns up up the TBG. IA psi gained slowly throughout the entire job before running out of fluid, WSL confirmed data should be effiecient for pre-eline. LLR established @ --1 bpm. Freeze Protected F/L. Pumped 10 bbls of meth and 25 bbls of crude per WOA formula, 9/30/2016 pressured up F/L. Tag hung on well. FWHP=187/448/0 ***WELL S/I ON ARRIVAL***(drlg/screen). DRIFT TO TOP OF CEMENT @ 10,571' SLM W/2-1/2" SAMPLE BAILER (bailer full of cement). TAGGED TOP OF HES 5-1/2" DWP PATCH WITH 4.0" LIB @ 10,564' SLM (No issues). 10/2/2016 ***WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** Fluids Summary Volume Type 1614 Bbls Diesel • • Daily Report of Well Operations G-08A 451.5 Bbls 1% Slick KCI 527.3 Bbls 50/50 McOH 17 Bbls 9.8 ppg NaCL Br 12.5 Bbls 8.6 ppg Cement 4 Bbls Fresh Water 25 Bbls Crude TREE= VOY • G-08A PLA3T�C OCO_S: TBG*** WILL)-EAD= McE�tOY S TES: WELL ANGLE>700 12141' ACTUATOR= BAKER C INITIAL KB.ELEV= 65.6' BF.gEV= 36.8' 2117' -15-112"CA-BAL-O SSSV NP,ID=4.562° KOP= 3050' _ - 2608' H9-5/8"DV FKR Max Angle= 96°@ 12873' Datum MD= 11915' i GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE Datum TVD= 8800'SS 12 3012 3011 8 CA DMY FE 0 08/31/15 13-3/8"CSG,72#,L-80,ID=12.347" -j 2700' 11 5463 4832 56 CA OMY FE 0 01/22/04 Minimum ID =2.377" 12202' 10 7207 5822 54 CA DMY RK 0 08/31/15 9 7347 5904 54 CA DMY FE 0 05/14/81 3-3/16" X 2-718" XO LNR PIN ID 8 8259 6451 53 CA DMY FE 0 05/14/81 TOC N IA(09/06/16) - 10400' 7 8404 6537 54 CA DMY RK 0 05/14/81 11V11 1�1t 6 9051 6914 50 CA DAY FE 0 01/22/04 1111( 1111 5 9197 7007 51 CA DMY RK 0 05/14/81 111 4. 5-1/2"I-ES DMP PATCH --I 10590'-10615' r1i �•1111 4 9772 7362 52 CA DMY FE 0 05/14/81 D=2.987" 03/19!13 11�1� X11 3 9914 7448 52 CA OW RK 0 05/14/81 ryvv pi O. 11 2 10448 7789 48 CA DMY RK 0 09/11/12 TOC N TBG(09/05/16) 10610' X11 :11 11 11111111.1':11 "1 10590 7884 48 CA '[MY RIC 0 02/28/13 1111�11111I11 1111.1..1,1 'SIA#1 1-XIl-IIWJ)F'<( fl Y E3F) )t7WPPATCH TBG PUNCH(09/05/16) 10669-10664 x.'��11. 1 1'i •11'/0_1/11 X111 �'1�1.1.1.1 1111 10657' --f 5-1/2"CAMCO SLD SLY,D=4.500" 11,,�•1•1•1•1A 1 10723' -BKR PBR SEAL ASSY L �.� 10743' -19-5/8"X 5-1/2"BKR PKR,13=4.0- 5-1/2' =4.0"5-1/2'TBG-PC,17#,L-801.146, -I 10744' 10744' H5-1/2"X 4-1/7'XO,ID=3.958" .0232 bpf,ID=4.892' 10773 ELM -14-1/2"OTIS X NP,13=3.813" TOP OF 7"LNR -I 10790' 10786' -3.70'BOT DEPLOY SLV,13=3.00" 3-112"LNR,9.3#,L-80 STL,.0087 bpf,D=2.992" 10837' 10805 ELM 14-1/2"OTIS)GI NIP,MILLED TO 3.80" BEHIND CT LNR 4-1/2"TBG,12.6#,L-80 CSE, -I 10854' 10805' -13-1/2"IES X NP,D=2.813" .0152 bpf,ID=3.958` 9-518"CSG,47#,L-80 BTRS,D=8.681" - 11289' 10837' --I3-1/2"X3-3/16"XO,ID=2.786" j TOC -I ^11415' & 10854' -I4-1/2"WLEG,D=3.958" BEHIND wHPSTOCK -I 11615' CT LNR 10837' -I ELMD TT LOGGED 06/12/82 7"LNC,29#,L-80 BTRS,.0371 bpf,D=6.184" H -11619 111111 11111 111 ►114 RA PP TAG H 11625' 111111 1111 MLLOUF WINDOW(G-08A) 11619'-11629' 11111 11111 111 ///4 12060' BKR CBP(09/04/16) PERFORATION SUMMARRY 111111 11111 REF LOG M]'&-GR CCL 03/12/07 �. ' , ,14 12202' H3-3/16"X 2-7/8"XO,ID=2.377" ANGLE AT TOP PERF: 63° 12103' "'4 ► @ �'�r`' �►� �-12.2"1NFD CEP(11/12/14) Note:Refer to Production D8 for historical pert data 1.1.1.1.1.1. 1•# 4 SIZE SPF INTERVAL OPNSOZ SHOT SOZ 11111111111111i1 12668'elmd I- POSSIBLE COLLAPSED TBG 2" 6 12103-12108 C 01/19/12 111111111 / (11l11l14 UNABLE TO[RF1) 2" 6 12245-12295 C 03114/0712960' H2-7/8"CIBP(05/30/10) 2" 6 12350-12405 C 03/14/07 / 2" 6 12440-12475 C 03/14/07 3-3/16"LNR, -I 12202' ..` 13190' -2-7/8"CEP 2" 6 12520-12550 C 03114/07 6.2#,L-80 TCN �" (04/23/09) 2" 6 12640-12690 C 03/14/07 .0076 bpf,D=2.80" , 2" 6 13056-13070 C 04/23/09 •101 2" 6 13100-13130 C 04/23/09 FBTD H 13969' 1411` 2" 6 13660-13830 C 03/13/07 2-718"LNR 6.4#,L-80 Sm,.0058 bpf,D=2.441" -1 14004' DATE REV BY COMMENTS DATE REV BY COM ENTS PRUDHOE BAY UNIT 05/14/81 ORIGINAL COMPLETION 09/01/16 DG/JMD RESET PRT&PULLED XX PLUG WELL: G-08A 03/15107 NORDIC 1 CTD SIDETRACK(G-08A) 09/06/16 JM[WJMD PILLED PRT(09/01/16) PE2MT No:'Z061830 11/12/14 SP PJC SET CEP/FOSSBLE LNR COLLAPSE 09/14/16 JDMJMD CMT IA/TBG,SET CBP,TBG FLINCH AR No: 50-029-20581-01 11/16/14 PJC COLLAPSED LIC CORRECTION SEC 12,T11N,R13E,2506'FSL&2367'FE. 09/10/15 SWC/JM2 GLV 00(08/31/15) 03/05/16 .MMNTLH BAIT SIB RANTED(11/21/15) PP Exploration(Alaska) 410 • SOF to !s), THE STATE Alaska Oil and Gas .> ,;,—s , of® TT sKA Conservation Commission _ 333 West Seventh Avenue c GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ° <1. ":4'0" "" '^' Fax: 907.276.7542 www.aogcc.alaska.gov Jaime Bronga Well Interventions Engineer BP Exploration(Alaska), Inc. SCAMS JAN 1 7 ZU11 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU G-08A Permit to Drill Number: 206-183 Sundry Number: 316-395 Dear Mr. Bronga: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, FL44 / Cathy '. Foerster Chair DATED this /Ay of August, 2016. RBDMS L V AUG 1 2 2016 IIEto-MTV-EU • STATE OF ALASKA J U l- 2 7 .016 ALASKA OIL AND GAS CONSERVATION COMM•N J • APPLICATION FOR SUNDRY APPROVALS /76r0 20 AAC 25.280 AOG 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 . Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other IA Packer Squeeze 0 • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 206-183 . Exploratory 0 Development 0. 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-20581-01-00 99519-6612 Stratigraphic 0 Service ❑ 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU G-08A 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028285 • PRUDHOE BAY,PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 14004 • 9017 • 12586 9025 See Attachment Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 33-113 34-114 Surface 2671 13-3/8"72#L-80 32-2703 32-2703 4930 2670 Intermediate 11260 9-5/8"47#L-80 29-11289 29-8344 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 5-1/2"Baker SAB Packer Packers and SSSV MD(ft)and TVD(ft): 10723, 7954.60 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 ' WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Bronga,Jaime be deviated from without prior written approval. Email Jaime.Bronga@bp.com Printed Name Bronga,Jaime Title Well Interventions Engineer Signature 4, Phone 9075644151 Date_91 2(g(/f U., COMMISSION USE ONLY ` ll Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3\ Q)- Plug Integrity 0 BOP Test 0 Mechanical Integrity Test V Location Clearance 0 Other: !G A/j T I-0 ! n Ge,. i >; rO G f--q '` 14 /T-/A1 N) 1T -fi ► l ?,„5:�J/7.h a /-101 z✓tr ” i� 1 Post Initial Injection MIT Req'd? Yes 0 No Lel /r et, V ,1. Spacing Exception Required? Yes 0 No li Subsequent Form Required: I C — 4 0 T APPROVED BYTHE Q Approved by' COMMISSIONER COMMISSION Date: U_ [0_i6,leei �'TL 29/91/46 ORIGINAL RBDMS (,V AUG 122016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachme is in Duplicate 8G 7,27/4> 4110 i Plugs Attachment PBU G-08A SW Name Date MD Description G-08A 11/13/2014 12586 2-7/8" WFD CIBP G-08A 05/30/2010 12950 2-7/8" BAKER CIBP G-08A 04/24/2009 13190 2-7/8" CIBP 40 i w • O O M O 0 0 N4 c N- (O Ln v- C0 p C`4 "4" o N- CO ti U L 00 (O (O t O LoNM • v (O O) 00 C0 M CO N O 10 ti N M cM 0 LO0 0 C)) O N CO M M C)) O N - 00 • , I I I I I I H r O N CO N- M N O O O M N N- N- M M N CA O O O N 0) N- 0) N- C M O N� O N V' (O M CO O CO M c- O O (() Cf) N- N 00 CO N O N- CO O N- N 0 0 N r r = ✓ p m 4-1a aCo (0 O N- N O Q M N C� (00) COC) if) ti CO N N- ''1 M M N O O O N N O C V r r r r r • ca a O p CO O s Op O m J J 000 J J J • y OM N *k M J N * N N ^ ' •N fn X- - V' O N O N 03 O a0 (V N 4) CV 2d ) M! Nu., M d' L M O M N N = CO O N ION M CO N- M N = 4- W C W W U NQ � 00 OONL CCEtCtoZZ ZWWWLUW OjHZZZZDD • • w N f6 m C) Lomm = mc.110 . N CO r- p_ N 6) M N N N 0) 0) a- • 0) 00 o0 0) O O 0) O a0 CO 0) p I- 0- 0 0 I- CO N (C) L0 f- M N N N .cN N (0 00 Cfl = M V LC) Q O M I- N M Cfl M Cfl 0 O co Co) CO N N N O) 0) O W 0 0) O O O O O O) C)) O > p CO 0) 0) 0) 0) 0) CO 00 O 0 w 0 00 w Z H I- 0 O W 0 ggQ " ° 0 00 0 ao � Lnl� 00000 o W U ° W W W 001.0101000000 L O O O r LC) CA I� M M J J W 1.9O_ ,- (N V V LC) CO O N- W ¢ ¢ ¢ W a a Z = O N N N N N N M c") M _U _U U_ J W W w Z Z Z 0 J J J 0 J C m ¢ ¢ ¢ = p p a w a G U U U W p o ~ -C W W W a H Q J Q Q 2 2 O co co co cn U ( co Q O o = s M LC) 0 0 0 0 Cfl O O O. O C LC) N (0 Ln O CO O = w — N Cr) (C) CO O Cfl • Ca O N N N N N N M 4-0 CO M L d G _ v) = O cn CL i a 0 cn ccnn cocn co CD a 0 T3 0 U c LI_ Q' W f:C CCW ) (1) Cl) <a O W W W W O D W d d < aMMdmmmm 0 t d 0 d I- p 0 0 0 0 0000 c 0 0 0 0 0 N N N N W O N N N N N ZZ W W N_ Nin N w Ip OO - V -f V c- Z CL W U �W w Il W 0. M CO CO CO L 0 ' r 0¢O O D W J J J 0 dW W ¢ ¢ O_ (n W LL ¢LI_ co C) E co z < < < < < < < < < 00 co co 0o co a0 10 (0 CO 0 0 0 0 0 0 0 0 0 W CL cn O LL N w 0000 0(.9OC1 < ¢ mmIUiECOU) am bp • Well : G-08 G-08 IA Cement Job Intervention Engineer Jaime Bronga 907-564-4151 Production Engineer Joleen Oshiro 907-564-4606 Reservoir Engineer Weston Smith 907-564-5090 History G-08 has no remaining vaf(HGOR) and is being progressed as a CTD sidetrack. In 2012, an LDL found a leak in GLM#1. A patch was set across the mandrel and integrity of the well restored. In 2015, during drilling screening, multiple MIT-Ts failed with IA pressure response. A subsequent LDL run showed a leak at the packer at 10722' MD. The well has been SI, non-operable since November 2015. CMIT-TxIA to 3000psi passes. Reserves/Economics There are 688 mbo reserves associated with the G-08B target; there is thus 593 mbo estimated to be recovered from the G-08B target. Current economics do not support a full blown rig-workover, therefore this alternative integrity repair is proposed to maintain integrity/operability of the well long term. Objective This cement job is to repair a tubing leak at 10607' MD behind the current patch and a packer leak at 10722' MD and make this well operable. Cement will be circulated down the CT and up the IA. The new TOC in the IA will be 7300' MD. After the cement job and restored integrity, the well is slated to receive a coiled tubing sidetrack to a new target. Expected Start Date: August 20, 2016 Post-Job Evaluation This well is a producer; an AA will not be applied for. The following BP internal criteria to evaluate the integrity of the non-rig workover will be applied: • MIT-IA and MIT-T • SCMT to locate TOC Long-Term Integrity Monitoring • Record WHPs daily (includes pressure monitoring of the Inner Annulus to be cemented to -7300'MD). • 4 year (quadrennial) MIT-lAs and MIT-Ts • • G-6QTIO flat • { —0—Tb9 '� • IA =.DOC+ --a,-OA 000A • 4� t 41,77 �.. ;.Y5:•4)1.12-5 CCyuC_ 5 DG 3i'5 33,C4'5 ".055'5 .2O i5 7X6:'6 340,11S CS,'"5... .�9�11P?1 2�".'.� 0",�.�...:�3Y26"s 15;� <&ia '�'%, , Procedure Objectives The objectives of this cement job is to repair a small one way TxIA leak at the packer at 10722'MD and a larger TxIA leak through GLM#1 at 10607'MD while maintaining kickoff GLV functionality. Cement will be circulated down CT and up the IA. The new cement top in the IA will be -7300' MD. Contacts: Jaime Bronga Joleen Oshiro 564-4151 (w) 564-4606 (w) 632-5941 (c) 650-483-4774 (c) Job Notes • Job calls for 5-1/2" plugs, plan BOPs accordingly. • Plastic coated tubing, use best practices • Tie in to attached CIBP setting record from May 29, 2010. o Tubing Tally and tie in log have a depth discrepancy of-20'. The Tie in log was used to locate the leak and will be used for setting plug, perforating, and setting the retainer on this job. • LLR for GLM #1 is -1.1 bpm @ 2400 psi. • LLR for packer leak is -3 gpm @ 3400 psi from the tubing to the IA. • SBHP is 3244 psi • BHCT is estimated to be 190F. • BHST 198 deg F. Cement Calculations Volume Cement 149 bbls Total cement to pump 149 bbls Ke Parameters Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F 2 FOLoss: 40-2OOcc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 6.5 hours • Cement thickening time: Mix on the fly Activity Time(hours) Shearing time,quality control, PJSM 0 Cement displacement 3.5 Cement contamination 2 Safety 1 Minimum required thickening time: 6.5 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 90 0 2:00 190 3000 6:00 190 1700 Volumes: top volume MD bot MD Size ID bbls/ft. Ft. bbls 5-1/2"tbg 0 10659 5-1/2" 17# 4.892" 0.0232 10659 247 9-5/8"47#x 5-1/2"x 9-5/8" annulus 0 10659 5-1/2" 17# 8.681" 0.0438 10659 467 1. Pull PRT from patch at 10590' MD. 2. Pull XX Plug from 1O805'MD. 3. Inspect PRT, if in good condition, reset. If in poor condition, redress prior to setting. 4. Reset PRT in anticipation of coil fishing attempts. 3 "3 r • • Well : G-08 ��fir f y j/,a„!. � r ,„,f F,. ri�.r��r r�r� r' � r ,�. f f r;;%�,#r �i''�" f;r'i ,"0.0.,#,//f ,r`%r `� /�r r fr/ /,�/r / r r / r y/�'f r�r r r/ / F:tosr % � '. :/Jlri'+`` % ,�l,`r/�4„1,rr ��r+a:9i,G,�f � %%�F�2 1. Rig up MM to IA for returns. This will help track TOC in the IA. PT coil connector and CT to 4800psi in anticipation of potential high circulating pressures toward the end of the cement job. In isolated cases CT pressure has been over -4000psi, pressure during this job aren't anticipated to be that high, however it is best to be prepared. 2. Fish the 5-1/2” patch from 10559'SLM. (Slickline left the patch baited on 11/21/2015). a. Fish on the patch for 4 runs of 50 jar licks or until the PRT fails. Do not attempt fishing with a spear as this jeopardizes the contingent cement squeeze options. b. If patch fishing fails, an 8.6ppg cement blend will be used to squeeze the packer and bring TOC to -10400'MD with 9.8ppg brine working fluid. See attached contingency procedure. 3. Drift for 5-1/2" plug with GR/CCL. Flag coil. Tie in via attached log from May 29, 2010 CIBP setting. 4. Load tubing with 242 bbls KCI @ max rate followed by 70bbl of freeze protect. Max pressure 3000 psi. Keep the IA SI while loading. 5. Set 5-1/2" composite bridge plug @ 10680'MD' (middle of the first full joint above the production packer). Reference attached CIBP Setting Record from May 29, 2010. 6. Punch tubing w/ 5' tubing puncher @ 10659'-10664'MD (across the top collar of the first full joint above production packer). Reference attached CIBP Setting Record from May 29, 2010. Note indication of tubing punch in AWGRS (likely won't be evident due to leak in GLM). 7. CMIT TxIA to 3500psi. If fails, establish LLR to 3500 psi to verify plug set. LLR is expected to be none to low (-0 to 3gpm @ 3500 psi). In the past, MIT-IA to 3000psi passed indicating the TxIA at the packer is a "one way leak" from the tubing to the IA. If LLR is higher than 9gpm contact Interventions Engr for plan forward. 8. Set 5-1/2" Halliburton Fas Drill SVB composite cement retainer with sliding sleeve © 10616' MD (middle of 2nd full joint above production packer). Reference attached CIBP Setting Record from May 29, 2010. 9. MU Halliburton Fas Drill SVB composite cement retainer stinger. RIH and circulate heated (160F) diesel to the stinger taking returns from the CT by CTBS. From just above the retainer, circulate 214bbIs of heated (160F) diesel out the CT to displace the CTBS to hot diesel prior to cementing. 10. Sting into the cement Siner. • • 11. Establish circulation with diesel down the CT and up the IA to tanks. Verify CTBS is shut in. Pump the following fluid schedule: Note: Do not pump any freezable fluids other than the FW spacer and cement though the retainer and into the IA as these fluids will remain in the IA after the cement job and may end up across the permafrost, freeze, and collapse the production tubing. Note: While circulating cement into the IA, expect the CTBS pressure to increase due to the communication through GLM#1. The anticipated pressure on the CTBS with TOC at -7300' MD is 950psi. DO not bleed down the CTBS pressure. This will cause cement to bleed into the Tubing. a. 470 bbls of heated diesel (160F) b. 5 bbl FW spacer c. 149 bbls cement per design above d. 5 bbl FW spacer e. CT volume of displacement (unsting from retainer w/ 1 bbl of cement in CT) 12. This should place TOC in the IA at 7300' MD. Keep track of returns from the IA. 13. If cement locks up while pumping into the IA, hold whatever CT by Tubing Backside pressure has already been established, cut cement at surface. Pull out of retainer and lay cement into the tubing at 1:1 maintaining the established CTx Tubing backside pressure. Swap to gel and contaminate and wash out cement all the way to surface continuing to maintain the established CT by Tubing Backside pressure throughout the operation. Trap the CT by Tubing Backside pressure on the well and SI after Freeze protecting. 14. While maintaining the established CT by Tubing backside pressure, unsting from cement retainer with 1 bbl of cement remaining in the CT. Lay the remaining cement onto the retainer at 1:1. 15. PUH pumping only CT displacement down the CT with a non freezeable fluid. POOH and pump at a rate which maintains the established CTx Tubing backside pressure. Approximately 32 bbls of fluid should be pumped down the CT by the time the CT reaches surface. 16. Leave the well SI with the trapped WHP (same as the established CTxTubing backside pressure) to keep IA cement in place. The 1 bbl of cement placed onto the retainer will be milled when milling retainer. 17. CT should be mostly freeze protected. If necessary, finish displacing the CT to a non- freezable fluid out to tanks. 18. RDMO. 5 i i Puttbore 1. Wait on Cement at least 5 days 2. MIT-IA to 2500 psi. 3. MIT-T to 2500 psi. 1. MU 3.8" junk mill (note: Sliding Sleeve @ 10657' MD has 4.5" ID and the Packer at 10743'MD has a 4"ID). Take care passing through SSD and Packer due to ID restrictions. RIH and tag TOC (expected —10573'MD). 2. Mill through cement, retainer, cement and the CBP set @ —10680' MD. 3. Mill/Push CBP down to the TOL at 10786'MD. Take care not to damage or mill the TOL. Once a hard tag is seen in this vicinity POOH for smaller mill. If progress is slow, changeout for intermediate sized mills. This program attempts to minimize mill runs, add runs as necessary to continue milling/pushing composites downhole. 4. MU junk mill for 3-1/2" (-2.7"). Continue milling/pushing remnants of CBP through the liner to the 3-3/16" x 2-7/8" XO (ID=2.377"). Once a hard tag is seen in this vicinity, POOH. 1. Load well as needed and run SCMT log from top of liner to surface casing shoe to find TOC and relative bond. This will be executed as a post sidetrack work in combination with production interval cement logging. , . = '' 1. Add Quadrennial (every four years) MIT-Ts and MIT-lAs to Anncomm. 6 • • Contingent Coil: If fishing patch is unsuccessful NOTE: This cement job will be executed with 8.6ppg cement to help prevent fallback, as the job can't be executed with a retainer. NOTE: Cement should be batch mixed. Cement parameters remain the same, lower compressive strength is acceptable (1000-1200psi). 1. Pull PRT. 2. Drift though patch with 3-3/16" CIBP drift with GR/CCL. Tag existing CIBP. Flag coil. Log up to above GLM #2. Tie-in via attached log. 3, Load tubing with 242 bbls KCI @ max rate followed by 70bbl of freeze protect. Max pressure 3000 psi. Keep the IA SI while loading. 4. Set CIBP in middle of first joint above top perf—12060'M D. Review jewelry log for collars. 5. Punch tubing w/ 5' tubing puncher @ 10659'-10664'MD (across the top collar of the first full joint above production packer). Reference attached CIBP Setting Record from May 29, 2010. Note indication of tubing punch in AWGRS. 6. CMIT TxIA to 3500psi. If fails, establish LLR to 3500 psi. CMIT-TxIA is expected to pass with the plug set below the packer. If CMIT-TxIA fails, contact Interventions Engr for plan forward. 7. With a BDJSN, RIH to just above the CIBP set at —12060'MD. Circulate 17bbls of 9.8 ppg brine down the coil and up the backside, taking returns from the tubing. 8. PUH to —50' above top squeeze perforation. Circulate 214bb1s hot (160F) diesel down the coil up the backside taking returns from the tubing to displace the CTBS to hot diesel prior to cementing. 9. Shut in the CTxTubing backside. Establish circulation with diesel down the CT and up the IA to tanks. Verify CTBS is shut in. Pump the following fluid schedule: Note: Do not pump any freezable fluids other than the FW spacer and cement though the retainer and into the IA as these fluids will remain in the IA after the cement job and may end up across the permafrost, freeze, and collapse the production tubing. Note: Do not take returns from the Tubing once circulating cement. a. 470 bbls of heated diesel (160F) b. 5 bbl FW spacer c. 12.5 bbls 8.6ppg Cement d. 5 bbl FW spacer e. CT volume of displacement 10. When the last bbl of cement has exited the coil, PUH pumping pipe displacement displacement down the CT with a non-freezable fluid (-32bbls). 11. At surface, SI well and finish FP CT, if necessary. 7 12. 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I =i � �.s 1111Manr- ANOSIIIIIIMISSIMIA,auraloameamalionamallim ma anew iiminimir MIN, ,,,,,. ,IM i111 RIME is; gnammin, ,,______ , ....... ,, , , . ......, .maammimminimmimostrumnrim=MMIIIIL so...i ............. , 4_ . . . , an : 9 , Milal$ 1111011.11$111110111M 111110111.$1111.41111111111111111 $11111110/11.111111111111 .1144111111•11 IMIIIMPOIMMOIMMI 111.111111111111111111101133 offizaryz 44,74., ., i12 • • loepp, Victoria T (DOA) From: Bronga,Jaime <Jaime.Bronga@bp.com> Sent Tuesday,August 09,2016 9:04 AM To: Loepp,Victoria T(DOA) Subject RE: PBU G-08A(PTD 206-183)Cement IA/Packer squeeze Hello Victoria, The TOC in the IA, 7300'MD, was selected to allow a deep GLV design to be set through station 10.This TOC enables future sidetrack options while covering potential tubing leaks through GLMs(already a known issue in this well)or wall loss and allows for 7300'MD of monitor-able inner annulus. Jaime From: Loepp, Victoria T(DOA) [mailto:victoria.loepp(aalaska.gov] Sent:Tuesday, August 09, 2016 8:35 AM To: Bronga, Jaime Subject: PBU G-08A(PTD 206-183)Cement IA/Packer squeeze Jaime, Why do you need over 3000' MD of cement for a IA cement packer squeeze? Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp aC�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeno@alaska.gov 1 • ! cn M )„ ocu cu on L' co w a) i (', • r u U > J ' ,$) e X (9 Q L J �a/ Y h 0a h NI • .. wiiw :; Y c C7 NZ -+ ' O�CO O aFL ro U OVI ; E Y o ro Q Y N •O • Q" • a a O O O 0 0 (a a < l9 e- r 10 I O CO O a) E m r F. 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DATA LOGGED PROACTIVE DIAGNOSTIC SERVICES, INC. 1,2./ I /201.5 A,, l K.BENDER To: AOGCC Makana Bender 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2— 1 900 Benson Blvd. Anchorage, AK 99508 uancpdcabp.com ) and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 10-Nov-15 G-08A BL/CD 50-029-20581-01 2) Signed : )7) ,,gttgetsick..,(/) Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BPTransmit.docx Gyrodata Incorporated • • 2'G ly 23000 Northwest Lake Dr. gyroldclta • INoust3n, Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 ECENFO ]CT 05 2015 9 DATA LOGGED tO/C./2015 M.K.BENDER SCAMS SEP 1 3 2v16 SURVEY REPORT BP Exploration G-Pad #G-08A Wellhead Prudhoe Bay, North Slope Borough, AK AK0915GCM167 1 September 2015 RIGHT PLACE FIRST TIMESO www.gyrodata.corn Gyrodata Incorporated • 23000 Northwest Lake Dr. gyro/data .Houston, Texas 77095 T: (281) 213-6300 • F: (281)213-6301 Precision Wellbore Placement October 1, 2015 State of Alaska -AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: G-Pad, Well # G-08A Prudhoe Bay, Alaska Enclosed, please find one (1) copies, and one (1) disk of the completed survey for the above referenced well. 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Q N I O O - O ,-1 ,... ,.noir O W CI CI W Ce CA OQ 0 w o I `'U � i I . •V I r w Q , 0 CA _________�_____.____._.__ -____..____ ._______.__._______. ---. _.0 7 , ' ' CTL_ �r Co — .fl co � _ .nr O I c _O . rN � -C C , i gid' t 0 .. 00O — 0 Z -. - 0 U1 O , N C .0 O -C • (0 Cl. t L. . . f•^l C 1 • 0.v O I I x _ ' I I ' I i l I ' I I i 1 I 1 I I ' 1 I I i ' l I 1 I ' i 1 I -1— W N u 1 1 1 1 1 I r-0 CCI J 0 N N 0 t!1 0 (4001/6aP) A1R19n3S 03100a • Survey QC - RGS-CT Specification Sheet ' a 8 • • SURVEY QUALITY CONTROL-SPECIFICATION DATA PRE-JOB CALIBRATION VERIFICATION CHECK(ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 64 270.79 122.74 0.00003067 1.29 63 270.79 126.34 0.00003158 0.72 62 225.45 -390.89 -0.00009775 -8.49 61 225.45 -390.05 -0.00009754 -9.54 60 45.62 -312.09 -0.00007806 -1.53 59 45.62 -305.10 -0.00007631 0.35 58 0.53 12.64 0.00000316 1.78 57 0.53 19.53 0.00000489 0.73 56 332.20 330.47 0.00008263 3.92 55 332.20 332.79 0.00008320 3.08 54 301.53 398.65 0.00009962 4.14 53 301.52 401.41 0.00010031 6.42 52 271.18 134.98 0.00003373 2.98 51 271.18 145.38 0.00003633 5.78 50 240.85 -271.51 -0.00006788 -4.01 49 240.84 -265.19 -0.00006630 -3.51 48 210.67 -365.97 -0.00009154 -10.15 47 210.67 -371.73 -0.00009298 -8.47 46 179.90 -12.85 -0.00000321 -10.22 45 179.90 -10.49 -0.00000262 -11.58 44 149.19 348.27 0.00008707 -7.94 43 149.19 354.27 0.00008857 -7.81 42 120.86 440.67 0.00011013 -4.36 41 120.86 443.75 0.00011090 -5.02 40 90.12 194.50 0.00004862 -2.24 39 90.12 198.63 0.00004965 -2.86 38 61.09 -180.70 -0.00004519 -3.45 37 61.09 -183.49 -0.00004588 -1.81 36 31.04 -287.38 -0.00007189 -1.87 35 31.04 -288.45 -0.00007216 -0.84 34 0.67 0.06 0.00000001 1.10 33 0.67 -2.43 -0.00000061 0.89 32 271.00 132.98 0.00003324 3.82 31 271.00 136.38 0.00003408 3.11 30 225.55 -421.09 -0.00010529 -4.99 29 225.55 -426.09 -0.00010654 -7.11 28 43.99 -343.96 -0.00008603 -0.99 27 43.99 -342.83 -0.00008574 -1.17 26 0.97 -29.34 -0.00000734 1.85 25 0.97 -29.65 -0.00000742 -0.10 24 332.71 286.15 0.00007154 5.88 23 332.71 284.81 0.00007120 6.41 22 301.88 389.95 0.00009745 4.72 21 301.88 392.01 0.00009796 5.61 20 271.59 151.27 0.00003781 5.00 19 271.60 155.06 0.00003875 5.81 18 240.79 -270.96 -0.00006775 1.04 17 240.79 -273.96 -0.00006849 -1.08 16 210.66 -396.87 -0.00009926 -6.60 15 210.66 -395.20 -0.00009884 -5.38 14 180.34 -79.41 -0.00001986 -9.82 13 180.35 -71.52 -0.00001789 -9.02 12 150.86 287.43 0.00007185 -6.99 11 150.87 289.54 0.00007238 -8.35 10 121.25 439.26 0.00010978 -4.80 9 121.25 438.91 0.00010969 -3.82 8 91.17 247.33 0.00006183 -5.53 7 91.17 254.96 0.00006373 -5.75 6 61.48 -157.53 -0.00003939 -1.59 5 61.48 -150.77 -0.00003770 -4.63 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 1 of 7 AK0915GCM167 • • Survey QC - RGS-CT Specification Sheet gy . ,: + - - 4 31.70 -329.63 -0.00008245 -1.54 3 31.70 -326.02 -0.00008155 -0.99 2 1.27 -89.20 -0.00002231 2.44 1 1.27 -88.13 -0.00002204 1.32 MBO= -0.33 Gravity Error= 0.48 Scale Factor Uncertainty=0.00000010 Rate Error= -1.81 POST-30B CALIBRATION VERIFICATION CHECK(ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 18731 270.78 215.20 0.00005379 -0.04 18730 270.78 227.08 0.00005676 -2.21 18729 226.99 -316.58 -0.00007918 -13.89 18728 226.99 -321.40 -0.00008038 -16.49 18727 46.15 -241.57 -0.00006043 -6.65 18726 46.15 -234.10 -0.00005856 -6.24 18725 0.75 70.70 0.00001769 0.51 18724 0.75 78.53 0.00001965 -2.31 18723 331.28 409.98 0.00010252 -0.19 18722 331.28 409.69 0.00010245 -0.66 18721 300.91 484.56 0.00012111 2.11 18720 300.91 486.32 0.00012155 0.64 18719 270.78 243.00 0.00006074 -0.26 18718 270.78 229.11 0.00005727 3.03 18717 241.55 -166.59 -0.00004166 -4.59 18716 241.55 -167.51 -0.00004189 -6.09 18715 210.99 -287.68 -0.00007197 -9.74 18714 210.98 -283.07 -0.00007081 -8.83 18713 181.13 27.17 0.00000680 -7.82 18712 181.13 31.43 0.00000786 -10.57 18711 151.45 394.22 0.00009857 -7.20 18710 151.45 400.27 0.00010009 -9.35 18709 121.36 513.50 0.00012835 -8.38 18708 121.36 515.05 0.00012874 -8.50 18707 91.05 296.54 0.00007414 -9.40 18706 91.04 305.35 0.00007634 -9.42 18705 60.45 -116.26 -0.00002908 -5.52 18704 60.45 -118.35 -0.00002960 -3.28 18703 28.89 -213.73 -0.00005347 -1.76 18702 28.89 -214.55 -0.00005368 -4.08 18701 0.95 67.98 0.00001701 -3.07 18700 0.95 70.72 0.00001769 -5.11 18699 270.87 205.89 0.00005146 11.69 18698 270.87 213.21 0.00005329 13.63 18697 226.09 -341.49 -0.00008540 -6.54 18696 226.09 -342.72 -0.00008571 -6.59 18695 46.11 -270.64 -0.00006769 -4.13 18694 46.11 -277.02 -0.00006929 -3.73 18693 0.50 26.95 0.00000674 1.94 18692 0.50 39.14 0.00000979 1.64 18691 330.83 376.55 0.00009415 8.72 18690 330.83 377.40 0.00009436 8.64 18689 300.69 473.53 0.00011835 14.86 18688 300.69 472.78 0.00011816 15.83 18687 270.69 225.11 0.00005627 12.31 18686 270.69 232.11 0.00005802 10.55 18685 239.62 -206.14 -0.00005155 1.89 18684 239.62 -200.79 -0.00005021 0.40 18683 209.24 -321.79 -0.00008049 -9.66 18682 209.24 -319.64 -0.00007996 -11.10 18681 182.57 -42.60 -0.00001066 -7.54 18680 182.57 -37.51 -0.00000938 -7.11 18679 151.87 346.65 0.00008667 1.17 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 2 of 7 AK0915GCM167 • • Survey QC - RGS-CT Specification SheetgY 0 0 18678 151.87 349.25 0.00008732 -0.01 18677 121.33 509.93 0.00012746 7.64 18676 121.33 513.07 0.00012825 7.72 18675 90.73 308.30 0.00007708 7.01 18674 90.73 322.82 0.00008071 6.99 18673 59.45 -113.96 -0.00002850 0.56 18672 59.45 -105.43 -0.00002637 0.00 18671 31.48 -272.53 -0.00006818 -7.15 18670 31.48 -269.71 -0.00006747 -4.66 18669 358.14 27.74 0.00000694 -0.31 18668 358.14 26.12 0.00000653 -0.65 MBO= -0.35 Gravity Error= 73.74 Scale Factor Uncertainty= 0.00001842 Rate Error= -1.58 INITIALISATION Gyro Compass Reading/Station Raw Inclination Raw Azimuth Abs(ERMeas-ERTheo) 125 10.25 144.40 0.0008 126 10.25 144.13 0.0204 127 10.25 144.21 0.0426 128 10.25 144.21 0.0451 129 10.25 144.39 0.0382 130 10.25 144.46 0.0148 Average 10.25 144.30 0.0270 Tolerance on Average* 0.0826 Standard Deviation '0.00 0.13 0.0178 Tolerance on St. Dev.