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Home My WebLink About208-171 STATE OF ALASKA AKA OIL AND GAS CONSERVATION COM, ;ION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubin❑ Operations shutdown ❑ Performed Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter CasinTri Change Approved Program ❑ Plug for Rednll n'erforate New Pool n Repair Well n Re-enter Susp Well n Wellhead Repair-Welding n 2 Operator 4 Well Class Before Work: 5.Permit to Dnll Number Name BP Exploration(Alaska),Inc Development ❑✓ Exploratory ❑ 208-171-0 3 Address P O Box 196612 Stratigraphic E Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20120-03-00 7 Property Designation(Lease Number). 8 Well Name and Number ADL0028281 PBU J-05C 9.Logs(List logs and submit electronic and pnnted data per 20AAC25 071) 10.Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 12069 feet Plugs measured NoneE( I q,E D true vertical 8707 88 feet Junk measured None a �r Effective Depth measured 12069 feet Packer measured See Attachment feet MA 0 7 2015 true vertical 8707 88 feet true vertical See Attachment feet AOGCC Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 28 09-108 09 28 09-108.09 0 0 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production 9957 41 7"26#L-80 25 06-9982 47 25 06-8652 12 7240 5410 Liner None None None None None None Perforation depth Measured depth 9982-11315 feet 11315-12069 feet C ''`` (Q l5 True Vertical depth 8651 89-8685 93 feet 8685 93-8707 88 feet SCkNtiE� MAI l 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 descnptions 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 0 0 0 0 0 Subsequent to operation 0 0 0 0 0 14 Attachments(required per 20 AAC 25 070 25 071,8 25 283) 15 Well Class after work Daily Report of Well Operations ❑ Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16 Well Status after work Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt 315-022/315-023-05CL1 Contact NitaSummerhays Email Nita.Summerha s• b•.com Printed Name Nita ummerhays Title Petrotechnical Data Manager SignatureAllir-;—,....reer_AV —' �J Phone 564-4035 Date 5/7/2015 vii- vJ4/5s RBDMSSc MAY 1 1 2015 fi'Y/f ,! II Form 10 404 Revised 10/2012 II Submit Original Orly Daily Report of Well Operations ADL0028281 AGTIVIT Starting head welding, prep: Initiate Haz confined space and hot work permits, review L2TRS. Weld thermal 6 coupling's and Rig up Cooper heat pad's fo AM 4/2/2015 start. T/I/O/OO= 90/90/90/34. Temp= SI. N2 Purge (SH repair). No AL. Held open bleed on FL in skid & maintained N2 purge on OOA as needed. Cleaned WH for welding. Job complete. See log for additional details. 4/2/2015 SV&WV=C. SSV& MV=O. IA, OA & OOA=OTG.1820 hrs. Starting head welding: Bring cooper heat to 550 degrees and soak for 4 hours. Weld the starting head collar both top and bottom per welding procedure, reduce heat to 450 degrees for 2 hours bake out. DHD maintaining the purge and monitoring the temperature. Tbg FL =138' - IA FL=114'T/IA/OA/OOA= 4/3/2015 87/91/94/30 T/I/O/OO = 90/90/90/30, Temp: SI, Monitor OC test void for SH weld Stung into OC test void, (0+ psi) rigged up hose and ran outside of wellhouse into bucket. Bled void to 0 psi, held open bleed during warm up. Monitored every 30 minutes. Once warm up complete, WSL instructed to RD manifold before welding 4/3/2015 operations. RD manifold and replaced alemite cap. **WSR continued from 4/3/15** Maintain N2 purge during cool down. Grind off thermal couple nuts. (See log for details). Job complete. Final WHPs= 90/90/90/15. 