** 0.1° 0.2° 0.0392 Advanced Initialisation Azimuth Advanced Initialisation Standard Deviation Tolerance=TBA * Tolerance on Average of earth horizontal rate difference is given by (1/Cosi)*J[(CosA*SInI*0.1)2+0.0821 °/hr ** Tolerance on Standard Deviation of earth horizontal rate difference tolerance is given by (1/Cosl)*J[(CosA*SInI*0.1)2+(0.082/(n-1))] °/hr DRIFT TUNES Drift Tune Ending Ending Ending Ending Residual Gx Bias Residual Gy Bias Number Time Depth Inclination Azimuth Start End Start End 1 575.92 3599.97 25.56 148.49 -0.001 -0.001 0.002 -0.000 2 569.34 4150.00 40.25 151.86 -0.001 0.000 0.001 -0.000 3 656.19 5100.04 55.82 153.48 0.002 -0.003 -0.000 0.002 4 1404.83 7300.05 53.99 159.04 0.002 -0.004 0.003 -0.000 5 1428.08 9250.06 51.24 165.20 0.001 -0.002 0.005 -0.002 6 1261.70 10700.33 47.70 166.94 0.001 -0.002 0.003 -0.001 7 1527.64 11550.17 44.82 168.17 0.000 0.000 0.001 -0.002 8 573.75 11759.97 26.75 147.84 -0.001 0.001 0.000 -0.000 9 398.07 11860.02 9.40 114.54 0.001 -0.000 0.001 -0.000 10 460.45 11999.94 32.81 59.24 -0.001 0.001 0.001 -0.001 11 544.61 12201.37 76.85 34.44 -0.004 0.004 0.001 -0.001 12 539.26 11999.97 34.41 57.06 0.003 -0.003 -0.002 0.002 13 470.34 11859.94 9.68 105.04 0.000 0.000 -0.000 0.000 14 427.35 11760.01 25.24 146.41 -0.003 0.003 0.001 -0.001 SURV-Q167(OPS SUR-MA-003) 19'"Nov 03/Rev 15 Page 3 of 7 AK0915GCM167 • 0 Survey QC - RGS-CT Specification Sheet gyro/data 15 544.99 11550.03 44.70 168.07 -0.001 0.001 -0.001 0.001 16 1499.39 10699.95 47.68 166.65 0.001 -0.003 -0.005 0.004 17 1404.34 9249.92 51.34 165.07 -0.001 0.000 -0.002 0.003 18 1813.11 7299.99 53.87 158.78 -0.003 0.002 -0.001 0.004 19 1443.53 5900.02 56.90 155.31 -0.003 0.003 0.001 0.002 20 916.32 5100.07 55.88 153.22 0.001 -0.001 -0.001 0.003 21 1009.79 4149.96 40.58 151.60 -0.003 0.003 0.003 -0.000 22 674.46 3599.98 26.00 148.10 -0.001 0.001 0.001 0.001 23 459.42 3343.32 18.40 139.22 -0.002 0.004 0.003 -0.003 24 1473.67 3110.02 11.73 132.92 -0.002 -0.001 0.000 0.001 Average -0.001 0.000 0.001 0.000 Standard Deviation 0.002 0.002 0.002 0.002 Tolerance for both the Average and the Standard Deviation 0.033°/hr 0.0330/hr 0.033°/hr 0.033°/hr INCLINATION AND AZIMUTH INRUN AND OUTRUN COMPARISON DepthCorrected Inclination Corrected Azimuth I Inrun* I Outrun* I Difference ( Inrun * I Outrun* I Difference 100.00 0.42 0.38 0.04 213.00 214.85 -1.84 200.00 0.36 0.42 -0.06 191.93 192.62 -0.69 300.00 0.40 0.40 0.00 189.23 197.10 -7.86 400.00 0.51 0.49 0.02 193.31 188.79 4.52 500.00 0.65 0.66 -0.01 178.36 183.95 -5.59 600.00 0.66 0.61 0.05 186.88 186.14 0.74 700.00 0.41 0.40 0.01 175.96 180.61 -4.65 800.00 0.35 0.40 -0.05 177.79 185.02 -7.23 900.00 0.24 0.23 0.01 217.42 217.43 -0.02 1000.00 0.15 0.20 -0.04 190.51 197.19 -6.67 1100.00 0.12 0.15 -0.02 205.04 181.50 23.54 1200.00 0.17 0.14 0.03 172.80 182.15 -9.34 1300.00 0.05 0.09 -0.04 54.18 147.90 -93.72 1400.00 0.13 0.15 -0.02 112.18 141.01 -28.82 1500.00 0.54 0.37 0.17 116.11 131.75 -15.64 1600.00 0.52 0.46 0.06 129.47 123.93 5.55 1700.00 0.61 0.54 0.07 110.11 110.45 -0.34 1800.00 0.64 0.61 0.03 92.92 98.24 -5.31 1900.00 0.64 0.63 0.01 105.46 102.14 3.32 2000.00 0.61 0.69 -0.08 100.36 108.88 -8.52 2100.00 0.55 0.68 -0.13 109.51 112.35 -2.84 2200.00 0.57 0.71 -0.14 128.43 132.84 -4.41 2300.00 0.58 0.67 -0.09 151.97 159.18 -7.21 2400.00 0.65 0.61 0.04 168.92 156.86 12.06 2500.00 0.43 0.37 0.05 167.61 168.39 -0.78 2600.00 0.27 0.29 -0.02 130.22 158.19 -27.97 2700.00 0.32 0.35 -0.02 87.00 106.24 -19.24 2800.00 1.01 1.53 -0.52 112.41 113.16 -0.75 2900.00 4.81 4.65 0.16 138.94 138.91 0.03 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 4 of 7 AK0915GCM167 • 110 • Survey QC - RGS-CT Specification Sheet girMidata 3000.00 7.42 7.42 -0.00 156.76 152.50 4.26 3100.00 12.28 12.20 0.09 135.98 135.25 0.73 3200.00 14.66 14.59 0.06 128.56 129.78 -1.22 3300.00 17.10 17.30 -0.20 135.51 135.32 0.19 3400.00 19.46 19.51 -0.05 140.85 140.22 0.63 3500.00 21.57 21.69 -0.12 145.05 144.55 0.50 3600.00 25.56 25.68 -0.12 150.31 148.14 2.18 3700.00 28.78 28.86 -0.08 149.68 149.35 0.33 3800.00 31.86 31.95 -0.09 149.84 149.53 0.31 3900.00 34.25 34.33 -0.08 150.02 149.73 0.29 4000.00 35.99 36.08 -0.09 150.77 150.50 0.28 4100.00 38.34 38.47 -0.12 151.71 151.45 0.26 4200.00 41.27 41.34 -0.07 151.86 151.59 0.27 4300.00 43.38 43.46 -0.08 151.68 151.40 0.28 4400.00 46.95 47.05 -0.10 151.43 151.15 0.28 4500.00 51.15 51.27 -0.13 151.18 150.90 0.28 4600.00 53.61 53.71 -0.11 151.84 151.58 0.26 4700.00 55.36 55.45 -0.09 152.24 151.98 0.26 4800.00 55.28 55.35 -0.07 152.26 151.99 0.27 4900.00 55.41 55.49 -0.08 152.40 152.13 0.27 5000.00 55.15 55.23 -0.07 152.96 152.71 0.25 5100.00 55.83 55.91 -0.08 153.55 153.22 0.33 5200.00 56.09 56.15 -0.06 153.96 153.70 0.26 5300.00 55.36 55.41 -0.05 154.15 153.88 0.26 5400.00 55.65 55.71 -0.06 154.22 153.96 0.26 5500.00 55.94 56.01 -0.07 154.76 154.51 0.24 5600.00 56.55 56.61 -0.06 154.95 154.70 0.25 5700.00 56.33 56.37 -0.04 155.06 154.82 0.24 5800.00 56.16 56.21 -0.05 155.24 154.99 0.24 5900.00 56.68 56.73 -0.04 155.50 155.27 0.23 6000.00 57.90 57.95 -0.05 155.84 155.61 0.23 6100.00 57.30 57.34 -0.04 156.31 156.07 0.23 6200.00 56.70 56.71 -0.02 156.15 155.89 0.25 6300.00 55.44 55.49 -0.05 155.64 155.40 0.25 6400.00 55.40 55.45 -0.05 156.26 156.02 0.24 6500.00 55.08 55.12 -0.05 156.76 156.53 0.23 6600.00 54.72 54.78 -0.05 157.32 157.08 0.24 6700.00 55.21 55.26 -0.05 157.97 157.74 0.23 6800.00 54.80 54.86 -0.06 158.39 158.14 0.25 6900.00 54.78 54.82 -0.04 158.39 158.14 0.25 7000.00 54.70 54.75 -0.06 158.46 158.21 0.25 7100.00 54.43 54.49 -0.06 158.67 158.42 0.24 7200.00 54.77 54.84 -0.06 158.98 158.73 0.25 7300.00 54.02 54.09 -0.07 159.04 158.80 0.24 SURV-Q167(OPS SUR-MA-003) 190 Nov 03/Rev 15 Page 5 of 7 AK0915GCM167 • • Survey QC - RGS-CT Specification Sheet WM 7400.00 53.66 53.71 -0.05 158.93 158.69 0.24 7500.00 53.47 53.53 -0.06 158.66 158.40 0.26 7600.00 53.40 53.46 -0.06 158.60 158.34 0.26 7700.00 53.40 53.45 -0.06 158.62 158.36 0.26 7800.00 53.42 53.47 -0.05 158.74 158.48 0.26 7900.00 53.68 53.72 -0.04 158.76 158.49 0.26 8000.00 53.22 53.27 -0.04 158.72 158.46 0.26 8100.00 52.91 52.94 -0.03 158.73 158.47 0.26 8200.00 52.57 52.61 -0.03 158.47 158.22 0.25 8300.00 53.37 53.41 -0.04 158.20 157.96 0.24 8400.00 54.60 54.63 -0.04 157.72 157.48 0.24 8500.00 55.06 55.10 -0.05 157.51 157.30 0.21 8600.00 55.94 55.99 -0.05 157.27 157.06 0.21 8700.00 57.33 57.38 -0.05 156.96 156.75 0.21 8800.00 57.71 57.75 -0.04 157.64 157.44 0.20 8900.00 51.58 51.62 -0.04 163.31 163.10 0.20 9000.00 49.97 50.02 -0.04 165.59 165.40 0.20 9100.00 50.31 50.35 -0.04 165.55 165.36 0.19 9200.00 50.87 50.92 -0.05 165.36 165.18 0.17 9300.00 50.84 50.90 -0.05 165.54 165.36 0.18 9400.00 51.12 51.17 -0.05 165.87 165.68 0.19 9500.00 52.04 52.09 -0.05 165.88 165.68 0.20 9600.00 52.82 52.86 -0.05 166.01 165.81 0.19 9700.00 52.53 52.57 -0.05 166.01 165.81 0.21 9800.00 52.23 52.30 -0.06 165.87 165.68 0.19 9900.00 52.44 52.49 -0.04 165.48 165.28 0.20 10000.00 51.62 51.65 -0.03 164.95 164.74 0.20 10100.00 51.52 51.54 -0.03 165.64 165.44 0.20 10200.00 50.74 50.76 -0.02 165.67 165.46 0.20 10300.00 49.56 49.58 -0.02 165.53 165.33 0.20 10400.00 48.70 48.73 -0.03 165.67 165.47 0.20 10500.00 48.45 48.49 -0.04 166.09 165.88 0.20 10600.00 48.25 48.27 -0.03 166.43 166.24 0.19 10700.00 47.72 47.73 -0.01 166.22 166.76 -0.54 10800.00 48.04 48.05 -0.01 167.01 166.77 0.24 10900.00 47.62 47.57 0.05 167.37 167.17 0.19 11000.00 46.74 46.73 0.01 167.21 167.05 0.16 11100.00 46.27 46.18 0.09 167.80 167.65 0.15 11200.00 45.75 45.76 -0.01 168.25 168.15 0.10 11300.00 43.86 43.93 -0.06 168.19 168.06 0.12 11400.00 43.73 43.67 0.06 168.44 168.48 -0.04 11500.00 44.80 44.82 -0.02 168.24 168.10 0.14 11600.00 45.16 45.13 0.02 168.33 168.27 0.06 11700.00 37.08 37.19 -0.12 156.61 156.61 0.00 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 6 of 7 AK0915GCM167 O • . Survey QC - RGS-CT Specification Sheet WU/data 11800.00 19.34 19.40 -0.06 143.20 142.96 0.24 11900.00 13.62 13.63 -0.01 78.80 77.75 1.05 12000.00 32.73 32.83 -0.10 59.25 57.91 1.33 12100.00 55.88 56.05 -0.17 49.38 48.23 1.15 12200.00 77.07 77.07 0.00 34.45 33.45 1.00 Average -0.0415 0.2760 Standard Deviation 0.0704 0.2894 Tolerance for both the Average and the Standard Casing 0.30 Casing 0.50 Deviation Dril!pipe 0.3° Drillpipe 0.75° * Inclination and Azimuth interpolated to same depths as shown. SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 7 of 7 AK0915GCM167 s 0 0 Survey QC - RGS-CT Analysis Sheet gNr `• ' a , SURVEY QUALITY CONTROL-DATA ANALYSIS REFERENCE SYSTEMS Grid System I I Grid Correction 10.00 Azimuth reference: Grid/True North TRUE NORTH Vertical reference: RKB/MSL/Other RKB I If other give details I TIE ON DATA Depth 0.00 Inclination 0.00 Azimuth 0.00 I TVD 10.00 Northings 0.00 Eastings 0.00 Latitude 70.3216 Az. Ref:Grid/True True Grid Corrected Y/N? N Description I CALIBRATION Tool Number I F0007 I Calibration Date 122 Apr 2013 OPERATING TEMPERATURE Calibration range From 49.49 To 119.45 Gyro operating range From 67.52 To 96.34 I Spec'-Within calibration range FIELD ROLL TEST Only valid on fixed structures. When not ossible input roll test data performed after return to base) Cal value Pre job offset Post job Abs dif.cal.post Abs dif.pre.post Spec' offset Accel Scale 0.000055 0.000000 0.000018 0.000018 0.000018 Cal/Post-0.00015 Mass Unbalance 0.90 -0.33 -0.35 0.35 0.02 Pre/Post-0.4°/hr INITIALISATION Depth(Approx) 3040.08 No of stns 6 Spec'-Min No. -6 Azimuth Mean 144.30 Std deviation 0.13 Spec'-Azi SD 0.2° Inclination Mean 10.25 Std deviation 0.00 Spec'-Inc SD 0.1° Earth Horizontal Rate Mean(Abs(meas-theor)) 10.03 Std deviation 0.02 Spec'-See Q167 DRIFT TUNE Residual x gyro bias Mean 0.000 Std dev' 0.002 Spec's-Mean and SD-0.333°/hr Residual y gyro bias Mean 0.000 Std dev' 0.002 Spec's-Mean and SD-0.333°/hr TOOLFACE RATE Maximum toolface rate 1213.37 I Spec'-400°/sec IN/OUT COMPARISON(AZI'N/A IF INC'<15°) Inclination Difference Mean -0.04 Std dev' 0.07 Spec's-Casing 0.3°/Drill pipe 0.3° Azimuth Difference Mean 0.28 Std dev' 0.29 Spec's-Casing 0.5°/Drill pipe 0.75° Lateral Divergence/1000 2.11 Spec-5.0/1000 Vertical Divergence/1000 0.48 Spec'-2.0/1000 DEPTH CONTROL Wireline Company Schlumberger I Line type 7/32" Encoder SF I Schlumberger Max Depth (TD) 12200 CCL Corrected NO Zero Depth(Rig up) RKB @ 65.6 ft AMSL Rezero Depth -12ft Given pup joint depth NA Measured P3 NA Strech cor.At TD divided by TD/1000 .6393 Spec'- 1.5/1000 Dif. Between rigup and rezero depths divided by TD/1000 .9836 Spec'- 2.0/1000 Dif. Between given and meas depth divided by meas/1000 NA Spec'-2.0/1000 SURV-Q165(OPS SUR-MA-010)22nd Jan 2004/Revision 20 Page 1 of 1 AK0915GCM167 41) 0 is • gyro 1 all 10; Survey QC - RGS-CT Acceptance Sheet FIELD AND SURVEY INFORMATION Operator BPXA Field/ Platform Wellhead Well Number Prudhoe Bay Drillsite:G Well:G-08A Survey section From 00.00 ft. to 12200.00 ft. Date 01 Sep 2015 Gyrodata Job No AK09156CM167 Gyrodata Surveyors Job Objective High Accuracy Gyro Survey SURVEY PERFORMANCE In Spec' QC Parameter Yes/No/NA Possible Actions Contact Duty Engineer to discuss options: Operational temperature within Yes 1. Recalibrate tool to higher temperature specification 2. Resurvey with backup tool 3. Resurvey'Hot'section at higher speed Roll test data within specification Contact Duty Engineer to discuss options: Only valid on land/fixed installations Yes 1. Recalibrate tool and reprocess survey 2. Resurvey with backup tool Continuous initialisation within Take new initialisation,after three failures: specification Yes 1. Contact Duty Engineer or, 2. Resurvey with back up tool. Contact Duty Engineer to discuss options: Toolface rate within specification Yes Resurvey section from previous bias check Investigate and comment if effects are negligible Contact Duty Engineer to discuss options: Drift tunes within specification Yes 1. Reprocess with different software settings 2. Resurvey with backup tool Inrun/Outrun comparison within Contact Duty Engineer to discuss options. specification Yes Resurvey is usually not required if either inrun or outrun meet all other QC parameters Depth control within specification Yes Contact Duty Engineer to discuss options. Action taken: Note: Provided satisfactory action has been taken,parameters out with specification will not necessarily fail a survey. SURVEY ACCEPTED Gyrodata Representative Client's Representative SURV-Q166(OPS SUR-MA-003)13th Nov 03/Revision 12 Page 1 of 1 AK0915GCM167 • M o0 cu m a, CO w7 u > ,d, co w v .,... O r r r r r r r r Y U >ro �L� �� a Z > X c0 a .G V7 la (SIN Z .__ N N t) ell l N a) L S C a hQ ? N @ p -Y N E O 0 t- r9 a c O L.p 5 -o c Q 0 ¢ O ci r r r r 0, r r r r ._, n3 ? a Q, 0 j, W f W b m o v •� m J _„,--1 Cir 0 4 t U y,,, L J q r 8eZ + cJ p , v) fy O W _C C C al VI Q "' vet a v a v v o a v F�X (7 r r r r r C c a, N Z a o '•.s 0 0 '0 0 0 0 0 u 8 O -o E o CC F WZZZZZZZ ZOZ > v D H i_ M M o0 r r !O c. 6 L (0 ,.:.a r r r , r r 7 N (3 O CO CU L y to O RI O kv E -O N c Y N O Cocs Q1 O C 0 0 0 0 0 0 0 0 aL u' -O `n t • C. .„ J J J J J J J J v _c 40-. u o Er) }} W W W W W W W W C "1- Jr LL IT. LL LL LL LL LL u L O �` Q J J J J J J J J p(73 �j > . U (` •Q Z Z Z Z Z Z Z Z •E N N O _ • r, LL LL LL LL LL LL LL LL c p C N U �� m N a) Z ca I i IL-< v _c u > cO• L G E-= 0 4 CD d_ U. W a LL U. al 0 (i; O CL J J O J O N L7 r moo -i ° asa rw ItQ z x CI — "rip � • OOOOnJOOJ E D W W W W W W7 7 D it u a 5 4 v u N CC J-, % o N a c2 0 u (ems r g m m m m m m m m ( m IL LU LU LLJ al li.1 LU W i co z0000 . 0000 E CD � DCCC 0000 -ts `^ • aaaa ;• a aaa ca, u I0 in to ct, to v CU Csi In W Yi r - ' 0 r O C 0 0 W O O O O O p 0 0 on L ce 0 G a o coN oL p 0 g� ... u H 0 (q e- to } CO CO>• N `'``' o (j () (.) 0 . (..) 00U L Y pi 7v Qam .� C '} O. u C 01 W ,O t0 u •5 y am cu Q a m LY c c Co.CM ql u .. X8 ammm r (O " 6`1 aJ• '^-1 z O O O co p - e~- - N fV (0 c N 3 d yL (^� O O r (0 `, mom C aQ — E ' . Z G1 co OCA ��nrL L uC C (I Yn CM �iL� d � 1! a= a` a C Image Pject ell Hist®ry File O~r 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. - 1 ~ ~ Well History File Identifier Organizing (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Project Proofing BY: Maria Scanning Preparation BY: Maria , o..s,a~ iiidumuiuim DIGITAL DATA iskettes, No. I ^ Other, No/Type: Date: Date: Production Scanning / ~ ~ x 30 = ~~ + ~ =TOTAL PAGES~~ (Count does not include cover sheet) Date: ~;~ !s! IIIIIIIIIIIIII IIIII Stage 1 Page Count from Scanned File: / `~t' (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: (~ !s/ `9 W t / ~`~~~~ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: Scanning is complete at this point unless rescanning is required. °fiiimumAUiii vn P rtiiiimmiiiiuii ~P ReScanned III IIIllllllll II III BY: Maria Date: ~s! • •I Quality Checked II I II'II) III II'I III Comments about this fi e R~~a~~ee,~ iuumuiuuiu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: 10!6!2005 Well History File Cover Page.doc . 4 4, Its `- -,r. �,! ^ . " STATE OF ALASKA AKA OIL AND GAS CONSERVATION COW ON . REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations Li Perforate L1 Other i-vb_yk , Fate h Performed: Alter Casing ❑ Pull Tubing] Stimulate - Frac ❑ Waiver ❑ Time Extension❑ J r L VF Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 4-411 13 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: BP Exploration Alaska Inc Name: Developmental Exploratory ❑ ° 206 -183 -0 3. Address: P.O. Box 196612 StratigraphiC Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20581 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: . ADL0028285 - PBU G -08A 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 14004 feet Plugs measured 12950, 13190 feet true vertical 9026 feet Junk measured None feet Effective Depth measured 12950 feet Packer measured See Attachment feet true vertical 9010.89 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 78 20" Conductor 32 - 110 32 - 110 0 0 Surface 2669 13 -3/8" 72# L -80 31 - 2700 31 - 2699.94 4930 2670 Intermediate None None None None None None Production 11270 9 -5/8" 47# L -80 30 - 11300 30 - 8371.94 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12103 - 12108 feet 12245 - 12295 feet 12350 - 12405 feet 12440 - 12475 feet 12520 - 12550 feet 12640 - 12690 feet 13056 - 13070 feet 13100 - 13130 feet 13660 - 13830 feet True Vertical depth 9006.87 - 9009.11 feet 9041.17 - 9045.51 feet 9043.81 - 9039.68 feet 9037.8 - 9037.03 feet 9037.63 - 9037.27 feet 9033.09 - 9028.65 feet 9006.27 - 9005.19 feet 9003.38 - 9002.58 feet 9016.48 - 9027.11 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: SCAHHE® APR 16 2013 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 817 8864 24 0 167 Subsequent to operation: 1255 8483 29 0 193 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El ` Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil r 0 Gas ❑ WDSPL[J GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG0 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.SummerhaVS(,BP.com Printed Name Nita Summerhays Title Petrotchnical Data Technician i r Signatur- �� .., Phone 564 -4035 Date 4/10/2013 J. ItBDMS APR 10 2013 kib \'I1 ' � 3 Form 10 -404 Revised 10/2012 / /* Submit Original Only • • Daily Report of Well Operations ADL0028285 • = .11 .IS I. ' emp = . : • s 're - ine . • . in.e. @ casing valve. TBG & IA FLs © surface. 3/12/2013 SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 22:00 hrs. ***WELL S/I ON ARRIVAL***(post tree c /o) DRIFT W/ 4.55" CENT S/D IN SSSVN @ 2114' SLM DRIFT W/ 27' 7" DUMMY PATCH(4.54" MAX OD) TO SLIDING SLEEVE AT 10,645' SLM/ 10,657' MD 3/16/2013 * ** CONT WSR ON 3/17/13 * "* * ** CONT WSR FROM 3/16/13 * ** DRIFT TBG TO SLD SLV W/ 4.55" CENT, 4.52" CENT AT 10640' SLM/10657' MD RIG SWCP 4517 DOWN 3/17/2013 * ** WELL LEFT SHUT IN ON DEPARTURE, PAD OP NOTIFIED " ** ** *WELL SHUT IN ON ARRIVAL * ** ( ELINE - SET PATCH) INITIAL T /I /O = 300/250/0 PSI ARRIVE ON LOCATION. STAND BY FOR STATE TESTING TO COMPLETE OPERATIONS ON G -27. MOVE IN. SPOT LOGGER AND 3RD PARTY CRANE. MAKE UP TOOLS. RIG UP AND PRESSURE TEST. RIH WITH HES 20FT 5.5" DWP PATCH. ** *JOB CONTINUED ON 03 -19- 2013 * ** 3/18/2013 ** *JOB CONTINUED FROM 03[1812013 * ** (ELINE - SET PATCH) SET 5.5" HES DWP PATCH. TOP ME SET AT 10594', BOTTOM ME SET AT 10614.5', TOP OF PATCH = 10590', OAL =24.8' MIN ID= 2.987 ". POOH. RDMO. FINAL T /I /O = 0/380/0 PSI 3/19/2013 ** *JOB COMPLETE. WELL SI UPON DEPARTURE * ** FLUIDS PUMPED BBLS 4 DIESEL 4 TOTAL Casing / Tubing Attachment 1 ADL0028285 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20" Conductor 32 - 110 32 - 110 LINER 51 3 -1/2" 9.3# L -80 10786 - 10837 8015.98 - 8050.4 10160 10530 LINER 839 7" 29# L -80 10790 - 11629 8018.68 - 8606.7 8160 7020 LINER 1365 3- 3/16" 6.2# L -80 10837 - 12202 8050.4 - 9035.76 LINER 1802 2 -7/8" 6.4# L -80 12202 - 14004 9035.76 - 9026.77 10566 11165 PRODUCTION 11270 9 -5/8" 47# L -80 30 - 11300 30 - 8371.94 6870 4760 SURFACE 2669 13 -3/8" 72# L -80 31 - 2700 31 - 2699.94 4930 2670 • TUBING 10715 5 -1/2" 17# L -80 29 - 10744 29 - 7987.66 7740 6280 TUBING 110 4 -1/2" 12.6# L -80 10744 - 10854 7987.66 - 8061.88 8430 7500 • • • Packers and SSV's Attachment ADL0028285 SW Name Type MD TVD Depscription G -08A PACKER 2608 2542.34 9 -5/8" DV Packer G -08A PACKER 10743 7921.38 5 -1/2" Baker Pkr TREE= C3W ' WB-LHEAD= McEVOY • C' -08A PLASTIC N CO TBG " >70° @12141' "' ACTUATOR = BAKER C N iIAL KB. B.EV = 65.6' I 1 BE EV = 36.8' I g_ 2117' (- {5 -1/2" CA -BAL -O SSSV NtFP, D= 4.562" KOP= 3050 � - 2608' H9-5/8" DV PKR . , Max Angle = 96° G. 12873' DatumMD= 11915' ST MD TVD DEV TYPE VLV LATCH FORT DATE Datum TVD = 8800' SS ' 12 3012 3011 8 CA DOME RK 16 03/24/13 11 5463 4832 56 CA DMY FE 0 01/22/04 10 7207 5822 54 CA SO RK 20 03/24/13 113 -3/8" CSG, 72#, L -80, D = 12.347" H 2700' 9 7347 5904 54 CA DMY RK 0 05/14/81 8 8259 6451 53 CA DMY RK 0 05/14/81 Minimum ID = 2377" @ 12202' 7 8404 6537 54 CA DMY RK 0 05/14/81 3- 3/16" X 2 -7 /8" XO LNR PIN ID 6 9051 6914 50 CA OMY RK 0 01/22/04 5 9197 7007 51 CA OMY RK 0 05/14/81 - - 4 9772 7362 52 CA DMY RK 0 05/14/81 3 9914 7448 52 CA DMY RK 0 05/14/81 5 87' OWP PATCH -1 10590' - 10615' I ' II I 2 10448 7789 48 CA DMY RK 0 09/11/12 .= 2.987" (03/19/13) ►_� 1 10590 7884 48 CA 'OMY RK 0 02/28/13 i 'STATION #1 = DMY HAS BCTENDED PACKING IG & IS BEFI D D IAP ,7\_ 11 11 PATCH 10657' 1- 15-1/2" CAMDO SLD SLV, ID = 4.500" I 10723' --j BKR PBR SEAL ASSY M ∎ 1- 10743' -19-5/8" X 5- 112" BKR PKR, D = 4.0" I 5 TBG 17#, L IJ4S, H 10744' 1 I 10744' j-15- 1/2"X4- 1 /2"XO,ID= 3.958" 0232 bpf, ID = 4.892" 1 10773 ELM H4 -1/2" OTIS X NP, D = 3.813" ITOP OF 7" LNR H 10790' ( L 10786' I- 13.70" BOT DEPLOY SLV, D = 3.00" 13 -1/2" LNR, 9,3#, L -80 STL, ,0087 bpf, D = 2.992' H 10837' � I 10805 ELM —4-1/T OTIS XN NIP, MILLED TO 3.80" BEHIND CT LNR 4 12.6#, L -80 CSH, --I 10854' I 10805' H3-1/2" HES X NP, D = 2,813" I .0152 bpf, D = 3.958' 19 - 5/8" CSG, 47 #, L -80, ID = 8.681" -1 11289' I 10837' H3-1/2" X 3-3116" XO, D = 2.786" TOO -{ - 11415' � 90854' 1- 14_1/2" WLiC, D= 3.958" I BEHIND NR WFi'STCX3C H 11615' I 10837' H ELMD TT LOGGED 06/12/82 I 7" LNR 29#, L - 80 BTC, .0371 bpf, 13= 6.184" — 11619 7��/ r•�V X11 ►•• IRA PP TAG 11625' � / •• / * / 4* MLLOUT WINDOW (G -08A) 11619' - 11629' PERFORATION SUMMARY ' • � • 1 1 • • • REF LOG: IVIC .- GR-OCL 03/12/07 ,,�,a' , • ANGLE AT TOP PBiF: 63" @ 12103 `*I Nate: Refer to Production DB for historical pert data f c •.�.•.�.•.� • • 12202' -13-3/16" X 2 - 7/8° XO, D = 2.377" SIZE SPF INTERVAL OPNISOZ SHOT SQ.Z , •••••• 2" 6 12103 -12108 0 01/19/12 •........A.A♦ 2" 6 12245 - 12295 0 03/14/07 2" 6 12350 - 12405 0 03/14/07 % 12950' -- 12 - 7/8" (ABP (05/30/10) 2" 6 12440 - 12475 0 03/14/07 l" 13190' H 2 -7/8" C BP 2" 6 12520 12550 0 03114!07 3 -3/16" LNR, 6.2#, L -80 TO, -I 12202' 4" (04/23/09) 2" 6 12640 - 12690 O 03/14/07 2" 6 13056 - 13070 C 04/23/09 .0076 bpf, D = 2.80' I 1 t• it 2" 6 13100 - 13130 C 04/23/09 (FBTD H 13969' I A ' Vj` 2" 6 13660 - 13830 C 03/13/07 I2 - 7/8" LNR 6.4#, L - 80 STL, .0058 bpf, ID= 2,441" H 14004' DATE REV BY C OWENTS DATE REV BY COMMENT'S PRUDHOE BAY UNIT 05/14/81 ORIGINAL COMPLETION 03/18/13 CJWJM) GLV CIO (02/28/13) WELL: G-08A 03/15/07 NORDIC 1 CTD SIDETRACK (G• -08A) 03/22/13 RWNYJMD SET DWP PATCH (03/19/13) PERMIT Na: 2061830 01/23/12 RWMJMJ ADPERF (01 /19/11) 04/05/13 TBI YJMD GLV CIO (03/24/13) AR Na: 50- 029 - 20581 -01 06/17/12 PJC LNR CORRECTIONS 04 /05/13 SWC/JMD PULLED PX PLUG (03/28/13) SEC 12, T11 N, R13E, 2506' FSL & 2367' Fla 09/07/12 CDJ/ PJC SET PX & GLV CIO (09/6 - 07/12) 01/16/13 CDJ/PJC GLV CIO (02/03/13) 11 81' Exploration (Alaska) Vi ti LJ STATE OF ALASKA MAP. 1 ,'2 2013 t AKA OIL AND GAS CONSERVATION COMMI SION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate [J Other LI Weld Wellhead Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development ID Exploratory El - 206 -183 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 20581 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028285 - PBU G -08A 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 14004 feet Plugs measured 10805, 12950, 13190 feet true vertical 9026 feet Junk measured None feet Effective Depth measured 2107 feet Packer measured See Attachment feet true vertical 2106.95 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 78 20" Conductor 32 - 110 32 - 110 0 0 Surface 2669 13 -3/8" 72# L -80 31 - 2700 31 - 2699.94 4930 2670 Intermediate None None None None None None Production 11270 9 -5/8" 47# L -80 30 - 11300 30 - 8371.94 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12103 - 12108 feet 12245 - 12295 feet 12350 - 12405 feet 12440 - 12475 feet 12520 - 12550 feet 12640 - 12690 feet 13056 - 13070 feet 13100 - 13130 feet 13660 - 13830 feet True Vertical depth 9006.87 - 9009.11 feet 9041.17 - 9045.51 feet 9043.81 - 9039.68 feet 9037.8 - 9037.03 feet 9037.63 - 9037.27 feet 9033.09 - 9028.65 feet 9006.27 - 9005.19 feet 9003.38 - 9002.58 feet 9016.48 - 9027.11 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 APR 1 2.013 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 817 8864 24 0 167 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Ell ) Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: o Oil el Gas U 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.Summ erhays(C7BP.com Printed Name Nita Summerhay / Title Petrotechnical Data Technician _, dromoysor Si nat Phone 564 -4035 Date 3/12/2013 B S MAR 14 2013 ,2 \ V i 4// / Form 10 -404 Revised 10/2012 `-- Submit Original Only • • Daily Report of Well Operations ADL0028285 - ; 1 SUMMARY ._..,.: 11 I. emp= . ►Y • •s va ce ar prep or e ar prep or • we • . is connected, SI @ casing valve. ALP =300 psi. Cellar is — 36" deep at containment in cellar, sloping up to 20" at edges. SV,WV,SSV= Closed. MV =Open. IA,OA =OTG. NOVP. (1500 1/5/2013 hrs) T /I /0 = SSV /300/20. Temp =Sl. WHPs, check on heater thawing cellar (Cellar prep SH). AL is connected, SI @ casing valve. ALP =300 psi. No heater in well house. Cellar is — 36" deep at containment in cellar, sloping up to 20" at edges. 1/10/2013 SV,WV,SSV= Closed. MV =Open. IA,OA =OTG. 11:50 T /1 /0= SSV /300/0 +, Temp =ST. PPPOT -IC (I -AIL), pre WH repair.PPPO1 -IC: Sting into test port (0+ psi), bled to 0 psi. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 400 psi in 15 min. Torqued LDS to 600 lb /ft. Re- pressured void to 3500 psi, lost 500 psi in 15 min (FAIL). Bled void to 0 psi. Suspect secondary seal needs to be re- 1/29/2013 energized. T /1 /0 = SSV /240/0 +. Temp = Si. Bleed IA & OAP to 0 psi (pre startinghead weld). ALP = 200 psi. IA FL @ surface. OA FL @ near surface. Cellar is 36" at containment. Bled IAP to 0 psi in 15 minutes (all fluid, 1 bbl). Removed grating for cellar access. Grease crew opened SSV. Bled OAP from 0+ to 0 psi in 5 minutes (all gas). Monitored WHPs for 30 minutes during RD, IAP increased 10 psi. Installed heater in cellar covered in visqueen. FWP's = 10/10/0. 2/7/2013 SV, WV = SI. SSV, MV = 0. IA, OA = OTG. 1615 hrs. T /I /0 = 10/10/0. Temp = SI. Celler Prep (Pre startinghead weld). ALP = 220 psi. Bled TBG to 0 psi in 5 minutes (3 -5 gallons fluid). Bled IAP to 0 psi in 10 minutes (10 gallons fluid). Used 1 & 1/2 bottles N2 to purge fluid from the TBG taking returns from the IA to the bleed tank (3 bbls). U -tubed N2 into the IA. Post U -tube T FL = 42', IA FL = 54'. Left 83 psi of N2 on TBG and IA. Attempted to purge methanol from the A/L line w/ N2 down the poor boy line, to well #27 s- riser, into a slop tank (all gas returns). Removed containment from around conductor pipe. OA FL = 12'. Job Incomplete. FWP's = 83/83/0.SV, WV = SI. SSV, MV = 2/8/2013 0. IA, OA = OTG. 1600 hrs. T /I /0= Vac /0/0 Temp= SI Energize secondary seal PPPOT -IC (PASS) Pre SH WeIdPPPOT- IC: DHD held open bleeds on IA and OA. Stung into test void (0+ psi.). Bled void to 0 psi. Verified 0 psi. in packing port with SBS. RU elephant gun to Packing port. Energized secondary seal. Pumped through test void, good returns. Pressured test void to 3500 psi. for 2/8/2013 30 min. Lost 0 psi. in 30 min. (PASS). Bled void to 0 psi. T /1 /0 = 85/85/1. Temp = SI. Assist SP w /Startinghead weld. Removed —1 yard of gravel from cellar. Bled OAP to 0 psi in 10 seconds. Held open bleed for 1 hr. SI, monitored for 1 hr, checking pressure every 10 min. No increase in OAP. Job incomplete. Final WHPs = 85/85/0. SV, WV =C. SSV, MV =0. IA, OA =OTG. NOVP. 16:00 **Note: Poor boy gas lift jumper was 2/9/2013 blinded at IA gate valve and line was purged with N2 by the night PO. ** 171/0 = 79/79/0 +. Temp = SI. Prep for welding (SH weld). Purged OA w/ N2 while electricians and welders installed thermocouples & blankets. See log for details. 2/15/2013 SV, WV = G. SSV, MV = 0. IA, OA = OTG. 1630 hrs. Pre -job safety mtg, open permits, T/170 = 80/87/0 barriers = TP plug, 9.8ppg brine (sott barrier), MV, SSV. SV, packer for IA, IA and OA valves; heat wellhead from 0620 to 1100hrs, commence 4 hr pre -heat; weld thread leak from 1500 hrs to 1644hrs, post weld heat 2/16/2013 treatment 1700 to 1900 hrs, SD heat, let cool to ambient. 2/19/2013 NDT completed - good weld • • Daily Report of Well Operations ADL0028285 T /I /O = 80/89/VAC. Temp = SI. MIT -OA w /N2 PASSED to 500 psi. AL SI @ skid, ALP = 0 psi. OA FL @ 3'. Used N2 to pressure up OAP to 500 psi. OAP lost 14 psi in 1 15 min & 3 psi in 2nd 15 min. Sniffed with four gas through out job. See log for details. SV, WV, = C. 2/20/2013 SSV, MV = O. IA, OA = OTG. NOVP. 17:00 FLUIDS PUMPED BBLS 0 TOTAL Casing / Tubing Attachment ADL0028285 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20" Conductor 32 - 110 32 - 110 LINER 51 3 -1/2" 9.3# L -80 10786 - 10837 8015.98 - 8050.4 10160 10530 LINER 839 7" 29# L -80 10790 - 11629 8018.68 - 8606.7 8160 7020 LINER 1365 3- 3/16" 6.2# L -80 10837 - 12202 8050.4 - 9035.76 LINER 1802 2 -7/8" 6.4# L -80 12202 - 14004 9035.76 - 9026.77 10566 11165 PRODUCTION 11270 9 -5/8" 47# L -80 30 - 11300 30 - 8371.94 6870 4760 SURFACE 2669 13 -3/8" 72# L -80 31 - 2700 31 - 2699.94 4930 2670 • TUBING 10715 5 -1/2" 17# L -80 29 - 10744 29 - 7987.66 7740 6280 TUBING 110 4 -1/2" 12.6# L -80 10744 - 10854 7987.66 - 8061.88 8430 7500 • 1 1 . ` • • Packers and SSV's Attachment ADL0028285 SW Name Type MD TVD Depscription G -08A PACKER 2608 2542.34 9 -5/8" DV Packer G -08A PACKER 10743 7921.38 5 -1/2" Baker Pkr TREE _= CTW - Jit, L HEAD = Mc EVOY ill G-08A P NOTES: W ANGLE > 70° @ 12141* `• ACTUATOR = BAKER PLASTIC COATED ' *` KB ELEV = 65.6' BF ELEV = 36.8 1 I 2117' H5 -1/2" CA -BAL -O SSSV N D = 4.562" KOP= _. 3050' Max Angle 96° G 12873' ��' 2608' H9 DV PKR Datum MD= 11915' GAS LIFT MANDRELS Datum ND 8800' SS , ST MD ND DEV TYPE VLV LATCH FORT DATE 12 3012 3011 8 CA DMY RK 0 09/06/12 11 5463 4832 56 CA DMY RK 0 01/22/04 113 -3/8" CSG, 72#, L -80, D = 12.347" H 2700' 10 7207 5822 54 CA DMY RK 0 09/06/12 9 7347 5904 54 CA DMY RK 0 05/14/81 8 8259 6451 53 CA DMY RK 0 05/14/81 7 8404 6537 54 CA DMY RK 0 05/14/81 6 9051 6914 50 CA DMY RK 0 01/22/04 5 9197 7007 51 CA DMY RK 0 05/14/81 Minimum ID = 2.377" @ 12202' 4 9772 7362 52 CA DMY RK 0 05/14/81 3 -3/16" X 2 -7/8" X0 LNR PIN ID 3 9914 7448 52 CA DMY RK 0 05/14/81 2 10448 7789 48 CA DMY RK 0 09/11/12 1 10590 7884 48 CA EMPTY _ 0 10/01/12 I I 10657' — I5 -1/2" CANDO SLD SLV, D =4.500" I 10723' IH BKR PBR SEAL ASSY I M IC, 10743' 1-19-5/8" X 5-1/2" BKR PKR , ID= 4.0" 5 TBG - PC, 17 #, L IJ4S, H 10744') I 10744' H 5-1/2" X 4 -112" XO, D = 3.958" .0232 bpf, ID = 4.892" 10773 ELM H4-1/2" OTIS X NP, D = 3.813" TOP OF 7" LNR H 10790' I 10786' H3.70" BOT DEPLOY SLV, D = 3.00" I3 -1/2" LNR, 9.3#, L -80 STL, .0087 bpf, 0= 2.99T —I 10837' 10805 ELM — 4-112" OTIS *I NIP, MILLED TO 3.80" BEHIND CT LNR 4-1/2" TBG, 12.6#, L -80 CSH H 10854' _ ' I 10805' H3 - 1/2" FES X Pi? D = 2.813" .0152 bpf, D = 3.958" 10805' —I3 -1/2" PX RUG (09/06/12) I 9 -5/8" CSG, 47 #, L -80, D = 8.681" H 11289' I 10837' — 1/2" -3/16" XO, ID= 2.786" TOC f — — 11415' \ • 10854' -- 14-1/2" WLEG, D = 3.958" I BEHIND VVHPSTOCK — 11615' CT LNR I 10837' H ELM) TT LOGGED 06/12/82 17" LNR, 29#, L -80 BTC, .0371 bpf, ID= 6.184" — — 11619 4444 14441 • �A • RA PP TAG — 11625' * *4. • FALLOUT T WPDOW (G -08A) 11619' - 11629' 44 ►44 •• 444 PERFORATION SLAMAARY 44,4 1,4••4 REF LOG: M }&- GR-CCL 03/12/07 4 4 �� ANGLE AT TOP PERE: 63° @ 12103' ®' ° z, • • • • • 12202' 3 -3/16" X 2 -7/8" XO, D = 2.377" Note: Refer to Production OB for historical pert data V4�44444 44444444) SVE SPF NTB?VAL OPNISOZ DATE • 4 4 4 4 4 4 4 4 4 4 4 4 44 2' 6 12103 12108 C 01/19/12 •••••••• % 2" 6 12245 - 12295 C 03/14/07 , 12950' 1- 12 -7/8" CIBP(05/30 /10) 2" 6 12350 - 12405 C 03/14/07 2" 6 12440 - 12475 C 03/14/07 A . 13190' I- 2 -7/8" CEP 2" 6 12520 - 12550 C 03/14/07 3 -3/16" LNR, 6.2#, L -80 TCI, — 12202' � (04/23/09) D 2" 6 12640 - 12690 C 03/14/07 .0076 bpf, = 2.80" 2" 6 13056 -13070 C 04/23/09 H `4444�4. 2" 6 13100 - 13130 C 04/23/09 STD H 13969' 4 2" 6 13660 - 13830 C 03/13/07 2 -7/8" LPR 6.4#, L -80 STL, .0058 bpf, ID = 2.441" —1 14004' - DATE REV BY COMMENTS DATE REV BY OOMNBJTS 1 PFUJHOE BAY UNi' 05114/81 ORIGINAL COMPLETION 09/07/12 CDJ/ PJC SET PX & GLV C/O (09/6 - 07/12) WELL. G-08A 03/15/07 NORDIC 1 CTD SIDETRACK (G -08A) 09/13/12 CDJ/JMD GLV C/O (09/11/12) PERMIT No: '1061830 01/23/12 RVMNJMD ADPERF (01/19/11) 10/03/12 DLWOMD GLV GO (10/01/12) AR No: 50 -029- 20581 -01 04/06/12 MSS/JMD SET 3-1/2" PX PLUG (04/05/12) SEC 12, T11 R R13E, 2506' FSL & 2367' Fes.. 04/22/12 CDJ/ PJC GLV C/O / PULL XX (4/18- 19/12) 06/17/12 PJC LNR CORRECTIONS 11 BP Exploration (Alaska) DATE: 5- Nov -12 Stephanie Pacillo TRANS#: 6192 c � Data Delivery Services Technician , M r� �� c91 I1 c� j� ender Schlumberger Oilfield Services -41. .~ -fi Natural Resources Technician II WIRELIKE +� �q� \ N - > ?Jaska Oil & Gas Consctvat:on OCi' muss :on 2525 Gambell St, Ste. 400 ` APR 1 9 I t _ ^ . , CO itIED J Anchorage, AK 99503 -';.n. fil: Office: (907) 273 -1770 g - WELL,, SERVICE , ' OH RESEW CNL NMECFE LOG DESCRIPTION DATE W 'COL ' Y f , NAME ORDER# 01ST' P1STr ", DII$ Q Ar sa f, �;1 ��$'►': MEMORY . . LOGCi�C .PRINTS PRINTS 15 - 30B BCRC - 00208 X MEMORY PPROF 05 -SEP -202 1 1 CD S -102 C5XI -00029 X MEMORY IPROF 18- Aug -12 1 1 CD • MPE -23 C600 -00055 X MEMORY (PROF 7-Oct-12 1 1 CD MPL -15 C600 -00035 X MEMORY IPROF 8- Aug -12 1 1 CD MPC -05A AMPSURVEEL X SCMT 1- Oct -12 IMIIIIIIII 1 1 CD 01 -02 CBTY -00004 X LEAK DETECTION LOG 5-Oct-12 1 CD G -08A CBAF -00009 X LEAK DETECTION LOG 27-Sep-12 ilia 9 1 CD 09 -05A APBNRWOSEL X FLOSCAN IMAGER 18-Oct-12 ._ 1 CD W -15A BZ2J -00023 X MEMORY GAS LIFT SURVEY 10•Au�12 IIII 1 CD MPI-18 BCRC -00204 X MEMORY IPROF 30-Au! -12 1111111111 1 CD 13.05 CBAF -00008 X IIIIIIIIIIII LEAK DETECTION LOG Egannallinnini 1 CD 13.08A BBSK -00139 LEAK DETECTION LOG 28- Sep -12 1111111111 1 CD V -225 BSM4 -00035 (PROF RST W/ WFL 28- Aug -12 l CD IIIIIMIMIIIIIIIIIIIII IIIIIIIIIIIIIIIIIIINIIIIIIINIIMIMIIMIIIIIINIIIIIIIIIIIIIIIIMIIIMIMIIMIIIII mil 0 IIII IIIIIIIIIIIIIIIIIIIMIIIIINIIIMIIIIIIIIIIINIIIMIMIIMIIMIIIIIIMIIIIMIIIIII X 1 Please return a signrsd copy to: Please return a signed copy to: _ BP POC LR2-1 DCS 2525 Gambell St, Suite 400 900 E Benson Blvd Anchorage AK 99503 0 Anchorage AK 99508 � ' • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg 4.1VMED AUG 3 ZU'i'L Alaska OH and Gas Conservation Commission 333 West 7 Avenue / Anchorage, Alaska 99501 �.O t0 Subject: Corrosion Inhibitor Treatments of GPB G -Pad CT , 0 ca Dear Mr. Regg, i list Enclosed please find multiple copies of a spreadsheet with a o f wells from GPB Pad G 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, Mehreen Vazir 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) G-Pad Date: 03/05/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal G -01A 1931710 50029202140100 3.0 NA 3.0 NA 10.2 5/10/2010 G -02B 2081580 50029202170200 0.5 NA 0.5 NA 2.6 5/10/2010 G -03A 1970700 50029202210100 0.7 NA 0.7 NA 6.0 5/27/2010 G-04B 2061400 50029202250200 0.1 NA 0.1 NA 1.7 5/10/2010 G -05 1780970 50029203510000 0.0 NA 0.0 NA 0.0 5/10/2010 G-06A 2060120 50029203580100 0.6 NA 0.6 NA 5.1 5/12/2010 G -07 1790180 50029203590000 0.5 NA 0.5 NA 3.4 5/11/2010 ----7 G-08A 2061830 50029205810100 0.1 NA 0.1 NA 0.9 5/27/2010 G -09B 2071100 50029205820200 9.0 NA 9.0 NA 69.7 5/20/2010 G -10C 2060090 50029205530300 0.9 NA 0.9 NA 8.5 3/5/2012 G -11B 2080270 50029205830200 0.0 NA 0.0 NA 0.0 5/21/2010 G -12B 2031410 50029205970200 0.5 NA 0.5 NA 2.6 5/13/2010 G -13A 2001630 50029206000100 0.0 NA 0.0 NA Trace 5/12/2010 G -14B 2090680 50029206460200 0.7 NA 0.7 NA 5.1 5/22/2010 G -15B 2080650 50029206470200 26.0 4.0 0.5 7/16/2011 3.4 7/19/2011 G -16A 2090560 50029206430100 0.0 NA 0.0 NA Trace 5/22/2010 G -17A 2060760 50029206190100 21.4 4.0 0.6 7/16/2011 3.4 7/19/2011 G -18A 1990320 50029206200100 71.7 14.0 1.0 7/16/2011 8.5 7/19/2011 G -198 2071240 50029215990200 0.0 NA 0.0 NA Trace 5/22/2010 G -21 1951540 50029226040000 0.5 NA 0.5 NA 3.4 5/12/2010 G -23B 2091440 50029216800200 0.5 NA 0.5 NA 4.3 5/11/2010 G -24A 2060820 50029216710100 0.1 NA 0.1 NA 0.9 5/11/2010 G -25B 2070860 50029216520200 5.3 NA 5.3 NA 23.8 5/28/2010 G -266 2050480 50029216610200 2.0 NA 2.0 NA 6.8 5/11/2010 G -27A 2070310 50029216460100 0.5 NA 0.5 NA 2.6 5/30/2010 G -29B 2101410 50029216500200 2.8 NA 3.0 NA 17.0 5/13/2010 G -30C 2091510 50029216130300 1.0 NA 1.1 NA 5.1 5/30/2010 G -31B 2090310 50029216160200 0.8 NA 0.8 NA 6.0 5/21/2010 G -32A 1970010 50029216360100 0.8 NA 0.8 NA 3.4 5/21/2010 en) 006 l g3 U Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIllntegrityCoordinator @bp.com] Sent: Tuesday, June 05, 2012 6:03 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad DG; Ramsay, Gavin; Yeager, Kevin E Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); LeBaron, Michael J; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer G -08A (PTD #2061830) POP well to allow Furmanite to Re- energize Starting Head Clamp All, G -08A (PTD #2061830) has currently 2 established barriers in the well, with a passing MIT -T and CMIT -TxIA, but is exhibiting seepage and bubbling at the installed Furmanite clamp over the starting head. Furmanite is now on the slope for an attempt to energize the clamp while the well is hot and on production. The well is reclassified as Under Evaluation to resume production to allow the wellhead to thermally cycle for the treatment. Plan forward: 1. Operations: Place well on Production JuL 1 3 are 2. Wellhead: Furmanite to re- energize starting head clamp . 