4/4/2015 SV, WV= C. SSV, MV= O. IA, OA, OOA= OTG. 17:00 T/I/O/OO = 85/90/85/ Temp = SI. MIT-OOA to 600 psi (SH Weld). No AL. Cellar floor removed. Initiated Non-Haz Confined Space Permit. NDT crew inspects well and gives an OK. RU to OOA and PT lines. 4/6/2015 **Continued on 04-07-15 WSR** **Continued from 04-07-15 WSR** MIT-OOA to 600 psi PASSED (SH Weld). Used 8.4 bbls DSL to increase OOAP from 4 to 600 psi. On 1st test, OOA lost 17 psi in 1st 15 min, 7 psi in 2nd 15 min, fora total loss of 24 psi in 30 min. Bled OOA to 0 psi in 10 min (1.3 bbls). OOAP increased 10 psi in 30 min. FWHPs = 85/90/80/10. 4/7/2015 SV, WV= C. SSV, MV= O. IA, OA= OTG. NOVP. 0330 T/I/O/OO = 80/90/80/10. Temp = SI. Cellar prep (Remove grating). No AL. OOAP ops gauge. Removed grating. Drawing &clips/screws in box on top of hydraulic fluid tank (back of wellhouse wall). Placed heater trucks in cellar depressured tree cap (door cracked). 4/12/2015 SV= C. WV= LOTO. SSV, MV= O. IA, OA= OTG. NOVP. 15:00 ***WELL S/I ON ARRIVAL***(wellhead/tree repair). SET 4-1/2"WHIDDON C-SUB @ 9,625' SLM. PULL ST#1 BK-FLOSLV @ 8,897' SLM/8,929' MD. PULL ST#3 BK-DLGV @ 5,443' SLM/5,468' MD. PULL ST#4 BK-DGLV @ 3,073' SLM/3,095' MD. SET ST#4 BK-LGLV(16/64", 1500#) @ 3,073' SLM/3,095' MD. 4/14/2015 ***JOB IN PROGRESS, CONTINUE ON 4/15/15 WSR*** T/I/O/OO = 80/90/80/10. Temp = SI. Install grating. (SH repair). No AL. Re- installed floor grating. SV, WV= C. SSV, MV= O. IA& OA= OTG. Unable to verify OOA valve position due to cellar depth. 11:45 4/14/2015 I' hi tai Daily Report of Well Operations ADL0028281 *** •NTINU P `•M 4/14/15 R***(wellhead/tree repair). SET ST#3 BK-LGLV(16/64", 1450#) @ 5,443' SLM/5,468' MD. SET ST#1 BK-DGLV @ 8,897' SLM/8,929' MD. PULL EMPTY 4-1/2"WHIDDON C-SUB @ 9,625' SLM. PULL P-PRONG @ 9,630' SLM. PULLED 4-1/2" PX PLUG BODY FROM 9,636' SLM/9,673' MD. (see log for details). 4/15/2015 ***WELL S/I ON DEPARTURE***(pad op notified of well &wellhead status). FLUIDS PUMPED BBLS 9.5 DIESEL 9.5 TOTAL 1!1. �Ii a) Q O O O O o O O ccCO (NQDOO p tLn °ON- ti U DDD O O O i N N- V CO OM CO CO 3 O CO N COV" 'Cr m Lo CO f— N co co • a co N co 00 V N O V O (xiN- V N0,5 "— N 00 co co Lo CO '- CO V CO LC) co co N LO CO O N CO CO I-- L O N- O) CO •- CO O) CO N- O O r O N CO CO LO 00 LO N- N O N N '- N N cN LO N CO CO CI) co CO N v- CO CO CO LO CO C) CO V CO CD N co O O N 0) O) 4-1 CO < co C) N co a co LO r,- CO CO Co N N N N NCO N 0) = Co Lnl.f) in O 00 O LO CO C co , a? DYO J a} ZZaoc *k00� k It cu c0 N x 00 co co CC O OO -• N _ _ U LO CV • rn v V +-' N CS) I- CO LO COO CO CO LO O '- N O CO 1- N- O CA N- a) N CO O) CCI 1- O) J W W Et I H Z 0) Q Q O c Oo o - ~ W w ~ W W V OCC CCO li w Z Z Z W W O CCCC m m OZZdu) WF- H tt It )i� lid I i 0 a) Y Y W C N O d a O.Y r N Q• Y a Q X X a) N N - Y RS ca 4) Q) m m �c �c _ C m m N N V L in CO ott C3 • V > U7 OO ~ ch ch V Lo N O c O -0 Q L LU O LU Op CD En O) co Lb 2 oo rn v r- f� Co I� LU LU 0) O) a a, wwww 0- >.C.) C.) 0 C.) _>+000U d d d d E U U U U aLUininin Z o 0 0 0 1- Ali �l TREE=� CJ 0 5 C WLHTAD= CM NV � 1Y NOTES:WELL ANGLE>70°@ 10015'. ACTUATOR= BAKER C ,;AB LNR HUNG OFF EMERGENCY SLIPS. __.___.. Ll •••4-1/2"CHROME TBG"` OKB.aE1/= 58.15 BF.t3EV= 38.25' KOP= 3107' Max Angle= 93°0 10273' 30"CONDUCTOR - 036" 1 PBR D=? Datum M)= NA Datum TVD= 8800'SS C 2151' H 13-3/8"X 9-58"XO,D=8.681" 219T H 9-5/8"FO alENTER 13-3/8"CSG,68#,D=12.415" H 2151' (7/ ' 2235 H4-1/2"HES X No,D=3.813" 9-5/8"SCAB CSG,_#, , ,D=? - 2169' 18-5/6'CSG,96.5#/109#,K-55,BTRS, !H 2553' , 2 1-I 9-5/8"FO CEMENTER D=17.655"/17.563"?? CARO GAS LFT MANDRILS ST MD TVD DEV TY FE VLV LATCH PORT DATE Minimum ID = 3.80" @ 9823' . 