3. WIE: Monitor wellhead for 5 -7 days to determine if treatment was successful Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWellIntegritvCoordinator (a�BP.com From: AK, D &C Well Integrity Coordinator Sent: Saturday, April 28, 2012 8:55 AM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (Do )'; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK •PS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D& ireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS We •ad DG; Ramsay, Gavin Cc: Walker, Greg (D &C); Olson, An, ew Subject: NOT OPERABLE: G -08 (PTD #2061830) SH Leak to Atmosphere All, 1 P G -0A P7-6246,1630 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator ©bp.com] 5 / Sent: Saturday, April 28, 2012 8:55 AM ( ` To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad DG; Ramsay, Gavin Cc: Walker, Greg (D &C); Olson, Andrew Subject: NOT OPERABLE: G -08A (PTD #2061830) SH Leak to Atmosphere All, G -08A (PTD #2061830) has passed an MIT -T and CMIT�TxIA after changing out gas lift valves confirming two competent barriers in the wellbore. However, the Furmanite clamp continues to exhibit seepage and bubbling indicating an active starting head leak to atmosphere. The well is reclassified asWot Operable until the starting head leak is repaired. Thank you, Mehreen Vazir t,f /rcrrn; {s: t, < rt1c1.11I1/7) /n•1 Well Integrity Coordinator BP Alaska Drilling & Wells � Y ME MAY 3 1 Luca Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Monday, March 19, 2012 4:11 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC1 OSM; AK, OPS GC1 Field 0 &M T • , K, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team -ad; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad DG; Ramsay, Gavin Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Wills, Shane M; LeBaron, Mic • -I J Subject: UNDER EVALUATION: G -08A (PTD #2061830) Sustained IA Casing Pre- ure Above MOASP All, G -08A (PTD #2061830) has confirmed sustained IA , asing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 2160/2190/0 on 03/18/201 . The well had been shut -in previously for a starting head leak on the installed Furmanite clamp. The well has been reclassified as Under Evaluation. f Plan forward: 1. Fullbore: Load and kill well 2. WIE: Evaluate for starting head repair A TIO plot and wellbore schematic have been included for reference. « File: G -08A (PTD # 2061830) TIO Plot.doc » Please call if you have.any questions or concerns. Thank you, 1 t;kt.t pit &( e 3Q Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] / Sent: Monday, March 19, 2012 4:11 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad DG; Ramsay, Gavin Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Wills, Shane M; LeBaron, Michael J Subject: UNDER EVALUATION: G -08A (PTD #2061830) Sustained IA Casing Pressure Above MOASP Attachments: G -08A (PTD # 2061830) TIO Plot.doc; G -08A (PTD # 2061830) wellbore schematic.pdf All, y G -08A (PTD #2061830) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 2160/219V on /18/2012. The well had been shut -in previously for a starting head leak on the installed Furmanite clamp. The well has been reclassified as Under Evaluation. Plan forward: 1. Fullbore: Load and kill well 2. WIE: Evaluate for starting head repair A TIO plot and wellbore schematic have been included for reference. «G -08A (PTD # 2061830) TIO Plot.doc» «G -08A (PTD # 2061830) wellbore schematic.pdf» Please call if you have any questions or concerns. Thank you, �A SC- Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator S'erf> = Z lgvr r; Office (907) 659 -5102 Cell (907) 752 -0755 /JP - 6t7c p ; ,` Pager (907) 659 -5100 Ext. 1154 4ivigititED MAR 2 ,. alL m p= 3f, 0 PBU G -08A PTD # 2061830 3/19/2012 TIO Pressures Plot Well: G -08 4 - • 3.000 - —#— T bg r . II-- IA 2 —46- OA OOA --40 00OA On 1,OOG - I • mom 12/31 /11 01/14/12 01/28/12 02/11/12 02/25/12 03/10/12 TREE = OW • WELLHEAD= McEVOY G-08A SAFET NOTES: WELL ANGLE> TO° @ 12141'. ACTUATOR = BAKER C KB. ELEV = 65 6' ... �._ BF. ELEV = 36.8' ® 2117' - - I5 -1/7' CA -BAL -O SSSV LAND NIP, ID = 4.562" KOP = 3050' 2608' -19 -5/8" DV PKR Mix Angle = 96° 12873' Datum MD = 11915' C GAS LIFT MANDRELS Datum TVD = 8800' S S /1 k ' ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 3012 3011 8 CA DOME RK 16 08/09/11 11 5463 4832 56 CA DMY RK 0 01/22/04 13 -3/8" CSG, 72#, L -80, ID = 12.347" - 2700' 10 7207 5822 54 CA DOME RK 16 08/09/11 9 7347 5904 54 CA DMY RK 0 05/14/81 8 8259 6451 53 CA DMY RK 0 05/14/81 7 8404 6537 54 CA DM' RK 0 05/14/81 6 9051 6914 50 CA DMY RK 0 01/22/04 5 9197 7007 51 CA DM' RK 0 05/14/81 Minimum ID = 2.377" @ 12202' 4 9772 7362 52 CA DMY RK 0 05/14/81 3- 3/16" X 2 -7/8" X4 LNR PIN ID 3 9914 7448 52 CA DMY RK 0 05/14/81 2 10448 7789 48 CA SO RK 22 08/09/11 1 10590 7884 48 CA 'DMY RK 0 05/10/10 • GLM #1 ©DMY HAS E(TENDS) PACKING ' I 10657' H5-1/2" CAMCO SLIDING SLV, ID = 4.500" 10723' --I BAKER PBR SEAL ASSY I _T, �� I 10743' I -19 -5/8" X 5 -1/7' BAKER PKR, ID = 4.0" 15.12" TBG, 17 #, L -80 U4S, .0232 bpf, ID = 4.892" — 10744' I 10744' 1 1 5 -112' X 4 -12" X0, ID = 3.958" ' 1 10773 ELM — 14 -1/2" OTIS X NIP, ID = 3.813" I TOP OF 7" LNR H 10790' I 10786' —13.70" BOT DEPLOYMENT SLV , ID = 3.00" 1 I N 13 -12" LNR, 9.3 #, L -80 STL, .0087 bpf, ID = 2.992" —I 10837' 10805 ELM 1— 4.1/2" OTIS XN NIP, MILLED TO 3.80 I 4 -1/2' TBG, 12.6#, L -80 CSH, H 10854' 0152 bpf, ID = 3.958" I 10805' — i 3-112' HES X NIP, ID = 2.813" I 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 11289' , I 10837' H3 -1/2' X 3-3/16" XO, ID = 2.786 er- 6410 re' TOO — — 11415' \\� � 10854' --I -12" WLEG, ID = 3.958" WHIPSTOCK 11615' 1 10837' --I ELMD TT LOGGED 06/12/82 I 1 7" LNR 29#, L -80 BTC, .0371 bpf, ID= 6.184" H — 11619 X � 4 4 ► IRA PIP TAG 1—I 11625' 1 1i 1 4 4 4 4 , 1 4 4 4 MLLOUT WINDOW (G -08A) 11619' - 11629' N4' 44 . ♦1 1 ►4 PERFORATION SUMMARY 14 ♦ 4 4 REF LOG: MCNL- GR -CCL 03/12/07 r�l. 't4 ANGLE AT TOP PERF: 63' a- 12103' ' = ' 4., Note: Refer to Production DB for historical pert data x'4'4'4' 12202' — 3 -3/16" X 2 -7/8" X0, ID = 2.377 4446 SIZE .. SPF INTERVAL ' OPWSQZ DATE 4 L 4A 4�4�4�4 • 1• 4�4 2' 6 - 12103 - 12108 O 01/19/12 2' 6 12245 - 12295 0 03/14/07 , 12950' --12.7/8" CIBP (05/30/10) I 2' 6 12350 - 12406 0 03/14/07 2' 6 12440 - 12475 0 03/14/07 4 13190' — 2 -7/8" CIBP 3 -3/16" LNR, 6 2 #, L -80 TCII, — 1 202' 2" 6 12520 12550 0 03/14/07 ' .0076 bpf, ID = 2.80' (04/23/09) 2' 6 13056 - 1330 12690 O C 04/23/09 1 ∎��4� 2" 6 13100 - 13130 C 04/23/09 'MID I 13969' 4 ,# 2" 6 13660 - 13830 C 03/13/07 12 -7/8" LNR 6.4 #, L -80 5Th, .0058 bpf, ID = 2.441" H 14004' 1 . 1 DATE REV BY COMMENTS DATE REV BY COMMENTS I PRUDHOE BAY UNIT 05/14/81 ORIGINAL COMPLETION 08/14/1 MBM PJC RJILL DSSSV & LTTP(8/8 -9/11) WELL. G-08A 03/15/07 NORDIC 1 CTD BIDET RACK (G -08A) 08/15/11 JLJ/ PJC GLV C/0 (8/9/11) PERMIT No: 1 206183 02/12/11 WRR/PJC GLV C/O (02/06/11) 01/23/12 RWMJMD ADPERF (01/19/11) API No: 50 -029- 20581 -01 06/01 /11 MSS/ PJC GLV 010 (05/20/11) 03/19/12 SW /JMD GLV CORRECTION (03/18/12) SEC 12, T11 N, R13E 2506' FSL & 2367' FEL 06/02/11 MSS/ PJC SET DSSSV PLUG (5/23/11) 03/19/12 JND GLV DATE CORRECTION (05/14/81) 07/01/11 FMC/ PJC TREE C/O (0527/11) I I BP Exploration (Alaska) STATE OF ALASKA ALAS AND GAS CONSERVATION COMMIS, REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ A 206 -1830 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 - 6612 50- 029 - 20581 -01 -00 8. Property Designation (Lease Number) : 4, 9. Well Name and Number: ADLO- 028285 PBU G -08A 4— 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 14004 feet Plugs (measured) 12950, 13190 feet true vertical 9026.77 feet Junk (measured) None feet Effective Depth measured 13969 feet Packer (measured) 2608 10743 feet true vertical 9027.37 feet (true vertical) 2608 7987 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 32 - 110 32 - 110 Surface 2669' 13 -3/8" 72# L -80 31 - 2700 31 - 2700 4930 2670 Production 11270' 9 -5/8" 47# L -80 30 - 11300 30 - 8372 6870 4760 Liner 839' 7" 29# L -80 10790 - 11629 8019 - 8607 8160 7020 Liner 51' 3 -1/2" 9.3# L -80 10786 - 10837 8016 - 8050 10160 10530 Liner 1365' 3- 3/16" 6.2# L -80 10837 - 12202 8050 - 9036 Liner 1802' 2 -7/8" 6.4# 1 -80 12202 - 14004 9036 - 9027 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ - _ Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# L -80 29 - 10744 29 - 7988 4 -1/2" 12.6# L -80 10744 - 10854 7988 - 8062 Packers and SSSV (type, measured and true vertical depth) 9 -5/8" DV Packer 2608 2608 SLANNE �" f� 7 'LUIS 5-1/2" BAKER PKR 10743 7987 ��! k RECEIVED 12. Stimulation or cement squeeze summary: FEB 0 2012 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: l Alaska C "I a Gas Cons. Commission Anchorage 13. Representative 1TaT �erage Production or Injectio n D ata Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 82 4024 1 127 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory El Development 0 A Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ,,. U Gas ❑ WDSPL U GSTOR ❑ WINJ ❑ WAGE' 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: NA Contact Nita Summerhays Printed Name Nita Summerh. s Title Data Manager i/ / Sig natur �i��i�ii %l�i, -- Phone 564 -4035 Date 1/31/2012 Form 10-404 Revised 10 /2RBbMtS FEB 0 3 20 3 . 2.--- ,,,..- _ Submit Original Only G -08A 206 -183 . PERF ATTACHMENT Sw Name Operation Date Perf Operation Code ! Meas Depth Top Meas Depth Base 1 Tvd Depth Top I Tvd Depth Base G -08A 3/14/07 PER 12,245. 12,295.; 9,041.17 9,045.51 - - - - - G-08A 3/14/07i PER 12,350. 12,405. 9,043.81 9,039.68 G -08A 3/14/07 1 PER 12,440. 12,475. 9,037.8 9,037.03 G -08A 3/14/07 PER 12,520. 12,550. 9,037.63' 9,037.27 G-08A 3/14/07 PER 12,640. 12,690. 9,033.09 9,028.65 G -08A 3/14/07' PER 13,660. 13,830.' 9,016.48 9,027.11 G -08A 4/20/09 BPS 13,190. 13,195. 9,002.77 9,002.8 G -08A 4/23/09 APF 13,100. 13,130. 9,003.38, 9,002.58 G-08A 4/23/09 APF 13,056. 13,070. 9,006.27 9,005.19 G -08A 5/30/10. BPS 12,950., 12,245. 9,010.89 9,041.17 G -08A 5/22/11' BPS 1 12,950. 8,015.98 9,010.89 G -08A 5/23/11 BPS 2,117. 12,245. 2,116.95 9,041.17 • G -08A 8/8/11 BPP 2,117. 10,786., 2,116.95 8,015.98 APF 12,103. 12,950. G -08A 8/9/111 BPP 10,786. 8,015.98 9,010.89 G -08A 1/18/12 ' 12,108. 9,006.87 9,009.11 AB ABANDONED IPER PERF APF ADD PERF I RPF REPERF BPP BRIDGE PLUG PULL ED 1 SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED I SQUEEZE MIS MECHANICAL ISOLATED SQZ STRADDLE PACK, - - CLOSED MLK MECHANICAL LEAK I STO ' STRADDLE PACK, OPEN OH OPEN HOLE j I 1 1 • • G -08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 1 ACTIYIYYDATE 1 'SUMMARY , . 1/11/2012 ***WELL S/I ON ARRIVAL ** *(pre pert) TROUBLE SHOOT SSV, POSSIBLE ICE BUILD UP. DRIFTED W/ 10' x 2.0" DMY PERF GUN, S.BAILER TO DEV @ 12,161' SLM (NO SAMPLE). TARGET DEPTH = 12103' TO 12108'. ** *WELL LEFT S /I, PAD OP NOTIFIED * ** 1/18/2012 ** *WELL SHUT IN ON ARRIVAL * ** E -LINE: PERFORATING INITIAL T/I/0 = 1000/1100/0 PSI ARRIVED TO LOCATION AND SPOTTED EQUIPMENT. WAITED FOR DSO TO SIGN PERMIT AND PERFORM A SNIFT TEST OF THE WELL HOUSE. 0 PPM FOUND. RIG UP AND PRESSURE TESTED LUBRICATOR. PERFORMED HOT CHECK AND ARMED 5' GUN 2" PJ 2006 HMX HSD. RIH AND TIED IN USING BAKER HUGHES GAMMA RAY LOG DATED 4- MARCH -2007. CONTINUED RIH WITHOUT PROBLEMS. RIH UP TO 12150' AND PERFORMED CORRELATION PASS. AFTER CONFIRMING WITH THE WSL THE PERF INTERVAL 12103' 12108', CCL TO TOP SHOT = 3.3', CCL STOP DEPTH = 12099.7' PERFORMED SHOOTING PASS. GOOD INDICATION AT SURFACE OF FIRING. FINISHED SHOOTING PASS AND BEGAN POOH. AT SURFACE. CLOSED THE SSV AND SWAB. RIG DOWN. PRESSURE TESTED TREE CAP WITH NEW 0-RING. CLOSE PERMIT AND LEAVE LOCATION FINAL T /I /O = 1100/1100/0 PSI ** *JOB COMPLETE * ** (WELL SHUT IN UPON DEPARTURE) FLUIDS PUMPED BBLS 1 METH 2 DIESEL 3 TOTAL WF� HEAD= McEVOY G -08A SAFETY NOTES: WELL ANGLE> 70° @ 12141' ACTUATOR = BAKER C KB. ELEV = 65.6' I BF ELEV = 36.8'' 1 2117' H5 -1/2" CA-BA L-0 SSSV LAND NIP, ID = 4.562" 1 KOP = 3050' �� 2608' —19 -5/8" DV PKR Max Angle = 96' @ 12873' GAS LIFT MANDRELS Datum MD = 11915' ' ST MD TVD DEV TYPE VLV LATCH FORT DATE 88 Datum TVD = 00' SS 12 3012 3011 8 CA DOME RK 16 08/09/11 11 5463 4832 56 CA DMY RK 0 04/11/03 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2700' 10 7207 5822 54 CA DONE RK 16 08/09/11 9 7347 5904 54 CA DMY RK 0 05/13/81 8 8260 6451 53 CA DMY RK 0 05/13/81 7 8404 6537 54 CA DMY RK 0 05/13181 6 9051 6914 50 CA DMY RK 0 01/22/04 5 9197 7007 51 CA DMY RK 0 05/13/81 Minimum ID = 2.377" @ 12202' 4 9772 7362 52 CA DMY RK 0 05/13/81 3 -3/16" X 2 -7/8" XO LNR PIN ID 3 9914 7448 52 CA DMY RK 0 05/13/81 2 10448 7789 48 CA DOME RK 22 08/09/11 1 10590 7884 48 CA 'DMY RK 0 05/10/10 "GLM #1 = DMY HAS EXTENDED PACKING I I 10657' H5 -1/2" CAMCO SLIDING SLV, ID = 4.500" 10723' H BAKER PBR SEAL ASSY 1 �� k■. 1 10743' 1-19 -5/8" X 5 -1/2" BAKER PKR, ID = 4.0" 1 15 -1/2" TBG, 17 #, L -80 U4S, .0232 bpf, ID = 4.892' H 10744' 1 1 10744' H5.1/2' X 4 -12" XO, ID = 3.958" II ' [10773 ELM H4 -1/2" OTIS X NIP, ID = 3.813" 1 1TOP OF 7" LNR H 10790' 1 10786' 1-13 70" BOT DEPLOYMENT SLV, ID = 3.00' 1 13 -1/2' LNR, 9.3 #, L -80 STL, .0087 bpf, ID = 2.992' H 10837' ' , 110805 ELM - 14 -12" 0116 XN NIP, MILLED TO 3.8(Y' 1 4 -1/2" TBG, 12.6#, L -80 CSH, —1 10854' .0152 bpf, ID = 3.958" 1 10805' I - 13 12 HES X NIP, ID = 2.813" 1 9 -5/8" CSG, 47 #, L -80, ID = 8.681" -1 11289' / ` 1 10837'1-- 13 - 1/2' X 3- 3/16" XO, ID = 2.786' 1 1TOCI -1 - 11415' ■ 10854' 1-1 -112' WLEG, ID= 3.958" 1 WHIPSTOCK H 11615' 1 10837' —1 ELMD TT LOGGED 06/12/82 1 1 7" LNR, 29#, L -80 BTC, .0371 bpf, ID = 6.184" H - 11619 VC r*T4 11 ∎ 11 1 IRA PIP TAG — 11625' 1 1 1 1 1 *1 1 1 1 1 1 1 MILLOUT WINDOW (G -08A) 11619' - 11629' 1 1 PERFORATION SUMMARY 11' 41 1 REF LOG: MCNL -GR CCL 03/12/07 �y 4 ■ ANGLE AT TOP PERF: 63° @ 12103' ,* Note: Refer to Production DB for historical perf data 0'0'0'0'4 12202' - 13 - 3/16" X 2 -7/8" XO, ID = 2.377" 1 • SIZE SPF INTERVAL OPN/SQZ DATE / ■ 4 , 2" 6 12103 - 12108 O 1/19/2012 �/ ••••••••• 2' 6 12245 - 12295 O 03/14/07 , 12950' H2-7/8" CIBP (05/30/10) 1 2' 6 12350 - 12405 O 03/14/07 , , 13190' -- 2 -7/8" CIBP 2" 6 12440 - 12475 O 03/14/07 3-3/16" Ltd, 6.2 #, L -80 TGi, — 1 202' 2' 6 12520 - 12550 O 03/14/07 4 ` , (04/23/09) 2' 6 12640 12690 O 03/14/07 .0076 bpf, ID = 2.80" 2' 6 13056 - 13070 C 04/23/09 14 `1 , 1 ■ 2' 6 13100 - 13130 C 0423/09 I PBTD H 13969' • 1 . 2' 6 13660 - 13830 C 03/13/07 12 -7/8" LNR 6 4 #, L -80 STL, .0058 bpf, ID = 2.441" — 14004' 1 DATE REV BY COMMENTS . DATE REV BY COMMENTS 1 PRUDHOE BAY UNIT 05/14/81 ORIGINAL COMPLETION 08/14/11 MBM/ PJC PUILL DSSSV & LTTP(8/8 -9/11) WELL: G-08A 03/15/07 NORDIC 1 CTD SIDETRACK (G -08A) 08/15/11 J..J/ PJC GLV C/O (8/9/11) PERMIT No. 206183 02/12/11 WRR/PJC GLV C/0 (02/06/11) 01/23/12 RWM/JMD ADPERF (01/19/11) API No: 50- 029 - 20581 -01 06/01/11 MSS/ PJC GLV C/0 (0520/11) SEC 12, T11 N, R13E, 2506' FSL & 2367' FEL 06/02/11 MSS/ PJC SET DSSSV PLUG (5/23/11) 07/01/11 FMC/ PJC TREE C/O (05/27/11) BP Exploration (Alaska) STATE OF ALASKA • • ALASKA OAND GAS CONSERVATION COMMISSI. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate 0 Other El FURMANITE WRAP Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 4 206 -1830 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20581 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028285 PBU G -08A 10. Field /Pool(s): _ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 14004 feet Plugs (measured) 2117, 10786, 12950, 13190 feet true vertical 9026.77 feet Junk (measured) None feet Effective Depth measured 13969 feet Packer (measured) 2608 10743 feet true vertical 9027.37 feet (true vertical) 2608 7987 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 32 - 110 32 - 110 Surface 2669' 13 -3/8" 72# L -80 31 - 2700 31 - 2700 4930 2670 Intermediate 11270' 9 -5/8" 47# L -80 30 - 11300 30 - 8372 6870 4760 Production 839' 7" 29# L -80 10790 - 11629 8019 - 8607 8160 7020 Liner 51' 3 -1/2" 9.3# L -80 10786 - 10837 8016 - 8050 10160 10530 Liner 1365' 3- 3/16" 6.2# L -80 10837 - 12202 8050 - 9036 Perforation depth: Measured depth: SEE ATTACHED - _ ; -M JUL" '2 9 Z011: True Vertical depth: z_ _ - Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# L -80 29 - 10744 29 - 7988 4 -1/2" 12.6# L -80 10744 - 10854 7988 - 8062 Packers and SSSV (type, measured and true vertical depth) 9 -5/8" DV PKR 2608 2608 5 -1/2" BAKER PKR 10743 7987 ,,.1I ,t < 12. Stimulation or cement squeeze summary: Intervals treated (measured): Qp i ®1 ryry 99 :ti; *> C5,` ;,�i'91if+.. L i imiSS1 Treatment descriptions including volumes used and final pressure: 1i " '",'uk;3 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 r Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE] 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: NA Contact Joe Lastufka Printed N. me J diki Last 1 Title Petrotechnical Data Technologist Signat e lum , I , Phone 564 -4091 Date 7/26/2011 RBDMS ?-L? Form 10 -404 Revised 10/2010 JUL 2 7 2011 �� ,, Submit Original Only G -08A 206 -183 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base G -08A 3/14/07 PER 12,245. 12,295. 9,041.17 9,045.51 G-08A 3/14/07 PER 12,640. 12,690. 9,033.09 9,028.65 G-08A 3/14/07 PER 12,520. 12,550. 9,037.63 9,037.27 G -08A 3/14/07 PER 13,660. 13,830. 9,016.48 9,027.11 G-08A 3/14/07 PER 12,350. 12,405. 9,043.81 9,039.68 G-08A 3/14/07 PER 12,440. 12,475. 9,037.8 9,037.03 G -08A 4/20/09 BPS 13,190. 13,195. 9,002.77 9,002.8 G -08A 4/23/09 APF 13,056. 13,070. 9,006.27 9,005.19 G-08A 4/23/09 APF 13,100. 13,130. 9,003.38 9,002.58 G-08A 5/30/10 BPS 12,950. 12,245. 9,010.89 9,041.17 G-08A 5/22/11 BPS 10,786. 12,950. 8,015.98 9,010.89 G -08A 5/23/11 BPS 2,117. 12,245. 2,116.95 9,041.17 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE III • • G -08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 6/28/2011,T/I/O =SSV /150/2. Temp =SI. Gravel sample (Furmanite repair). ALP =550 psi, SI @ ;casing valve. Gravel sample taken to lab. IAP increased 140 psi, OAP increased 2 ;psi since 06/16/11. ** Gravel is —8" below the lower threads of the SH. 37" sombrero; installed on 20" conductor. SV, WV, SSV =C. MV =O. IA, OA =OTG. NOVP. 6/29/2011 T /I /O= SSV /210/0. Temp= SI. Prep cellar and assist Furmanite. (Pre Furmanite). ALP= 575 psi SI @ casing valve. Removed 3 yds of contaminated gravel from cellar to assist Furmanite. Furmanite installed clamp and strong back support on the ;starting head. Job complete. SV, WV, SSV= C. MV= 0. IA, OA= OTG. NOVP. i � ! { I 7/2/2011'T/I/0= SSV /172/0. Temp = SI. Assist Furmanite and MIT -OA to 1200 psi * *PASS ** (Post Furmanite). AL SI @ casing valve. OA fluid level near surface. Furmanite =injected clamp to activate seals. Two attempts were made to MIT -OA with slight fluid seepage found at the Furmanite clamp installation (see log for details). Furmanite ,injected more teflon compound to complete seal activation after each test. During the :3rd test, the OAP lost 32 psi in 1st 15 mins & 8 psi in 2nd 15 mins for a total of 40 psi and no further hydrocarbon seepage was found (PASS). Bled OAP to 0 psi to slop tank in <1 min. Job complete. Final WHPs= SSV /172/0. !SV, WV & SSV =C. MV =0. IA & OA =OTG. NOVP. 1 FLUIDS PUMPED BBLS NO FLUIDS PUMPED TJREE=, . CM/ • G-08A SAFETY NA: WELL ANCLE > 70° @ 12141' - VVELLHEAD = IvIcEVOY ACTUATOR := BAKERC 1 1 . KB. ELEV = 65.6" I 2117' H5-1/2" CA-BAL-O SSSV LAND NIP, ID = 4.562" 1 BF. ELEV = 36.8' 5-1/2" DSSSV PLUG 2117' ______ KOP = 3050' W /PRONG (5(23/11) Max Angle = 96' @ 12873' - GAS LFT MA NDREI.S ...... Datum MO = 11915' — 2608' 19-5/8" DV PKR1 ST MD TVD DEV TYPE VIA/ LATCH PORT DATE ... ibatum TV6 = 8800' SS 12 3012 3011 8 CA CM' RK 0 05120/11 11 5463 4832 56 CA DMY RK 0 04/11/03 113-3/8" CSG, 72#, L-80, 0 = 12.347" I - 1 2700' 10 7207 5822 54 CA DMY RK 0 05/20/11 9 7347 5904 54 CA MY RK 0 05/13/81 8 8260 6451 53 CA MAY RK 0 05/13/81 7 8404 6537 54 CA DMY RK 0 05/13/81 6 9051 6914 50 CA DMY RK 0 01/22/04 5 9197 7007 51 CA DMY' RK 0 05/13/81 Minimum ID = 2.377" @ 12202' 4 9772 7362 52 CA DMY RK 0 05/13/81 3-3/16" X 2-7/8" XO LNR PIN ID 3 9914 7448 52 CA DMY RK 0 05/13/81 2 10448 7789 48 CA COW RK 0 05/20/11 1 105901 7884 48 CA *DMY RK 0 05/10/10 I I ' GLM #1 = DMY HAS EXTENDS) PACKING 10657' 5-1/2" CAMCO SLIDING SLV, ID = 4.500" 1 il 10723' H BAKER PBR SEAL A ssy I I C4 1■4 I 10743' J X 5-1/2" BA KB2 PKR, ID =4.0" 1 15-1/2" TBG, 17#, L-80 U4S, .0232 bpf, ID = 4.892" 1-1 10744' I I 10744' H5-1/2" X 4-1/2" X0, I 1 = 3.958" 1 I I 110773 ELM1 OTIS X NIP, OD = 3.813" [TOP OF 7" LNR H 10790' 1 10786' H3.70" BOT DEPLOYMENT SLV, ID = 3.00" 1 10805 ELM M H4-1/2" OTIS XN NIP, MILLED TO 3.80" 13-1/2" LNR, 9.3#, L-80 511, .0087 bpf, ID = 2.992" 1-1 10837' I I 1 1 10805' H3-1/2" HES X NIP, ID = 2.813" 41/2" TBG, 12.6#, L-80 CSH, - 10854' h .0152 bpf, ID = 3.958" g a 10837' H3-1/2" X 3-3/16" XO, ID = 2.786" J 1 9-5/8" CSG, 47#, L-80, ID= 8.681" 1-1 11289' 10854' H4-1/2" WLEG, 0 = 3.958" 1 1TOC 1 - 11415' I 10837' H ELMD TT LOGGED 06/12/82 1 !WHIPSTOCK 1-1 11615' KV AS' 444 444 i r LNR, 29#, 1 BTC, .0371 bpf, ID = 6.184" I ' 0* • 4+4 444 444 1444 4 444 MILLOUT WINDOW (G 11619' - 11629' * 444 RA PIP TAG 11625' 444 444 144 4** ,4 4, 44 PERFORATION SUVA/ARV . • ■.- N. . 1 .., • REF LOG MCNL-GR-CCL 03/12/07 • - -.....-, - . - : v *, ANGLE AT TOP PERF: 84° 12245' 12202' -13-3/16" X 2-7/8" XO, ID = 2.377" 1 orb ■;• V „...„ Note: Refer to Production DB for historical perf data ■WAvAyAl■••••■•■ SE SPF 1 INTERVAL OPN/SOZ DATE 2" 6 12245 - 12295 0 03/14/07 12950' 1-12-7/8" CEP (05/30/10) 1 2" 6 12350- 12405 0 03/14/07 .1,. 13190' H2-7/8" CIBP 2" 6 12440 - 12475 0 03/14/07 3-3/16" LNR, 6.2#, L-80 TCII, 1 202' 4 Nt, 2" 6 12520 - 12550 0 03/14/07 .`4 raio. (04/23/09) .0076 bpf, ID = 2.80" , 2" 6 12640 - 12690 0 03/14/07 ' ■4'■ 2" 6 13056 - 13070 C 04/23/09 44.■ PBTD 13088` 4' .4 2" 6 13100-13130 C 04/23/09 2" 6 1 13660 - 13830 C 03/13/07 i 12-7/8 . LNR, 6.4#, 1-80 STL, .0058 bpf, ID = 2.441" H 1400 . ' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY umn 05/14181 ORIGINAL COMPLETION 02/12111 WRR/PJC - GLV C/0(02106/11) — WELL: G-08A 03/15/07 NORDIC 1 CTD SIDETRACK (G-08A) 06/01/11 MSS/ PJC GLV C/0 (05/20/11) PERMIT No: 2O6183 02/23/10 MUM °RIG DRAFT CORRECTIONS 06/02/1i MSS/ PJC SET DSSSV PLUG (5/23/11) API No: 50-029-20581-01 05/31/10 MBM/PJC GLV C/0 (05/10/10) 07/01/11 FMC/ PJC TREE C/0 (05/27/11) SEC 12, TI 1 N, R13E, 2506' FSL & 2367' FEL 05131/10 MV/PJC SET GBP (05/30/10) 09/23/10 IVMS/AGR GLV C/0 (09/18/10 BP Exploration (Alaska) • • S~if~~~ 0~ p~pS~~(p /~..aa.~~a.E~ John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. ~~ ~~~~~~~_ ~, ;~ ~~ x~,~~ ~ ~~~-; , ~ ~3 P.O. Box 196612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU G-08A Sundry Number: 310-197 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. / l Chair DATED this ~ day of July, 2010. Encl. Anchorage, AK 99519-GG 12 STATE OF ALASKA ~,~%cyr~-- ~~O~ALASK~L AND GAS CONSERVATION COMMIS~N ~ v?~ 10 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: ^ Abandon ®Plug for Redrill ~ ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 206-183 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20581-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU G-08A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): , ADL 028285 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14004 - 9027 - 13969 - 9027 ~ 12950' & 13190' None Casin Len th Size MD ND Burst Colla e Structural Conductor 110' 2 " x 3 11 11 ' Surface 2700' 13-3/8" 2700' 270 ' 4930 2670 Intermediate 11300' 9-5/8" 11300' 8372' 6870 4760 Production Liner 1695' 7" 10790' - 11619' 8019' - 8600' 8160 7020 Liner 3218' 3-1/2" x 3-3/16" x 2ais" 10786' - 14004' 8016' - 9027' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12245' - 13830' 9041' - 9027' 5-1/2", 17# x 4-1/2", 12.6# L-80 10854' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker packer Packers and SSSV 10743' / 7987' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch - ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: July 15, 2010 ^ Oil ^ WINJ ^ WDSPL Plugged 16. Verbal Approval: Date: ^ Gas ^ GINJ ^ GSTOR ^ Abandoned d d PL G - S ^ ^ Commission Representative: uspen e S U WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ron Phillips, 564-5913 Printed Name Jo eMull~ Title Engineering Team Leader ( ~ ~ Terrie Hubtilea564-4628 Signature ~ "-- Phone 564-4711 Date r~ Commission Use Onl (~ Conditions approval~N tify Commission so that a representative may witness Sundry Number: 3~ ~ "~-t~~ ^ Plug Integrity L17 BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~ 35-00 ~ s ` BAP Ts ~ Other: .!(vJr~ ~ 201[1 Subsequent Form Required: ~ ~ - ~Q ~' Alaska Oil A~ Cas Cfuts. Commis ~nc3~a age APPROVED BY Approved By: COMMISSIONER THE COMMISSION Date log; Form 10-403 Revised b1/~~pN['S ~~~ ~ 9 20~ ~ ~. /v Submit ~IJn~~upl'cate 0R1G1n'nn %~ 9C9~`r N t1 • • To: Alaska Oil & Gas Conservation Commission From: Ron Phillips b p CTD Engineer Date: June 23, 2010 Re: G-08A Sundry Approval Sundry approval is requested to abandon the G-08A well by setting a packer whipstock above the perforations. The history of G-08A. Well G-08A was sidetracked in March 2007 as a CTD sidetrack. The well reached marginal GOR within 3 months. The well was placed on a 14 day on / 21 day off cycle and showed good recharge until August 2009. Additional perforations were added in May 2009 and the well came on strong for two months then gas rates climbed back up to pre add-perf levels. Six months of being shut in showed no recharge. The well has a passing MIT-T, MIT-IA and MIT-OA. The reason for side track is G-08A has been a cycle well for 2-1/2 years, the well does not recharge very well and does not see much on time. The proposed plan for G-08A is to drill a through tubing sidetrack with the Nordic 1 Coiled Tubing Drilling rig ~. on or around September O1, 2010. The existing perforations will be isolated by a 3-3/16" packer whipstock and '` the primary cement job. The following describes work planned and is submitted as an attachment to Form 10- 403. Aschematic diagram of the proposed sidetrack is attached for reference. Pre-Rig Work: (scheduled to begin July 15, 2010). 1. S Dummy WS drift to 12,200'. l~-e ~~~~f~ ~,r~7~ 7~,~ef~ inn fti~ ~ 2. S Dummy GLV s. ~ ~ < ~ `~ „~ 3. E Set 3-3/16" Baker packer whipstock 150° R,OHS at~11,830'. 4. O MIT-IA ~ p~~;x CX~~~r'"~"~~T 5. O AC-LDS; AC-PPPOT-T f'~C~vl~ f~ ~/~l` ~'~~J~~.v~s (~ : S i~h 6. O PT MV, SV, WV ~ ~~ ~ ~: D~+ 7. O Bleed gas lift and production flowlines down to zero and blind fla ge. r 8. O Remove wellhouse, level pad. • Rig Work: (scheduled to begin on Sept O1, 2010) 1. MIRU and test BOPE to 250 psi low and 3500 psi hi 2. Swap the well to Geo-Vis. Mi112.8" window at 11,83( 3. Drill Build: 3.0" OH, 370' (30°/100). 4. Drill Lateral: 3.0" OH, 895' (12°/100). 5. Run 2-3/8" L-801iner leaving TOL at 11,730'md. 6. Pump primary cement leaving TOC at TOL (11,730'), 7. Cleanout to TD at 13,095'. 8. MCNL/GR/CCL log. 9. Test liner lap to 2,000 psi. 10. Perforate liner per asset instructions 0600'). 11. Plan on setting a LTP (only 100' of liner lap). 12. Freeze protect well, set BPV and RDMO. r ~ C/f ~gaa/ fC'C~c~ i~~_ P~~fi~ 7.3 bbls of 15.8 ppg liner cmt planned. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's. 3. RU test separator, flow test well. Ron Phillips CTD Engineer 564-5913 C~ CC: Well File Sondra Stewman/Terrie Hubble tEE = CNV WELLHEAD. McEVOY A6TUATOR = OTIS KB. ELEV = 65.6' BF. ELEV = 36.8' KOP = 3050' Max Angle = 96° @ 12873' Datum MD = 11915' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I--I 2700' Minimum ID = 2.377" @ 12202' 3-3/16" X 2-7/8" XO LNR PIN ID 5-1/2" TBG, 17#, L-80 U4S, .0232 bpf, ID = 4.892" H 10744' TOP OF 7" LNR 3-1/2" LNR 9.3#, L-80 STL, .0087 bpf, ID = 2.992" 4-1/2" TBG, 12.6#, L-80 CSH, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" WHIPSTOCK RA PIP TAG 7" LNR, 29#, L-80 BTC, .0371 bpf, ID = 6.184" PERFORATION SUMMARY REF LOG: MCNL-GR CCL 03/12/07 ANGLE AT TOP PERF: 84° @ 12245' 10837' 10854' 11289' ,.11415' 11615' 11625' 12485' No te: Refer to Production DB for historical pert data SIZE SPF INTERVAL OPWSQZ DATE 2" 6 12245 - 12295 O 03/14/07 2" 6 12350 - 12405 O 03/14/07 2" 6 12440 - 12475 O 03/14/07 2" 6 12520 - 12550 O 03/14/07 2" 6 12640 - 12690 O 03/14/07 2" 6 13056 - 13070 C 04/23/09 2" 6 13100 - 13130 C 04/23/09 2" 6 13660 - 13830 C 03/13/07 12202' H 3-3/16" X 2-7/8" XO, ID = 2.377" 12950' 2-7/8" CIBP (05/30/10) 13190' 2-7/8" CIBP 3-3/16" LNR 6.2#, L-80 TCII, 12202' (04/23!09) .0076 bpf, ID = 2.80" PBTD 13969' 2-7/8" LNR, 6.4#, L-80 STL, .0058 bpf, ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS 05/14/81 ORIGINAL COMPLETION 02/23/10 SM/JMD DRLG DRAFT CORRECTIONS 03/15/07 NORDIC 1 CTD SIDETRACK (G-08A) 05/31/10 MBMIPJC GLV GO (05/10/10) 03/17/07 /PAG DRLG DRAFT CORRECTIONS 05/31/10 MV/PJC SET CIBP (05!30/10) 04/07/07 BSE/PAG GLV GO (04/04/07) 05/31/09 WEGTLH CIBP SET/ADPERFS (04123/09) 10/01/09 JLJ/SV GLV GO (09/07/09) PRUDHOE BAY UNfT WELL: G-08A PERMff No: 206183 API No: 50-029-20581-01-00 SEC 12, T11 N, R13E, 2506' FSL & 2367' FEL BP Exploration (Alaska) G ~O 8A SS: WELL ANGLE> 70° @ 12141' ® 2117' 5-1/2" CA-BAL-O SSSV LAND NIP, ID = 4.562" 2608' 9-5/8" DV PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 3012 3011 8 CA DMY RK 0 09/07/09 11 5463 4832 56 CA DMY RK 0 04111 /03 10 7207 5822 54 CA DMY RK 0 09/07/09 9 7347 5904 54 CA DMY RK 0 05/13/81 8 8260 6451 53 CA DMY RK 0 05/13/81 7 8404 6537 54 CA DMY RK 0 05/13/81 6 9051 6914 50 CA DMY RK 0 01 /22/04 5 9197 7007 51 CA DMY RK 0 05/13/81 4 9772 7362 52 CA DMY RK 0 05/13/81 3 9914 7448 52 CA DMY RK 0 05/13/81 2 10448 7789 48 CA DMY RK 0 05/13181 1 10590 7884 48 CA *DMY RK 0 05/10/10 " GLM #7 = DM Y HAS F,(TFNnFII YAGKIN(a 10657' 5-1/2" CAMCO SLIDING SLV, ID = 4.500" 10723' BAKER PBR SEAL ASSY 10743' 9-5/8" X 5-1/2" BAKER PKR, ID = 4.0" 10744' 5-1/2" X 4-1/2" XO 10773 ELM 4-1/2" OTIS X NIP, ID = 3.813" 10786' 3.70" BOT DEPLOYMENT SLV, ID = 3.00" 10805 ELM 4-1/2" OTIS XN NIP, MILLED TO 3.80" 10805' 3-1 /2" HES X NIP, ID = 2.813" 10837' 3-1/2" X 3-3/16" XO, ID = 2.786" 10$54' 4-1/2" SOS/TTL 1 o83r ELMD Tr LOGGED 06/12/82 MILLOUT WgVDOW (G-OSA) 11619' - 11629' VVB_LHEAD= McEVOY ACTUATOR = OTIS K.B.'~EV = 65.6' BF. ELEV = 36.8' KOP = 3050' Max Angle = 96° ~ 12873' Datum MD= 11915' DatumTVD= 8800' SS ~0 8 B SA TES: WELL ANGL.E> 70° ~ 12141' 2117' S-112' CA-BAL-O SSSV LAND M1IP, ID = 4.562' 113-31e" CSG, 72#, L-80, ID = 12.347" I~ z7oa Minimum ID = 2.377" Ldf 12202' 3-3116" X 2-718" XO LNR PIN ID PERFORATION SUMMARY REf LOG: MCNL-GR-CCL 03!12107 ANGLE AT TOP PERF: 84' ~ 12245' Note: Rater to Protluction DB for historical rt data SIZE SPF INTERVAL OPN/SQZ DATE 2" 8 12245 - 12295 O 03114p7 2" 6 12350 -12405 O 03114p7 2" 6 12M0 - 12475 O 03M4p7 2" 6 12520 - 12550 O 03/14p7 Y 6 12840 • 120 O 03M4p7 7 6 13056 - 13070 O w123p9 2" 6 13100 - 13130 O w123p9 2" 6 13660 - 13830 C 03/13p7 ~5-112' TBG, 17#, L-80 IJ4S, .0232 bpf, ID = 4.892" ~TOPOF 7' LNR 13-1/2" LNR, 9.3#, L-80 STL, .0087 bpf, ID=2.992' ~ .0152 bpf, ID = 3.958' 10837' 1 9- 518' DJ PKR GAS LIFT MANDR~S ST MD TVD DE/ TYPE VLV LATCH PORT DATE 12 3012 3011 8 CA DMY RK 0 09/07/09 11 5462 4832 56 CA DMY RK 0 04/11103 10 7206 5821 54 CA DMY RK 0 09107!09 9 7347 5904 54 CA DMY RK 0 05/13/81 8 8259 6451 53 CA DMY RK 0 05!13181 7 8404 6536 54 CA DMY RK 0 05/13/81 6 9050 6913 50 CA DMY RK 0 01!22/04 5 9197 7007 51 CA DMY RK 0 05!13181 4 9771 7361 52 CA DMY RK 0 05!13!81 3 9913 7448 52 CA DMY RK 0 05!13181 2 10447 7788 48 CA DMY RK 0 05/13x'81 1 10589 7883 48 CA DMY RK 0 05/31x05 10657' ~ 5-112' CAMCO SLIDING SLV , ID = 4.500' 10723' BAKff2P3RS64LASSY 10743' 9-518' X 5-112' BAKER PKR, ID = 4.0" 10744' S-t12" X 4-t12" xo 10773 ELM 4-112" O11S X NIP, ID = 3.813" 13.70" BOT DEPLOY MENT SLV , ID = 3.00" I 10805 ELM I"'(4-1J2" OTIS XN NIP, MILL®TO 3.80" 10803' H3-112" HES X NP, ID = 10837' ~3-1/2' X 3-3116" XO, ID =2.786" 10854' 4-112' SOS/TTL MILLCd.1T WRVDDW (G-0aA) 1 1619' - 11629' 10837' ELMD TT LOGGED O6! 12182 TOC ~ ^-11415' ~ w,•fPSTOCK 11615' r-~ t~ 7" LNR, 29#, L-80 BTC, .0371 bpf , ID = 6.184' 12465' 3-3116" LNR, 6.2#, L-80 TGI .0076 bpf , ID = 2.80' ~~nerx~~1o3r~ I~zsrr' 11730' 3- 3116` KB LTP ID = 1.7 5' 12202' 11740' Top of 2-318" liner deployment sleeve '11830' 3-3116' pkrwhipstock ri1~ FBTD 13969' ~ 2-718' LNR, 6.4#, L-80 STL, .0058 bpf, ID= 2.441" 14004' A B 2-318" L-80 Lner, Cerrented & Perf'd 13095' DATE REV BY COMMENTS DATE REV BY COMMBJfS 06!14181 ORIGINAL COMPLETION 02/23!10 SMlJMD DRLGDRAFTCORRECTIONS 03!15107 NORDIC 1 CTD SIDETR4 CK (G-08A ) 03!17107 IPA G DRLG DRAFT CORRECl1DNS 04/07/07 BSE>'PAG GLV GO (04104107) 05131109 VUEGTLH GBP SETIA CPff2FS (04!23109) 10101/09 JLJ/SV GLV GO (09107109) PRUDHOE BAY UNfT 1NELL: G-OBA F~v1ff No: "106183 AA No: 50-029-20581-01-DO SEC 12, T1 1 N, R13E, 2506' FSL & 2367' FEL ~ Exploration (Alaska) STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other Q SET Pertormed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ MECHANICAL Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter uspended Well ^ PLUG 2.Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development Q Exploratory ^ 206-1830 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-20581-01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Numbe ~ ADLO-028285 PBU G-08A 10. Field/Pool(s): PRUDH OE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 14004 feet Plugs (measured) 13190' 12950' feet true vertical 9026.77 feet Junk (measured) None feet Effective Depth measured 13969 feet Packer (measured) 2608 10743 true vertical 9027.37 feet (true vertical) 2608 7987 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surtace 2700 13-3/8" 72# L-80 SURFACE - 2700 SURFACE - 2700 4930 2670 Intermediate Production 11300 9-5/8" 47# L-80 SURFACE - 11300 SURFACE 11300 - 8372 6870 4760 Liner 1129 7"29# L-80 10790 - 11619 8019 - 8600 8160 7020 Liner 3218 3-1/2"/3-3-16/2-7/8" 10766 - 14004 8016 - 9027 9.3#/6.2#/6.4# Pertoration depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# L-80 SURFACE - 10744 SURFACE - 7987 4-112" 12.6# L-80 10744 - 10854 7988 - 8062 Packers and SSSV (type, measured and true vertical depth) 9-5/8" DV PKR 2608 2608 9-5/8"X5-1/2" BAKER PKR 10743 7987 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ~~~ ~~;°~:~:t ~ :.. ~ _ . ~ , r~ ~ , ,.I U N ~ ~ 2010 Treatment descriptions including volumes used and final pressure: Alaska Oil ~ r~ Gertz. Corrxnission 13. Representative Daily Average Production or Injection Data nC Ot~~'P. Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sund ry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pr ble Title Data Management Engineer Signature Phone 564-4944 Date 6/28/2010 Form .~~sewr rvs^ M V ~~/~ r cLl /~f f G-08A 206-183 PERF ATTA[:HMFNT • Sw Name Operation Date Pert Operation Code - ---- --- ----------- Meas Depth Top -- Meas Depth Base Tvd Depth Top Tvd Depth Base G-08A 3/14/07 PER 12,245. 12,295. 9,041.17 9,045.51 G-08A 3/14/07 PER 12,350. 12,405. 9,043.81 9,039.68 G-08A 3/14/07 PER 12,440. 12,475. 9,037.8 9,037.03 G-08A 3/14/07 PER 12,520. 12,550. 9,037.63 9,037.27 G-08A 3/14/07 PER 12,640. 12,690. 9,033.09 9,028.65 G-08A 3/14/07 PER 13,660. 13,830. 9,016.48 9,027.11 G-08A 4/20/09 BPS 13,190. 13,195. 9,002.77 9,002.8 G-08A 4/23/09 APF 13,056. 13,070. 9,006.27 9,005.19 G-08A 4/23/09 APF -,. 13,100. 13,130. 9,003.38 9,002.58 G-08A 5/30/10 BPS 12,950. 12,245. 9,010.89 9,041.17 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • G-08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/29/20101''**WELL SI ON ARRIVAL*** (ELINE DRIFT AND CIBP w. WELLTEC ' TRACTOR) ~ INITIAL T/I/O = 150/600/0. 1WELL DRIFTED TO 13185' WITH WELLTEC TRACTOR AND 2.25" SWED_~,,, RAN BAKER 2-7/8" CIBP TO SET DEPTH, SETTING TOOL DID NOT STROKE, PLUG DID NOT SET, POOH. PERFORM CHECKS AT SURFACE, IGNITOR INITIATED, POWER CHARGE DID NOT BURN COMPLETELY. RUNNING IN HOLE WITH NEW PLUG. ***JOB CONTIUED ON 30 MAY 2010*** 5/30/2010. ***CONTINUED FROM 29 MAY 2010*** SET BAKER CIBP AT 12950 FT. TAGGED WITH TRACTOR AFTER ~ FINAL T/I/O =0/600/0. i***JOB COMPLETE*** FLUIDS PUMPED BBLS 2 meoh 1 diesel 3 Total TREE _ „ CM! ~ WELLHEAD = McEVOY ACTUATOR = OTIS KB. ELEV = 65.6' BF. ELEV = 36.8' KOP = 3050' Max Angle = 96° @ 12873' Datum MD = 11915' DatumTVD= 8800'55 13-318" CSG, 72#, L-80, ID = 12.347" I-{ 2700' Minimum ID = 2.377" @ 12202' 3-3116" X 2-7/8" XO LNR PIN ID { 5-112" TBG, 17#, L-80 U4S, .0232 bpf, ID = 4.892" I--I 10744' TOP OF 7" LNR I-{ 10790' I3-1/2" INR, 9.3#, L-80 STL, .0087 bpf, ID = 2.992" ~ 10837' 4-112" TBG, 12.6#, ~_„$,,,,,,,,,,,,,,,,,,,,,, o CSH, 10854' .0152 bpf, ID = 3.958" 9-518" CSG, 47#, L-80, ID = 8.681" 11289' WHIPSTOCK -1 11615' RA PIP TA G 11625' 7" LNR, 29#, L-80 BTC, .0371 bpf, ID = 6.184" 12485' PERFORATION SUMMARY REF LOG: MCNL-GR-CCl 03/12/07 ANGLE AT TOP PERF: 84° @ 12245' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OPWSOZ DATE 2" 6 12245 - 12295 O 03/14/07 2" 6 12350 - 12405 O 03/14/07 2" 6 12440 - 12475 O 03/14/07 2" 6 12520 - 12550 O 03/14/07 2" 6 12640 - 12690 O 03/14/07 2" 6 13056 - 13070 C 04/23/09 2" 6 13100 - 13130 C 04/23/09 2" 6 13660 - 13830 C 03/13/07 •O 8 A S ES: W ELL ANGLE > 70° @ 12141' - ~, - 2117' 5-1/2" CA-BAL-O SSSV LAND NIP, ID = 4.562" 2608' 9-518" DV PKR GAS L IFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 3012 3011 8 CA DMY RK 0 09/07/09 11 5463 4832 56 CA DMY RK 0 04/11/03 10 7207 5822 54 CA DMY RK 0 09107109 9 7347 5904 54 CA DMY RK 0 05!13181 8 8260 6451 53 CA DMY RK 0 05/13181 7 8404 6537 54 CA DMY RK 0 05!13!81 6 9051 6914 50 CA DMY RK 0 01/22/04 5 9197 7007 51 CA DMY RK 0 05/13181 4 9772 7362 52 CA DMY RK 0 05113/81 3 9914 7448 52 CA DMY RK 0 05!13/81 2 10448 7789 48 CA DMY RK 0 05/13/81 1 10590 7884 48 CA *DMY RK 0 05/10/10 "' GLM #1 = DMY HAS EXTEND® PACKING 10657' 5-1/2" CAMCO SLIDING SLV, ID = 4.500" 10723' BAKER PBR SEAL ASSY 1 10743' 9-518" X 5-1/2" BAKER PKR, ID = 4.0" 10744' 5-112" X 4-112" XO 10773 ELM 4-112" OTIS X NIP, ID = 3.813" 10786' 3.70" BOT DEPLOYMENT SLV, ID = 3.00" 10805 ELM 4-1/2" OTIS XN NIP, MILLED TO 3.80" 10805' 3-1/2" HES X NIP, ID = 2.813 10837' 3-1/2" X 3-3/16" XO, ID = 2.786" 10854' 4-112"soS1TrL 10837' ELMD TT LOGGED 06/12/8 ~___~_~ MILLOUT WINDOW (G-08Aj 11619' 11629' 3-3/16" LNR, 6.2#, L-80 TCII, I 12202' .0076 bpf, ID = 2.80" 12202' I-,13-3116" X 2-7/8" XO, ID = 2.377" 1 12950' ~2-718" CIBP(05/30/10) U~ 2-7/8" CIBP (04(23/09) PBTD -( 13969' r 2-718" LNR, 6.4#, L-80 STL, .0058 bpf, ID = 2.441" 14004' DATE REV BY COMMENTS DATE REV BY COMMENTS 05!14/81 ORIGINAL COMPLETION 02/23/10 SNVJMD DRLG DRAFT CORRECTIONS 03/15/07 NORDIC 1 CTD SIDETRACK (G-08A} 05/31/10 MBNUPJC GLV GO (05!10!10) 03/17/07 /PAG DRLG DRAFT CORRECTIONS 05/31/10 MV/PJC SET CIBP (05/30/10) 04/07/07 BSE/PAG GLV GO (04104/07) 05/31/09 WEGTLH CIBP SET/ADPERFS (04/23/09} 10/01(09 JLJ/SV GLV GO (09/07/09) PRUDHOE BAY UNIT WELL: G-08A PERMIT No: 206183 API No: 50-029-20581-01-00 SEC 12, T11 N, R13E, 2506' FSL & 2367' FEL BP Exploration {Alaska) n ~-~~~~ .;~ ~, .-~ "~ ~~ ~` m k ~~ - ~~ ~, ~: <, ~~~ ~~ ~o ~~ ~~~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporazy Internet Files\OLK9\Microfilm_Mazker.doc ~ ~ WELL LOG S TRANSM/TTAL PrtoAcrive DiAyroosric SeevicES, Iwc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/ Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 rFF f . h ~'. ` ~ ~~ lk7 G ~~'~~3 ~~ ~ -E' 1) Leak Detection - WLD 07-May-10 G08A 2) Signed Print Name: 1 BL/ EDE 50-029-20581-01 MAY ~ 12010 Date . D®r . ~ `~ A ..~ PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : pdsanchoraaeCa)memorvlog.com WEBSn'E : www.memorvloa.com C:\Documems and Settings\Diane wlliams\Desktop\Transmit_BP.docx OPERABLE: G-08A (PTD# 2061830) Tubing Integrity has been Restored Page 1 of 1 ~ • Maunder, Thomas E (DOA) From: NSU, ADW Welt Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, September 08, 2Q09 10:55 PM To: Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Area Mgr Central (GC1/3/FS3); GPB, GG1 OTL; GPB, GC1 Wellpad Lead; GPB, Weli Pad EKG; GPB, Prod Controtlers; GPB, Optimization Engr; Zamora, Chris A; GPB, Wells Opt Eng; Regg, James B {DOA); Schwartz, Guy L(DQA}; Maunder, Thomas E(DOA) Cc: NSU, ADW Well Integrity Engineer; Williams, Carrie Subject: OPERABLE: G-08A (PTD# 2061830) Tubi~g Integrity has been Restored All, G-08A (PTD# 2061834) passed an MITIA after dummy gas lift valves were set. The passing test verifies two competent barriers. The well has been reclassified as Operable and may be POP when convenient for operations. Please be careful when POPing as the IA is fluid packed. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 ~ a ;~ , '~~~{~~ . _~_. . „~~ ,~., _ . ~- ,~ t ~, 9/9/2009 STATE OF ALASKA > ALAS~OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS ~~ EI`~/ED s-/S-a~ MAY 1 2 2009 ~iaska Oil ~ Gas Cons. Commissii 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ pnr:hora4e Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory [~ 2os-1830 3. Address: P.O. Box 196612 Stratigraphic i'" Service ~~ 6. API Number: Anchorage, AK 99519-6612 50-029-20581-01-00 7. KB Elevation (ft): 9. Well Name and Number: 65.6 KB PBU G-08A 8. Property Designation: 10. Field/Pool(s): ADLO-028285 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 14004 feet Plugs (measured) 13190' 4/20/09 true vertical 9026.77 feet Junk (measured) None Effective Depth measured 13969 feet true vertical 9027.37 feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" Surface - 110 Surface - 110 Surface 2700 13-3/8" 72# L-80 Surface - 2700 Surface - 2700 4930 2670 Production 11300 9-5/8" 47# L-80 Surface - 11300 Surface - 8372 6870 4760 Liner 1129 7" 29# L-80 10790 - 11619 8019 - 8600 8160 7020 Liner 3218 3-1/2X3-3/16X2-7/8" 10786 - 14004 8016 - 9027 9.3#/6.2#/6.4# Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 SURFACE - 10744' 4-1/2" 12.6# L-80 10744' -10854' Packers and SSSV (type and measured depth) 9-5/8" DV PKR 2608' 9-5/8"X5-1/2" BAKER PKR 10743' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~,~5~~i5~~:J !VIAL. `'~ e~olj 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: 539 36260 17 1243 Subsequent to operation: 2827 11516 113 264 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory [~` Development Service [ Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG GINJ I WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O: Exempt: N/A Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature Phone 564-4944 `' Date 5/12/2009 Form 10-404 Revised 04/2006 ~~ ' a, I ~ I - ~'' ~~4 ~ ~ 2~Q~ ~ Submit Original Only G-08A 206-183 PFRF ~TTArHMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base G-08A 3/14/07 PER 12,245. 12,295. 9,041.17 9,045.51 G-08A 3/14/07 PER 12,350. 12,405. 9,043.81 9,039.68 G-08A 3/14/07 PER 12,440. 12,475. 9,037.8 9,037.03 G-08A 3/14/07 PER 12,520. 12,550. 9,037.63 9,037.27 G-08A 3/14/07 PER 12,640. 12,690. 9,033.09 .9,028.65 G-08A 3/14/07 PER 13,660. 13,830. 9,016.48 9,027.11 G-08A 4/20/09 BPS 13,190. - 13,195. 9,002.77 9,002.8 G-08A 4/23/09 APF 13,056. 13,070. 9,006.27 9,005.19 G-08A 4/23/09 APF 13,100. 13,130. 9,003.38 9,002.58 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE U • • G-08A ADESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/19/2009 '** Continue on WSR#4-20-09 **" CTU #5 w/1 3/4" coil. MIRU on well to set ~ CIBP, perforate. 4/20/2009 ----- *** Continued from WSR 4-20-09 *"* CTU#5 w/1 3/4" coil. Run CIBP add aperforations. <InterAct publishing> Continue rigging up on well. MU BOT BHA with Sch carrier to log well. PT. Open well pump 100 bbls 1 %KCL to kill well. RIH with logging tool. Tag TD at 13839' Log up to .12800' -paint flag at 13140' .program calls for CIBP to be set at 13140' and new pert btm at 13130' - 10' not :enough room at this depth and angle to get stretch/weight back to use CIBP for perf tie in -confer with CT Cord and set CIBP 50' deeper at 13190') POH verify , .good data -31' correction - MU/RIH with BOT 2.25" (2.22"od) CIBP -Set CIBP with center of element at 13190' -check set with 1 k weight down to verify plug se an no moving - c can re ease from CIBP - POH. Coil pulled up to -3.9' ctm. ;Swab check only could get 23 turns on both master and swab. Suspect pipe crimped or Hydrates. RIH with Pipe. Bull headed fluid down well. Continue to `work to clear in ector with i e. *"** Job in ro ress *""* ~_ ~~_.P__P.._~. ~._ .~ P. ~.~ _ ~ ~. ~_ 4/21/2009 *''" Continued from WSR #4-20-09 *"" CLU#5 w/1 3/4" coil. Set CIBP, add perforations. Pumping down back side with KCL reduce pressure on well. Continue to attempt to move pipe through tight spot on coil. Pump down well head, bled IA to OT. Continue pumping down well to lower pressure on well. Had well support on location to MU hard line to choke. Notify Pad Op /Nordic 2/ ~ Field Radio of venting gas. Bleed IA from 1320 to 0 in 3 hrs. Tbg increased to i 1220 same time frame. SI/ IA. Monitor WHP while prepping for well kill. Tbg slowly decreasing from 1220 to 1130 in 4 hrs.. Received confirmation on plan forward - On line to kill well -WHP increased to 2715 at 4.7 bpm -decreased to 2430 after 450 bbls (400 bbls is 1.5 x hole vol) fluid pumped -reduced rate to 3 , bpm for trucks to round trip WHP at 2100 SD pump -observe WHP -dropped 1390 psi in 20 min leveled at 720 -continue pumping. S/D pump rock catcher on inlet hose backed off caused 1 %KCL to kiddy pool. Est. 3 gals to ground. Everyone notified. Start pumping @ 4.2 gpm/WHP= 1400 psig. Total of 1450 bbls pumped @ 1550 psig. S/D pump monitor fall off. WHP dropped 1823 psig in 40 minutes. **** Job in progress ""*" 4/22/2009** Continued from WSR 4-21-09 "** CTU #5 w/ 1 3/4" coil, set CIBP add aperforations. <InterAct Publishing> Continue to monitor WHP. Swich to pumping Flopro down well head, 17.5 bbls flopro pumped, switched to 1 %KCL, pumped 205 bbls, switched to Diesel to freeze protect. Pumped 48 bbls, monitor well. Pressure started @ 2431 psig, work pressure down on well. Slowly bleed WHP down to zero -conduct 30 min no flow test -well dead. Prep o mspec col damage. Break off well strip over pipe 8' -observed collapsed pipe.- Stab back !ont well - PU 10'. Repeat previous pipe inspection steps and observed collapsed any viv wm close. no down same- Dbl clar F install straps pull fish to surface -check vlv for closure -close master /swab vlly )P test. Plan forward, make drift run pro out of hole. 4/23/2009. *"" Continued from WSR # 4-22-09*" CTU#5 w/ 1 3/4" coil, Set CIBP & add perforations. <InterAct Publishing >. Finished BOP test. PU additional lubricator. 33'. MU to well. PT 200 low/ 4500 high. RIH with 2.25" JSN. tag @ 13,238, puh free pipe at 13, 230' ctm. RIH to top of plua wash across perforations @ 2.0 bpm. POOH chasing flopro to surface. MU/RIH with 30' - 2" - ~6spf - 60° - PJ2006 HMX pert gun -Tag and tie into CIBP at 13224.6 ctm - PUH ;to bottom shot depth at 13130. Good indication gun fired and erfed int 13100 - 13130- POH -all shots fired -recovered 1/2" alum ball - MU/RIH with - '- 6spf - 60 - pert gun. Tag CIBP @ 13226.5', correct tag depth to `.13190' ctm. PU to perforates from 13 056' - 13070'. Drop 1/2" ball, ball on seat ;after 33 bbls. good indication gun fired. wi~Fi coil *"* job in progress "** **** NOTE !!***'` recovered 1/2"alum ball from CIBP setting tool laid down with collapsed coil on_4/22/09 *** _ _ _ 4/24/2009 CTU #5 w/ 1 3/4". set CIBP & add perforations. Continue OOH with gun Run#2 - At surface discuss swab check with all personnel. Continue swab checks. 34 '.turns to cls swab. Open up to freeze protect well head. closed swab, checked '....gun all shots fired. 1/2' ball recovered. Rig down unit, move to next well. ** fob FLUIDS PUMPED BBLS 384 50/50 METH 266 2% KCI 93 1 % XS KCI 330 GALLONS N2 743 Total ~y'i~ DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2061830 Well Name/No. PRUDHOE BAY UNIT G-OSA Operator BP EXPLORATION (ALASKA) INC MD 14004 TVD 9027 Completion Date 3/15/2007 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log IVo Samples IVo DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR ! RES, CNL / GR ! CCL Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number Name ' D~ D Asc Directional Survey i.Rpt/ END C L D/iyectional Survey 15678 "I i /R i ti it d as on v y n uct es s '' -~ED C Lis 16017 Neutron Xg ,/I~leutron fQ t LIS V ifi ti p ; er ca on ~D C Lis 17420/Induction/Resistivity "LO .Induction/Resistivity Induction/Resistivity ~g Gamma Ray g See Notes Well Cores/Sampl es Information: Interval Name Start Stop ~~~ Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH _ Received Comments 11600 14004 Open 5/8/2007 11600 14004 Open 5/8/2007 11454 14003 Open 11/9/2007 ATR, RPM, GR, RAM, ROP w/PDS and PDF graphics 10413 13882 Open 3/13/2006 LIS Veri, GR, CNT 5 Blu 10405 13875 Open 3/13/2008 MCNL, GR, CNL, 11-Mar- 2007 11454 11004 Open 1/14/2009 LIS Veri, GR, Rop, RAD, RAS, RPD, RPS 11454 11004 Open 1/14/2009 LIS Veri, GR, Rop, RAD, RAS, RPD, RPS 25 Col 11615 14004 Open 4/14/2009 MD MPR, GR 9-Mar-2007 25 Col 11615 14004 Open 4/14/2009 TVD MPR, GR 9-Mar-2007 25 Col 11615 14004 Open 4/14/2009 MD GR 9-Mar-2007 2 Col 11440 13980 Open 1/14/2008 Depth Shift Monitor Plot Sample Set Sent Received Number Comments API No. 50-029-20581-01-00 UIC N DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2061830 Well Name/No. PRUDHOE BAY UNIT G-08A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20581-01-00 MD 14004 TVD 9027 ADDITIONAL INFORMATION W ll C d? Y~ ore e Chips Received? T7lC-- Analysis ~l7-IV' Received? Completion Date 3/15/2007 Completion Status 1-OIL Current Status 1-OIL Daily History Received? ~N Formation Tops ~./ N UIC N Comments: Compliance Reviewed By. - - -- - - -- - - -- Date: --- --- INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: G-08A 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#: 1368209 ~c~~ -~f~~ ~ 7~ Sent by: Catrina Guidry Date: Ol~~r09 " `1' F F~ ~I__ _ Received by: ~~ ~ ~ Date: ~ ~ t ~ ~ ~'~. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING ~ RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ B~N~ 7260 Homer Drive ~ Anchorage, Alaska 99518 Direct: (907) 267-6612 INTEQ FAX: (907) 267-6623 .` r-, ®~i BAKER HV6ME5 Saker Atlas PRINT DISTRIBUTION LIST CUMYANY BY EXYLUKA'f1UN (ALASKA) lNC COUNTY NUK'1'H SLOYE BUKUUCiH WELL NAME G-08A STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 1/12/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 1368209 Copies of Copies Digital Copies oC Copies Digital Each Log of Film Dala Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC ] 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 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 I 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 By BAKER ATLAS-PDC 17015 Aldine Westfield Houston Texas 77073 This Distribution List Completed Bv' ~~°~ n '~f1CC? _ `~ .~4Jt1:J Page 1 of 1 03/12/08 d~r'~~~m~ps~~~r~ NO. 4629 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,Endicott Ulnll .Inh 1t Inn noeerinfinn Hato RI Cnlnr rn C-17B 12031461 USIT tl 03/09/08 1 1 1-67/T-20 12014001 USIT L .~ 03/09/08 1 1 E-21B 11661157 MCNL a' 06/19/07 1 1 02-35B 11216177 MCNL ~ 02/09/06 1 1 C-34A 11216194 MCNL - / Q( 05/11/06 1 1 G-08A 11628761 MCNL ~ ~ 05/f f/07 1 1 04-01A 11661146 MCNL 05/15/07 1 1 t'LtA,t AI:KNUWLtU(Gt Fitl:tlYl F3Y 51laNINla ANU litl UFiNINIi UNt I:VYY tAl:ri 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 - 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~s a~'~ t ,1~~~~Pj Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by: Date I 1-09-2007 Transmittal Number:92919 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Douglas Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 05-10C '3~: { ~~-:; mow, G-048 ~(~-~..1.~....._. ~._1 S ~.~-7 ~. ,- ~ .-~ _ __. _ Please sign and Return one copy of this transrruttal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 ., ~; _ ~~- _` _ ,3 ' ~, e Petrotechnical Data Center LR2- l 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 1 9-66 1 2 I/ ,~~ • p~ 2 ~ ~~~7 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska ~ t ~~. ~~as C~~~YPI3#I~FLETION OR RECOMPLETION REPORT AND LOG anchorage Revised 04/26/07: Corrected TPI 8~ BHL 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC25.105 zoAACZS.>>o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 3/15/2007 12. Permit to Drill Number 206-183 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 3/5/2007 13. API Number 50-029-20581-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 3/9/2007 14. Well Name and Number: PBU G-08A 2773 FNL, 2367 FEL, SEC. 12, T11 N, R13E, UM Top of Productive Horizon: 3447' FNL, 20' FWL, SEC. i8, T11N, R14E, UM 8. KB Elevation (ft): 65.6' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2710' FNL, 856' FEL, SEC. 13, T11 N, R13E, UM 9. Plug Back Depth (MD+TVD) 13969 + 9027 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 657864 y- 5968867 Zone- ASP4 10. Total Depth (MD+TVD) 14004 + 9027 Ft 16. Property Designation: ADL 028305 TPI: x- 660377 y_ 5962966 Zone- ASP4 Total Depth: x- 659485 y- 5963684 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ~ Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD DIR / GR / RES, GNL / GR / CCL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING D EPTW TVD HOLE AMOUNT SIZE WT.' PER FT. GRADE TOP BOrrOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2700' Surface 2700' 17-1/2" 3441 cu ft Arctics t II 9-5l8" 47# L-80 Surface 11300' Surface 8372' 12-1/4" 16 cu ft Class' 130 cu ft AS II 7" 29# L-80 10790' 1161 8019' 8600' 8-1/2" 390 cu ft Class'G' s-vz~ x 33116" x z-~~s° .3# 16.2# / 6.4# L-80 10786' 14004' 8016' 9027 4-1/8" 212 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TuerwG RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter, 6 spf 5-1/2", 17#, L-80 10744' 10743' MD TVD MD TVD 4-1/2", 12.6#, L-80 10744' - 10854' 12245' - 12295' 9041' - 9046' 12350' - 12405' 9044' - 9040' 2rj, ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12440' - 12475' 9038' - 9037' DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED 12520' -12550' 9038' - 9037' 12640' - 12690' 9033' - 9029' 2500' Freeze Protected with 60/40 McOH 13660' - 13830' 9016' - 9027' 26. PRODUCTION TEST Date First Production: April 8, 2007 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 4/10/2007 Hours Tested 6 PRODUCTION FOR TEST PERIOD OIL-BBL 1,015 GAS-MCF 2,813 WATER-BBL -0- CHOKE SIZE 74 GAS-OIL RATIO 2,772 FIOW TUbing Press. 360 Casing PreSSUre 650 CALCULATED 24-HouRRATE• OIL-BBL 4,059 GAS-McF 11,252 WATER-BBL -0- OIL GRAVITY-API (CORK) 27. GORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 12/2003 t J ~ ~ ~ ~ j„~ ;CONTINUED ON REVERSE SIDE ~~_, ,~,1" (~ ~ 20~~ V 28. GEOLOGIC MARKS 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NnME MD TVD and attach detailed supporting data as necessary. If Ro tests were conducted, state "None". Top of CGL /Zone 3 11760' 8716' None Base of CGL /Zone 2C 11823' 8776' 23S6 /Zone 2B 11871' 8823' 22TS 11956' 8903' 14N /Zone 1 B 12112' 9011' 30. List o#Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. ~ / ~" / t - f~ Z`~/v Signed TerrieHubble Title Technical Assistant Date PBU G-08A 206-183 Prepared By Name/Number.~ Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Mary Endacott, 564-4388 INSTRUCTIONS GeNe~~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: True vertical thickness. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". ITeM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only G-08A, PTD # 206-183 Subject: G-08A, PTD # 206-183 From: "Hubble, Terrie L" <Terre.Hubble@bp.com> Date: Thu, 26 Apr 2007 14:05:29 -0800 To: bob_fleckenstein(c~admin.state.ak.us Hi Bob, Yes, I see that the TPI and BHL are quite wrong. I don't know what happened, but I am sending over a corrected page (2 actually). Please just replace them. Thanks for catching the error! Terrie 1 of 1 4/27/2007 7:17 AM STATE OF ALASKA ~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION RECEI~/E~ APR 1 3 2007 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Qi(& Gas Cons. Commission 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAaczs.~os zoAACZS.»o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Abna~n 3/15/2007 ~J" ~ 12. Permit to Drill Number 208-183 - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 3/5/2007 13. API Number 50-029-20581-01-00 ~ 4a. Location of Well (Governmental Section): Surface: ' 6 ' F 7. Date T.D. Reached 3/9/2007 14. Well Name and Number: PBU G-08A - 2773 FNL, 23 7 EL, SEC. 12, T11N, R13E, UM Top of Productive Horizon: 2710' FNL, 856' FEL, SEC. 18, T11 N, R14E, UM 8. KB Elevation {ft): 65.6' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 5202' FNL, 284' FWL, SEC. 13, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 13969 + 9027 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 657864 y- 5968867 Zone- ASP4 10. Total Depth (MD+TVD) 14004 + 9027 Ft 16. Property Designation: ADL 028305 TPI: x- 660377 y_ 5962966 Zone- ASP4 Total Depth: x- 659485 y- 5963684 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD DIR / GR / RES, CNL / GR / CCL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MO SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2700' Surface 2700' 17-1/2" 3441 cu ft Arcticset II 9- / " 47# L-80 Surfa 11300' S rface 372' 12-1/4" 1668 cu ft Class'G' 130 cu ft AS II 7" 29# L-80 10790' 8019' 8600' 8-1/2" 390 cu ft Class'G' s-vz~~ x 3-3116" x zaia~~ .3# 16.2# 16.4# L-80 10786' 14004' 8016' 9027' 4-1 /8" 212 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter, 6 spf 5-1/2", 17#, L-80 10744' 10743' MD TVD MD TVD 4-1/2", 12.6#, L-80 10744' - 10854' 12245' - 12295' 9041' - 9046' 12350' - 12405' 9044' - 9040' 25. ACID, FRACTURE,-CEMENT SQUEEZE, ETC. 12440' - 12475' 9038' - 9037' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 12520' -12550' 9038' - 9037' 12640' - 12690' 9033' - 9029' 2500' Freeze Protected with 60/40 McOH 13660' - 13830' 9016' - 9027' 26. PRODUCTION TEST Date First Production: April 8, 2007 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 4/10/2007 Hours Tested 6 PRODUCTION FOR TEST PERIOD OIL-BBL 1,015 GAS-MCF 2,813 WATER-BBL -0- CHOKE SIZE 74 GAS-OIL RATIO 2,772 Flow Tubing Press. 360 Casing Pressure 650 CALCULATED 24-HOUR RATE OIL-BBL 4,059 GAS-MCF 11,252 WATER-BBL -0- OIL GRAVITY-API {CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheen., if necessary). Submit core chips; if none, state "none". ~ C~ ,:'L~i~,Jd None ` '3~===~~ Form 10-407 Revised 12/2003 C NTINUED ON REVERSE SIDE 1,~y 28. GEOLOGIC MARKE 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top of CGL /Zone 3 11760' 8716' None Base of CGL /Zone 2C 11823' 8776' 23SB /Zone 26 11871' 8823' 22TS 11956' 8903' 14N /Zone 1 B 12112' 9011' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ / Signed Terrie Hubble Title Technical Assistant Date « f PBU G-08A 206-183 Prepared By Name/Number. Terrie Hubble, 564-4628 Drillin Engineer: Well Number Permit No. / A royal No. g Mary Endacott, 564-4388 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 1212003 Submit Original Only BP EXPLORATION Page 1 of 16 Operations Summary Report Legal Well Name: G-08 Common Well Name: G-08 Spud Date: 4/19/1981 Event Name: REENTER+COMPLETE Start: 2/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 3/15/2007 Rig Name: NORDIC 1 Rig Number: N1 Date ~ From - To Hours Task Code NPT Phase Description of Operations 2/25/2007 10:00 - 22:00 12.00 MOB P PRE Move rig from C-32B to G-08A. 22:00 - 00:00 2.00 MOB P PRE 2/26/2007 00:00 - 04:00 4.00 BOPSU P PRE 04:00 - 15:00 11.00 BOPSU P PRE 15:00 - 15:15 0.25 BOPSU P 15:15 - 16:45 1.50 BOPSU P 16:45 - 18:00 1.25 KILL P 18:00 - 20:00 2.00 ZONISO P 20:00 - 20:30 0.50 ZONISO P 20:30 - 21:30 1.00 ZONISO P 21:30 - 23:45 I 2.251 ZONISO I P 23:45 - 00:00 0.25 ZONISO P 2/27/2007 00:00 - 01:50 1.83 ZONISO P 01:50 - 02:40 0.83 ZONISO P 02:40 - 04:00 I 1.331 STWHIPI P 04:00 - 04:30 I 0.501 STWHIPI P 04:30 - 07:30 3.00 STWHIP P 07:30 - 08:00 0.50 STWHIP P PRE PRE WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT PJSM before backing over well. Bleed WHP to zero. Position rig over well. Accept rig at 2200 hrs. Spot cutting box. NU BOP NU BOPE and secure. NU lubricator. Pressure /Function Test ROPE. AOGCC rep John Crisp waived witnessing the BOP test. Send test report to AOGCC. Fill pits up with 290 bbls, 2% KCL water. Send vac off for second load. PJSM and THA. Review procedure, hazards and mitigation for pulling the BPV. RU lubricator and BPV retrieving tool. RIH. Turn 7.5 turns, correct MU. Pull up above master valve. SIWHP = 600 psi. Close master. Retrieve BPV and layout lubricator and tools. Kill well with 2% KCL water, bullhead 5 bpm at 700 psi. Pump press increased to 1200 psi at 270 bbls. Fill pits. Load Baker mill and motor. Test inner reel valve to 3500 psi. Close master valve and bleed off gas from tree. Stab injector on to well. Circulate 16 bbl MEOH to tiger tank. PT hardline to tiger tank 2500 psi. OK. Circulate balance of MEOH to TT.( Hard line crew couldn't get triplex during initial RU) Behead coil and replace stripper. Pull test to 35K and PT to 3500 psi. MU milling BHA with LEFT HAND mill and motor. Stab on to well. Zero mechanical and electronic counters. Open master 230 psi Shutin pressure. RIH with closed choke. Continue to RIH wo pump. Well head pressure 289 psi. PT 302 bbls. Bleed off gas RIH at min rate.4 bpm RIH to 10790 UP Wt 42k. SHut down pump . 18K DN. RIH tag at 10814 Electronic and 10817 mechanical. Correct electronic to 10804. Mechanical cannot be corrected and remains at 10817'. PU bring pump up to 1.9 bpm 1250 psi PT 274 bbl. No fluid returns gas only. At PT 254 bbp. 2.2 bpm at 1926 psi. Crude in returns divert out side. Mill at 2.5 bpm ~ 2260 psi , increase to 2333 psi. brine to surface PT 177. Time mill. Loss rate 1.5 bbl/min time mill from 10803 To 10805. No motor work seen. RIH tag and MW at 10808 possible scale. RIH to 10840. Back ream twice at 2.48 bpm at 2160 psi, 1.3 bpm loss rate. POH thru nipple dry &RIH thru nipple dry. No Problem. RIH at min circulating rate no returns. RIH 12100 stop pump. RIH 29 fpm tag twice at 12253'.electronic. Mechanical 12272 un corrected. Up wt 41 K PU to 12200. PT 99 bbl. Nipple to TD depths 1455' Mechanical. 1449' Electronic. Circulate in very high vis used Flo Pro and lay in 100 bbl. POH. Pump 1.4 bpm, losing 0.8 bpm. Lay out BHA. MIII gauged at 3.79". Printed: 3/26/2007 10:31:11 AM ~ ! BP EXPLORATION Page 2 of 16 Operations Summary Report Legal Well Name: G-08 Common Well Name: G-08 Spud Date: 4/19/1981 Event Name: REENTER+COMPLETE Start: 2/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 3/15/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours j Task Code ~ NPT Phase Description of Operations 2/27/2007 08:00 - 14:30 6.50 STWHIP N WAIT WEXIT Wait for N2 unit and MEOH. N2 Crew was busy until 0200 hrs on another job. 14:30 - 17:00 2.50 STWHIP N WAIT WEXIT N2 unit heater problem wait on mechanic. 17:00 - 18:00 1.00 STWHIP P WEXIT Blow down reel with N2. 18:00 - 21:00 3.00 STWHIP P WEXIT PJSM, M/U internal CTC. Pull test. Pull coil stub to reel. Secure coil on reel with chains and crossbar, RD hard line, Cleared snow drifts to establish path for CT reel trailer, 21:00 - 22:45 1.75 STWHIP P WEXIT PJSM, Load out CT reel, spot on G-pad, loaded pipeshed with 18 joints of 2 3/8" PH6 22:45 - 00:00 1.25 STWHIP P WEXIT PJSM, Move in, spot reel, PU a-coil reel, PJSM, M/U internal CTC, Pull test 2/28/2007 00:00 - 02:00 2.00 STWHIP P WEXIT Pull E-coil across, stab injector, Cut off internal grapple, RU hard line 02:00 - 03:15 1.25 CEMT P LNR1 Offload Baker equipment, PU to rig floor, strap and rabbit 18 jts of 2 3/8" PH6, Cut 12' of CT, exposed 15' of eline 03:15 - 05:00 1.75 STWHIP P WEXIT Install Baker CTC, pull test CTC, RU a-line collector 05:00 - 05:15 0.25 CASE P LNR1 PJSM w/ rig crew and Baker, discussed operational procedures, safety hazards and safety precautions 05:15 - 05:30 0.25 CASE P LNR1 RU handling tools for 2 3/8" tbg, dressed out slips, can not find parts for 2 3/8" elevators, Nordic called out elevators from Baker rentals, checked tbg, IA and OA pressures, all 0 psi. 05:30 - 06:00 0.50 CASE N WAIT LNR1 Waiting on 2 3/8" elevators from Baker rentals 06:00 - 08:00 2.00 CASE P LNR1 PU ball catcher sub, 15 jts PH-6 swivel 08:00 - 09:00 1.00 STWHIP P WEXIT Fold back pigtail and insert back into coil. Install XO and circulating hose. Fill coil with 58.8 bbls. PT coil 3500 psi OK. 09:00 - 10:30 1.50 CASE N SFAL LNR1 Near Miss. While picking up little Jerks to make up tool joint the tugger line snagged the rear expanded metal chain guard on the injector. The guard was picked up out of its keepers and fell to the floor brushing against two hand who were making the connection. No injuries or property damage. Guard weight 22# and fell 10.5'. Job was shut down and investigated by Bob Laule Ron Holmes Eloy Mu?iz Alan Graff and rig crew. IR # 2170785 documents investigation. 10:30 - 12:00 1.50 CASE P LNR1 RIH to 8000'. 12:00 - 12:30 0.50 CASE P LNR7 Position reel for ball drop. Drop 5/8" phenolic ball. Launch with 900 psi. Circulate 2.73 bpm @ 2130 psi. Landed @53.9 bbls 60.2 bbl calculated. Shear at 2730 Psi pinned for 2400 psi. 12:30 - 13:15 0.75 CASE P LNR1 Drop 7/8" steel ball. Launch with 1100 psi. Circulate 2.67 bpm ~ 1830 psi. Landed ~ 51.7 bbls 60.2 bbl calculated. Shear at 3650 Psi. Pinned for 3200 psi. 13:15 - 14:45 1.50 CASE N WAIT LNR1 Warm up second motor 30 min. POH 14:45 - 16:15 1.50 CASE P LNR1 Pull 360 ' of Eline from PH-6. Megger E Line.OK (2000+ Meg Ohms, &470hms continuity test) 16:15 - 17:00 0.75 CASE P LNR1 Stand back PH-6. 17:00 - 19:30 2.50 CASE P LNRf MU, RIH w/ 2 7/8" x 3 3/16" x 3 1/2" liner Hanger Assy, OAL = 403.23' 19:30 - 20:30 1.00 CASE P LNR1 MU, RIH w/ Liner running tool assy, SELRT, Disconnect, X-O's, 15 jts of 2 3/8" PH6 20:30 - 21:30 1.00 CASE N SFAL LNR1 Found torn injector pick-up sling, Replaced with new sling 21:30 - 22:00 0.50 CASE P LNR1 MU x-o, swivel, x-o to CTC, Stab inj 22:00 - 00:00 2.00 CASE P WEXIT RIH w/ Liner Assy, present depth at 8125' 3/1/2007 00:00 - 01:15 1.25 CASE P LNR1 RIH, Tagged Btm at 12253', PU Wt 42k, S/O Wt 23.5k, S/O 10k, mixed 30 bbls of 2ppb biozan in pill pit Printed: 3/26/2007 10:31:11 AM BP EXPLORATION Operations Summary Report Page 3 of 16 Legal Well Name: G-08 Common Well Name: G-08 Spud Date: 4/19/1981 Event Name: REENTER+COMPLETE Start: 2/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 3/15/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To j Hours Task Code ~ NPT Phase Description of Operations 3/1/2007 01:15 - 01:45 0.50 CASE P LNR1 01:45 - 02:00 0.25 CASE P LNR1 02:00 - 03:30 I 1.501 CASE ) P LNR1 03:30 - 03:45 0.25 CASE N DFAL LNR1 03:45 - 04:00 0.25 CASE P LNR1 04:00 - 04:15 I 0.251 CASE ~ P ~ I LNR1 04:15 - 08:15 I 4.00 I CEMT ~ N ~ WAIT I LNR1 08:15 - 08:45 0.50 CEMT P LNR1 08:45 - 10:00 1.25 CEMT P LNR1 10:00 - 13:30 I 3.501 CEMT I P I I LNRi 13:30 - 14:00 I 0.501 CEMT I P I I LNR1 14:00 - 15:30 1.50 CEMT N DFAL LNR1 15:30 - 16:30 1.00 FISH N DFAL LNR1 16:30 - 16:45 0.25 FISH N DFAL LNR1 16:45 - 18:45 2.00 FISH N SFAL LNRi 18:45 - 21:15 I 2.501 FISH I N I DFAL I LNR1 21:15 - 00:00 2.75 FISH N DFAL LNR1 3/2/2007 00:00 - 01:30 1.50 FISH N DFAL LNR1 01:30 - 02:00 0.50 FISH N DFAL LNR1 Brk circ at 2.12/2.16bpm w/ 1400/ 1377psi Drop 5/8" phenolic ball, circ down at 1.93bpm at 1200psi, hold PJSM with rig and cmt crews, discussed cement job, safety concerns, safety precautions and safety hazards. Slowed pumps down to .5bpm, 210psi after pumping 44 bbls, micro motion unstable do to gas in returns, divert FloPro returns overboard, increased rate to .80bpm, 344psi after pumping 67.5bbls, increased rate to 1.06bpm, 526psi, slow rate to .86bpm, 344psi, surging pump in between several time, pumped total of 77.1bbls, calculated volume 60.2 bbls Shut pumps down, check ball drop sub, did not find ball Bring pump up to 1 bpm, ball on seat after pumping a total of 79bbls, shear ball seat w/ 3600psi, PU to Up Wt, Wt fell off slightly indicating SELRT released from deployment sleeve, S/O with 10k down Wt Circ at 1.90bpm, 1500psi, taking returns of gassed up flo-pro mud Cement job delayed at the request of town engineer while waiting on SLB coil cade modeling results on liner/CT during cement job. PJSM for cement job. RU water to Cementers flood lines and PT lines. DS had fresh water release to pad . Pump cement to rig. Zero in total based on MM. Pump 16.6 bbl 15.8 ppg cement and displace with 32.6 bbl Bio followed with KCL. Displace cement to 2 bbl short of liner wiper plug volume ~ 74.6 bbls. Full returns. PU Up Wt 42k. Pull up to 12338 and Park ct. Circulate 5 bbls (2 cement+3 Bio). RIH tag 23K ~ 12253. set down -40K,(-16 on wt indicator) start pumping getting returns 1 bpm ~ 770 psi. should be closed system against the liner wiper plug. Repeat operation. PU to 12238. RIH tag 12253 set -46K on liner( -23K on indicator). Start pumping 1 fo 1 returns. Attempt to pump off. PU white pumping 1.7 bpm (~ 1200 psi still 1 for 1 returns. stop at 12241. RIH Stop ~ 12241. RIH pumping to 12261 set down -35K (-11 k on indicator) Still 1 for 1 returns. Suspect that liner isn't released. decided to POH and have a look. Circulate out cement at 3 bpm while POH. POH to BHA. Total of 74 bbl of contaminated flopro and KCL recovered. Stand back PH-6 tubing. LD running tools . No Liner. Suspect the reverse flapper valve in liner wiper plug failed. Plan forward operations. PU fishing BHA. RIH to 603' Retaining plate on reel motor was discovered to have a broken weldment on the stud that locks it in place. SLB welded bolt back to retainer plate and replaced nut RIH tagged and engaged liner at 11857', Up Wt 41 k, Dn Wt 21 k, attempt to pull free w/ 55k, released GS, P/U 100', RIH, re-engaged liner, pulled free w/ 64k POH to BHA, Up wt 45k off btm, .42bpm, 92psi POH LD GS retrieving Tool BHA LD Baker Deployment sleeve w/ pup jt, Pulled wet, liner wiper Printed: 3/26!2007 10:31:11 AM • ! BP EXPLORATION Page 4 of 16 ~ Operations Summary Report Legal Well Name: G-08 Common Well Name: G-08 Spud Date: 4/19/1981 Event Name: REENTER+COMPLETE Start: 2/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 3/15/2007 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To I Hours I Task I Code I NPT I Phase 3/2/2007 02:00 - 02:30 0.50 f FISH N DFAL LNR1 02:30 - 04:30 I 2.001 FISH I N I DFAL I LNR1 04:30 - 05:00 0.50 EVAL P LNR1 05:00 - 06:00 1.00 EVAL P LNR1 06:00 - 06:30 0.50 EVAL P LNR1 06:30 - 10:15 3.75 EVAL P LNR1 10:15 - 12:15 2.00 EVAL N DFAL LNR1 12:15 - 16:30 4.25 EVAL N DFAL LNR1 16:30 - 17:45 1.25 EVAL P 17:45 - 18:30 0.75 STWHIP P 18:30 - 18:45 0.25 STWHIP P 18:45 - 17:15 22.50 ZONISO P 17:15 - 20:30 ~ 3.25 ~ ZONISO ~ P 20:30 - 23:00 2.50 ZONISO P 23:00 - 00:00 1.00 ZONISO P 3/3/2007 00:00 - 01:30 1.50 ZONISO N 01:30 - 01:45 0.25 ZONISO P 01:45 - 03:45 I 2.00 I ZONISO P 03:45 - 04:15 I 0.501 ZONISO I P 04:15 - 07:15 3.00 ZONISO I P 07:15 - 08:30 1.251 ZONISO ~ P 08:30 - 10:30 2.00 ZONISO ~ P 10:30- 13:15 2.75 STWHIPP 13:15 - 16:00 2.75 STWHIP P 16:00 - 19:45 3.75 STWHIP P 19:45 - 22:15 I 2.501 STWHIPI P LNR1 WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WAIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Description of Operations plug w/flapper was gone (launched) PJSM, RU head pin, unable to break circ, pressured up to 1000 psi, released pressure, RD head pin POH, LD wet liner, found liner wiper plug on landing collar w/ flapper in closed position, still intact. Small particles of fine debris around sealing area of flapper Clearing and cleaning rig floor, spot S/L unit and PDS van PJSM w/ all involved personnel on S/L operations RU and running caliper log, PU, RU SLB S/L PJSM with change out crew. RIH with slick line caliper. No Data, full of metal debris. Wait on arrival of new caliper. Second Calliper run Good Data identifing the pipe within API spec at ws setting depth 11800 - 11500. Rig down slickline unit. Attempt Infectivity test, pressured up to 2000psi, held for 30 mins with minimum bled off. Unable to establish injection rate. Load out and release SLB E-line PJSM w/ rig crew, review change of plans, discussed operational procedure for running cmt BHA RU handling tools, MU Cmtg BHA, 2 7/8" jet nozzle, 6 Stds of 2 3/8" PH6, X-O, CTC, stab injector RIH w/ Cmtg BHA, tagged up at 12195' Circ at 2.27bpm, 824psi, Up Wt 45k, S/O Wt 21 k Wait on Lab results on cmt, circ at 2.55bpm, 1050psi Held PJSM w/ cmt and rig crews, reviewed operational procedure for cmt job Fin RU cmt equipment, prime pumps, pump 5 bbls of FW, test lines to 4000 psi, mix and pump 25 bbls of 15.8 ppg CI G cement, pumped 15 bbls of biozan followed by 45 bbls of KCL water, lay in cement f/ 12195' to 11450', POH to 10760', Drop 7/8" Aluminum ball, circ w/ 2.57 bpm, 1040psi, pump another 15 bbls biozan sweep RIH to 11665', pressure increased f/ 1100 - 1300 psi at 2.57bpm circ and dress off cmt w/ 2.57bpm, 1300psi, Paint EOP flag at 11277' POH as biozan rounds nozzle, circ at 2.70bpm, 1375psi, wash thru completion accessories slowly, cmt in returns Standback PH6 tubing and LD nozzel. NO 7/8 Aluminum BALL. 15' of E wire exposed. PU swizzel stick Stab on to well and flush stack. Will pump coil volumn 2.7 bpm ~ 1230 psi. Attempting to recover ball while waiting on SLB Eline. SLB crew timed out from previous day resulted in late start. Pumped a total of 235 bbls. Open master valve. Pop off well and LD swizzel stick. No Ball. Pull back injector and circulate thru hose. Spot Eline unit. PJSM with E-line and Baker. RU E-line. RIH with Baker 4 1/2" x 7" Gen II WS WEXIT Tie-in correction -9.2'. Tag TOC 11647' ELM. Working wire. WS wants to stay high side. worked up into tbg tail, RIH at various speeds, several times with consistant highside results WEXIT POH to a-line BHA Printed: 3/26/2007 10:31:11 AM BP EXPLORATION Fage 5 of 16 Operations Summary Report ~~ Legal Well Name: G-08 Common Well Name: G-08 Spud Date: 4/19/1981 Event Name: REENTER+COMPLETE Start: 2/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 3/15/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To ~ Hours i Task Code NPT Phase Description of Operations 3/3/2007 22:15 - 23:15 ~ 1.00 ~ STWHIP P WEXIT POH w/ BHA #6, LD a-line tools and WS, RD a-line, inspected 23:15 - 00:00 0.75 STWHIP P WEXIT 3/4/2007 00:00 - 00:15 0.25 STWHIP P WEXIT 00:15-01:45 ~ 1.50STWHIP~P ~ WEXIT 01:45-02:15 0.50 STWHIP P WEXIT 02:15 - 04:15 2.00 STWHIP P WEXIT 04:15-04:301 0.25ISTWHIPP (WEXIT 04:30 - 05:00 0.50 STWHIP P WEXIT 05:00 - 06:00 1.00 STWHIP N DFAL WEXIT 06:00-06:45 0.75 STWHIP N DFAL WEXIT 06:45-08:00 1.25 STWHIP N DFAL WEXIT 08:00-08:30 0.50 STWHIP N SFAL WEXIT 08:30-09:30 1.00 STWHIP N SFAL WEXIT 09:30 - 12:00 2.50 STWHIP N DFAL WEXIT 12:00 - 12:30 0.50 STWHIP N DFAL WEXIT 12:30 - 13:00 0.50 STWHIP N DFAL WEXIT 13:00 - 15:45 2.75 STWHIP N DFAL WEXIT 15:45 - 17:30 1.75 STWHIP N DFAL WEXIT 17:30-20:15 2.75 STWHIP P WEXIT 20:15-00:001 3.75STWHIP~P I (WEXIT 3/5/2007 00:00 - 01:00 1.00 STWHIP P WEXIT f~ ~ \~, ~ 01:00-03:30 2.50 STWHIP P WEXIT 03:30 - 04:00 I 0.501 STWHIPI P I I WEXIT 04:00-04:301 0.501STWHIPIP I (WEXIT 04:30 - 05:15 I 0.751 STWHIPI P I I WEXIT 05:15-05:451 0.501STWHIPIP I (WEXIT 05:45-08:45 I 3.OOISTWHIPIP I (WEXIT WS, OK C/O encoder to Baker, replace pack-off Cut and megger E Line.OK (1875 Meg Ohms, 470hms continuity test), cap off the end of a-line RU return line to pits, perform slack management reversing thru kill line up coil, taking returns to pit, listening for e-coil line movement to cease Cut 370' of CT, 15' of a-line, install SLB CTC Behead, a-line check,(2000 Meg Ohms, 470hms continuity test), MU whipstock Assy BHA #7, X-O, UOC, LOblind, X-O, Nozzle, Attempt to circ, froze up RIH to 732', thaw out CT, break circ at 1.5bpm, 700psi, circ 30bbls POH, bk out inj, RU, PT CTC MU whipstock Assy BHA #7 EDC failed surface test. RIH to 750' to thaw coil. POH swap out EDC. Stab and RIH to 200' Correct over lapped raps on reel. Open EDC RIH pumping 2 bpm. Tie in correction -4 MWD depth -20 CT depth. Start Bio down hole. RIH to 11632.5 placing TOW at 11615'. TF 195. Close EDC. WS sheared at 3200 psi. PU confirm can circulate thru tool. Open EDC. POH continue circulating well to Bio. LD whip stock running tool and PU milling BHA. RIH, tag top of whipstock at 11615' corrected depth, pinch point at 11619.6', top of window(unoffical depth), UP Wt 45k, Dn Wt 18.2k, FS 2.55bpm, 2540psi Mill 3.8" window thru 7" liner, 2.53 bpm, 2644 - 2750psi, 1 fph, .5 - 3k WOB. Top of window at 11619.6'. Control milling at ihr/ft. Milled to 11622.8'. Mill 3.8" window thru 7" liner, 2.53 bpm, 2644psi, 1 fph, 2 - 4k WOB. Top of window at 11619.6'. steady milling to 11624'. Control mill 3.8" window thru 7" finer to 11625.8' with 2.54/2651 psi, 3 - 4k WOB, ifph ave BOP, stalled out, PU above window, reamed down slowly to 11625.8' Control mill 3.8" window thru 7" liner to 11626' with 2.62/2700psi, 1 - 2k WOB, ifph ave BOP, stalled out at 11625.8', 11626.3', PU above window after each stall, reamed down slowly to btm Drilled 10' formation to 11626' - 11636' with 2.6/2618psi, 21fph BOP, 1k WOB. Geo confirmed Z-4 in samples. Backream/dress window/rat hole w/ 2.6bpm, 2500psi, 3x & drift 2x. Window looks clean. Tentative window depths are: TOWS/TOW = 11615'/11619', RA PIP Tag = 11625'. BOW = 11626'. Up Wt 45.1 k, Dn Wt 18k, offloading pits to dirty vac trk Displace CT to new 8.6 ppg flopro mud with 12ppb K-G & 2% L-T POH, Displace wellbore to new 8.6 ppg flopro mud with 12ppb Printed: 3/26/2007 10:31:11 AM BP EXPLORATION Page 6 of 16 ~ Operations Summary Report Legal Well Name: G-08 Common Well Name: G-08 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date j From - To Hours Task ~ Code NPT 3/5/2007 05:45 - 08:45 3.00 STWHIP P 08:45 - 09:00 0.25 STWHIP P 09:00 - 09:15 0.25 BOPSU P 09:15 - 10:30 1.25 DRILL P 10:30 - 13:00 2.50 DRILL P 13:00 - 13:45 0.75 DRILL P 13:45 - 19:45 6.00 DRILL P Start: 2/21 /2007 End: Rig Release: 3/15/2007 Rig Number: N1 Phase Description of Operations W EXIT W EXIT W EXIT PROD1 PROD1 PROD1 PROD1 19:45 - 20:30 0.751 DRILL N SFAL PROD1 20:30 - 22:30 2.00 DRILL P ', 22:30 - 23:00 0.50 DRILL P 23:00 - 00:00 1.00 DRILL P 'I 3/6/2007 I 00:00 - 06:45 6.75 DRILL P ~ i 06:45 - 09:30 2.75 DRILL P t ~~ 09:30 - 11:30 2.00 DRILL P 11:30 - 14:00 2.50 DRILL P 14:00 - 14:15 0.25 DRILL P 14:15 - 14:30 0.25 DRILL N 14:30 - 15:10 0.67 DRILL N 15:10 - 15:25 0.25 DRILL P 15:25 - 18:00 2.58 DRILL P 18:00 - 20:15 2.25 DRILL P 20:15 - 21:45 1.50 DRILL P 21:45 - 22:00 0.25 DRILL P Spud Date: 4/19/1981 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DFAL PROD1 DFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 K-G & 2% L-T LD milling assy and PU building BHA. Mill 3.8 go 3.79 NO GO. Function test BOP. PU 2.0 drilling BHA to build ramp to target. RIH to 11515 CT = 11500 MWD depth. Tie - in log. Correction -5'. RIH tag at 11636. Directionally drill 2.65/2.66 bpm ~ 3200 psi, FS= 3125 psi, Annular pressure 4178, DH well bore pressure 4631 psi, ECD 9.41 WOB 1K, ROP 22. Confirm RA ~ 11625' placing window 11619 to 11626. PT 323 bbls. Unable to PU off Btm, Troubleshoot problem, found auto drill counter balance dial was closed which will not allow upward movement of CT when auto drill is on Directionally drill 2.68/2.68 bpm @ 2950 psi, Up Wt 45k, Dn Wt 19k, Annular pressure 4233, DH well bore pressure 4558 psi, ECD 9.45 WOB 1K, ROP 12. PT 322 bbls. Wiper Trip to window Directionally drill 2.6/2.6 bpm (~ 3000 psi, Up Wt 45.4k, Dn Wt 19k, Annular pressure 4233, DH well bore pressure 4558 psi, ECD 9.45 W OB 1 K, ROP 10 PT 320 bbls. Directionally drill 2.65/2.67 bpm ~ 3000 psi, TF 289 - 330, Dn Wt 19k, Annular pressure 4286 psi, DH well bore pressure 4901 psi, ECD 9.44, WOB 3K, ROP 15 - 20', PT 311 bbls. Wiper/ POH for more motor bend. Swap out bit (4.3 ringout) with Hycalog 4.25" Bi-Center Bit, RIH w/ Drlg BHA # 11 RIH to 11655', closed EDC at 11550', TOWS at 11615', TF 208, no problems sliding thru window w/o pumps, open EDC once below window Tie-in to PIP tag at 11625', logging down f/ 11655' - 11675', 0 correction w/ MWD, -17' correction w/ CT, note: GR tool 40' above bit PU to 11630', MAD pass from 11630' to 11691', logging speed at +/- 500'/hr, mwd tool shut down due to command response it did not like, trying to get resistivity to read correctly, POH to 11630' to repeat MAD pass Madd pass from 11630' to 11731', logging speed at +/- 500'/hr, circ at .36bpm, 872psi, problem w/ resistivity tool as above, work pipe, circ at min rate, troubleshoot problem not sure software or tool problem RIH to 11950', troubleshoot resistivity while drilling Directionally drill 2.65 bpm, 2925 psi, FS 2.65/2.66 bpm ~ 2800 psi, TF 332, Dn Wt 20k, Annular pressure 4256 psi, DH well bore pressure 4818 psi, ECD 9.53, WOB 1 - 2K, ROP 23', PT 309 bbls. Resistivity working at 11957', set up converse factor to read Ohms vs milliOhms to correct interpretation problem Drill to 12030' with 30-15L TF, 2.55/2.55bpm, 2800/3150psi, 2.5k DWOB, 9.52ppg ECD & 20fph ave ROP. Up wt = 42k. Run-in wt = 20k. PVT = 307bb1s. IAP = Opsi. OAP = 50psi. Drill to 12085' with 30-15L TF, 2.55/2.55bpm, 2800/3150psi, 1.5k DWOB, 9.55ppg ECD & 40fph ave ROP. Drill to 12100' with 30-15L TF, 2.55/2.55bpm, 2800/3150psi, Printed: 3/26/2007 10:31:11 AM BP EXPLORATION Operations Summary Report Page i of 16 ~ Legal Well Name: G-08 Common Well Name: G-08 Spud Date: 4/19/1981 'Event Name: REENTER+COMPLETE Start: 2/21/2007 End: 'Contractor Name: NORDIC CALISTA Rig Release: 3/15/2007 Rig Name: NORDIC 1 Rig Number: N1 Date i From - To I Hours Task Code NPT Phase Description of Operations 3/6/2007 3/7/2007 13/8/2007 21:45 - 22:00 0.25 DRILL P PROD1 22:00 - 22:25 0.42 DRILL P PROD1 22:25 - 00:00 1.58 DRILL P PROD1 00:00 - 03:45 3.75 DRILL P PROD1 03:45 - 04:15 0.50 DRILL P PROD1 04:15 - 06:40 2.42 DRILL P PROD1 06:40 - 07:00 0.33 DRILL N STUC PROD1 07:00 - 08:00 1.00 DRILL N STUC PRODi 08:00 - 11:00 3.00 DRILL P PRODi 11:00 - 12:00 1.00 DRILL P PROD1 12:00 - 13:00 1.00 DRILL P PRODi 13:00 - 15:15 I 2.251 DRILL I P I I PROD1 15:15 - 15:30 I 0.251 DRILL I P I I PRODi 15:30 - 16:15 I 0.751 DRILL I P I I PROD1 16:15 - 18:00 I 1.751 DRILL I P I I PROD1 18:00 - 18:50 0.83 DRILL P PROD1 18:50 - 20:05 1.25 DRILL P PROD1 20:05 - 20:15 0.17 DRILL P PROD1 20:15 - 21:15 1.00 DRILL P PROD1 21:15 - 22:15 1.00 DRILL P PROD1 22:15 - 00:00 1.75 DRILL P PROD1 00:00 - 00:10 0.17 DRILL P PRODi 00:10 - 00:20 0.17 DRILL P PRODi 00:20 - 01:00 0.67 DRILL P PROD1 1.5k DWOB, 9.60ppg ECD & 70fph ave ROP. Wiper trip clean to window. RBIH clean to btm. Drill to 12160' with 30-60L TF, 2.55/2.55bpm, 2800/3250psi, 3.5k DWOB, 9.64ppg ECD & 40fph ave ROP. Drill to 12250' with 60-85L TF, 2.55/2.55bpm, 2800/3250psi, 1.5k DWOB, 9.68ppg ECD & 30fph ave ROP. Wiper trip clean to window. RBIH clean to btm. Drill to 12328' with 45L TF, 2.55/2.55bpm, 2800/3250psi, 3.5k DWOB, 9.75ppg ECD & 40fph ave ROP, PVT 296bb1s. Drilling ahead with no motor work, PU, working pipe, stuck on btm, shut down pumps Monitor well, waiting while hole is relaxing Working pipe w/ overpull to 82k, several times, brk circ at 1.5 bpm, 1850psi, reduced rate to min at .20bpm, 950psi, S/O w/ do wt of -4k, circ at min rate, PU to 60k ,circ at min rate, increased rate to 2.65bpm, pulled CT free POH to BHA # 11 POH w/ BHA #11, LD bit and Res tool PU BHA #12 for lateral section w/ rebuilt 4 1/8" x 3 3/4" Hughes bi-center bit, adjust motor to 1.2 deg bend, HOT, new USMPR, DGS, DPS, EDC, Powercomms, Wear Protection Sub, LOC, UOC, X-O, MU to CTC, Stab Inj RIH to 11655', closed EDC above window, TOWS at 11615', TF 210, no problems sliding thru window w/o pumps, open EDC once below window Tie-in to PIP tag at 11625', logging down f/ 11655' - 11677', -8 correction w/ MWD, -44' correction w/ CT, note: GR tool 40' above bit RIH to 12300', MAD pass to btm, mtr work at 12147 to 12151', stalled mtr at 12151' 2x, work thru effected hole sevveral times, ok Drill to 12475' w/ 89R - 110E TF, 2.65/2.64 bpm, 3300 psi, FS 2.65 bpm ~ 2900 psi, Dn Wt 19k, Annular pressure 4607 psi, DH well bore pressure 5320 psi, ECD 9.91ppg, WOB 2-6K, ROP 69 -103fph', PT 282 bbls. Wiper trip to window. Max O/pull across 14N area - 5k. RBIH as drilled TF with only minor wt bobbles thru the 14N shale. Drill to 12570' with 55-85L TF, 2.65/2.65bpm, 2850/3250psi, 2k DWOB, 9.90ppg ECD & 80fph ave ROP. Up wt = 42k. Run-in wt = 20k. PVT = 280bb1s. IAP = Opsi. OAP = 65psi. Short BHA wiper. Conduct kick while tripping drill with an excellent response by the SLB driller. Drill to 12615' with 45L TF, 2.65/2.65bpm, 2900/3250psi, 1.5k DWOB, 9.92ppg ECD & 55fph ave ROP. Wiper trip to window. Relatively clean across 14N area. RBIH to btm. Geo wants to aim for 95degs inc. Drill to 12723' with 35L TF, 2.65/2.65bpm, 2950/3250psi, 2k DWOB, 9.94ppg ECD & 65fph ave ROP. Drill to 12728' with 55L TF, 2.65/2.65bpm, 2950/3250psi, 2k DWOB, 9.96ppg ECD & 65fph ave ROP. Short BHA wiper. Meanwhile work on centrifuge. Drill to 12800' with 60-80L TF, 2.65/2.65bpm, 2950/3250psi, 2k DWOB, 9.99ppg ECD & 115fph ave ROP. Printed: 3/26/2007 10:31:11 AM i BP EXPLORATION Page 8 of 16 Operations Summary Report Legal Well Name: G-08 Common Well Name: G-08 Spud Date: 4/19/1981 Event Name: REENTER+COMPLETE Start: 2/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 3/15/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase ~ Description of Operations 3/8/2007 01:00 - 02:30 1.50 DRILL P PROD1 Wiper trip to 10700' (into 5-1/2" tbg). Relatively clean across 14N area. RBIH to below window. 02:30 - 02:45 0.25 DRILL P PROD1 Log down GR & tie into RA Pip tag. Add 6' to CTD. ~! 02:45 - 03:00 0.25 DRILL P PROD1 RBIH to btm with only one slight bobble across the 14N. ~ 03:00 - 05:30 2.50 DRILL P PROD1 Drill to 12950' with 80L TF, 2.65/2.65bpm, 2950/3350psi, 2.5k DWOB, 9.88ppg ECD & 75fph ave ROP. 05:30 - 06:45 1.25 DRILL P PROD1 Wiper trip to window was relatively clean across 14N, RBIH, ~ slight bobbles f/ 12145' to 12151', in 14N interval 06:45 - 09:00 2.25 DRILL P PROD1 Drill to 13100' with 135 - 30L TF, 2.71/2.70bpm, 3400/3350psi, 09:00 - 10:25 1.42 DRILL P 10:25 - 11:50 1.42 DRILL P 11:50 - 13:40 1.83 DRILL P 13:40 - 14:15 0.58 DRILL P 14:15 - 15:30 1.25 DRILL P 15:30 - 17:00 1.50 DRILL P 17:00 - 17:45 0.75 DRILL P 17:45 - 17:55 0.17 DRILL P 17:55 - 18:20 0.42 DRILL P 18:20 - 20:45 20:45 - 21:50 21:50 - 00:00 3/9/2007 00:00 - 02:45 02:45 - 03:45 2.42 DRILL P 1.08 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 2.171 DRILL I N I STUC I PROD1 2.75 DRILL N STUC PROD1 1.00 DRILL N STUC PROD1 4.6k DWOB, 9.9ppg ECD, Annular Pressure 4571 psi, DH well bore pressure 5410psi & 60 - 75fph ave ROP. Displaced well with new 8.6ppg Flo-Pro mud with 14ppb Kla-Gard W iper trip to window was relatively clean across 14N, RBIH, one slight bobble at 12155' in 14N interval Drill to 13251' with 111 - 74L TF, 2.65/2.62bpm, 2900/2900psi, 2k DWOB, 9.59ppg ECD, Annular Pressure 4423psi, DH well bore pressure 5039psi, PVT 298bb1s & 145 - 95fph ave ROP. Wiper trip to 10700' (into 5-1/2" tbg). Relatively clean across 14N area. RBIH to below window. Tie-in to PIP tag at 11625', logging down f/ 11655' - 11677', +4 correction w/ MWD, +3' correction w/ CT, note: GR tool 40' above bit, RIH to btm, one bobble at 12150' Control Drill to 13400' with 90L TF, 2.60/2.59bpm, 3300/3290psi, 1.5 - 2k DWOB, 9.75ppg ECD, Annular Pressure 4539psi, DH well bore pressure 5072psi, PVT 292bb1s & 120fph ave ROP. Wiper trip to window was relatively clean across 14N, RBIH, one slight bobble at 12150' in 14N interval Control Drill to 13500' with 60L TF, 2.66/2.68bpm, 3245/3245psi, 2.5k DWOB, 9.76ppg ECD, Annular Pressure 4530psi, DH well bore pressure 5228psi, PVT 282bb1s & 135fph ave ROP. Short BHA wiper, Up Wt 43.5K, Dn Wt 16.8k, FS 2.64bpm, 2750psi Control Drill to 13550' with 82L TF, 2.65/2.63bpm, 3275/3275psi, 2.3k DWOB, 9.76ppg ECD, Annular Pressure 4530psi, DH well bore pressure 5315psi, PVT 282bb1s & 95 - 120fph ave ROP. Wiper trip clean to window. RBIH clean to btm. Up wt = 40k. Run-in wt = 17k. PVT = 272bb1s. IAP = Opsi. OAP = 125psi. Drill to 13634' with 60-80L TF, 2.65/2.65bpm, 2800/3100psi, 1.5k DWOB, 9.80ppg ECD & 85fph ave ROP. Get differentially stuck. Call out crude. Meanwhile put CT in neutral wt. CBU, S/D pumps & relax CT for 15mins. Work pipe btw -5k to 90k without success. Circ for 5mins. S/D pumps & relax CT for another 20mins. Work pipe several times btw -10k to 90k without success. Continue W.O. crude. Meanwhile relax & work CT additional 2x without success. Crude arrive onsite. Conduct Reid vapor pressure measurement of crude - OK C~ Opsi. Hook up to crude transport & pump 10bbls of crude. Chase crude & pump out Printed: 3/26/2007 10:31:11 AM ~ ~ BP EXPLORATION Page 9 of 16 Operations Summary Report Legal Well Name: G-08 Common Well Name: G-08 Spud Date: 4/19/1981 Event Name: REENTER+COMPLETE Start: 2/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 3/15/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 3/9/2007 02:45 - 03:45 1.00 DRILL N STUC PROD1 5bbls out of the bit. Stack down -10k & pull CT free with 85k 03:45 - 04:00 0.25 DRILL P PROD1 04:00 - 04:45 0.75 DRILL P PROD1 04:45 - 06:45 2.00 DRILL C PROD1 06:45 - 07:50 1.08 DRILL C PROD1 07:50 - 08:20 0.50 DRILL C PROD1 08:20 - 08:35 0.25 DRILL C PROD1 08:35 - 09:00 0.42 DRILL C PROD1 09:00 - 10:55 1.92 DRILL C PROD1 10:55 - 11:15 0.33 DRILL C PROD1 11:15 - 11:20 0.08 DRILL C PROD1 11:20 - 11:50 0.50 DRILL C PROD1 11:50 - 12:10 0.33 DRILL C PROD1 12:10 - 12:15 0.08 DRILL C PROD1 12:15 - 14:15 2.00 DRILL P PRODi 14:15 - 14:30 0.25 DRILL P PROD1 14:30 - 17:50 3.33 DRILL P PROD1 17:50 - 21:30 3.67 DRILL P PROD1 21:30 - 21:45 0.25 DRILL P PROD1 21:45 - 22:45 1.00 DRILL P PROD1 pull. Short BHA wiper. Drill to 13700' with 100E TF, 2.65/2.65bpm, 2800/2950psi, 1.5k DWOB, 9.78ppg ECD & 85fph ave ROP. Wiper trip relatively clean to 10700' (into 5-1/2" tbg). Relatively clean across 14N area. RBIH to below window. Tie-in to PIP tag at 11625', logging down f/ 11645' - 11663', +7 correction w/ MWD, +6' correction w/ CT, note: GR tool 40' above bit, RIH to btm, no bobbles, hole clean Control Drill to 13775' with 103E TF, 2.65/2.65bpm, 3100/3115psi, 1 - 2k DWOB, 9.86ppg ECD & 127fph ave ROP. Short BHA wiper to 13675', Up Wt 41 k, Dn Wt 13.5k, FS at 13760', 2.61 bpm, 2808psi Control Drill to 13850' with 103E TF, 2.73/2.71 bpm, 3055/3075psi, 1 - 2k DWOB, 9.96ppg ECD & 130 - 145fph ave ROP. Wiper trip clean to window. RBIH clean to btm. Up wt = 41.5k. Run-in wt = 15k. PVT = 189bb1s. IAP = Opsi. OAP = 115psi, circ rate out 2.71/2.55bpm, 2944/2970psi, circ rate in 2.44/2.72bpm, 2825/2840psi Control Drill to 13900' with 70L TF, 2.70/2.65bpm, 3105/3120psi, 1 - 2k DWOB, 9.98ppg ECD & 165 - 150fph ave ROP. Short BHA wiper to 13800', Up Wt 41 k, Dn Wt 14.6k Control Drill to 14001' with 56 - 100E TF, 2.70/2.65bpm, 3200/3215psi, 1 - 2k DWOB, 10.03ppg ECD & 50 - 135fph ave ROP. Added 60 bbls of new FLO-Pro mud to system, PVT 244bb1s Short 351' wiper trip to 13650', Up Wt 41 k, Dn Wt 14.6k Drill to 14004' with 56 - 100E TF, 2.70/2.65bpm, 3200/3215psi, 1 - 2k DWOB, 10.03ppg ECD & 50 - 135fph ave ROP, stacking weight, little motor work, formation change heavy oil(HOT), Geologist called TD at 14004' Wiper trip clean to window. RBIH clean to btm. Up wt = 42.5k. Run-in wt = 15k. PVT = 239bb1s. IAP = Opsi. OAP = 120psi, circ rate out 2.68/2.55bpm, 3051/3076psi, circ rate in 2.44/2.72bpm, 2825/2840psi Tie-in to PIP tag at 11625', logging down f/ 11645' - 11667', +8 correction w/ MWD, +8' correction w/ CT, note: GR tool 40' above bit, Mad Pass at 800fph f/ 11667' to 14004', set down at 12171', TF 70L, increase pump rate f/ .50bpm to 2.63/2.60bpm 3080/3080psi, work thru hole 2x, OK, set down at 12600', PU, RBIH, no problems passing 12600', pumping 60bb1 liner pill POH, lay-in liner pill across openhole. OOH. S/B injector. Held PJSM & THA for UD drilling BHA. Flush BHA with water & air. UD drilling BHA#12. Bit grade 2/7/I with some missing gauge cutters (probably due to faulty bonding during rebuilt). Recover lost 7/8" AL ball in flow sub in the UOC/LOC. The 7/8" AL ball was pumped during cementing job on 3/312007 & got lodged in & causing erosion of the flow sub. Printed: 3/26/2007 10:37:11 AM BP EXPLORATION Page 10 of 16 ~ Operations Summary Report Legal Well Name: G-08 Common Well Name: G-08 Spud Date: 4/19/1981 Event Name: REENTER+COMPLETE Start: 2/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 3/15/2007 Rig Name: NORDIC 1 Rig Number: N1 i Date From - To j Hours Task !Code NPT Phase j Description of Operations 3/9/2007 22:45 - 23:15 0.50 CASE P RUNPRD M/U side jet nozzle to CTC & stab injector on well. Shut in swab. Meanwhile R/U N2 pumpers. 23:15 - 23:30 0.25 CASE P RUNPRD PJSM for B/D CT with N2. 23:30 - 00:00 0.50 CASE P RUNPRD Pump 40bbls of water ahead followed by 10bbls of McOH spacer. 3/10/2007 00:00 - 00:15 0.25 CASE P RUNPRD P!T N2 lines - OK. 00:15 - 01:45 1.50 CASE P RUNPRD Blow down CT with N2 & bleed down. 01:45 - 02:00 0.25 CASE P RUNPRD PJSM for stripping off & pulling back CT to the reel. 02:00 - 04:15 2.25 CASE P RUNPRD P/U injector & cut off CTC. Prep end of CT for internal grapple. Slip grapple connector into CT, M/U & pull test. Strip-off CT from injector & spool back CT stub to reel. Secure CT with crossbar and chains & prep reel for shipment. Release reel drive bushings. P/U eline CT reel with bridge crane. 04:15 - 04:30 0.25 CASE P RUNPRD PJSM with Veco crew on CT reel swap. 04:30 - 06:00 1.50 CASE P RUNPRD Open up bombay doors & lower eline CT reel onto Veco trailer. P/U replacement eline-free CT reel into reel house with bridge crane & align drive pins & bushing. 06:00 - 06:30 0.50 CASE P RUNPRD PJSM w/ change out crew on RU CT hardline, MU intemal CTC, Stab Gooseneck and Injector, PVT 267bbts, RD Baker encoder f/ injector 06:30 - 09:00 2.50 CASE P RUNPRD RU hardline, install internal CTC, pull test, pull across pipeshed roof, stab gooseneck and injector, cut off grapple, head up CTC, pull test 09:00 - 09:15 0.25 CASE P RUNPRD RU, brk out stuffing box, C/O pack-off, MU stuffing box 09:15 - 09:55 0.67 CASE P RUNPRD RU dart catcher sub, RU McOH pup, unable to gravity feed f/ same, moved out pup, moved in 290bb1 McOH tanker, RU line to pump manifold 09:55 - 10:55 1.00 CASE P RUNPRD Pump 5bbis of McOH, 5bbls of water, P/test hardline to reel to 3500psi, OK. Pump, fill CT with mud, Pressure test inner reel valve to 3500psi - OK 10:55 - 11:30 0.58 CASE P RUNPRD Load, launch wiper dart, Chase dart with mud, pig CT, Dart bumped on catcher at 57.7bbls, calculated displacement 57.6bbls for 15442' of 2 3/8" CT, PVT 204bb1s 11:30 - 12:00 0.50 CASE N RREP RUNPRD Troubleshoot mud pump #1, bring pump #1 online, when pressuring up to 2000psi a loud knocking noise in the pump line occurs consists, causing the pump pressure to fall of by 500 - 700psi, then regaining the lost pressure as pumping continues. At the same time the pulsation damper does not track the pump pressure until the noise sounds occurs in which the pulsation damper pressures gauge increases to pump pressure. Continue troubleshooting pump #1 Also, discovered that the rod oiler was not working on pump #2, found overload switch for the rod oiler on the motor starter tripped, reset switch, rod oiler working. 12:00 - 12:45 0.75 CASE P RUNPRD Pressure test CTC to 4000psi, OK, PU Baker to rig floor, Std back Injector 12:45 - 13:00 0.25 CASE P RUNPRD RU floor, pipeshed and handling tools for 2.875" liner 13:00 - 13:15 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for running 2-7/8" liner. 13:15 - 14:30 1.25 CASE N SFAL RUNPRD Master valve frozen up, partially open with 19 turns, thawed out with steam, opened valve with 34 turns, installed fusible cap on SSV 14:30 - 16:00 1.50 CASE P RUNPRD Run 2-7/8", 6.4#, L-80, STL Liner with BOT Indexing guide Printed: 3/26/2007 10:31:11 AM ~ ~ BP EXPLORATION Page 11 of i 6 Operations Summary Report Legal Well Name: G-08 Common Well Name: G-08 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours i Task Code NPT --- -- 3/10/2007 14:30 - 16:00 1.50 CASE ~ P 16:00 - 16:30 0.50 CASE P 16:30 - 18:00 1.50 CASE P 18:00 - 18:15 I 0.251 CASE I P 18:15 - 19:00 I 0.75 I CASE I P 19:00 - 21:00 1 2.001 CASE ! P 21:00 - 22:45 I 1.751 CASE I P 22:45 - 23:15 I 0.501 CASE I N 23:15 - 00:00 f 0.751 CASE 1 P 3/11/2007 100:00 - 02:00 I 2.001 CASE I P 02:00 - 03:00 1.00 CASE P 03:00 - 05:00 2.00 CASE P 05:00 - 05:15 0.25 CEMT P 05:15 - 07:15 2.00 CEMT P 07:15 - 09:15 I 2.001 CEMT I P 09:15 - 10:00 0.75 CEMT P 10:00 - 10:45 0.75 CEMT P 10:45 - 14:30 I 3.75 I EVAL I P WAIT Spud Date: 4/19/1981 Start: 2/21/2007 End: Rig Release: 3/15/2007 Rig Number: N1 Phase ~ Description of Operations RUNPRD shoe, float collar, 1 jt, float collar and Landing collar followed with 58 jts of 2-7/8" liner, 10' pup jt, Make Up Torque 1500 ft-Ibs, fill pipe RUNPRD FIII Liner, Swab Elevators, PJSM on handling 3 3/16" liner RUNPRD M/U 2-7/8" STL x 3-3/16" TCII X/O sub, PU, RIH w/ 45jts of 3-3/16" 6.2# L-80 TCII, XO & 1 jt of 3-1/2" 9.3# L80 STL liner. RUNPRD Held PJSM with new crew. Conduct THA for M!U &RIH with completion liner. RUNPRD Continue M/U X nipple & 3-1/2" pups. M/U Baker Deployment sleeve &CTLRT. OAL - 3227.44'. Pull test CTLRT by P/U Inr string. RUNPRD RIH with liner, circ ~ min rate. Wt check ~ 11500': Up = 45k. Run-in wt = 20k. Continue RIH smoothly ~ 50fpm thru window into OH. Observe minor wt bobbles across shales. Set down 12902'. P/U & work Inr with -ve wt to btm tagged ~ 14025'. P/U ~ 64k & retag TD ~ same depth. Establish circ C~ 0.3bpm/1350psi. PUH to ball drop position @ 14001'. RUNPRD Load 5/8" steel ball &circ with mud @ 2.02/1.98bpm & 2350psi. Set down 10k down on CTLRT. Slow down pumps to 0.61 bpm/1450psi ~ 40bbls away. Ball on seat fib 49.7bbls. Pressure up to 4450psi & release CTLRT. P/U ~ 36k & confirm release. RUNPRD W.O. KCL trucks to arrive onsite. Meanwhile circ mud around ~ 2.8/2.8bpm & 3060psi. RUNPRD Circ weN to 2% KCL water with double friction reducer ~ 2.80/2.78bpm & 1710psi. Send used FloPro to MI for reconditioning. Meanwhile R/U SLB cementers. RUNPRD Continue circ well to 2% KCL water with double friction reducer ~ 2.80/2.78bpm & 1710psi. RUNPRD Set clock 1 hour forward for daylight savings. RUNPRD Load balance KCL into pits & mix KCL-bio displacement pill. Meanwhile continue circulating KCL C~J 1.89/1.84bpm & 680psi. RUNPRD PJSM with all personnel concerning cementing operations. Continue circulating 2% KCL @ 1.88/1.82bpm & 670psi. RUNPRD Batch mix 38bbls 15.8ppg 'G' latex cmt with additives. Cmt to wt @ 05:40hrs. Flush/PT lines to 4k. Pump 37.7bbls cmt slurry ~ 1.51/1.42bpm & 1050psi. Close inner reel valve & clean lines. Load/launch CTWP with 500psi. Confirm dart has passed inner reel valve. Chase with 30bbls bio-KCL ~ 2.77/2.73bpm & 2050psi. Slow down pumps to 1.60bpm/620psi C~ 50bbls. CTWP engage LWP ~ 58.2bbls away. Shear plug with 3500psi. Continue displacing LWP C~3 2.60/2.56bpm, 2300psi & bump ~ 79.2bbls away with 1000psi over. Bleed off & check floats -held. Pressure up to 500psi & sting out of liner. 37.6bbls cmt pumped around shoe. CIP @ 07:10hrs. RUNPRD POOH to BHA at 100fpm pumping at 0.55bpm to replace CT voidage only. RUNPRD POH with BHA, LD and Off-oad Baker equipment RUNPRD RU Handling tools 2 3/8" PH6 Tbg, Held PJSM, LD 6 stds from Derrick LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for M/U milling and MCNL logging BHA. Printed: 3/26/2007 10:31:11 AM BP EXPLORATfON Page 12 of 16 ~ Operations Summary Report Legal Well Name: G-08 Common Well Name: G-08 Spud Date: 4/19/1981 Event Name: REENTER+COMPLETE Start: 2/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 3/15/2007 Rig Name: NORDIC 1 Rig Number: N1 Date I'I From - To Hours Task ~ Code NPT Phase Description of Operations 3/11/2007 10:45 - 14:30 3.75 EVAL P LOWERI M/U 2.27" mill, BOT motor, x-o, 2 jts CSH, x-o, SWS MCNL-GR-CCL in carrier, circ sub, hyd disc, x-o, 102 jts CSH, rattled every std, recovered ice plugs from ends along w/ scale debris, x-o, lower and upper disc, checks, lower NRJ, upper NRJ, Baker x-o and Baker CTC, Stab Inj. OAL = 3256' 14:30 - 15:15 0.75 EVAL N DFAL LOW ER1 Attempt to pump down CT, std pipe manifold, along with Baker choke froze up, thawed out, Note outside temperature -36 degrees, rig floor temperature below 32 degrees, RIH with mill and MCNL logging BHA to 5000', unable to circ, pressured up to 1500psi 15:15 - 16:00 0.75 EVAL N DFAL LOWERI POH to BHA ~ 16:00 - 17:15 1.25 EVAL N DFAL LOW ER1 RU Handling tools, Held PJSM, POH w/ BHA, wet, LD MHA, Std back 51 stds, 1 1/4" CS Hydril, LD plugged lower MHA, MCNL carrier was plugged up with debris falling out of 1 1/4" CSH, cleaned MCNL tools and carrier 17:15 - 19:30 2.25 EVAL N DFAL LOWERI PU MCNL carrier, RU head pin, attempt to circ, pressured up to ', 900psi, RD hd pin 19:30 - 19:45 0.25 EVAL N DFAL LOWERi PJSM for UD rest of BHA & for P/U &RIH MCNL tools & 1-1/4" CHS tbg. 19:45 - 20:30 0.75 EVAL N DFAL LOWERI UD 2jts of 1-1/4" CSH tbg, XO, 2-1/8" straight motor & mill. Could turn motor with wrenches. B/D 2jts of CSH &MCNL carrier with air. 20:30 - 23:15 2.75 EVAL N DFAL LOWERI P/U logging/cleanout BHA #15 with 2.30" D331 mill, new 2-1/8" ~, straight motor, XO, 2jts of 1-1/4" CSH tbg, MCNUCCUGR logging tool carrier, XO, new lower MHA, 104jts of 1-1/4" CSH tbg, XO & upper MHA. OAL ~ 3325.07'. M/U Injector. Establish circ ~ 0.7/0.7bpm & 420psi. 23:15 - 00:00 0.75 EVAL N DFAL LOWERI RIH logging/cleanout BHA #15. 3/12/2007 00:00 - 01:00 1.00 EVAL P LOWERI Continue RIH logging/cleanout BHA #15 to 10500'. 01:00 - 03:00 2.00 EVAL P LOW ER1 Cleanout wellbore ~ 1.5bpm & log down MCNUCCUGR C~ 30fpm from 10500'. Log down to PBTD tagged 2x C~ 13986'. ', 03:00 - 03:30 0.50 EVAL P LOWERI Circ down pert pill to mill. ~ 03:30 - 04:30 1.00 EVAL P LOW ERi Log up ~ 60fpm from PBTD to 10500' while laying-in 150kcps pert pill in liner. 04:30 - 07:30 3.00 EVAL P LOWERI Paint EOP flag ~ 7000'. Drop 5/8" ball & open up circ sub. POOH to logging/cleanout BHA #15 from 10500' while swapping wellbore to clean/new KCL fluid, Brk out Injector, CTC, Std back injector 07:30 - 10:00 2.50 EVAL P LOW ER1 POH wJ logging/cleanout BHA #15, LD upper MHA, Std Bk 52 stds of 1 1/4" CSH, LD lower BHA, std bk 1 std of 1 1/4" CSH, process MCNL. Fax log data to ANC Geo & AnC Geo confirms preliminary pert intervals. From log data, PBTD = 13962' & TOL = 10778'. 10:00 - 11:15 1.25 EVAL N RREP LOW ER1 Test Pump froze up, thawed out, rebuild pump 11:15 - 11:30 0.25 EVAL P LOW ER1 Grease choke manifold valves 11:30 - 17:30 6.00 EVAL P LOW ERi Perform BOP test, test pump transducer freezing up during testing, testing choke manifold, all valves, rams, lines- 400 - 3500 psi and annular- 300 - 2500psi as per BP and AOGCC regulations, Lou Grimaldi with AOGCC waived witnessing BOP test 17:30 - 20:30 3.00 EVAL N SFAL LOW ER1 BOP test have normally taken 4 to 5 hrs to complete, because of poorly heated areas on rig, lines are freezing up prevent a Smoot sailing BOP test. Printed: 3/26/2007 10:31:11 AM • BP EXPLORATION Page 13 of 16 Operations Summary Report Legal Well Name: G-08 Common Well Name: G-08 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task ~ Code NPT 3/12/2007 20:30 - 22:30 2.00 EVAL N SFAL 22:30 -23:00 0.50 EVAL P 23:00 - 23:50 0.83 EVAL P I 23:50 - 00:00 0.17 EVAL P 3/13/2007 00:00 - 01:30 1.50 EVAL P 01:30 - 02:00 0.50 EVAL N SFAL 02:00 - 02:30 0.50 PERFO P 02:30 - 02:45 0.25 PERFO P 02:45 - 03:15 0.50 PERFO P 03:15 - 06:00 2.75 PERFO P 06:00 - 08:00 2.00 PERFO P 08:00 - 09:30 1.50 PERFO N SFAL 09:30 - 11:00 1.50 PERFO P 11:00 - 13:00 2.00 PERFO N SFAL 13:00 - 13:45 0.75 PERFO P 13:45 - 14:35 0.83 PERFO P Spud Date: 4!19/1981 Start: 2/21 /2007 End: Rig Release: 3/15/2007 Rig Number: N1 Phase Description of Operations LOWERI Nordic crew change. PJSM for P/Testing BOPE. Continue performing bi-weekly BOPE pressure /function test. P/tested TIW valves. Outside kill & 2" valves failed. Choke manifold Valves #3, 4, 5, 9 & 14 failed. Greased & retested all valves OK. LOW ER1 P/Test inner reel valve to 3500psi _ OK. Gall out LRS for pumping up the IAP but crew is stuck in snow drift on V-pad. LOW ER1 Cement > 2000psi compressive strength. Line up & P/test wellbore via the kill-line as follows: Time WHP CTP IAP OAP Onset 0 0 0 0 0 2065 0 0 0 10 1930 0 0 0 20 1820 0 0 0 _> Failed: Leaked 12% of test pressure in 20 mins. Will repeat test. LOW ER1 Circ CT to prevent freezing up. Meanwhile DSM thaw out frozen hardline to TT. LOWERI Repeat liner lap test & leaked 18% of test pressure in 30 mins. Circ CT to prevent freezing up. Repeat test again & achieve same result. Will have to set a LTP. LOW ER1 Observe ice plug in CT. M/U nozzle & stab injector onto well. RIH to 200' & thaw out ice in CT. PBUH. S/B injector. LOW ER1 Prep rig floor to run guns. R/U safety jt. Drift MHAs with 1/2" ball - OK. LOW ER1 PJSM on perforation run#1. Review job procedure & conduct THA. LOW ER1 M/U 9jts of 2" HSD 6spf 2006PJ guns with CBF firing system. LOWERI M/U lower disconnect, 50stds of 1-1/4" CSH tbg & upper MHA. M/U injector. Meanwhile OSM is still trying to thaw out frozen hardline to TT. Will delay gun firing till hardline is thawed out and ready to be used. LOWERi RIH to 10165' with perforating BHA#16 circ pert pill ahead ~ min rate, thawing out hardline to tiger tank, greased bearings on injector LOWERI Thawing out hardline and valves to tiger tank while waiting on DSM well support to supply replacement lines and valves, temperature at -30degrees w/ 13 mph WSW, WC -56degrees LOWERI RIH w/ 2" pert gun assy #16, tagged PBTD at 13982' CTM, 3x, .59bpm, 264psi, Up wt 38.4k, S/O wt 18.7k. corrected depth to 13962' MCNL PBTD, Paint EOP Flag at 10667', PUH 132', position btm shot at 13830', top shot at 13660'. Meanwhile R/U sonogram detector to injector for shot detection. LOWERI Thawing out frozen valve and tiger tank riser line, all lines have been thawed out f/ rig to tiger tank but tiger tank is frozen. Review situation with ANC & decide to proceed with pert job while DSM replaces the tiger tank. LOW ERi Held PJSM &THA for continuing pert job without the tiger tank. LOWERI Load & launch 1/2" steel ball. Position btm shot ~ 13830'. Pump 5bbls of pert pill behind & chase ball @ 2.1bpm/2700psi. Slow to 0.85bpm/600psi @ 45bbls. Ball on seat after 57.8bbls away. S/D pumps & RBIH to 13835'. PUH, ramp up to 3340psi & observe guns fire with good pressure drop indication & Printed: 3/26/2007 10:31:11 AM • BP EXPLORATION Page 14 of 16 ~ Operations Summary Report Legal Well Name: G-08 Common Well Name: G-08 Spud Date: 4/19/1981 Event Name: REENTER+COMPLETE Start: 2/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 3/15/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task ~ Code NPT Phase Description of Operations 3/13/2007 13:45 - 14:35 0.83 PERFO P LOW ERi sonogram detection. Perforated interval = 13660' - 13830'. POOH & check circ pressure ~ 0.85bpm -had 550psi (previously had 600psi) indicating guns have fired. Continue POOH with pert gun BHA. 14:35 - 15:55 1.33 PERFO P LOWERI POOH with pert gun BHA @ 35fpm pumping down the CT ~ 1.95bpm/2120psi. Observe no losses while POOH to TOL. 15:55 - 16:10 0.25 PERFO P LOW ER1 S/D pump &flowcheck well for 15 mins -well stable. Meanwhile DSM R/U new tiger tank & P/test hardline to 4k. 16:10 - 17:35 1.42 PERFO P LOWERI POOH with pert gun BHA @ 80fpm pumping down the CT Q 1.15bpm/600psi. Observe no additional losses while POOH to surface. 17:35 - 17:50 0.25 PERFO P LOW ER1 S/D pump &flowcheck well for 15 mins -well stable. 17:50 - 18:15 0.42 PERFO P LOWERI S/B injector. R/U for L/D 1-1/4" CSH. Conduct a valve drill with satisfactory response. 18:15 - 18:30 0.25 PERFO P LOW ER1 SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH workstring. 18:30 - 20:30 2.00 PERFO P LOW ER1 Stand back 50 stds of CSH. 20:30 - 21:00 0.50 PERFO P LOW ER1 SAFETY MEETING. Review procedure, hazards and mitigation for laying out fired pert guns. 21:00 - 22:00 1.00 PERFO P LOWERI Lay out 9 pert guns. All shots fired. Check gun layout for running second set of pert guns. Well full. 22:00 - 00:00 2.00 PERFO P LOWERI M/U SWS 2" HSD PJ perf guns, loaded at 6 SPF. M/U as per perforating program. OAL of perf guns and blanks = 472.98'. 22 guns. 3/14/2007 00:00 - 00:30 0.50 PERFO P LOWERI RIH with 25 stds of CSH. M/U SWS MHA. Perforating BHA OAL = 2032.1'. 00:30 - 01:30 1.00 PERFO P LOWERI RIH with BHA #17, Perforating BHA #2. Pumped 1.5 bbl and press up to 800 psi, unable to circ at surface. RIH to 4700' to thaw possible ice plug in CSH. Still not able to circ. Press up to 800 psi with no circ. 01:30 - 02:15 0.75 PERFO N DPRB LOW ER1 POH. Still not able to circ at surface. 02:15 - 02:30 0.25 PERFO N DPRB LOWERI SAFETY MEETING. Review procedure, hazards and mitigation to stand back CSH. Plan on wet string. 02:30 - 03:45 1.25 PERFO N DPRB LOWERI Stand back CSH. Wet string. Found small piece of wood in BOT Hyd Disc, pumped on seat from CSH workstring. Change out BOT Hyd Disc. Check SWS firing head, OK. 03:45 - 05:00 1.25 PERFO N DPRB LOWERI RIH with 25 stds of CSH. M/U SWS MHA. Perforating BHA OAL = 2032.1'. 05:00 - 06:00 1.00 PERFO P LOW ER1 RIH with BHA #17. Circ. at surface, 0.4 bpm, 100 psi. OK. RIH. 06:00 - 07:30 1.50 PERFO P LOW ER1 Continue RIH with perforating BHA#17 circ 10bbls of perf pill - ahead @ min rate. Correct CTD by -18.5' @ EOP flag. Wt check ~ 12700' - Up wt = 39.5k & Run-in wt = 22.7k. RIH & locate no-go sub on TOL 2x ~ 12810' CTD. Pull to P/U wt (~ 12806') & correct CTD to 12801.5' {TOL as per MCNL + BHA length below no-go sub). PUH to ball drop position ~ 12689'. Meanwhile R/U sonogram detector to injector for shot detection. 07:30 - 08:10 0.67 PERFO P LOWERi Load & launch 1/2" steel ball. Position btm shot ~ 12690.7'. Pump 10bbls of perf pill behind & chase ball 2.22bpm/2350psi. Slow to 0.87bpm/580psi @ 45bbls. Ball on seat after 55.6bbls away. S/D pumps & RBIH to 12695'. PUH, Printed: 3/26/2007 10:31:11 AM BP EXPLORATION Page 15 of 16 Operations Summary Report Legal Well Name: G-08 Common Well Name: G-08 Spud Date: 4/19/1981 .Event Name: REENTER+COMPLETE Start: 2/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 3/15/2007 ',Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task ~ Code NPT Phase Description of Operations - - -- -- - - __ 13/14/2007 07:30 - 08:10 0.67 PERFO~ P LOWERI 08:10 - 08:55 0.75 PERFO P LOWERI 08:55 - 09:10 0.25 PERFO P LOW ER1 09:10 - 10:45 1.58 PERFO P LOWERI 10:45 - 11:00 0.25 PERFO P LOWERi 11:00 - 11:15 0.25 PERFO P LOWERI 11:15 - 12:00 0.75 PERFO P LOWERI 12:00 - 12:15 0.25 PERFO P LOWERi 12:15 - 12:30 0.25 PERFO P LOWERI 12:30-14:00 1.50 PERFO P LOWERI 14:00 - 14:15 0.25 PERFO P LOWERI 14:15 - 14:45 0.50 CASE C RUNPRD 14:45 - 15:00 0.25 CASE C RUNPRD 15:00 - 16:15 1.25 CASE C RUNPRD 16:15 - 18:15 I 2,001 CASE I C I I RUNPRD 18:15 - 20:15 2.001 CASE C RUNPRD 20:15 - 20:45 0.501 CASE I C I RUNPRD 20:45 - 23:00 ~ 2.251 CASE I C RUNPRD 23:00 - 23:30 I 0.501 CASE I C I I RUNPRD 23:30 - 00:00 I 0.501 RIGD I P I I POST ramp up to 3850psi & observe guns fire with good pressure drop indication & sonogram detection. Perforated interval = r 12245' - 12295', 12350' - 12405', 12440' - 12475', 12520' - 12550' & 12640' - 12690'. POOH & check circ pressure @ 0.85bpm -had 530psi (previously had 580psi) indicating guns have fired. Continue POOH with pert gun BHA. POOH with pert gun BHA ~ 50fpm pumping down the CT ~ 0.87bpm/530psi. Observe 1 bbl loss while POOH to TOL. S/D pump &flowcheck well for 15 mins -well stable. Meanwhile held "Spill Prevention Control & Countermeasure Plan" table-top refresher with Rig crew. POOH with pert gun BHA C~ 60fpm pumping down the CT ~ 0.86bpm/290psi. Observe no additional losses while POOH to surface. S/D pump &flowcheck well for 15 mins -well stable. S/B injector. R/U for R/B 1-1/4" CSH. R/B 25 stands of 1-1/4" CSH. R/U to UD perf guns. Held PJSM & THA for UD perf guns. UD 22 jts of perf guns & blanks. ASF! Load out spent perf guns & blanks. R/U to run LTP. P/U tools into rig floor. Held PJSM for M/U &RIH LTP. M/U LTP BHA #18 with Bkr seal assy, 2 pup jts of 2-7/8" STL Lnr, KB Packer, GH R/Tool, 2 jts of PH6 tbg & MHA. M/U injector. RIH with Bkr LTP BHA#18. Tag & observe faulty depth tracking on CTDS - showing a depth of 5455.7' after 1.75 hours of RIH ~ +/-100fpm. Check mechanical depth counter -showing 10732'. Suspect we're ~ TOL. Check wt: Up wt = 35.5k, Dwn wt = 21 k. RIH ~ 10fpm circ ~ min rate. Sting seal assy into deployment sleeve & S/D pumps. Reset CTD to 10784'. Sting out and circ. during crew change. Sting in and stack wt to 10K at 10,786'. Sting out at 10,775'. Up wt = 38K. Drop 5/8" steel ball and circ on seat. 1.5 bpm, 400 psi. BaII on seat at 56.1 bbls. Sting seals into PBR. Set down 10K at 10,786'. Pick up 2' off bottom at 10,779'. Press up to 2500 psi to set slips. Stack 10K at 10784'. Slips holding. Energize element with down wt. Mechanically LTP set looked good. Press test LTP seal with 2000 psi. Double block all surface lines. Lost 600 psi in 20 min. Failed test. Talked to town engineer about plan forward. Pull release LTP with 68K up wt, 30K over as designed. Fill well from backside while POH with LTP. Lay out LTP. Element was good, it had been energized. Seals were good. Slips had set. No indication of problem with LTP set. Jet stack with swizle stick at 3.7 bpm. RIH to 2500' and freeze protect 5-1/2" tubing to surface with Printed: 3/26/2007 10:31:11 AM BP EXPLORATION Page 16 of 16 Operations Summary Report Legal Well Name: G-08 Common Well Name: G-08 Spud Date: 4/19/1981 Event Name: REENTER+COMPLETE Start: 2/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 3/15/2007 Rig Name: NORDIC 1 Rig Number: N1 Date i From - To Hours Task Code i NPT Phase Description of Operations 3/14/2007 23:30 - 00:00 0.50 RIGD P POST MEOH. 3/15/2007 00:00 - 01:00 1.00 RIGD P POST RIH to 2500' and Freeze protect 5-1/2" tubing with 60/40 - MEOH. POH. Leave coil full of 60/40 MEOH for rig move. No N2 unit available to blowdown reel. Will blowdown reel on next well for reel swap. 01:00 - 01:15 0.25 RIGD P POST SAFETY MEETING. Review procedure, hazards and mitigation for setting BPV. 01:15 - 02:00 0.75 RIGD P POST Set BPV in 5-1/2" tubing hanger. 02:00 - 03:00 1.00 RIGD P POST Clean rig pits and cuttings tank. Supper suck cuttings tank. Send tank to Veco to get cleaned out. 10-15 bbls of contaminated cement in tank from last well liner cement job. 03:00 - 06:00 3.00 RIGD P POST N/D BOP stack. Secure stack for rig move. N/U tree cap and pressure test. Released Rig at 06:00 Hrs on 3/15/07. 17 days and 8 hours from rig accept to release. All future DIMS information will be on next well. A-42A. Printed: 3/26/2007 10:31:11 AM • ~..r by BP Alaska s~ Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 3/12/2007 Time: 11:00:10 Page: I Field: Prudhoe Bay Co-ordinate(NE) Reference: WeA: G-O8, True North Site: PB G Pad Vertical (TVD) Reference: 12:08 4/19!1981 00:00 65.6 Well: G-08 Section (VS) Reference: Well (O.OON,O.OOE,340.OOAzi) Wellpath: G-08A Survey 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 : bggm2006 Site: PB G Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5966832.87 ft Latitude: 70 18 58.211 N From: Map Easting: 656301.39 ft Longitude: 148 43 59.013 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.19 deg Well: G-08 Slot Name: 08 G-08 Well Position: +N/-S 2001.30 ft Northing: 5968867.00 ft Latitude: 70 19 17.892 N +E/-W 1604.74 ft Easting ; 657864.00 ft Longitude: 148 43 12.180 W Position Uncertainty: 0.00 ft Wellpath: G-08A Drilled From: G-08 Tie-on Depth: 11600.00 ft Current Datum: 12:08 4/19/1981 00:00 Height 65.60 ft Above System Datum: Mean Sea Level Magnetic Data: 2/27/2007 Declinafion: 24.02 deg Field Strength: 57657 nT Mag Dip Angle: 80.94 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.10 0.00 0.00 340.00 Survey Program for Defmitive Wellpath Date: 1/25/2007 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 100.00 11600.00 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Speny-Sun BOSS gyro multishot 11615.00 14004.00 MWD (11615.00-14004.00) MWD MWD -Standard Annotation MD TVD -4_-- ft ft 11600.00 8586.17 TIP 11615.00 8596.70 KOP 14004.00 9026.76 TD Survey: MWD Start Date: 3/6/2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey iVLD ft Inc! deg Azim deg 1ti"D ft Sys TVD ft N/S ft E/W ft MapN ft MapE ft VS ft DLS Tool deg/100ft 11600.00 45.28 168.81 8586.17 8520.57 -5931.50 2225.53 5962984.05 660213.63 -6334.96 0.00 MWD 11615.00 45.47 168.78 8596.70 8531.10 -5941.97 2227.60 5962973.62 660215.92 -6345.51 1.27 MWD 11665.61 37.98 161.20 8634.47 8568.87 -5974.47 2236.95 596294f.31 660225.15 X378.98 17.82 MWD 11697.13 32.47 156.35 8660.22 8594.62 -5991.42 2242.67 5962924.50 660232.03 X397.13 19.59 MWD 11721.15 29.65 151.91 8680.79 8615.19 -6002.57 2248.06 5962913.47 660237.65 -6409.45 15.12 MWD 11753.59 23.93 145.25 8709.75 8644.15 -6015.07 2255.59 5962901.13 660245.44 -6423.78 19.89 MWD 11782.87 18.53 143.22 8737.03 8671.43 -6023.68 2261.77 5962892.65 660251.80 -6433.98 18.61 MWD 11811.29 13.11 137.55 8764.36 8698.76 -6029.68 2266.65 5962886.76 660256.81 -6441.29 19.81 MWD 11841.39 9.42 110.91 8793.90 8728.30 -6033.08 2271.26 5962883.45 660261.49 -6446.06 20.89 MWD 11873.70 13.09 79.34 8825.61 8760.01 -6033.35 2277.34 5962883.31 660267.56 -6448.39 21.79 MWD 11902.42 17.40 65.36 8853.32 8787.72 -6030.96 2284.44 5962885.86 660274.62 -6448.57 19.62 MWD ~, d c~ - t~ 3 • bP BP Alaska $ Baker Hughes INTEQ Survey Report 1NTEQ Company: BP Amoco Date: 3/12/2007 Tim e: 11:00:10 Page: 2 ~ Field: Prudhoe Bay Co-ordinate(NE) Reference: WeA: G-08, True North Site: PB G Pad Vertical (TVD) Reference: 12 : O8 4/19/1981 00:00 65.6 weu: G-o8 Section (VS) Reference: Well (O.OON,O, OOE,340.OOAzi) Wellpath: G-08A Surve y Calculation Method: Minimum Curvature Db: Orade Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 11930.71 22.55 62.47 8879.90 8814.30 -6026.68 2293.10 5962890.31 660283.19 -6447.52 18.53 MWD 11960.19 28.32 59.49 8906.52 8840.92 -6020.52 2304.15 5962896.71 660294.10 -6445.50 20.04 MWD 11992.92 35.34 56.44 8934.31 8868.71 -6011.33 2318.75 5962906.20 660308.50 -6441.86 22.00 MWD 12027.81 43.55 51.92 8961.23 8895.63 -5998.31 2336.65 5962919.59 660326.12 -6435.75 24.92 MWD 12055.80 49,65 49.90 8980.46 8914.86 X985.48 2352.41 5962932.75 660341,61 -6429.09 22.41 MWD 12083.86 56.85 47.62 8997.24 8931.64 -5970.66 2369.29 5962947.92 660358.17 -6420.93 26.47 MWD 12112.42 65.55 44.64 9010.98 8945.38 -5953.31 2387.30 5962965.64 660375.81 -6410.79 31.80 MWD 12140.50 71.25 40.30 9021.32 8955.72 -5934.05 2404.90 5962985.26 660393.00 -6398.71 24.87 MWD 12170.52 76.77 33.70 9029.60 8964.00 -5911,02 2422.23 5963008.66 660409.84 -6382.99 28.01 MWD 12199.97 80.41 27.45 9035.43 8969.83 -5886.18 2436.89 5963033.80 660423.98 -6364,66 24.19 MWD 12237.00 84.28 18.77 9040.37 8974.77 -5852.46 2451.27 5963067.82 660437.64 -6337.89 25.47 MWD 12266.14 83.75 12.69 9043.41 8977.81 -5824.57 2459.12 5963095.86 660444.91 -6314.38 20.83 MWD 12297.08 88.22 6.06 9045.58 8979.98 -5794.15 2464.14 5963126.38 660449.28 -6287.50 25.80 MWD 12332.67 93.72 3.06 9044.97 8979.37 -5758.69 2466.97 5963161.88 660451.37 -6255.15 17.60 MWD 12361.05 94.18 6.37 9043.02 8977.42 -5730.48 2469.30 5963190.14 660453.10 -6229.44 11.75 MWD 12390.79 94.61 9.90 9040.74 8975.14 -5701.13 2473.49 5963219.57 660456.68 -6203.29 11.92 MWD 12420.47 93.17 13.35 9038.73 8973.13 -5672.13 2479.46 5963248.68 660462.03 -6178.08 12.57 MWD 12456.82 91.41 14.44 9037.27 8971.67 -5636.87 2488.18 5963284.11 660470.01 -6147.94 5.69 MWD 12484.82 89.36 10.09 9037.08 8971.48 -5609.52 2494.13 5963311.58 660475.38 -6124.27 17.17 MWD 12514.00 88.86 5.59 9037.54 8971.94 -5580.62 2498.11 5963340.55 660478.75 -6098,47 15.51 MWD 12542.50 91.35 3.64 9037.49 8971.89 -5552.22 2500.40 5963369.00 660480.44 -6072.57 11.10 MWD 12574.57 93.90 0.45 9036.02 8970.42 -5520.21 2501.54 5963401.02 660480.91 -6042.88 12.73 MWD 12606.37 91.26 355.83 9034.58 8968.98 -5488.47 2500.51 5963432.73 660479.21 -6012.70 16.72 MWD 12640.86 93.91 353.79 9033.03 8967.43 -5454.16 2497.40 5963466.96 660475.38 -5979.40 9.69 MWD 12672.48 95.81 350.96 9030.35 8964.75 -5422.94 2493.22 5963498.09 660470.54 -5948.63 10.75 MWD 12706.77 94.77 346.02 9027.19 8961.59 -5389.49 2486.40 5963531.38 660463.03 -5914.87 14.66 MWD 12736.39 92.43 343.11 9025.33 8959.73 -5361.00 2478.54 5963559.70 660454.57 -5885.41 12.59 MWD 12765.74 93.50 341.55 9023.81 8958.21 X333.08 2469.64 5963587.43 660445.08 -5856.12 6.44 MWD 12800.61 91.29 337.41 9022.35 8956.75 -5300.46 2457.43 5963619.78 660432,19 -5821.29 13.45 MWD 12835.42 94.70 335.11 9020.53 8954.93 -5268.64 2443.44 5963651.29 660417,54 -5786.61 11.81 MWD 12873.06 96.37 331.19 9016.90 8951.30 -5235.23 2426.52 5963684.34 660399.92 -5749.42 11.28 MWD 12906.28 94.92 326.93 9013.63 8948.03 -5206.88 2409.53 5963712.33 660382,34 -5716.97 13.49 MWD 12932.18 93.66 325.16 9011.69 8946.09 -5185.46 2395.11 5963733.44 660367.47 -5691,91 8.37 MWD 12950.56 91.41 324.58 9010.88 8945.28 -5170.44 2384.54 5963748.23 660356.59 -5674.19 12.64 MWD 12981.97 89.72 321.95 9010.57 8944.97 -5145.27 2365.76 5963772.99 660337.28 -5644.11 9.95 MWD 13010.57 93.84 319.23 9009.68 8944,08 -5123.19 2347.61 5963794.68 660318.68 -5617.16 17.26 MWD 13041.23 94.55 314.77 9007.44 8941,84 -5100.83 2326.77 5963816.60 660297.37 -5589.02 14.69 MWD 13071.53 94.40 311,54 9005.07 8939.47 -5080.18 2304.73 5963836.79 660274.90 -5562,07 10.64 MWD 13100.45 92.40 309,12 9003.36 8937.76 -5061.50 2282.73 5963855.00 660252.51 -5536.99 10.84 MWD 13131.75 90.52 305.25 9002.56 8936.96 -5042.59 2257.80 5963873.38 660227.20 -5510.70 13.74 MWD 13160.42 89.60 301.91 9002.53 8936.93 -5026.73 2233.92 5963888.72 660202.99 -5487.63 12.08 MWD 13189.72 89.48 298.45 9002.77 8937.17 -5012.01 2208.60 5963902.91 660177.37 -5465.13 11.82 MWD 13221.70 90.80 296.33 9002.69 8937.09 -4997.30 2180.21 5963917.02 660148.67 -5441.60 7.81 MWD 13253.68 91.82 293.33 9001.96 8936.36 -4983.87 2151.19 5963929.83 660119.39 -5419.06 9.91 MWD 13283.58 90.18 290.12 9001.43 8935.83 -4972.81 2123.43 5963940.31 660091.39 -5399.17 12.05 MWD 13312.88 89.17 286.40 9001.60 8936.00 -4963.63 2095.61 5963948.90 660063.39 -5381.03 13.16 MWD 13344.69 88.68 282.99 9002.20 8936.60 -4955.56 2064.85 5963956.32 660032.47 -5362.93 10.83 MWD 13370.14 87.64 279.43 9003.02 8937.42 -4950.62 2039.90 5963960.74 660007.43 -5349.75 14.57 MWD 13401.11 87.45 276.33 9004.34 8938.74 X946.38 2009.26 5963964.33 659976.70 -5335.28 10.02 MWD 13430.29 87.23 273.68 9005.70 8940.10 -4943.83 1980.22 5963966.26 659947.62 -5322.96 9.10 MWD 13460.71 85.52 269.73 9007.62 8942.02 -4942.93 1949.88 5963966.53 659917.27 -5311.73 14.13 MWD 13490.59 85.72 265.51 9009.90 8944.30 -4944,17 1920.12 5963964.67 659887.55 -5302.72 14.10 MWD 13523.36 85.85 261.03 9012.31 8946.71 -4948.00 1887.67 5963960.16 659855.19 -5295.22 13.64 MWD • bP BP Alaska Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 3/12/2007 Time: 11:00:10 Page: 3 Field: Prudhoe Bay Caordinate(NE) Reference: Well: G-08, Tr ue North Site: PB G Pad Vertical (TVD) Re ference: 12:08 4/13/1981 00:00 65.6 Welt: G-08 Sectio n (VS) Reference: Well (O.OON,O.OOE,340.OOAzi) Wellpath: G-08A Survey Calculation Method: Minimum Curvature Db: Orade Survey MD Iucl Azim "I'U'D Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 13551.54 87.57 258.48 9013.93 8948.33 -4953.00 1859.99 5963954.57 659827.62 -5290.45 10.90 MWD 13580.52 88.83 256,58 9014.84 8949.24 X959.25 1831.71 5963947.72 659799.48 -5286.66 7.86 MWD 13610.94 89.78 251.88 9015.21 8949.61 -4967.52 1802.45 5963938.85 659770.40 -5284.41 15.76 MWD 13640.40 88.10 248.52 9015.76 8950.16 -4977.49 1774.74 5963928.29 659742.91 -5284.31 12.75 MWD 13670.41 87.42 245.55 9016.93 8951.33 -4989.19 1747.13 5963916.02 659715.55 -5285.86 10.15 MWD 13700.57 85.70 241.85 9018.74 8953.14 -5002.53 1720.15 5963902.12 659688.86 -5289.16 13.51 MWD 13730.19 84.80 237.62 9021.19 8955.59 -5017.40 1694.66 5963886.71 659663.69 -5294.42 14.55 MWD 13762.50 86.65 235.55 9023.60 8958.00 -5035.14 1667.77 5963868.41 659637.18 -5301.90 8.58 MWD 13795.08 86.50 229.89 9025.55 8959.95 -5054.83 1641.90 5963848.18 659611.73 -5311.55 17.35 MWD 13843.01 89.09 224.25 9027.39 8961.79 -5087.44 1606.85 5963814.85 659577.38 -5330.21 12.94 MWD 13877.31 89.20 220.70 9027.91 8962.31 -5112.73 1583.70 5963789.08 659554.76 -5346.05 10.35 MWD 13910.54 90.49 217.15 9028.00 8962.40 -5138.58 1562.82 5963762.80 659534.44 -5363.20 11.37 MWD 13942.23 90.46 216.03 9027.73 8962.13 -5164.02 1543.93 5963736.96 659516.09 -5380.65 3.54 MWD 13960.82 90.98 211.27 9027.50 8961.90 -5179.49 1533.64 5963721.28 659506.12 -5391.66 25.76 MWD 14004.00 90.98 211.27 9026.76 8961.16 -5216.39 1511.23 5963683.92 659484.49 -5418.68 0.00 MWD TRH= 6" McEVOY V1~LIfAD= Mt:EVOY AG RIATOR = OTIS KB. REV = 65.6' BF. FLEI/ = 36.8' KOP = 3050' M9x Angle = 96 37° @ 132 Datum MD = 12012' Ds3tum TV D = 8800' SS G-08 A FROM CTD/DRLG -DRAFT I O I 13-3/8" CSG, 72#, L-80, D = 12.347" I-{ 2700' Minimum ID = 2.37" @ 12202' X/Over Sub, 2-7/8" STL LNR Pin ID SAFETY NOTES: I 2117' 5-1/2" CA-BAL-O SSSV LAND NIP, ID = 4.562" 2608' 9-5/8" DV PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 3012 2953 8 CA DOME RK 16 06/23/05 11 5462 4773 56 CA DMY RK 0 10 7206 5763 54 CA SO RK 20 09/05/18 9 7347 5846 54 CA DMY RK 0 8 8259 6393 53 CA DMY RK 0 7 8404 6479 54 CA DMY RK 0 6 9050 6855 50 CA DMY RK 0 01/22/04 5 9197 6949 51 CA DMY RK 0 4 9771 7303 52 CA DMY RK 0 3 9913 7390 52 CA OMY RK 0 2 10447 7731 48 CA DMY RK 0 1 10589 7826 48 CA DMY RK 0 05!31/05 I 5-1/2" CAMCO SLIDING SLV, ID=4.500" ~ 10723' I~ BAKER PBR SEAL ASSY 5-1/2" TBG, 17#, L-80, IJ4S IPC, 0.0232 bpf, ID = 4.892" 10744' TOP OF 4-1 /2" TBG 10744' ITOPOF 3-' - I~ 10786' [CNL: 10773'] ~- TOP OF 7" LNR 10790' 4-1/2" TBG, 12.6#, L-80, . 0.0152 bpf, ID = 3.958" 10854' 9-5/8" CSG, 47#, L-80, ID = 8.681" 11289' E5T iti)P OF uNER CEti1EN T 11415' - MECHANICAL WHIPSTOCK 11615' WINDOW 11619' - 11626' RA = ' 11625' PERFORATION SUMMARY REF LOG' MCNL-GR-CCL 03'~2'0~ ANGLER " - Note. Refer to Pr - ~ ~;afa SIZE SPF DATE 2" o 03/14/07 2•~ ~~ ~ ~ - 2 ° ~' O 2" ~;~ O 10743' I-~ 9-5/8" X 5-1 /2" BAKER PKR, ID = 4.0" 10744' ~ 5-1/2" X 4-1/2" XO 10773' 4-1/2" OTIS X NIP, ID= 3.813" 10786' 10805' --~ 4-1/2" OTIS XN NIP, ID ? = 3.80" 10804' ~' ~^~r ~- 10854' a-1/2" sos/1"TL. 10837' ELMD TT LOGGED 06/12/82 13-3/16" x 2-7/8" X-OVER SUI3 I 13969' [CNL: 13962'] I 3 ~ !; 2~ L-30- TC-II. ID=2.788" X 2- 3 4# L-60. STL ID=2.441" 14004' CEMENT F_U,r, CEMENTTOP-11665' CEMENT BTM 12195' 12200' :RTLY COLLAPSED LINER 12247' FISH - 1" X 1" X 2.5" UNDERREAMER ARM, 11 /21 /97 12447' PBTD 12485' 7" LNR, 29#, L-80, BTC; 0.0371 bpf, ID = 6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS 05/14/81 ORIGINALCOMPLETION 09/23/03 CMO/TLP PERFANGLECORRECTION 03/02101 SIS-MD FINAL 06/23/05 TWS/PJC GLV C/O 09/21/01 RWKAK CORRECTIONS 12/14/06 MSE Proposed CTD sidetrack 07/13/03 CMO/TLP MAX ANGLE CORRECTION JUE 08/02/03 BJMc/TL ADD PERF 03/17/07 /PAG PRUDHOE BAY UNff WELL: G-08A PERMff No: 206-183 API No: 50-029-20581-01 SC-C 12, T11 N, R13E, 2367' FEL 8 2773' FNL BP Exploration (Alaska) • Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU G-08A BP Exploration (Alaska) Inc. Permit No: 206-183 Surface Location: 2773' FNL, 2367' FEL, SEC. 12, T11N, R13E, UM Bottomhole Location: 2497' FNL, 682' FEL, SEC. 13, T11N, R13E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or 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 (907)-3607 (pager). DATED this day of December, 2006 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. ~E~EIVED t~ `.~~~~° STATE OF ALASKA .} ,~~.. ~~ ALAS IL AND GAS CONSERVATION COM I N SEC ~ o Zoos <i~ ~ ,, PERMIT TO DRILL Alaska Oil ~ Oas Eons Commission 20 AAC 25.005 `1 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 for: ^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 G-08A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612' 6. Proposed Depth: MD 13675 TVD 8971 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 2367' FEL 2773' FNL 12 T11N R13E UM SEC 7. Property Designation: ADL 028285 ~ Pool , , , , . , Top of Productive Horizon: 3383' FNL, 152' FEL, SEC. 13, T11 N, R13E, UM ~ 8. Land Use Permit: 13. Approximate Spud Date: April 1, 2007 Total Depth: 2497 FNL, 682' FEL, SEC. 13, T11N, R13E, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: 9,100' 4b. Location of Well (State Base Plane Coordinates): Surface: x-657864 y-5968867 Zone-ASP4 10. KB Elevation (Height above GL): 65.6 feet 15. Distance to Nearest Well Within Pool: 632' 16. Deviated Wells: Kickoff Depth: 11650 feet Maximum Hole An le: 96 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3225 Surface: 2340 18. Casin Pr ram: S ifica io ns To - Se in De th - atom uant" of Dement c.f. or cks Hole Casin Wei hf Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/8" s-sns° x zais" 6.2# / 6.16# L-80 TCII / STL 2887 10788' 7952' 13 75' 8971' 157 cu ft Class 'G' 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 12489' .' Total Depth TVD (ft): 9174 Plugs (measured): None Effective Depth MD (ft): 12447 v. Effective Depth TVD (ft): 9147 Junk (measured): 12247 asing : _: •"L~ngth Size ~: ,Cement Voliume MD- TVD Conductor Y Structuraf 11 20" x 30" 8 cu ds Concrete 110' 11 ' Surface - '.2700' 13-3/8" 3441 cu ft Arcticset I I 2700' 2700' Intermediate 11300' 9-5/8" 1668 cu ft Class 'G' 130 cu ft AS II 11300' 8372' Production Liner 1695' 7" 390 cu ft Class 'G' 10790' - 12485' 8019' - 9172' Perforation Depth MD (ft): 12209' - 12291' Perforation Depth TVD (ft): 8994' - 9047' 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 Mary Endacott, 564-4388 Printed Name Mary Endacott Title CT Drilling Engineer Prepared By Name/Number: Si nature ~ Phone 564-4388 Date F Z Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Numb r:~?A6•I~3 API Number: 50-029-20581-01-00 Permit Approval See cover fetter for Date: •0(i therre uir m nts Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes [/~ No Mud Log Req'd: ^ Yes ~No HZS Measures: Yes ^ No Dire Tonal Survey Req'd: ~ Yes ^ No Other: 3500 eS~ r~~v~\~v~~~ ~S~- Date ~ -Z ~.~ APPROVED BY THE COMMISSION COMMISSIONER Form 10-401 Revised 12/2005 ~~!; 1 ~ p ~ Submit (n Duplicate BP Prudhoe Ba G-08A Y CTD Sidetrack Summary Rig Work: 1. MIRU and test BOPS 2. Mi113.8" window at 11650'and 10' of rathole. Swap the well to Flo-Pro. 3. Drill Build: 4.125" OH, 565' (35 and 15 deg/100 planned) 4. Drill Lateral: 4.125" OH, 1460' (12 deg/100 planned), with resistivity 5. MAD pass with resistivity tools in memory mode 6. Run 3-3/16" x 2-7/8" solid liner leaving TOL at 10788' 7. Pump primary cement leaving TOC at 11450' 8. Cleanout liner and MCNL/GR/CCL log 9. Test liner lap to 2000 psi. 10. Perforate liner per asset instructions (1000') 11. Freeze protect well, RDMO Post Rig Work: N2 lift Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 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 10,788' - 12,300' • 2-7/8", L-80 6.16# STL 12,300' - 13675' • A minimum of 28 bbls 15.8 ppg cement will be used for liner cementing. S4v5~ ~o~v~ ~ a~ ~4~15 • TOC planned 200ft above kick off point, 11450'. ~~ ~` Well Control: a~ 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 96 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 9,100 ft. • Distance to nearest well within pool - 632 ft. (G-17A at 12805') Logging • MWD directional, Gamma Ray, and resistivity will be run over all of the open hole section. • A cased hole CNL/GR/CCL log will be run. Hazards One planned fault crossing, losses not expected. Complex directional plan to avoid second fault, optimize wellpath through Zone 3 conglomerates. Reservoir Pressure • The max res. press. is estimated to be 3225 psi at 8800'ss (7.1 ppg EMW). • Max. surface pressure with gas (0.10 psi/ft) to surface is 2340 psi. ~Ktt= b" MCtVVY W0.LHEA~ = McEVOY ACTUATOR = OTIS KB. ELEV = 65.6' BF. 0.EV = 36.8' KOP = 3050' Max Angle = 58 @ 6000' Datum MD = 12012' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" i~ 2700' Minimum ID = 3.725" @ 10821' 4-1/2" OTIS XN NIPPLE 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" (-{ 10744' TOP OF 4-112" TBG TOP OF 7" LNR 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 10854' 9-5/8" CSG, 47#, L-80, ID = 8.681" 11289 PERFORATION SUMMARY REF LOG: SWS BRCS ON 05/09/81 ANGLE AT TOP PERF: 49 @ 12127' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OPN/SOZ DATE 2-5/8" 8 12127 - 12145 S 04/26/01 2-5/8" 8 12153 - 12189 S 04/26/01 2-7/8" 4 12195 - 12224 S 11 /01 /97 2-718" 6 12209 - 12214 O 08/02/03 2-7/8" 6 12224 - 12230 O 12/06/97 2-314" 10 12260 - 12291 O 10/01/88 u-~ ~1~,- 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 12485' G-08 2117' -~ 5-1/2" CA-BAL-O SSSV LAND NIP, ID = 4.562" 2608' 9-5/8" DV PKR GAS I IFT MANDRFI S ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 3012 2953 8 CA DMY RK 0 11/17/06 11 5462 4773 56 CA DMY RK 0 04!11/03 10 7206 5763 54 CA DMY RK 0 11/17/06 9 7347 5846 54 CA DMY RK 0 05/13/81 8 8259 6393 53 CA DMY RK 0 05/13/81 7 8404 6479 54 CA DMY RK 0 05!13/81 6 9050 6855 50 CA DMY RK 0 01/22/04 5 9197 6949 51 CA DMY RK 0 05/13/81 4 9771 7303 52 CA DMY RK 0 05/13/81. 3 9913 7390 52 CA DMY RK 0 05/13/81 2 10447 7731 48 CA DMY RK 0 05/13/81 1 10589 7826 48 CA DMY RK 0 05/31/05 I I 10657 -i 5-1/2" CAMCO SLIDING SLV, ID = 4.500" 10723 BAKER PBR SEAL ASSY 10743' 9-5/8" X 5-1/2" BAKER PKR, ID = 4.0" 10744' - 5-1 /2" X 4-1 /2" XOl 10788' -~4-1/2" OTIS X NIP, ID = 3.813" !~ 10821' 4-1/2" OTIS XN NIP, ID = 3.725" 10$54' 4-1/2" SOS/TTL 10837' ELMD TT LOGGED 06/12/82 11997' I-~ 7" MARKER JOINT 12247' ~ FISH- 1" X 1" X 2.5" UNDERREAMERARM, (1 1 /2 111 997) DATE REV BY COMMENTS DATE REV BY COMMENTS 05(14/81 ORIGINAL COMPLETION 06/23105 TWS/PJC GLV GO 08!02/03 BJMclTLH ADD PERF 11/17/06 CJNIPAG GLV GO 09/23/03 CMO/TLP PERF ANGLE CORRECTION 12/29/03 JLJ/PAG GLV GO 01/22/04 KSB/TLH GLV GO 05/31/05 KSB/PJC GLV GO PRUDHOE BAY UNIT WELL: G-08 PERMff No: 1810480 API No: 50-029-20581-00 SEC 12, T11 N, R13E, 2367' FEL & 2773' FNL BP Exploration (Alaska) TREE= 6" McEVOY WELLHEAD= MCEVOY ACTUATOR = OTIS KB. ELEV = 65.6' BF. ELEV = 36.8' KOP = 3050' Max Angle = 58 ~ 6000' Datum MD = 12012' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, D = 12.347" ~-{ 2700' Minimum ID = 2.377" @ 12300' LSL sub, STL pin ID G -0 8 A S,~YI~>i~: Proposed CTD Sidetrack ® 2117' 5-1/2" CA-BAL-O SSSV LAND NIP, D = 4.562" 17#, L-80, 1~4S `F~, ID = 4.692" 10744' TOP OF 4-1/2" TBG 10744' SOP OF ~ 3 1„° LNR 10788' TOP OF 7" LNR ~ 10790' 4-1/2" TBG, 12.6#, L-80, CSH, 0.0152 bpf, ID = 3.958" 10854' 9-5/8" CSG, 47#, L-80, ID = 8.681" 11289' Top of cement 11450' PERFORATION SUMMARY REF LOG: SWS BHCS ON 05/09/81 A NGLE AT TOP PERF: 49 @ 12127' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OPWSOZ DATE 2-5/8" 8 12127 - 12145 isolated proposed 2-5/8" 8 12153 - 12189 isolated proposed 2-7/8" 4 12195 - 12224 isolated proposed 2-7/8" 6 12209 - 12214 isolated proposed 2-7/8" 6 12224 - 12230 isolated proposed 2-3/4" 10 12260 - 12291 isolated proposed 7" LNR, 29#, L-80, PBTD 12447' ID = 6.184" 12485' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 3012 2953 8 CA DOME RK 16 06/23/05 11 5462 4773 56 CA OMY RK 0 10 7206 5763 54 CA SO RK 20 09/05/18 9 7347 5846 54 CA DMY RK 0 8 8259 6393 53 CA DMY RK 0 7 8404 6479 54 CA DMY RK 0 6 9050 6855 50 CA DMY RK 0 01/22/04 5 9197 6949 51 CA DMY RK 0 4 9771 7303 52 CA DMY RK 0 3 9913 7390 52 CA DMY RK 0 2 10447 7731 48 CA DMY RK 0 ~ I I 1t~` ~ ~ i ~~>~ I I 10657' S-1/2" CAMCO SLIDING SLV, ID = 4.500" 10723' BAKER PBR SEAL ASSY 10743' 9-5/8" X 5-1 /2" BAKER PKR, ID = 4.0" 10744' 5-1/2" X 4-112" XO 10773' HELi~~14-1/2" OTIS X NIP, ID= 3.813" ---{ 10805' 11 ELM 4-1/2" OTIS XN NIP, ID milled to = 3.80" - 10808' 3-1/2" F~~O~.^JCO X NIP fD= 2.813" 10854' 4-1/z" sos/T'fL 10837' ELMD TT LOGGED 06/12/82 11650' Mechanical Whipstock 12300' 3-3/16" x 2-7/8" X-over 6.4#, L SO ~STL, ID=2.441" I 13675' 12247' FISH - 1" X 1" X 2.5" Ut` 11 /21 /97 DATE REV BY COMMEN(T'S DATE REV BY COMMENTS 05114/81 ORIGINAL COMPLETION 09/23/03 CMO/TLP PERF ANGLE CORRECTION 03102/01 SIS-MD FINAL 06/23/05 TWS/PJC GLV C/O 09/21/01 RN/KAK CORRECTIONS 12/14!06 MSE Proposed CTD sidetrack 07/13/03 CMO/TLP MAX ANGLE CORRECTION 08/02/03 JMc/TL ADD PERF PRUDHOE BAY UNfr WELL: G-08A PERMfr No: API No: 50-029-20581-01 SEC 12, T11 N, R13E, 2367' FEL & 2773' FNL BP Exploration (Alaska) r • by BP Alaska '~ Baker Hughes INTEQ Planning Report ):NTE Q Companyc BP Amoco Date: 12/3/2006 Time: 12:37:27 Fage: Field: Prudhoe$ay, Co-ordioate(tYE}Reference: WeN: G-08, True North -Site: PB G Pad. Vertical (TVD) Reference: 12 :08 4/19/1981:00:00 65.6 Well: G-08 Section (VS) References Welt (O.OON,O.OOE,340.OOAzi) Wellpat6s Plan 6, G-08A Survey Calculation Method: Minimum Curvature Ub: 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: bggm2006 Site: PB G Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5966832. 87 ft Latitude: 70 18 58.211 N From: Map Easting: 656301. 39 ft Longitude: 148 43 59.013 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.19 deg Well: G-08 Slot Name: 08 G-08 Well Position: +N/-S 2001.30 ft Northing: 5968867. 00 ft Latitude: 70 19 17.892 N +E/-W 1604.74 ft Easting : 657864. 00 ft Longitude: 148 43 12.180 W Position Uncertainty: 0.00 ft Wellpath: Plan 6, G-08A Drilled From: G-08 Tie-on Depth: 11 600.00 ft Current Datum: 12:08 4/19/1981 00 :00 Height 65. 60 ft Above System Datum: Mean Sea Level Magnetic Data: 12/3/2006 Declination: 24.13 deg Field Strength: 57653 nT Mag Dip Angle: 80.94 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.10 0.00 0.00 340.00 Plan: Plan #6 Date Composed: 12/3/2006 copy Lamar's plan 6 Version: 5 Principal: Yes Tied-to: From : Definitive Path Targets Map Map <-- Latitude ---> c-- Longitude ---> Name Description TVD +N!-S +E/-W Northing Easting Deg Miu Sec Deg Mia See Dip. Dr•. R ft ft ft ft G-08A Polygon 65.60 -6085.47 2409.71 5962834.00 660401.00 70 18 18.038 N 148 42 1.913 W -Polygon 1 65.60 -6085.47 2409.71 5962834.00 660401.00 70 18 18.038 N 148 42 1.913 W -Polygon 2 65.60 -5656.55 2609.79 5963267.00 660592.00 70 18 22.256 N 148 41 56.074 W -Polygon 3 65.60 -4899.33 2514.69 5964022.00 660481.00 70 18 29.704 N 148 41 58.840 W -Polygon 4 65.60 -4912.37 1518.13 5963988.00 659485.00 70 18 29.578 N 148 42 27.905 W -Polygon 5 65.60 -5367.59 1569.57 5963534.00 659546.00 70 18 25.101 N 148 42 26.407 W -Polygon 6 65.60 -5435.23 2122.31 5963478.00 660100.00 70 18 24.434 N 148 42 10.288 W G-08A Faultl 65.60 -5898.41 1886.50 5963010.00 659874.00 70 18 19.880 N 148 42 17.168 W -Polygon 1 65.60 -5898.41 1886.50 5963010.00 659874.00 70 18 19.880 N 148 42 17.168 W -Polygon 2 65.60 -5935.09 2298.84 5962982.00 660287.00 70 18 19.518 N 148 42 5.144 W -Polygon 3 65.60 -5926.49 2508.09 5962995.00 660496.00 70 18 19.602 N 148 41 59.042 W -Polygon 4 65.60 -5939.79 2664.85 5962985.00 660653.00 70 18 19.470 N 148 41 54.471 W -Polygon 5 65.60 -5926.49 2508.09 5962995.00 660496.00 70 18 19.602 N 148 41 59.042 W -Polygon 6 65.60 -5935.09 2298.84 5962982.00 660287.00 70 18 19.518 N 148 42 5.144 W G-O8A Fault3 65.60 -4728.40 1617.02 5964174.00 659580.00 70 18 31.387 N 148 42 25.019 W -Polygon 1 65.60 -4728.40 1617.02 5964174.00 659580.00 70 18 31.387 N 148 42 25.019 W -Polygon 2 65.60 -4700.25 1705.64 5964204.00 659668.00 70 18 31.664 N 148 42 22.434 W -Polygon 3 65.60 -4700.97 1929.69 5964208.00 659892.00 70 18 31.656 N 148 42 15.900 W -Polygon 4 65.60 -4685.75 2062.05 5964226.00 660024.00 70 18 31.806 N 148 42 12.039 W -Polygon 5 65.60 -4646.71 2250.93 5964269.00 660212.00 70 18 32.189 N 148 42 6.530 W -Polygon 6 65.60 -4638.55 2481.17 5964282.00 660442.00 70 18 32.269 N 148 41 59.815 W -Polygon 7 65.60 -4654.30 2611.87 5964269.00 660573.00 70 18 32.113 N 148 41 56.003 W -Polygon 8 65.60 -4638.55 2481.17 5964282.00 660442.00 70 18 32.269 N 148 41 59.815 W -Polygon 9 65.60 -4646.71 2250.93 5964269.00 660212.00 70 18 32.189 N 148 42 6.530 W -Polygon 10 65.60 -4685.75 2062.05 5964226.00 660024.00 70 18 31.806 N 148 42 12.039 W -Polygon 11 65.60 -4700.97 1929.69 5964208.00 659892.00 70 18 31.656 N 148 42 15.900 W by BP Alaska s Baker Hughes INTEQ Planning Report INTE Q Company: BP Amoco Date: 12/3/2006 Time: 12:37:27 Fage: 2 .Field: Prudhoe Bay. Co-ordinate(NE) Reference:: We{h G-08, True North Site: PB G Pad Vertical. (1'VD) Reference: 12:08 4/19/1981 00:00 65.6 We1L G-08 Section (VS) Reference: Weli (O:OOtU0.00E,340.00Azi) Wellpath: Plan 6 G-08A Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <--- Latitude ---> <~ Longitude --> Name Description TVD +N!-S +E/-W Northing `Easting ; ... ..Deg Mia Sec Deg hfin Sec pip. I)c ft ft ft ft ft -Polygon 12 65.60 -4700.25 1705.64 5964204.00 659668.00 70 18 31.664 N 148 42 22.434 W G-08A Fault2 65.60 -6172.69 1800.70 5962734.00 659794.00 70 18 17.182 N 148 42 19.672 W -Polygon 1 65.60 -6172.69 1800.70 5962734.00 659794.00 70 18 17.182 N 148 42 19.672 W -Polygon 2 65.60 -6143.97 2147.41 5962770.00 660140.00 70 18 17.464 N 148 42 9.562 W -Polygon 3 65.60 -6152.09 2343.29 5962766.00 660336.00 70 18 17.383 N 148 42 3.850 W -Polygon 4 65.60 -6150.49 2647.42 5962774.00 660640.00 70 18 17.398 N 148 41 54.982 W -Polygon 5 65.60 -6152.09 2343.29 5962766.00 660336.00 70 18 17.383 N 148 42 3.850 W -Polygon 6 65.60 -6143.97 2147.41 5962770.00 660140.00 70 18 17.464 N 148 42 9.562 W G-08A Target3 9022.60 -5089.50 2282.63 5963827.00 660253.00 70 18 27.834 N 148 42 5.610 W G-08A Target2 9026.60 -5559.08 2493 .81 5963362.00 660474.00 70 18 23.215 N 148 41 59.455 W G-08A Target4 9036.60 -5003.94 1686 .25 5963900.00 659655.00 70 18 28.677 N 148 42 23.002 W G-08A Target1 9046.60 -5851.62 2182 .57 5963063.00 660169.00 70 18 20.339 N 148 42 8.534 W Annotation MD TVD ft ft 11600.00 8586.17 11650.00 8621.15 11670.00 8635.29 11710.00 8667.10 11760.00 8713.48 11800.00 8752.49 11910.00 8857.17 12020.00 8957.54 12078.60 9003.64 12215.74 9044.79 12305.74 9035.14 12455.74 9026.98 12755.74 9027.32 13155.74 9027.67 13255.74 9027.74 13430.74 9030.34 13675.00 9037.05 TIP KOP End of 9 Deg/100 DLS 4 5 End of 35 Deg/100 DLS 7 End of 15 Deg/100 DLS 9 End of 35 Deg/100 DLS 11 12 13 14 15 16 TD Plan Section Information MD ft Incl deg Azim deg 11600.00 45.28 168.81 11650.00 45.92 168.71 11670.00 44.12 168.71 11710.00 30.12 168.71 11760.00 12.62 168.71 11800.00 15.22 108.71 11910.00 22.30 60:26 12020.00 27.49 22.28 12078.60 48.00 22.28 12215.74 96.00 22.28 12305.74 96.27 33.14 12455.74 89.93 16.26 12755.74 89.94 340.26 13155.74 89.96 292.26 13255.74 89.96 280.26 13430.74 88.35 259.32 13675.00 88.56 288.64 TVD +N/S +E/-W ft ft ft 8586.17 -5931.50 2225.53 8621.15 -5966.54 2232.49 8635.29 -5980.41 2235.26 8667.10 -6004.02 2239.97 8713.48 -6021.82 2243.53 8752.49 -6027.82 2249.38 8857.17 -6022.06 2281.40 8957.54 -5987.97 2309.34 9003.64 -5954.96 2322.87 9044.79 -5837.76 2370.90 9035.14 -5758.66 2412.45 9026.98 -5623.13 2474.72 9027.32 -5328.17 2465.76 9027.67 -5047.55 2197.23 9027.74 -5019.60 2101.41 9030.34 -5020.23 1927.41 9037.05 -5003.46 1686.48 DLS Build Turo TFO Target deg/100ft deg/100ft degMOOft deg 0.00 0.00 0.00 0.00 1.29 1.28 -0.20 353.59 9.00 -9.00 0.00 180.00 35.00 -35.00 0.00 180.00 35.00 -35.00 0.00 180.00 35.00 6.50 -150.00 250.00 15.00 6.44 -44.05 270.00 15.00 4.72 -34.52 270.00 35.00 35.00 0.00 0.00 35.00 35.00 0.00 0.00 12.00 0.30 12.07 88.00 12.00 -4.23 -11.25 250.00 12.00 0.00 -12.00 270.00 12.00 0.00 -12.00 270.00 12.00 0.00 -12.00 270.00 12.00 -0.92 -11.97 265.50 12.00 0.09 12.00 90.00 i ~ by BP Alaska $ Baker Hughes INTEQ Planning Report LNTE Q Company: BP Amoco Date: 12/3/2006 Time: 12:37:27 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: WetG G-08, True North Site: PB G Pad Vertical (TVD) Reference: 12 : OS 4/19/198T 00:00 65.6 Well: G-08 ` Section (VS) Reference: Well (O.OON,O.OOE,340.OOAzi) Wellpat6: Plan 6, G-08A Survey Calculation Met6ud: Minimum Curvature Db: OraGe Survey MD Incl Azim SS TVD N/S E/W ft deg deg ft ft ft 11600.00 45.28 168.81 8520.57 -5931.50 2225.53 11650.00 45.92 168.71 8555.55 -5966.54 2232.49 11670.00 44.12 168.71 8569.69 -5980.41 2235.26 11680.00 40.62 168.71 8577.07 -5987.02 2236.58 11690.00 37.12 168.71 8584.86 -5993.17 2237.81 11700.00 33.62 168.71 8593.01 -5998.85 2238.94 11710.00 30.12 168.71 8601.50 -6004.02 2239.97 11720.00 26.62 168.71 8610.30 -6008.68 2240.90 11730.00 23.12 168.71 8619.37 -6012.80 2241.73 11740.00 19.62 168.71 8628.68 -6016.38 2242.44 11750.00 16.12 168.71 8638.20 -6019.39 2243.04 11760.00 12.62 168.71 8647.88 -6021.82 2243.53 11770.00 11.88 152.53 8657.66 -6023.80 2244.22 11780.00 12.13 135.69 8667.44 -6025.47 2245.42 11790.00 13.32 120.68 8677.20 -6026.81 2247.15 11800.00 15.22 108.71 8686.89 -6027.82 2249.38 11825.00 15.66 94.69 8711.00 -6029.15 2255.86 11850.00 16.93 82.07 8735.00 -6028.92 2262.83 11875.00 18.85 71.56 8758.80 -6027.14 2270.27 11900.00 21.24 63.12 8782.29 -6023.82 2278.14 11910.00 22.30 60.26 8791.57 -6022.06 2281.40 11925.00 22.41 54.35 8805.45 -6018.98 2286.20 11950.00 23.06 44.78 8828.51 -6012.72 2293.52 11975.00 24.24 35.90 8851.42 -6005.09 2299.98 12000.00 25.89 27.94 8874.07 -5996.10 2305.55 12020.00 27.49 22.28 8891.94 -5987.97 2309.34 12030.00 30.99 22.28 8900.67 -5983.45 2311.20 12040.00 34.49 22.28 8909.08 -5978.45 2313.25 12050.00 37.99 22.28 8917.14 -5972.98 2315.49 12060.00 41.49 22.28 8924.83 -5967.07 2317.91 12070.00 44.99 22.28 8932.12 -5960.73 2320.51 12078.60 48.00 22.28 8938.04 -5954.96 2322.87 12080.00 48.49 22.28 8938.97 -5953.99 2323.27 12090.00 51.99 22.28 8945.36 -5946.88 2326.18 12100.00 55.49 22.28 8951.28 -5939.42 2329.24 12110.00 58.99 22.28 8956.69 -5931.64 2332.43 12110.61 59.20 22.28 8957.00 -5931.15 2332.63 12118.77 62.06 22.28 8961.00 -5924.58 2335.32 12120.00 62.49 22.28 8961.57 -5923.57 2335.74 12130.00 65.99 22.28 8965.92 -5915.24 2339.15 12140.00 69.49 22.28 8969.71 -5906.67 2342.66 12143.81 70.82 22.28 8971.00 -5903.36 2344.02 12150.00. 72.99 22.28 8972.92 -5897.91 2346.25 12160.00 76.49 22.28 8975.55 -5888.99 2349.91 12170.00 79.99 22.28 8977.59 -5879.93 2353.62 12180.00 83.49 22.28 8979.03 -5870.77 2357.37 12190.00 86.99 22.28 8979.86 -5861.55 2361.15 12200.00 90.49 22.28 8980.08 -5852.30 2364.94 12210.00 93.99 22.28 8979.69 -5843.06 2368.73 12215.74 96.00 22.28 8979.19 -5837.76 2370.90 12225.00 96.04 23.40 8978.22 -5829.28 2374.47 12250.00 96.13 26.41 8975.57 -5806.74 2384.94 12275.00 96.20 29.43 8972.88 -5784.78 2396.58 MapN `MapE DLS VS TFO Tool ft ft : deg/100ft ` ft deg 5962984.05 660213.63 0.00 -6334.96 0.00 MWD 5962949.17 660221.33 1.29 -6370.27 353.59 MWD 5962935.36 660224.39 9.00 -6384.25 180.00 MWD 5962928.78 660225.84 35.00 -6390.91 180.00 MWD 5962922.65 660227.20 35.00 -6397.11 180.00 MWD 5962917.00 660228.45 35.00 -6402.83 180.00 MWD 5962911.85 660229.60 35.00 -6408.05 180.00 MWD 5962907.21 660230.62 35.00 -6412.75 180.00 MWD 5962903.11 660231.53 35.00 -6416.90 180.00 MWD 5962899.55 660232.32 35.00 -6420.51 180.00 MWD 5962896.55 660232.98 35.00 -6423.54 180.00 MWD 5962894.13 660233.52 35.00 -6425.99 180.00 MWD 5962892.16 660234.25 35.00 -6428.09 250.00 MWD 5962890.52 660235.50 35.00 -6430.07 265.82 MWD 5962889.22 660237.25 35.00 -6431.92 282.30 MWD 5962888.26 660239.50 35.00 -6433.63 296.94 MWD 5962887.07 660246.00 15.00 -6437.09 270.00 MWD 5962887.44 660252.97 15.00 -6439.27 283.52 MWD 5962889.37 660260.36 15.00 -6440.14 295.63 MWD 5962892.86 660268.17 15.00 -6439.70 305.65 MWD 5962894.69 660271.39 15.00 -6439.17 313.57 MWD 5962897.87 660276.12 15.00 -6437.91 270.00 MWD 5962904.28 660283.31 15.00 -6434.54 275.47 MWD 5962912.05 660289.61 15.00 -6429.57 284.30 MWD 5962921.14 660294.98 15.00 -6423.04 292.43 MWD 5962929.35 660298.61 15.00 -6416.70 299.65 MWD 5962933.91 660300.36 35.00 -6413.08 360.00 MWD 5962938.95 660302.31 35.00 -6409.08 0.00 MWD 5962944.47 660304.43 35.00 -6404.71 360.00 MWD 5962950.43 660306.73 35.00 -6399.98 0.00 MWD 5962956.82 660309.20 35.00 -6394.91 0.00 MWD 5962962.64 660311.44 35.00 -6390.30 360.00 MWD 5962963.62 660311.81 35.00 -6389.53 0.00 MWD 5962970.79 660314.58 35.00 -6383.84 0.00 MWD 5962978.31 660317.48 35.00 -6377.88 0.00 MWD 5962986.16 660320.50 35.00 -6371.66 0.00 MWD 5962986.64 660320.69 35.00 -6371.27 0.00 G-08A 5962993.28 660323.25 35.00 -6366.01 360.00 G-08A 5962994.29 660323.64 35.00 -6365.20 360.00 MWD 5963002.70 660326.88 35.00 -6358.54 0.00 MWD 5963011.33 660330.20 35.00 -6351.69 360.00 MWD 5963014.67 660331.49 35.00 -6349.04 0.00 G-08A 5963020.16 660333.61 35.00 -6344.69 360.00 MWD 5963029.16 660337.08 35.00 -6337.55 360.00 MWD 5963038.30 660340.60 35.00 -6330.31 0.00 MWD 5963047.53 660344.16 35.00 -6322.99 0.00 MWD 5963056.82 660347.74 35.00 -6315.62 360.00 MWD 5963066.15 660351.33 35.00 -6308.22 0.00 MWD 5963075.47 660354.93 35.00 -6300.83 360.00 MWD 5963080.81 660356.98 35.00 -6296.60 0.00 MWD 5963089.37 660360.38 12.00 -6289.85 88.00 MWD 5963112.12 660370.37 12.00 -6272.25 88.12 MWD 5963134.32 660381.54 12.00 -6255.59 88.44 MWD • • ~p BP Alaska Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amoco Date: 12/3/2006 Time: 12 :37:27 Page: 4 .Field:. Prudhoe Bay _ Co-ordinate(NE) Reference: WeII: G-f18, True North Site: PB G Pad Vertical(TVD) Reference: ' 12 : OS 4/19/19$ 1 00:00 65. 6 Welt: G-08 Section (VS) Reterencet Well (O.OON,O.OOE,340.OOAzi) Wellpath: Plant 6, G-08A Survey Calculation Method: Minimum Curvature Db: OraGe Survey MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft' ft ft ft ft deg/100ft " R, deg 12300. 00 96.26 32.45 8970.17 -5763.46 2409.35 5963155.90 660393.87 12.00 -6239.93 88.76 MWD 12305. 74 96.27 33.14 8969.54 -5758.66 2412.45 5963160.76 660396.86 12.00 -6236.48 89.09 MWD 12325. 00 95.47 30.96 8967.57 -5742.43 2422.61 5963177.20 660406.68 12.00 -6224.70 250.00 MWD 12350. 00 94.43 28.14 8965.41 -5720.77 2434.89 5963199.12 660418.50 12.00 -6208.54 249.78 MWD 12375. 00 93.38 25.32 8963.71 -5698.49 2446.11 5963221.63 660429.24 12.00 -6191.45 249.53 MWD 12400. 00 92.31 22.51 8962.47 -5675.67 2456.23 5963244.65 660438.88 12.00 -6173.46 249.34 MWD 12425. 00 91.25 19.71 8961.69 -5652.36 2465.23 5963268.14 660447.39 12.00 -6154.64 249.20 MWD 12450. 00 90.18 16.91 8961.38 -5628.63 2473.08 5963292.03 660454.74 12.00 -6135.03 249.11 MWD 12455. 74 89.93 16.26 8961.38 -5623.13 2474.72 5963297,57 660456.26 12.00 -6130.41 249.08 MWD 12475. 00 89.93 13.95 8961.40 -5604.54 2479.74 5963316.26 660460.89 12.00 -6114.66 270.00 MWD 12500. 00 89.93 10.95 8961.43 -5580.13 2485.13 5963340.78 660465.76 12.00 -6093.57 270.00 MWD 12525. 00 89.93 7.95 8961.46 -5555.47 2489.23 5963365.51 660469.34 12.00 -6071.80 270.01 MWD 12550. 00 89.93 4.95 8961.49 -5530.63 2492.04 5963390.40 660471.63 12.00 -6049.42 270.01 MWD 12575. 00 89.93 1.95 8961.52 -5505.68 2493.54 5963415.38 660472.61 12.00 -6026.49 270.01 MWD 12600. 00 89.93 358.95 8961.55 -5480.68 2493.74 5963440.37 660472.28 12.00 -6003.07 270.02 MWD 12625. 00 89.93 355.95 8961.58 -5455.71 2492.63 5963465.31 660470.64 12.00 -5979.22 270.02 MWD 12650. 00 89.94 352.95 8961.61 -5430.83 2490.21 5963490.14 660467.70 12.00 -5955.01 270.02 MWD 12675. 00 89.94 349.95 8961.64 -5406.11 2486.49 5963514.77 660463.47 12.00 -5930.51 270.03 MWD 12700. 00 89.94 346.95 8961.66 -5381.62 2481.49 5963539.15 660457.95 12.00 -5905.79 270.03 MWD 12725. 00 89.94 343.95 8961.69 -5357.42 2475.21 5963563.21 660451.16 12.00 -5880.90 270.03 MWD 12750. 00 89.94 340.95 8961.71 -5333.59 2467.67 5963586.87 660443.13 12.00 -5855.93 270.04 MWD 12755. 74 89.94 340.26 8961.72 -5328.17 2465.76 5963592.25 660441.11 12.00 -5850.19 270.04 MWD 12775 .00 89.94 337.95 8961.74 -5310.18 2458.90 5963610.09 660433.86 12.00 -5830.93 270.00 MWD 12800 .00 89.94 334.95 8961.76 -5287.27 2448.91 5963632.79 660423.40 12.00 -5805.98 270.00 MWD 12825. 00 89.94 331.95 8961.79 -5264.91 2437.74 5963654.91 660411.76 12.00 -5781.15 270.01 MWD 12850. 00 89.94 328.95 8961.81 -5243.16 2425.41 5963676.39 660398.97 12.00 -5756.50 270.01 MWD 12875. 00 89.95 325.95 8961.84 -5222.09 2411.96 5963697.17 660385.09 12.00 -5732.10 270.01 MWD 12900 .00 89.95 322.95 8961.86 -5201.75 2397.43 5963717.20 660370.13 12.00 -5708.02 270.01 MWD 12925 .00 89.95 319.95 8961.88 -5182.20 2381.85 5963736.41 660354.14 12.00 -5684.32 270.02 MWD 12950 .00 89.95 316.95 8961.91 -5163.50 2365.27 5963754.76 660337.18 12.00 -5661.07 270.02 MWD 12975 .00 89.95 313.95 8961.93 -5145.68 2347.73 5963772.20 660319.27 12.00 -5638.33 270.02 MWD 13000 .00 89.95 310.95 8961.95 -5128.81 2329.29 5963788.68 660300.48 12.00 -5616.17 270.03 MWD 13025. 00 89.95 307.95 8961.97 -5112.93 2309.99 5963804.16 660280.85 12.00 -5594.64 270.03 MWD 13050. 00 89.95 304.95 8961.99 -5098.07 2289.88 5963818.58 660260.43 12.00 -5573.81 270.03 MWD 13075 .00 89.96 301.95 8962.01 -5084.30 2269.02 5963831.92 660239.29 12.00 -5553.73 270.03 MWD 13100 .00 89.96 298.95 8962.03 -5071.63 2247.47 5963844.13 660217.48 12.00 -5534.45 270.04 MWD 13125 .00 89.96 295.95 8962.05 -5060.10 2225.29 5963855.18 660195.06 12.00 -5516.04 270.04 MWD 13150 .00 89.96 292.95 8962.07 -5049.76 2202.54 5963865.05 660172.10 12.00 -5498.53 270.04 MWD 13155 .74 89.96 292.26 8962.07 -5047.55 2197.23 5963867.14 660166.75 12.00 -5494.64 270.04 MWD 13175 .00 89.96 289.95 8962.08 -5040.62 2179.27 5963873.70 660148.65 12.00 -5481.98 270.00 MWD 13200 .00 89.96 286.95 8962.10 -5032.70 2155.56 5963881.11 660124.78 12.00 -5466.44 270.00 MWD 13225 .00 89.96 283.95 8962.12 -5026.05 2131.46 5963887.26 660100.55 12.00 -5451.94 270.00 MWD 13250 .00 89.96 280.95 8962.13 -5020.66 2107.06 5963892.13 660076.03 12.00 -5438.53 270.01 MWD 13255 .74 89.96 280.26 8962.14 -5019.60 2101.41 5963893.07 660070.37 12.00 -5435.60 270.01 MWD 13275 .00 89.78 277.96 8962.18 -5016.55 2082.40 5963895.72 660051.30 12.00 -5426.24 265.50 MWD 13300 .00 89.55 274.97 8962.33 -5013.74 2057.56 5963898.01 660026.41 12.00 -5415.10 265.51 MWD 13325 .00 89.31 271.98 8962.57 -5012.22 2032.61 5963899.00 660001.43 12.00 -5405.14 265.52 MWD 13350 .00 89.08 268.98 8962.92 -5012.01 2007.62 5963898.68 659976.44 12.00 -5396.40 265.55 MWD 13375 .00 88.85 265.99 8963.38 -5013.11 1982.65 5963897.06 659951.50 12.00 -5388.89 265.59 MWD 13400 .00 88.63 263.00 8963.93 -5015.51 1957.77 5963894.14 659926.68 12.00 -5382.63 265.65 MWD 13425 .00 88.40 260.01 8964.57 -5019.20 1933.06 5963889.93 659902.06 12.00 -5377.65 265.71 MWD 13430 .74 88.35 259.32 8964.74 -5020.23 1927.41 5963888.78 659896.43 12.00 -5376.68 265.79 MWD • • ~p BP Alaska Baker Hughes INTEQ Planning Report iNTE Q Company: BP Amoco Date: 12/3/2006 Time: 12:37:27 - Page: Field:. Prudhoe Bay., Co-ordinate(NE) Reference: Wetl; G-08, True North Site:. PB G Pad Vertical (TVD) Reference: 12:08 4!19!198 1: 00:00 65. 6 Well: G-08 Section (VS) Reference: Well {O.OON,O.OOE,340.OOAzi) Wellpath: Plan 6, G-08A Survey Cakulatiou Method: Minimum Curvature Db: OraGe Survey MD Inc! Azim SS TVD N/S E/W MapN MapE DLS VS TFO' Tool. ft :.:deg deg ft ft ft ft ft' degl100ft ft deg: 13450.00 88.36 261.63 8965.29 -5023.41 1908.43 5963885.20 659877.52 12.00 -5373.18 90.00 MWD 13475.00 88.36 264.63 8966.00 -5026.40 1883.62 5963881.69 659852.78 12.00 -5367.51 89.93 MWD 13500.00 88.37 267.63 8966.72 -5028.09 1858.69 5963879.48 659827.90 12.00 -5360.56 89.85 MWD 13525.00 88.39 270.64 8967.43 -5028.46 1833.70 5963878.58 659802.93 12.00 -5352.37 89.76 MWD 13550.00 88.41 273.64 8968.13 -5027.53 1808.73 5963878.98 659777.94 12.00 -5342.96 89.68 MWD 13575.00 88.43 276.64 8968.82 -5025.29 1783.85 5963880.70 659753.02 12.00 -5332.34 89.59 MWD 13600.00 88.46 279.64 8969.50 -5021.76 1759.11 5963883.71 659728.21 12.00 -5320.56 89.51 MWD 13625.00 88.49 282.64 8970.16 -5016.93 1734.59 5963888.02 659703.60 12.00 -5307.64 89.43 MWD 13650.00 88.52 285.64 8970.81 -5010.83 1710.36 5963893.62 659679.25 12.00 -5293.61 89.35 MWD 13675.00 88.56 288.64 8971.45 -5003.46 1686.48 5963900.48 659655.22 12.00 -5278.52 89.27 2 3/8" • • ~~~ ~+-. ~ rl it r' li i tF i~~ ~-~~ = h li I i ~' t ~ 't ~P ,r r I~.~.i ;1- trli Ftt} I1 ~+~--~,rl~ F i , t ~r.-t ~ ~ i ~ ~ )1+ ~~ t~ i'~~r~ I } 1 ~ ~ ~ .1 ~ r~ t~ T`, Ikj Thrilfllt 111t Ii t Iri, lil 1~1 ICI lt~'~ ~ x ~±! ~ 't,III ~{{~~ll ~~ I I`ll lilt rf~1 lif~ i{~Ff oaf[ lti~ ~~Ek ` ~~`~~~`i~ ~~ ~~ T # a t Ii,lk k ~ ' t , r F, ! j~ l r , .$t i-f- ' I ' I -4 i f i ~ -~ ~ ~ ~ I' 7 - ,~-I a ri ' 1 (r ; +r ~ I"~'r7i1 111 ITE~ #~I~ ' l try} tll i~ {~) ~~t t~~t ~ $ .- 1 Ir {11} ftr~ 8~ tl 0 ' ~ -f-+ L.. - .+r 1 U 1 t ~ l'- ' 1- f- ~ I i~. 1 3 ~ F_ - ~ I 4 1. ; - x ~~, _ ~'ITl 1t~ Ir~r, `~ . I~ ,++~ F t r~ It~~ ~i~~~ it,~ ~~i ~ 1 r ~ :~It tt_ r I ~ i ~.. _ + i t' t r~ tl t t t ~ ~ C ' 1}I-1-} + +~ ~ Tt , f ,_~ r F r t ~ I ~ 1' i~ i =~ 1~ r I I II ~ l;' t i ~r~r ~ + tt~~ 1~1tt {r~ t.: ~tCk :r- II ~ ~~ i { ~ I ,yl i ~~ T F{.1-=.t - 1' I ~11 + I+` 1+ 1 t„ 1{ ~~ k ~.~ t I f h r I I 11 + I I~ f: T j~ ~I l I':, r I r~ rt t i tl~ 1~'i r II ' r I tlr' ~• I I Ir I G~I ~~TI I TF r r hTr r I }' I i + 1 1 I ~I ~ r r~ tt ~~l ~ ~~1$l# li:l ~~1~ rl~~ ~~Kl ~~i# 1~{i f1=1 #~~$ ;~:' ~~ +}{ ~-'$~1~C~ ~`~~~_ 1 E~-I .4i' e 95 '~}~ ~~ a,'I t ~ ~ k~{ !t#. ~{tf ~1~k' ~ ~ . ~ 1 .1 i x ~~ ~~a~~ I ~~ ~r { ' ^ ~r~, ~' Q' t+ i t_ ~ s ~ p i,' t T~ ~ I ~~ ~ 1; ~ -; ~~ f~t~it( i ~~ t ~ t `Y* ~l k _ ~rt~i l I• I ~ If $ ~~~ tt} ~ ~ I~ ~F 8 ¢}111 k _~ f~~ ~ ~ ~ k ~ 3 jj it7t~acil { i k+ I ts~lf}t rill 11ff t'1i 1111: ~ t + t ~~ ,~ 1 ~ t k F ` ._ ~ 2 r ~ I - _ _ f ~ r~ 11 t k I~1 T }.1 Ir?t}j7',#,T~ri I t' 1 ij'i }`jj IIr,{Il i11 I ~t;: ~ 'F ~~' ~~ ~~ ; ,.I I r ~ ` ~'ll, 1, 11~111~~~,11~~1~~ int '~~ ;=j; l ~~ 'rj ; 1~~ ~ ~; ~ r't r ~rulu I .r rlt rr ti I; 1- k }i u~# }lit I + ~}It'~, Ott' '111 Ir;t II k I f r , r I ~r ~ a_. ~ ~~ 1~ I Il ~I!{ ~ilf ~j? ~~ ~{ I B r~. ~ ,l ~ ~"r tIT i1j` ~ I ..y r ~, I ~ r~ ~ i" ~~ I ~ '.}' 1 , r,,I t 1r1, rl~{ Ifi f7 I tll I{r I li ~ tpy +i7 l l' I I 11 I t l i i l ~` 1 f f li I i m TI rt,t k- ~ I: i~ ~. i{U~11i-r n ~I{11`~'I 1?' Tr'I 'IiI~I,r~~llit If+~Jliii tt~ ~~j ` ~i~ ~ ~ = i+a-r a ~ {+ I 'i-, I r 7 t ~, , ~.-r 11 f lul t ~ ~11~ Ij ~ IF~f lr ~:I ~,, i ~ i 11 Y~I{I I ~ i. i ~1 ~ trT t s ' t ~ ~[w33oo31ldo+ewi•)wet 1 ~ : - ~ A ~ '~ _ L __ rt ~ ~ j . ' -~ ~ E r _~ -:3:axS~;:s3s5 ai sss"s Q '``n{]l {~ G8R53 q n '1 ~ l.: ' i g $ ' ;~~~9?i~,:5~36, ~gA ~~~5 Y IrY71 ~+ 4 1 ?~•fi I i " ~ sas3a3sa3::::[:~ ~ aeaeaeas 4 as 8 E e s$ 3 8333333z3i6fii3 X838 i d:i:d F 5 ~ '_ N 3~ R o~ ~ ".'3:.3. ~Y ~73j'k~flj i 'I 1 ---1 g s e a^: as e Sg} t .i' a i ~ 3 ~ ~ a :~Si~:da~i.:SS~ 1 ~~~3~33~ ~ ~' - rti T1 1' 1 1 III ~ ~ ~ $ s ~ $ E :aaa.aaxaasai's:f I ~ i `~ r + } a }a + r 1 r I ~ ! a' sr i ~ ?x353 as:s•zac.3q t{}. ' jl` 'T#T ~+T ~ + - + i1 ~ `+- E I: -. ~~ a+ $ ~ a 9 ~" ~==4~=i'~='==3i~~ . j I tt I f I k r~ I I~ f G ~- ~ t k t. , t . -r= -t a ~ ~ =a_s. ^:zz3::~anxa33si ~ 7 i t t. ~..-}} T~ t -~~ I ii. H ~~ ~ m i ~ .:°:? s .•.::fzi i f f f r t ri I f s _ ~ r ~I =T~1 ± r T t g ~~ i~ ~ $ i°?a.~ ;8:383....33 4 1 ' i t ~ ~ ~a~$' ---...a:aza a3 ; fi a e a' }} -4 ~t ~ ~~ ~ t I t 1 :: i „ + ~ ~~ ~ '~,~; iid'iA~dsafa~d~ ~ F s :: ~ ~ ~ F ~ ' ~ r # 3 az^s:ax3::333az: . ! c~i..i^i.i:c:ap r ~ I. - - 33~a::aa38.33:3ff tilt ifi •i••• ~ 8 . 3 CA~i',S..~S : :....~3A7A~C ~~x '~; i '., ~ ~' _.............ei53c ~~~i~~€~~Elae~f~e i ,.tv.+rjg-~.+..}.r ~ g • ~ /.~.~ -- ~ r~rr..t .t.,. r~ ~. ~ 8A Y 9Y I~V40f1 q~O I ~~~f~+l 8 x ~ • by BP Alaska Anticollision Report ~~~ B wtf~s ItNTEQ Company: BP Amoco - Date:. 12/15!2006. Time: 0931:28 Page: I Field: Prudhoe Bay 12eference Site: PB G'Pad Co-ordinate(NE) Reference: Well: G-08, True North Reference Well: G-08 Vertical (TVD) Reference; 12:08 4/1 911 9$1' 00: 00 65.6 Reference Wellpath: Plan 6, G-Ot3A Db: Orade NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan 8< PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 11 600.00 to 13675.0 0 ft Scan Method: Trav Cylinder North Maximum Radius: 2000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wel lpath Date: 12/3/2006 Validated: No Version: 0 Planned From To Snrvey Toolcode Tool Name ft ft 100.00 11600.00 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 11600.00 13675.00 Planned: Plan #6 V5 MWD MWD -Standard Casing Points MD TVD Diameter Hole Size Name ft it in in 13675.00 9037.05 2.375 3.000 2 3/8" Summary <---- -- Offset Wellpath ------- -------> Reference Offset Ctr-Ctr No-Go" Allowable Site Well Wellpath MD MD Distance Area Deviation Warning.: " it ft ft ft ft , PB D Pad D-30 D-30 V3 11863.28 12300.00 1308.97 996.14 312.83 Pass: Major Risk PB G Pad G-08 G-08 V8 11600.00 11600.00 0.001459.71 -1459.71 FAIL: Major Risk PB G Pad G-17 G-17 V7 12913.08 11400.00 525.78 0.00 525.78 Pass: Minor 1/10 PB G Pad G-17 G-17A V16 12805.66 11500.00 632.41 0.00 632.41 Pass: Minor 1/10 PB G Pad G-18A G-18A V2 Out of range PB G Pad G-24 PIan2, G-24A VO P lan: 13375.00 11200.00 1088.24 450.53 637.71 Pass: Major Risk Site: PB D Pa d Well: D-30 Rule Assigned: Major Risk Wellpath: D-30 V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area. Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11825.00 8776.60 11400.00 9033.60 413.03 71.39 218.13 123.44 4.500 1998.021218.23 779.78 Pass 11825.00 8776.60 11500.00 9033.78 413.03 72.73 216.88 122.19 4.500 1910.271209.15 701.12 Pass 11825.00 8776.60 11600.00 9034.98 413.03 74.13 215.39 120.69 4.500 1826.571197.61 628.95 Pass 11825.00 8776.60 11700.00 9034.06 413.03 75.55 213.65 118.96 4.500 1745.961183.26 562.70 Pass 11835.09 8786.30 11800.00 9032.26 411.19 77.07 211.56 122.19 4.500 1666.741161.31 505.43 Pass 11839.98 8791.00 11900.00 9031.37 410.29 78.50 209.46 122.56 4.500 1588.541138.23 450.31 Pass 11850.00 8800.60 12000.00 9029.42 408.46 80.02 207.04 124.96 4.500 1512.571103.91 408.65 Pass 11850.00 8800.60 12100.00 9028.05 408.46 81.43 204.55 122.47 4.500 1440.571076.26 364.31 Pass 11850.00 8800.60 12200.00 9028.28 408.46 82.80 201.81 119.74 4.500 1372.421043.63 328.79 Pass 11863.28 8813.27 12300.00 9027.82 405.74 84.35 198.49 122.27 4.500 1308.97 996.14 312.83 Pass 11875.00 8824.40 12400.00 9025.85 403.33 85.81 194.82 123.26 4.500 1251.76 932.97 318.80 Pass 11875.00 8824.40 12500.00 9027.53 403.33 87.22 191.11 119.55 4.500 1201.25 879.65 321.60 Pass 11887.75 8836.42 12600.00 9034.02 400.47 88.64 186.90 119.89 4.500 1158.41 809.46 348.95 Pass 11900.00 8847.89 12700.00 9033.12 397.72 90.05 182.23 119.11 4.500 1125.23 719.74 405.49 Pass 11904.75 8852.31 12800.00 9029.11 396.59 91.44 177.42 115.69 4.500 1101.03 634.50 466.53 Pass 11914.09 8860.95 12900.00 9026.46 395.68 92.76 172.33 113.69 4.500 1085.09 537.32 547.77 Pass 11922.06 8868.33 13000.00 9018.90 396.33 94.05 167.04 111.54 4.500 1077.27 437.82 639.44 Pass 11925.00 8871.05 13100.00 9015.07 396.57 95.38 161.93 107.58 4.500 1075.33 370.64 704.68 Pass 11939.77 8884.69 13200.00 9012.84 397.85 96.38 156.50 107.87 4.500 1081.03 445.43 635.60 Pass 11950.00 8894.11 13300.00 9004.76 398.73 97.40 151.21 106.43 4.500 1096.81 557.54 539.27 Pass 11950.00 8894.11 13400.00 9002.91 398.73 98.79 146.47 101.70 4.500 1119.12 652.39 466.73 Pass 11963.66 8906.66 13500.00 9000.11 399.99 99.58 141.52 101.70 4.500 1148.77 751.40 397.37 Pass 11975.00 8917.02 13600.00 8994.94 401.04 100.34 136.87 100.97 4.500 1186.26 843.56 342.70 Pass 11975.00 8917.02 13608.35 8994.51 401.04 100.45 136.52 100.63 4.500 1189.68 849.77 339.91 Pass • by BP Alaska Anticollision Report • ~.r ins 1NTEQ Company: $P Amoco Date:.. 12/15!2006 Time: 09:31:28 Page: 2 Field: Prudhoe Bay Reference Site: PB G Pad, Go-ordinate(NE) Reference: WeIL' G-08, True North Reference WeIL• G-08 Vertical (1'VD) Reference: 12:08 4/19/1981 00: 00 65.6 .Reference WellpathP . Plan 6, G-08A Db: Orade Site: PB G Pad Well: G-08 Rule Assigned: Major Risk Wellpath: G-O8 V8 Inter-Site Error: 0.00 ft Reference Offset` Semi-MajorAais Ctr-Ctr No-Go Allowable MD TVD MD TVD lef Offset TFO+AZI TFO-HS Casing/HSi)istance Area Deviation Waroiog ft ft ft ft ft ft deg deg in ft ft ft 13387.92 9029.25 9500.00 7196.42 106. 52 89.99 283.10 18.65 4.000 1934.92 199.15 1735.77 Pass 13383.81 9029.16 9600.00 7257.22 109. 91 93.42 281.88 16.95 4.000 1852.79 193.70 1659.08 Pass 13378.86 9029.05 9700.00 7317.86 114. 00 97.46 280.61 15.08 4.000 1772.59 187.90 1584.69 Pass 13372.98 9028.94 9800.00 7378.86 118. 86 102.22 279.29 13.06 4.000 1694.18 181.41 1512.78 Pass 13365.93 9028.80 9900.00 7439.99 124. 69 107.90 277.93 10.85 4.000 1618.01 174.15 1443.85 Pass 13357.47 9028.65 10000.00 7501.45 131. 70 114.67 276.54 8.45 4.000 1544.19 167.26 1376.93 Pass 13347.10 9028.48 10100.00 7563.64 140. 26 122.86 275.18 5.85 4.000 1472.69 161.56 1311.14 Pass 11600.00 8586.17 11600.00 8586.17 422. 41 422.41 168.81 0.00 4.000 0.001459.71 -1459.71 FAIL 11699.37 8658.09 11700.00 8655.72 424. 66 428.72 168.27 -0.44 4.000 4.24 372.92 -368.68 FAIL 11779.55 8732.60 11800.00 8723.88 424. 50 434.10 169.80 33.38 4.000 49.84 503.11 -453.27 FAIL 11840.27 8791.28 11900.00 8790.95 410. 24 425.09 176.19 89.44 4.000 117.62 761.58 -643.96 FAIL 11885.55 8834.35 12000.00 8857.37 400. 96 421.09 178.11 110.35 4.000 195.32 792.08 -596.76 FAIL 11920.24 8866.65 12100.00 8923.42 396. 18 421.71 178.57 122.35 4.000 278.99 761.99 -483.01 FAIL 11947.61 8891.92 12200.00 8988.52 398. 53 430.13 178.09 132.43 4.000 366.93 719.19 -352.26 FAIL 11969.13 8911.66 12300.00 9052.85 400. 50 438.34 177.44 139.53 4.000 457.79 676.91 -219.12 FAIL 11986.62 8927.59 12400.00 9117.14 402. 16 446.29 176.79 144.71 4.000 550.41 638.98 -88.57 FAIL 12000.00 8939.67 12489.00 9174.31 403. 44 453.24 176.24 148.30 4:000 633.98 605.02 28.95 Pass Site: PB G Pad Well: G-17 Rule Assigned: Minor 111 0 Wellpath: G-17 V7 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/Iisflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 13255.74 9027.74 9400.00 7575.76 213. 26 24.19 321.93 41.67 7.000 1943.82 0.00 1943.82 Pass 13250.00 9027.73 9500.00 7649.00 217 .67 24.69 322.87 41.92 7.000 1852.84 0.00 1852.84 Pass 13237.29 9027.72 9600.00 7722.42 227 .22 25.41 324.69 42.22 7.000 1762.53 0.00 1762.53 Pass 13225.00 9027.72 9700.00 7796.24 236 .46 26.11 326.54 42.59 7.000 1672.79 0.00 1672.79 Pass 13211.79 9027.71 9800.00 7870.43 246 .06 26.85 328.58 43.05 7.000 1583.57 0.00 1583.57 Pass 13200.00 9027.70 9900.00 7944.60 254 .63 27.54 330.53 43.58 7.000 1495.17 0.00 1495.17 Pass 13183.26 9027.69 10000.00 8018.97 266 .33 28.38 333.19 44.23 7.000 1407.68 0.00 1407.68 Pass 13167.68 9027.68 10100.00 8093.40 277 .04 29.17 335.83 45.00 7.000 1321.27 0.00 1321.27 Pass 13151.23 9027.67 10200.00 8168.29 288 .05 29.98 338.76 45.95 7.000 1236.10 0.00 1236.10 Pass 13134.04 9027.66 10300.00 8243.92 299. 05 30.78 342.00 47.13 7.000 1152.09 0.00 1152.09 Pass 13116.17 9027.64 10400.00 8320.42 310 .16 31.59 345.61 48.60 7.000 1069.51 0.00 1069.51 Pass 13100.00 9027.63 10500.00 8397.55 319 .95 32.32 349.35 50.40 7.000 988.45 0.00 988.45 Pass 13079.14 9027.62 10600.00 8476.39 331 .86 33.12 354.10 52.65 7.000 908.53 0.00 908.52 Pass 13060.30 9027.60 10700.00 8557.32 342 .07 33.83 359.30 55.59 7.000 832.16 0.00 832.16 Pass 13041.09 9027.59 10800.00 8639.77 351 .99 34.50 5.35 59.33 7.000 760.23 0.00 760.23 Pass 13021.27 9027.57 10900.00 8723.09 361 .68 35.14 12.38 63.98 7.000 694.13 0.00 694.13 Pass 13000.00 9027.55 11000.00 8807.10 371 .40 35.75 20.65 69.70 7.000 635.44 0.00 635.44 Pass 12979.65 9027.53 11100.00 8891.52 379 .88 36.30 29.98 76.59 7.000 586.47 0.00 586.47 Pass 12957.66 9027.51 11200.00 8976.43 388 .31 36.64 40.71 84.68 7.000 550.41 0.00 550.41 Pass 12935.54 9027.49 11300.00 9062.46 395 .98 36.72 52.47 93.78 7.000 529.76 0.00 529.75 Pass 12913.08 9027.47 11400.00 9149.07 402 .91 36.75 64.75 103.37 7.000 525.78 0.00 525.78 Pass 12910.32 9027.47 11412.10 9159.54 403 .71 36.75 66.24 104.53 7.000 526.45 0.00 526.45 Pass r by BP Alaska Anticollision Report • ~.r ~ai~s 1NTEQ Company: BP Amoco Date: 12/15/2006. Time: 09:31:28 Page: 3 Field: Prudhoe Bay . Reference Site: PB G-Pad Co-ordin9te(NE) Reference. Well: G-08, True North Reference Well: G-08 Verlical(TVD) Reference: 12:08 411 9/4 981-00: 00.65.6 Reference:Welipatb Plant's,G-08A Db: Oracle Site: PB G Pad Well: G-17 Rule Assigned: Minor 1 /1 0 Wellpath: G-17A V16 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable NID TVD MD TVD Ref' Offset TFO+AZI TFO-HS Casing/H~istance Area Deviation. Warning ft ft ft ft ft ft deg deg in ft ft ft 13255.74 9027.74 9400.00 7575.76 213.26 24.19 321.93 41.67 9.625 1943.82 0.00 1943.82 Pass 13250.00 9027.73 9500.00 7649.00 217.67 24.69 322.87 41.92 9.625 1852.84 0.00 1852.84 Pass 13237.29 9027.72 9600.00 7722.42 227.22 25.41 324.69 42.22 9.625 1762.53 0.00 1762.53 Pass 13225.00 9027.72 9700.00 7796.24 236.46 26.11 326.54 42.59 9.625 1672.79 0.00 1672.79 Pass 13211.78 9027.71 9800.00 7870.42 246.07 26.87 328.58 43.05 7.000 1583.59 0.00 1583.59 Pass 13200.00 9027.70 9900.00 7944.52 254.63 34.68 330.64 43.69 7.000 1497.97 0.00 1497.97 Pass 13180.30 9027.69 10000.00 8021.11 268.41 43.30 334.01 44.69 7.000 1415.90 0.00 1415.90 Pass 13162.86 9027.68 10100.00 8099.04 280.29 45.39 337.44 46.03 7.000 1337.61 0.00 1337.61 Pass 13144.98 9027.66 10200.00 8177.85 292.06 46.46 341.20 47.64 7.000 1261.33 0.00 1261.33 Pass 13125.00 9027.65 10300.00 8256.45 304.82 47.57 345.42 49.47 7.000 1186.74 0.00 1186.73 Pass 13107.40 9027.64 10400.00 8335.10 315.47 48.49 349.64 51.58 7.000 1114.43 0.00 1114.43 Pass 13087.76 9027.62 10500.00 8413.80 326.94 49.45 354.43 54.01 4.500 1044.57 0.00 1044.57 Pass 13067.44 9027.61 10600.00 8493.28 338.25 50.36 -0.19 56.95 4.500 979.88 0.00 979.88 Pass 13050.00 9027.59 10700.00 8573.69 347.57 51.07 5.38 60.43 4.500 919.77 0.00 919.77 Pass 13025.00 9027.57 10800.00 8654.19 359.98 51.98 12.34 64.39 4.500 863.76 0.00 863.76 Pass 13000.00 9027.55 10900.00 8732.47 371.40 52.75 19.69 68.74 4.500 813.91 0.00 813.91 Pass 12980.39 9027.53 11000.00 8810.49 379.57 53.26 26.94 73.63 4.500 770.29 0.00 770.29 Pass 12950.00 9027.51 11100.00 8878.44 391.18 53.88 35.19 78.24 4.500 731.21 0.00 731.21 Pass 12925.00 9027.48 11200.00 8937.03 399.48 54.25 42.50 82.55 4.500 697.55 0.00 697.55 Pass 12886.96 9027.45 11300.00 8983.33 409.86 54.52 50.72 86.20 4.500 665.65 0.00 665.65 Pass 12850.00 9027.41 11400.00 9012.20 417.74 54.47 57.59 88.64 4.500 641.54 0.00 641.54 Pass 12805.66 9027.37 11500.00 9028.14 423.64 54.00 64.34 90.07 4.500 632.41 0.00 632.41 Pass 12763.08 9027.33 11600.00 9034.16 425.98 53.13 69.99 90.61 4.500 641.37 0.00 641.37 Pass 12721.48 9027.29 11700.00 9034.54 425.00 51.90 75.00 90.63 4.500 659.92 0.00 659.92 Pass 12681.82 9027.24 11800.00 9035.88 421.02 50.37 79.85 90.72 4.500 689.07 0.00 689.07 Pass 12644.14 9027.20 11900.00 9036.26 414.60 48.63 84.37 90.72 4.500 724.72 0.00 724.72 Pass 12608.87 9027.16 12000.00 9036.00 406.23 46.74 88.55 90.66 4.500 767,54 0.00 767.54 Pass 12575.00 9027.12 12100.00 9033.92 396.25 44.71 92.43 90.48 4.500 815,38 0.00 815.38 Pass 12545.23 9027.09 .12200.00 9033.19 385.65 42.76 95.93 90.40 4.500 868.78 0.00 868.78 Pass 12516.88 9027.05 12300.00 9033.62 374.21 40.77 99.33 90.41 4.500 926.55 0.00 926.55 Pass 12491.05 9027.02 12400.00 9032.85 362.67 38.85 102.36 90.34 4.500 989.58 0.00 989.57 Pass 12466.85 9026.99 12500.00 9032.67 350.94 36.97 105.24 90.31 4.500 1054.59 0.00 1054.59 Pass 12444.27 9027.01 12600.00 9032.41 339.56 35.21 107.82 90.28 4.500 1123.70 0.00 1123.70 Pass 12425.00 9027.29 12700.00 9033.02 329.73 33.71 109.97 90.26 4.500 1192.47 0.00 1192.47 Pass 12400.00 9028.07 12800.00 9035.79 316.29 31.71 112.87 90.36 4.500 1263.24 0.00 1263.24 Pass 12381.82 9028.93 12900.00 9040.20 306.06 30.25 115.04 90.48 4.500 1335.95 0.00 1335.95 Pass 12363.68 9030.03 13000.00 9047.83 295.60 28.77 117.32 90.72 4.500 1410.35 0.00 1410.35 Pass 12350.00 9031.01 13055.22 9051.86 287.59 27.53 119.01 90.87 4.500 1452.07 0.00 1452.07 Pass Site: PB G Pad Well: G-24 Rule Assigned: Major Risk Wellpath: PIan2, G-24A VO Pian : Plan #2 V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go. Allowable NID TVD IYID TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 13255.74 9027.74 10000.00 8790.51 213.26 24.39 3.41 83.15 4.500 1988.38 736.46 1251.92 Pass 13251.11 9027.73 10100.00 8866.38 216.82 24.88 6.00 85.19 4.500 1922.78 751.79 1170.99 Pass 13250.00 9027.73 10200.00 8940.79 217.67 25.11 8.27 87.32 4.500 1858.93 757.49 1101.44 Pass 13238.96 9027.73 10300.00 8996.92 225.97 25.36 11.28 89.01 4.500 1780.30 784.66 995.64 Pass 13239.59 9027.73 10400.00 9030.59 225.49 25.36 12.30 90.10 4.500 1686.76 783.70 903.06 Pass 13250.00 9027.73 10500.00 9037.02 217.67 25.14 11.28 90.33 4.500 1594.20 759.46 834.75 Pass 13260.91 9027.74 10600.00 9031.70 209.26 24.93 9.79 90.15 4.500 1512.04 733.36 778.68 Pass • • by BP Alaska Anticollision Report ~.r ~i~s INTEQ Company: BP Amoco Date:.. 12/15/2006.. Time: 09:31:;28 Page: 4 Field: Prudhoe Bay Reference8ite: PB G Pad Co-ordinate(NE)Reterence: WeICG-08, True North Reference Welk G-08 Vertical (1'VD) Reference: 12:08:4/19/1981 00;00 65.6 Reference Wellpath: Plan 6, G-08A - Db: OraGe Site: PB G Pad Well: G-24 Rule Assigned: Major Risk Wellpath: PIan2, G-24A VO Plan: Plan #2 V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go ` Allowable MD, TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/H3?istaace Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 13275.00 9027.78 10700.00 9030.90 198.36 24.73 8.08 90.12 4.500 1444.64 699.72 744.92 Pass 13300.00 9027.93 10800.00 9030.27 178.57 24.38 5.06 90.10 4.500 1388.25 638.72 749.52 Pass 13325.00 9028.17 10900.00 9029.66 158.38 24.10 2.05 90.08 4.500 1320.22 576.54 743.68 Pass 13335.25 9028.31 11000.00 9029.10 149.97 24.09 0.79 90.04 4.500 1240.58 550.91 689.67 Pass 13350.00 9028.52 11100.00 9028.59 137.88 24.04 358.99 90.00 4.500 1156.98 513.91 643.07 Pass 13375.00 9028.98 11200.00 9028.10 117.19 24.00 355.96 89.96 4.500 1088.24 450.53 637.71 Pass • • Alaska Department of Naturasources Land Administration System Page 1 of 8 .~laska Mapper Land RecordslStatus Plats Recorder's Search S#ate Cabins N~tur;~l '~~~~~' ~2j 1rc~S- tact File Type: ADL '; File Number:... 2$2$5 ~i Printable Case File Abstract See Township, Range, Section and Acreage? t Yes C No New Search LAS Menu.... I Case Summary I Case Detail I Land Abstract File: ADL 28285 As of 12/26/2006 Customer: OOOI07377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISS/APPRV/ACTV AUTH Status Date: 08/19/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: 013E Section: 13 Section Acres: 640 Search Plats Meridian: U Township: O11N Range: 013E Section: 14 Section Acres: 640 Meridian: U Township: O11N Range: 013E Section: 23 Section Acres: 640 Meridian: U Township: O11N Range: 013E Section: 24 Section Acres: 640 Case Actions OS-28-1965 TRACT DEFINED SALE DATE 07-14-1965 STATUS (11) 11 TRACT DEFINED BID TYPE 1 FIXED ROYALTY RATE SALE NUMBER 14 TRACT NUMBER 96 FORM NUMBER 5 DL-1 OCTOBER 1963 CONDITIONAL Y/N N PRIMARY TERM 10 http://www.dnr.state. ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber=028285... 12/26/2006 Alaska Department of Natura~,.~esources Land Administration System Page 2 of 8 07-14-1965 NOTIFICATION LESSEE DESIGNATED NEW REL (20) 20 NOTIFICATION LESSEE OLD REL CODE 21 DISPOSAL NAME NOTIFICATION CID NUMBER 154737 BP EXPLORATION COMPA OLD CID # (SALE NO) 4568 SALE 14 07-14-1965 INITIAL OWNER SEGMENT CODE 1 CID NUMBER 000154737 BP EXPLORATION COMPA WORKING INTEREST % 100 ROYALTY INTEREST % 87.500000 07-14-1965 INITIAL OWNER SEGMENT CODE 1 CID NUMBER 000004568 SALE 14 ROYALTY INTEREST % 12.500000 07-14-1965 BID RECEIVED STATUS (12) 12 BID RECEIVED BID TYPE 1 FIXED ROYALTY RATE TOTAL BONUS BID 121856 DEPOSIT AMOUNT 24375 ROYALTY SHARE % 12.500000 BP EXPLORATION COMPANY (ALASKA) INC., 100% 07-16-1965 LEASE AWARDED STATUS (13) 13 LEASE AWARDED 08-19-1965 LEASE ISSUED EFFECTIVE DATE 09-01-1965 EXPIRATN DATE 08-31-1975 STATUS (20) 20 ACTIVE 08-08-1966 NOTIFICATION LESSEE CHANGED NEW NL (20) 20 NOTIFICATION LESSEE OLD NL (20) 20 NOTIFICATION LESSEE NEW NOTIF LESSEE CID# 107377 BP EXPLORATION USA I OLD NOTIF LESSEE CID# 154737 BP EXPLORATION COMPA 08-11-1966 ASSIGNMENT APPROVED EFFECTIVE DATE 08-08-1966 SEGMENT CODE 1 ASSIGNOR'S CID 000154737 BP EXPLORATION COMPA ASSIGNEE'S CID 000107377 BP EXPLORATION USA I http://www.dnr.state.ak.us/las/Case Abstract.cfm?FileType=ADL&FileNumber=028285... 12/26/2006 Alaska Department of Natural~ources Land Administration System ~ Page 3 of 8 WORKING INTER % ASSIGNED 100 ROYALTY INTER % ASSIGNED 75 02-17-1969 CUSTOMER CHANGED NAME NEW NAME: BP OIL CORPORATION OLD NAME: BP EXPLORATION USA INC. 08-28-1969 CUSTOMER CHANGED NAME NEW NAME: BP ALASKA INC OLD NAME: BP EXPLORATION COMPANY (ALASKA) INC. 10-06-1969 ASSIGNMENT APPROVED EFFECTIVE DATE 10-06-1969 SEGMENT CODE 1 ASSIGNOR'S CID 000154737 BP ALASKA INC ASSIGNEE'S CID 000107377 BP OIL CORPORATION ROYALTY INTER % ASSIGNED 12.500000 12-17-1971 COMMENTS PURSUANT TO AS 38.05, WELL DATA IS REQ UIRED WITHIN 30 DAYS OF LESSEE'S RECEIPT OF THIS NOTICE OR 30 DAYS AFTER THEIR RECEIPT OF SAID DATA. 01-25-1974 CUSTOMER CHANGED NAME NEW NAME: SOHIO PETROLEUM COMPANY OLD NAME: BP OIL CORPORATION 04-08-1974 PATENT RECEIVED EFFECTIVE DATE 03-27-1974 EXPIRATN DATE 03-27-1984 TITLE ACQUISITIONFILE NUMBER NOT ONDOCUMENT. 04-01-1977 UNITIZED EFFECTIVE DATE 04-01-1977 UNIT CODE PB PRUDHOE BAY TOTAL ACRES 2560 UNIT ACRES 2560 LEASE COMMITTED TO PR UDHOE BA Y UNIT AREA. DECISION NOT IN FILE. 02-26-1979 CUSTOMER CHANGED NAME NEW NAME.• SOHIO NATURAL RESOURCES COMPANY OLD NAME: SOHIO PETROLEUM COMPANY 02-21-1980 CUSTOMER CHANGED NAME NEW NAME: SOHIO ALASKA PETROLEUM COMPANY OLD NAME: SOHIO NATURAL RESOURCES COMPANY 03-25-1986 CUSTOMER CHANGED NAME http://www.dnr.state.ak.us/las/Case Abstract.cfm?FileType=ADL&FileNumber=028285... 12/26/2006 • Alaska Department of Natura~esources Land Administration System Page 4 of 8 NEW NAME: STANDARD ALASKA PRODUCTION COMPANY OLD NAME: SOHIO ALASKA PETROLEUM COMPANY 07-07-1987 PARTICIPATING AREA ESTABLISHED EFFECTIVE DATE 12-01-1986 UNIT CODE PB PRUDHOE BAY TOTAL ACRES 2560 UNITIZED ACRES 2560 PARTICIPATING ACRES 640 FORMATION OF THE INITIAL LISB URNS PARTICIPATING AREA. O 1-31-1989 CUSTOMER CHANGED NAME NEW NAME: BP EXPLORATION (ALASKA) INC OLD NAME: STANDARD ALASKA PRODUCTION COMPANY 02-28-1989 COMMENTS ASSIGNMENT OF 16.4246 ROYALTY INTEREST TO SOCO INC AND SUBSEQUENTLY TD BP PR UD. BAY ROYALTY TR UST IS DEFINED IN ORR CONVEYANCE. 02-28-1989 ASSIGNMENT APPROVED EFFECTIVE DATE 02-27-1989 SEGMENT CODE 1 ASSIGNOR'S CID 000107377 BP EXPLORATION (ALAS ASSIGNEE'S CID 000012213 THE STANDARD OIL COM ROYALTY INTER % ASSIGNED 16.424600 02-28-1989 ASSIGNMENT APPROVED EFFECTIVE DATE 02-27-1989 SEGMENT CODE 1 ASSIGNOR'S CID 000012213 THE STANDARD OIL COM ASSIGNEE'S CID 000012212 BP PRUDHOE BAY ROYAL ROYALTY INTER % ASSIGNED 16.424600 12-19-1996 COMMENTS UPPER NET PROFITS ROYALTYINTEREST (NPRI) CONVEYANCE BETWEENBP ALASKA INC. AND BP EXPLORATION (ALASKA) INC. PLACED IN CASE FILE. OS-10-2000 CUSTOMER CHANGED NAME NEW NAME: PHILLIPS ALASKA, INC. OLD NAME: ARCO ALASKA, INC. 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 http://www.dnr. state.ak.us/las/Case_Abstract.cfin?FileType=ADL&FileNumber=028285... 12/26/2006 Alaska Department of Natura~sources Land Administration System ~ Page 5 of 8 ASSIGNORS CID 000107377 BP EXPLORATION (ALAS ASSIGNEES CID 000106346 PHILLIPS ALASKA, INC WORKING INTER % ASSIGNED 36.492700 ROYALTY INTER % ASSIGNED 31.931110 08-43-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000107377 BP EXPLORATION (ALAS ASSIGNEES CID 000106600 EXXON MOBIL CORPORAT WORKING INTER % ASSIGNED 35.822830 ROYALTY INTER % ASSIGNED 31.344980 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000107377 BP EXPLORATION (ALAS ASSIGNEES CID 000033073 MOBIL ALASKA E&P INC WORKING INTER % ASSIGNED .999800 ROYALTY INTER % ASSIGNED .874830 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000107377 BP EXPLORATION (ALAS ASSIGNEES CID 000034758 FORCENERGY INC WORKING INTER % ASSIGNED .020000 ROYALTY INTER % ASSIGNED .017500 08-08-2000 COMMENTS CONVEYANCE & MERGER (UPPER LOWER NPRI & UPPER NPRI) DOC. DATED 6/30/00 BETWEEN STANDARD OIL & BP EXPLORATION WAS PLACED IN THE CASE FILE. 01-02-2001 COMMENTS OVERRIDING ROYALTYINTERESTSARE NOT TRACKED AFTER INITIAL SEPARATION FROM THE WORKING INTEREST. CHECK THE APPROPRIATE RECORDER'S OFFICE. 03-30-2001 ASSIGNMENT APPROVED EFFECTIVE DATE OZ-O1-2001 SEGMENT CODE 1 ASSIGNORS CID 000034758 FORCENERGY INC http://www. dnr. state. ak.us/las/Case_Abstract. cfin?FileType=ADL&FileNumber=028285... 12/26/2006 .Alaska Department of Natura~sources Land Administration System Page 6 of 8 ASSIGNEES CID 000004134 FOREST OIL CORPORATI WORKING INTER % ASSIGNED .020000 ROYALTY INTER % ASSIGNED .017500 07-09-2001 COMMENTS A SUMMATION OF OVERRIDING ROYALTYINTERESTS HAS OCCURRED. INDIVIDUAL OVERRIDING ROYALTYINTERESTSARE NO LONGER TRACKED SEPARATELY. 07-31-2001 CUSTOMER CHANGED NAME NEW NAME: EXXONMOBIL ALASKA PRODUCTION, INC. OLD NAME: MOBIL ALASKA E&P INC. 09-21-2001 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2001 SEGMENT CODE 1 ASSIGNORS CID 000106600 EXXON MOBIL CORPORAT ASSIGNEES CID 000033073 EXXONMOBIL ALASKA PR WORKING INTER % ASSIGNED 35.822830 ROYALTY INTER % ASSIGNED 31.344980 09-26-2002 CUSTOMER CHANGED NAME NEW NAME. CONOCOPHILLIPS ALASKA, INC. OLD NAME: PHILLIPS ALASKA, INC. 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-01-2002 SEGMENT CODE 1 ASSIGNORS CID 000107377 BP EXPLORATION (ALAS ASSIGNEES CID 000106539 CHEVRON U.S.A. INC WORKING INTER % ASSIGNED .309314 ROYALTY INTER % ASSIGNED .270650 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-01-2002 SEGMENT CODE 1 ASSIGNORS CID 000106346 CONOCOPHILLIPS ALASK ASSIGNEES CID 000106539 CHEVRON U.S.A. INC WORKING INTER % ASSIGNED .423315 ROYALTY INTER % ASSIGNED .370401 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-0 I -2002 SEGMENT CODE 1 http://www.dnr.state.ak.us/las/Case Abstract.cfm?FileType=ADL&FileNumber=028285... 12/26/2006 Alaska Department of Natura~sources Land Administration System• Page 7 of 8 ASSIGNORS CID 000033073 EXXONMOBIL ALASKA PR ASSIGNEES CID 000106539 CHEVRON U.S.A. INC WORKING INTER % ASSIGNED .427139 ROYALTY INTER % ASSIGNED .373747 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-O1-2002 SEGMENT CODE 1 ASSIGNORS CID 000004134 FOREST OIL CORPORATI ASSIGNEES CID 000106539 CHEVRON U.S.A. INC WORKING INTER % ASSIGNED .000232 ROYALTY INTER % ASSIGNED .000203 12-31-2002 STATUS CODE STANDARDIZED STATUS CODE 35 ISS/APPRV/ACTV AUTH * * * * * STATUS CODE STANDARDIZATION STATUS CODE CHANGED BYBATCH UPDATE 12-04-2006 ASSIGNMENT APPROVED EFFECTIVE DATE 09-01-2006 SEGMENT CODE 1 ASSIGNOR'S CID 000004134 FOREST OIL CORPORATI ASSIGNEE'S CID 000106346 CONOCOPHILLIPS ALASK WORKING INTER % ASSIGNED .007361 ROYALTY INTER % ASSIGNED .006441 12-04-2006 ASSIGNMENT APPROVED EFFECTIVE DATE 09-01-2006 SEGMENT CODE 1 ASSIGNOR'S CID 000004134 FOREST OIL CORPORATI ASSIGNEE'S CID 000107377 BP EXPLORATION (ALAS WORKING INTER % ASSIGNED .005211 ROYALTY INTER % ASSIGNED .004560 12-04-2006 ASSIGNMENT APPROVED EFFECTIVE DATE 09-01-2006 SEGMENT CODE 1 ASSIGNOR'S CID 000004134 FOREST OIL CORPORATI ASSIGNEE'S CID 000033073 EXXONMOBIL ALASKA PR WORKING INTER % ASSIGNED .007196 ROYALTY INTER % ASSIGNED .006296 http://www. dnr. state. ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber=028285 ... 12/26/2006 Alaska Department of Natural~ources Land Administration System ~ Page 8 of 8 h I Legal Description OS-28-1965 * * *SALE NOTICE LEGAL DESCRIPTION* C14-96 T11N-R13E-UM 13,14,23,24 2,560.00 LISBURNE PARTICIPATING AREA DESCRIPTION T. I1., R. 13 E., U.M. SECTION 13: ALL 640 ACRES CONTAINING 640 ACRES, MORE OR LESS. Last updated on 12/26/2006. Not sure who to contact? Have a question about DNR? Visit the Pu_bfic Information Center. Report technical problems with this page to the 1Neb_m__a_ster. Site optimized for Netscape 7, IE 6 or above. This site also requires that all COQKIE must be accepted. State_of_Aiaska Natural.Resources LA8 Home Copyright Privacy System„Status http://www.dnr. state. ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber=02828 5... 12/26/2006 C] ?~ Terri L. tiubbte BP Exploration AK Inc. PO .Box 196:612 MB 7-5 Anchorage, A.K. 99519 "Mastercard Check" • 89-6/1252 318 DATE I ~ ~ ~~ ~ `'' • • TRAYSMITTAL, LETTER C~IECKLIST WELL YANIE ~~6/ C~ -O~~ PTD# a2 a~ " ~}~.~ Development Service Exploratory Stratigraphic Test iYon-Conventional Welt Circle 4ppropriate Letter /Paragraphs to be Included is Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER Vb'I-IAT ~ (OPTIONS) ~ APPLIES l MliLTI LATERAL ~ The permit is for a new wellbore segment of existing ~ ~ well (If last two digits in Permit No. , AP[ No. 30- - - i API number are Production should continue to be reported as a function of the ,' between 60-69) original AP[ number stated above. PILOT HOLE [n accordance with 20 AAC 26.0050, all records, data and logs !acquired for the pilot hole must be clearly differentiated in both ;well name ( PH) and API number (50_ _ -_~ from records, data and logs i ~ acquired for well I SPACING I The permit is approved subject to full compliance with 20 AAC 'EXCEPTION ~ 25.0». Approval to perforate and produce /inject is contingent ' I upon issuance of a conservation order approving a spacing i ~ exception. assumes the ~ i liability of any protest to the spacing exception that may occur. i DRY D[TCH ~ 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 Fiat caught and 10' sample intervals j through target zones. ;Please note the following special condition of this perrrti*_: Non-Conventional production or production testing of coal bed methane is not allowed j Well ~ for (name of well) until after ~Com,_panv Name) has designed and implemented a water welt testing program to provide baseline data on water quality and quantity. (Com~anv Name) must contact the 'Commission to obtain advance approval of such water well testing I I i ,Program. Rev: t'2~i06 C `jody'~transmiRal_checklist WELL PERMIT CHECKLIST Field 8 Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT G-08A Program DEV Well bore seg r ] PTD#:2061830 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV! PEND GeoArea 890 Unit 11650 OnlOff Shore ~ Annular Disposal [i Administration '1 Permit_fee attache_d_ - - - - - - - -------------------- Yes . - i 2 Lease number appropriate- - . Yes - . - - 3 Uniquewell_nameandnumber___________________________ ___________Yes- _-------__., 4 Well located in_a defined_pool _ _ _ Yes - _ - - - . - - 5 Well located proper distancefrom drilling unit-boundary_ - - - - . - - Yes . - - - - - - - - ------------------------ 6 Well located proper distance from other wells, - - _ _ - - - Yes _ _ - _ _ _ _ _ _ ~7 Sufficient acreage-available in_drilling unit_ - _ Yes i;8 If deviated, is_wellbore plat_included - Yes - i9 Operator only affected party Yes 10 Ope[atorhas-appropriate-bond infprce______________________ ___________Yes_ __-_.- 11 Permitcan be issued without conservation order- - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ - _ _ _ _ _ _ , . Appr Date 12 Pe[mit_can be issued without administrative_appr_oval Yes - - . - - - - ACS 12127/2006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by_ Injection Order # (put 10# in_comments)_(For_ NA- - - . - - . - 15 All wells-within 1/4_mile area of review identified (For sere-ice well only)- - - - - - - - - - - - - NA- - - - _ - . _ _ - - , _ - - _ ---------------------------------------------------------- 16 Pre-produced injector: dur_at_ion of pre production Less than_ 3 months_ (For_seruice well only) - NA_ _ _ - - 17 Nonconven, gas conforms to A$31,05,D30Q.1,A),(~.2.A-D) N_A_ Engineering 18 Conductor stringprovided - - - - - - - - - - - - - - - - - - - - _ - - - - - _ _ - - _ - - - - - _ - NA_ _ _ ---------- _ _ _ _ Conductor satin G-08_(1.81-048), _ _ _ _ _ _ _ _ _ _ 19 Surface casing_protects all_known_ U$DWs - - - NA_ - - ...Surface casin set i4 G-08.- - - 9- 20 CMT_vol_ adegu_ate_to circul_afe_on conducto[& surf_csg NA- - Surface casing set in_ G-DB.. - .. . !, 21 CMT_vol adequate_to tie-in long string to_surf csg_ NA- - - _ _ - . - Intermediaie_ casing set in_G-08. - - - 1 22 CMT.will cover all known-productive horizons_ - - _ - - - - . Yes _ - - ~, 23 Casing designs adequatef_orC,T,6&_permafr_ost Yes-- --------------------- ------------.---- --- ------_-- 24 Adequate tankage-or reserve pit . - - - - - - - - - - - Yes - - Rig is-equipped with st_eel_pits. No resen!e_p_itplanned, All waste to approved disposal wells. 25 If a-re-drill, has_a 10-403 for abandonment been approved - - - - - - - - - - - - - - - - - - - Yes . - - - - - - - - 306-402.- - - - _ - - - . - . - - 1 26 Adequate wellbore separatio_nproposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ _ - .Proximity analysis performed, Close approaches identified.- Nearest segment_is original well & pat hs diverge. 27 If diverter required, does it meet regulations_ Yes _ _ _ . - BOP stackwil_I alread -be in -lace. Appr Date 28 Drilling fluid_ program schematic_& equip listadequate- - - - . - .. - Yes - - Maximum expected formatipn pressure 7,1_EMW._ Planned MW 8.6ppg._ TEM 12/2712006 2g BOPEs,_do they meet_ regulation _ _ _ _ _ _ _ - _ _ - Yes _ - - - - - . _ _ - _ 3D BOPS-press rating appropriate; test to-(put psig in comments)- - Yes MASP calculated at 2340psi, Planned BOP_test pressure 3500 psi._ 31 Choke manifold complies wlAPl RP-53 (May 84)_ _ _ _ _ _ Yes _ - - - - - - - - - - - - - - - - - - - - - - 32 Work will occur without operation shutdown_ _ _ _ _ _ _ Yes _ _ . - _ _ _ _ _ _ --------------------------------------------------------------- / 33 3 Is presence of H2S gas probable M l d Yes . - . - - H2S is present in Prudhoe Bay: Mud should-preclude H2$ on rig. _Rig has sensors_and alarms, 4 echanica _con itron of wells within AOR verified For service well only) NA - - Geology 35 Permit can be issued w/o hydrogen-sulfide measures No_ 36 Data-presented on_ potential overpressure zones.. - . .. NA_ ------- Appr Date 37 Seismic analysis of shallow gas_zones_ NA- - - -------------------- - - - ACS 12/27/2006 j 38 Seabed condition curve rf off_-shore Y( ) NA 1 39 Contact namelphone for weekly_progress reports-[exploratory only] - - - - - - - - - - - - - - - - NA _ _ _ _ _ _ - - _ . Geologic Engineering Commissioner: Date: Co missione . Date ~~~ ~Z Date ~ l2 ~~~ ~ °'~ a Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to sirn.piify 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 08/12/31 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 07/03/09 1368209 O1 3.0" 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. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 11454.0000: Starting Depth STOP. FT 14004.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: G-08A FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 19' 17.892"N 148 deg 43' 12.180"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 09 Mar 2007 API API NUMBER: 500292058101 Parameter Information Block #MNEM.UNIT Value SECT. 12 TOWN.N T11N RANG. R13E PDAT. MSL EPD . F 0 LMF DF FAPD.F 65.6 DMF DF EKB .F 0 EDF .F 65.6 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks 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 (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless (3) All True Vertical Depths (TVDSS) (4) All Formation Evaluation data is (5) Baker Hughes INTEQ utilized Coil' Advantage otherwise noted. are Subsea corrected. realtime data. Prak downhole tools and the 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. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated 11 Mar 2007 per BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from G-08 through a milled window in a 7 inch liner. Top of window 11619 ft.MD (8533.9 ft.TVDSS) Bottom of window 11626 ft.MD (8538.9 ft.TVDSS) (9) Tied to G-08 at 11539 feet MD (8477.5 feet TVDSS). (10) The interval from 13964 feet to 14004 feet MD (8962 feet to 8961 feet TVDSS) was not logged due to sensor to bit offset at well TD. 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 ohm.m RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, TVD -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 11457.6, 11458.4, ! 0.829102 11465, 1 1463.8, ! -1.24414 11466.5, 11465.4, ! -1.03711 11471.7, 11469.8, ! -1.86621 11476, 1 1473.5, ! -2.4873 11478.3, 11475.6, ! -2.69434 11479.7, 11477.5, ! -2.28027 11483.3, 11482.2, ! -1.03711 11488.7, 11486, ! -2.69531 11493, 1 1490.5, ! -2.4873 11493.8, 11491.4, ! -2.48828 11498, 1 1494.7, ! -3.31641 11502.3, 11500.1, ! -2.28027 11504.6, 11502.3, ! -2.28027 11509.4, 11507.3, ! -2.07324 11517.7, 11515.2, ! -2.4873 11521.8, 11519.6, ! -2.28027 11526.2, 11525.6, ! -0.621094 11531.2, 11529.5, ! -1.6582 11535.7, 11533.6, ! -2.07324 11539.7, 11537.4, ! -2.28027 11545, 1 1543.6, ! -1.45117 11582.1, 11580.8, ! -1.24414 11601.2, 11600.1, ! -1.03613 11612.1, 11612.1, ! 0 11618, 1 1619.2, ! 1.24316 11623.3, 11623.5, ! 0.207031 11624.4, 11625.2, ! 0.829102 11625.8, 11626.9, ! 1.03613 11668.4, 11669.7, ! 1.24414 11673.2, 11674, ! 0.829102 11688.3, 11690, 11706.5, 11708.6, 11732.8, 11734.9, 11743.6, 11745, 11748.4, 11750.2, 11758.3, 11760.4, 11774.7, 11776.1, 11780.9, 11782.1, 11807, 11809.3, 11821.7, 11824, 11867.2, 11869.9, 11875, 11877.5, 11901.2, 11903.9, 11908, 11910.7, 11951.7, 11951.3, 11957.7, 11957.9, 11970.1, 11970.7, 11972.4, 11972.6, 11979.9, 11980.7, 11981.9, 11982.6, 11986.1, 11987.3, 11994.2, 11994.6, 12001.6, 12002, 12003.4, 12004.9, 12007.2, 12008, 12024, 12024, 12026, 12026.4, 12028.9, 12028.9, 12035.6, 12036.4, 12046.5, 12046.1, 12070.3, 12071, 12081.1, 12080.3, 12083.2, 12083.2, 12085.3, 12085.7, 12108.1, 12107.9, 12110.6, 12110.4, 12114.1, 12113.9, 12119.1, 12119.9, 12124.7, 12125.5, 12128.6, 12128, 12130.7, 12131.5, 12131.5, 12132.6, 12135.9, 12137.5, 12143.3, 12144.2, 12149.4, 12150.4, 12156.4, 12156.6, 12163.7, 12163.5, 12172, 12172.8, 12184, 12185.7, 12190.2, 12192.9, 12196, 12198.7, 12198.5, 12201.4, 12213.4, 12216.8, 12231.7, 12233.5, 12239.3, 12241.8, 12245.6, 12247, 12256.1, 12255, 12293.6, 12292.6, 12296.3, 12295.7, 12354.3, 12353.5, 12366.2, 12368.5, 12377.8, 12380.3, 12386.9, 12386.7, 12392.7, 12391.5, 12401, 12401.4, 12410.3, 12409.5, 12416.5, 12415.7, ! 1.6582 ! 2.07227 ! 2.07324 ! 1.45117 ! 1.86621 ! 2.07324 ! 1.45117 ! 1.24414 ! 2.28027 ! 2.28027 ! 2.69531 ! 2.4873 ! 2.69434 ! 2.69434 ! -0.414062 ! 0.208008 ! 0.621094 ! 0.208008 ! 0.829102 ! 0.62207 ! 1.24414 ! 0.415039 ! 0.415039 ! 1.4502 ! 0.829102 ! 0 ! 0.415039 ! p ! 0.829102 ! -0.415039 ! 0.62207 ! -0.829102 ! p ! 0.415039 ! -0.207031 ! -0.207031 ! -0.208008 ! 0.829102 ! 0.830078 ! -0.62207 ! 0.829102 ! 1.03711 ! 1.6582 ! 0.829102 ! 1.03711 ! 0.207031 ! -0.207031 ! 0.829102 ! 1.6582 ! 2.69531 ! 2.69531 ! 2.90234 ! 3.31641 ! 1.86523 ! 2.48828 ! 1.4502 ! -1.03613 ! -1.03613 ! -0.621094 ! -0.829102 ! 2.28027 ! 2.4873 ! -0.207031 ! -1.24414 ! 0.414062 ! -0.829102 ! -0.829102 12421.8, 12422.9, 12428.3, 12429.3, 12435.5, 12437.4, 12437.6, 12439.5, 12443.2, 12445.5, 12476.2, 12477.5, 12485.4, 12487.2, 12489.7, 12491.8, 12498.8, 12499.2, 12504.6, 12506.7, 12550.1, 12551.3, 12555.3, 12557.5, 12598.7, 12601.8, 12604.3, 12607.8, 12611.5, 12613.6, 12613.4, 12615.9, 12618.6, 12619.2, 12620, 12621.3, 12623.8, 12624.6, 12627.3, 12631.8, 12637.3, 12640.8, 12651, 12655.1, 12657.2, 12660.5, 12686.9, 12688.3, 12698.3, 12698.7, 12701.8, 12702.6, 12714, 12713.6, 12727.1, 12727.1, 12849.1, 12844.5, 12862.6, 12862.1, 12869.8, 12867.1, 12877.7, 12873.5, 12889.7, 12885.4, 12898.6, 12894.7, 12905.5, 12899.3, 12909.6, 12904.3, 12919.2, 12916.3, 12922.9, 12918.6, 12928.7, 12924.2, 13010.7, 13007, 13013.6, 13010.7, 13046.2, 13044.7, 13049.9, 13049.1, 13056.3, 13055.1, 13066.1, 13064, 13069.5, 13070.1, 13074.7, 13075.3, 13078.8, 13078.2, 13097.3, 13095.8, 13132.4, 13132.2, 13135.1, 13135.1, 13137.4, 13137.2, 13142.8, 13142.8, 13148.8, 13149, 13151.1, 13151.3, 13154.4, 13155.2, 13160.4, 13160.6, 13167.1, 13166.6, 13167.7, 13167.9, 13241, 13240.1, 13244.9, 13242.6, 13275.9, 13274.6, 13299.5, 13298.9, 13308.4, 13309, 13310.5, 13310.9, 13320, 13320, 13491.7, 13495.2, 1.03613 1.03613 1.86523 1.86621 2.28027 1.24414 1.86621 2.07324 0.414062 2.07324 1.24316 2.28027 3.10938 3.52441 2.07324 2.4873 0.621094 1.24316 0.830078 4.56055 3.52344 4.14551 3.31641 1.45117 0.415039 0.829102 -0.414062 0 -4.56055 -0.415039 -2.69434 -4.14551 -4.35254 -3.93848 -6.21875 -5.38965 -2.90137 -4.35254 -4.56055 -3.73145 -2.90234 -1.45117 -0.829102 -1.24414 -2.07324 0.621094 0.62207 -0.62207 -1.45117 -0.207031 0 -0.207031 0 0.207031 0.207031 0.829102 0.207031 -0.415039 0.208008 -0.829102 -2.28027 -1.24414 -0.62207 0.62207 0.415039 0 i 3.52344 13497.3, 13500.2, ! 2.90234 13503.7, 13507.1, ! 3.31738 13520.1, 13524.2, ! 4.14648 13524.6, 13529.2, ! 4.56055 13544.7, 13549.1, ! 4.35352 13550.9, 13555.5, ! 4.56055 13581.1, 13585.5, ! 4.35254 13614.5, 13619, ! 4.56055 13648.9, 13653, ! 4.14648 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 249 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN G-O8A_5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN G-08A 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 adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated 11 Mar 2007 per 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 Total Data Records: 142 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 11454.000000 Tape File End Depth = 14004.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 155 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN G-08A.xtf LCC 150 CN BP Exploration (Alaska) WN G-08A 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 MWD data. *** INFORMATION TABLE: LIFO 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: 284 Tape File Start Depth = 11454.000000 Tape File End Depth = 14003.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 297 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/03/09 • • 1368209 O1 **** REEL TRAILER **** MWD 08/12/31 BHI Ol 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 11454.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11454.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11500.0000 119.3915 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11600.0000 32.8935 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11700.0000 24.1299 17.9149 2000.0000 2000.0000 47.3230 34.2617 11800.0000 21.4071 10.6000 2000.0000 91.0314 47.2730 45.3240 11900.0000 21.1389 27.1199 2000.0000 79.4225 40.0523 33.4420 12000.0000 29.4200 85.6908 14.9634 9.7788 8.9081 7.8363 12100.0000 24.6538 73.0142 19.8930 22.6308 15.9439 15.1201 12200.0000 66.3725 44.2839 10.2735 8.7377 8.3580 8.4547 12300.0000 79.7504 24.2229 20.7203 18.7289 14.6976 13.0153 12400.0000 47.2264 119.1916 16.2840 16.2389 14.0213 13.8961 12500.0000 112.8457 77.2935 23.1532 20.3315 17.1785 16.3025 12600.0000 73.1982 70.7876 17.7372 15.1201 12.1607 11.8554 12700.0000 68.2158 119.3257 14.1861 13.7423 12.3456 12.1855 12800.0000 81.3575 130.9874 28.8770 22.9124 19.3792 17.5432 12900.0000 54.0927 91.6293 21.6558 21.7646 23.3994 28.2496 13000.0000 192.7390 67.6931 10.6416 8.2959 7.1484 6.7678 13100.0000 25.4998 106.3191 13.5552 14.4514 13.9958 15.2672 13200.0000 24.1626 92.5531 15.2669 18.5444 17.3400 19.4093 13300.0000 36.3248 129.4628 23.0250 20.0821 15.4846 13.8700 13400.0000 28.362E 124.3963 18.3230 16.4710 13500.0000 26.8536 483.7645 17.3338 16.9065 13600.0000 29.5904 87.3452 13.6572 13.5136 13700.0000 28.9043 143.5996 17.7555 20.6307 13800.0000 24.2598 174.8023 14.0015 16.6690 13900.0000 26.8395 149.9812 12.0807 12.1685 14000.0000 -999.2500 70.8789 -999.2500 -999.2500 14009.0000 -999.2500 121.3785 -999.2500 -999.2500 Tape File Start Depth = 11454.000000 Tape File End Depth = 14004.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • 25.8680 17.8504 14.1671 15.3883 11.5486 13.2295 -999.2500 -999.2500 21.5866 21.2158 15.3152 20.1409 14.3415 12.8669 -999.2500 -999.2500 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 11454.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11454.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11500.0000 56.3000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11600.0000 27.1000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11700.0000 24.8000 17.8000 2179.3999 3825.0171 44.6850 32.9570 11800.0000 24.9000 305.6000 1939.5369 70.7640 48.6070 52.5440 11900.0000 20.8000 29.1000 2179.3999 57.8150 35.5750 32.8720 12000.0000 29.5000 51.6000 15.0290 9.7460 8.6680 7.5290 12100.0000 24.6000 73.0000 19.8930 22.6290 15.9330 15.1110 12200.0000 50.4000 54.6000 10.8310 9.2280 8.5740 8.6930 12300.0000 80.8000 24.3000 20.9210 18.8050 14.7830 13.0920 12400.0000 46.6000 118.6000 16.2840 16.2800 13.9740 13.8700 12500.0000 109.5000 77.9000 22.9860 20.3860 16.9210 16.3590 12600.0000 101.7000 99.8000 16.3540 13.0040 11.3920 10.2770 12700.0000 72.5000 120.1000 14.2630 13.9030 12.4340 12.2800 12800.0000 73.8000 577.2999 29.0230 23.3550 19.4390 18.0250 12900.0000 34.9000 83.7000 23.8080 23.7960 22.7660 24.2280 13000.0000 176.6000 69.7000 11.4760 8.2040 7.2420 6.3980 13100.0000 32.8000 119.6000 13.2660 14.0560 13.2370 13.6000 13200.0000 23.7000 92.9000 15.2380 18.6190 17.3400 19.2890 13300.0000 36.7000 128.9000 23.0250 19.9770 15.6000 13.8700 13400.0000 23.8000 151.4000 18.1890 16.4710 13500.0000 36.9000 141.2000 16.9120 16.8840 13600.0000 31.9000 88.7000 13.9740 14.5010 13700.0000 25.4000 114.1000 16.5090 18.3590 13800.0000 21.8000 156.0000 13.9740 16.2490 13900.0000 25.9000 195.4000 10.8470 11.0090 14000.0000 -999.2500 110.8000 -999.2500 -999.2500 14003.7500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 11454.000000 Tape File End Depth = 14003.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • 25.8680 17.3560 13.7450 14.8340 11.6820 11.7470 -999.2500 -999.2500 21.8220 21.4760 15.2530 18.0890 14.3020 11.1010 -999.2500 -999.2500 Tape Subfile 4 is type: LIS