4 3095 3092 10 KG82 DOME BK 16 04/15/15 4-1/2" HES XN NIPPLE '`- 3 5468 5081 40 KGB2 DOW BK 16 04/15/15 2 7346 6565 36 KGB2 MY BK 0 01/19/09 1 8929 7837 34 KG82 DAY BK 0 04/15/15 r TEBK,26#,L-80 BTD-M,.0383 bpf,0=6.276' -1 5802' -, 5790' -19-58"X r BKR ZXP TEBK PKR,D=6.313' TCP OF 7'LNR H 6802' b802' I-9-58'X r BKR ZXP LTP,D=7.50' 7' VN-%STOCK()X/XX/X) -I 6900' t 5818' H9-5/8"X 7"BKR HMC HGR,D=6.313" 9-5/8"BKR EZSV H 6986' I FALLOUT 1MWDOW(J 05B) 5956'-598T 9-5/8'CSG,47#, -I 10510' L-80,D=8.681" ' 9628' -14-1/2"FES X NP,D=3.813' �� 9649' H r x 4-12'BKR S-3 FER,D=3.870" ' 9673' --14-172'HES X NP,D=3.813" 4-12"TBG,12.6#,13CR-80 VAM TOP, -{ 9736' .0152 bpi,D=3.958' 1 9751' j r x 4-1/2'UNIQUE OVERSHOT 4-12"TBG STUB(01/09/09) 9725' ELMD' ' 9765' H4-1/2"FES X NP,D=3.813' EF-~ 9778' H r x 4-12"BKR S-3 FKR,D=3.875' 9802' -14-1/2'HES X NP,D=3.813' ' 9823' -4-12'FES XN,MLLED TO 3.80'(01/25/09) 4-12'TBG,12.6#,L-80,.0152 bpf,D=3.958' -I 9836' '----{ 9835' H4-12'WLEG,D=3.958" r LM.26#,L-80,BTC M.0383 bpf,D=6.276' - 9985' I 10110' H 3-3/4"OPEN HOLE SIDETRACK J-05B J-05C L1 OFEN HOLE TD H 11316' I- ...) ) 3-3/4-OPEN HOLE TD `-- 11740' 4-1/8'OPEN HOLE TD - 12070' J-05 C DATE REV BY COMMENTS DATE REV BY ( JUTS PRUDHOE BAY UNIT 11/ ORIGINAL COMPLETION 06/24/14 DIJ-I/JMD SET PLUG/GLV CIO(06/22/14) C WELL J-05C/J-05L1 05/24/98 SIDETRACK(J-05A) 04/08/15 PJC GLV LATCH TY FE CORRECTIONS PERMIT Pb_ 2081710/2081720 03/14/00 SIDETRACK(J-05B) 04/15/15 JLS/PJC RAI PX PLUG/GLV CJO API No: 50-029-20120-03,(60) 02/01/09 NORDIC2 CTD ML(J-05C/CL1) SEC 9,T11 N,R13E,650'FPL&1245'FEL 09/07/10 SMJM) DRLG DRAFT _ ! 0412211 1 MCMWPJC GLV C/O(04/10/11) BIploration(Alaska) l l TTT��I III I ISI • 0:1 ;O � 71/// ,7/114",s.,, THE STATE Alaska Oil and Gas ofl 1LAsKA Conservation Commission _ .#2__ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1 433 OF ALAS r" Fax 907.276.7542 c www aogcc.alaska.gov S �ED JAN. 2 2 `LD is UFul Carrie Janowski Well Interventions Specialist BP Exploration (Alaska), Inc. cq 0 1 71 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU J-05C Sundry Number: 315-022 Dear Ms. Janowski: 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, Cathy P. oerster Chair DATED this day of January, 2015 Encl. RECEIVED • STATE OF ALASKA JAN 1 3 201 ALASKA OIL AND GAS CONSERVATION COMMISSION DD 5 I I iS 1 15 DI MS APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request Abandon El Plug for Redrill❑ Perforate New Pool❑ Repair Well[• Change Approved Program El Suspend l=1 Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp Well❑ Stimulate❑ After Casing❑ Other. a 0`�Y1Er 2.Operator Name: 4.Current Well Gass_ 5.Permit to Drill Number 6 `�'{j f BP Exploration(Alaska),Inc. Exploratory ❑ Development 2 • 208-171-0 vT,L 3.Address: Stratgraphic ❑ Service ❑ 6.API Number Y20/5— P.O. 20/P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20120-03-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU J-05C • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s). ADL0028281 • PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft). Effective Depth ND(ft). Plugs(measured): Junk(measured): 12069 • 8708 • 12069 • 8708 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" ' 28.09-108.09 28.09-108.09 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production 9957 7"26#L-80 25.06-9982.47 25.06-8652.12 7240 5410 Liner None None None None None None Perforation Depth MD(ft). Perforation Depth ND(ft): Tubing Size: Tubing Grade. Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type. See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 1 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development 0 Service El 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil 0 . Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Came Janowski Email Carrie.Janowski@BP Corn Printed Name Carrie Janowski Title Well Intervetions Specialist Signature Phone 564-5273 Date i /1 3 // 5 Prepared by Garry Catron 564-4424 cc r (.4,,,c. JA.+bu - 1....—; COMMISSION USE ONLY C� Conditions of approval. Notify Commission so that a representative may witness Sundry Number: ✓ — 2---2--`2-- Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes El No u Subsequent Form Required: / 46 4 APPROVED BY )pe.....1,74...._.Approved by: p COMMISSIONER THE COMMISSION Date: /- 2z ./ em VT1- 120/15 0110 `� 4�. Form 10-403 Revised 10/2012 A p e ill valid for 12 months from the date of appro al. Submit Form and Attachments in Duplicate RBDMSAV JAN 2 1 2015/1" /'/,..-----/s--- O -O 0 0 O LO LO OO @ CO CO CO LO LO CO • Z Z Y Y co Q.) Q 0 0 0 0 0 0 0 • CO V N- co co I� N o LO Ln o v 10 N- N U 0 0 0 0 0 0 CO OV CO 0 N CO M V V CO CO LO N- N O CO O a) In CO CO o Ll o LN M co N CO Lf) N o co N o co k- • N- ch N CO CO Lf) Lf) CO 0 Q N N- N N N V N LO • N O CO > ~ 1` E co� r a) a N-t a) m 0 CO 00 ONO co V CO O O O LC) I� CO U) O 0 L() Nrn NOO 0) _1 J O N < F- co co LO in N- V co co Q NN N CN N co N N- 0 0 L0 LO O 0 co Y `� U co O Z Z OD — J co N X *k O c N CT) - o _ O o - - N ao N L Mpp M L!) CO -cr L N o u-) Is O CO CO LO r N o 0) • o 1` CO N O) O a- O) W W F- Z OQ Q O - o o i w U• Q CC C Q u Z Z Z W W O CCCCCOCO OUZZeL DDD Perforation Attachment ADL0028281 Well Date Perf Code MD Top MD Base TVD Top TVD Base J-05C 3/13/00 OH 9982 11315 8652 - 8686 J-05C 1/26/09 OH 11315 12069 8686 8708 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028281 Well Facility Type MD Top Description TVD Top J-05C PACKER 5788 7" Baker ZXP Tie-back Packer 5326 J-05C PACKER 5799 7" Baker ZXP Packer 5334 J-05C PACKER 9647 4-1/2" Baker S-3 Perm Packer 8439 J-05C PACKER 9776 4-1/2" Baker SB-3A HYD PERM PKR 8531 by Date: 1-5-15 To: Well Services Operations Team Lead — Len Seymour/ Tyler Norene From: Well Interventions Specialist— Carrie Janowski Office 564-5273, Cell 575-7336 Subject: J-05 Welding Program Rev 1 AFE: APBNRWOS Step Type Procedure 1 O/D Prep cellar& cut conductor 2 D Remove cmt from around SC, prep for UT and PMI 3 0 Weld per specified program 4 0 Post weld QC Inspection & MPI (magnetic particle inspection) 5 D MIT-00A with diesel to 600 psi 6 S Contingent: Install GLVs, Pull TTP Objective: This program is for repairing the starting head leak on J-05 by welding. The program includes preparing cellar & conductor, welding, and post weld activities. This work will need to be conducted during the winter months when ground water inflowing to the cellar can be managed. Well Detail: Current Status: Not Operable - Producer Previous Test: PPPOT-IC to 3500 psi passed 03-17-13 PPPOT-OC to 1500 psi passed 8-17-14 MIT-OA to 1200 psi passed 6-13-14 MIT-IA to 3000 psi passed 6-13-14 Note: collapse rating of 13 3/8" K-55 and J-55 is 1950 psi x 80% = 1560 psi Integrity Issues: SH leak confirmed 09-11-11 Last Slickline: Set TTP 6-22-14 Min ID: 3.80" @ 9823' (1-25-09 milled out xn) Max Deviation: 93 deg at 10273' SSSV Status: Not Required - out Last H2S Reading: 2 ppm on 1/27/11 BHP/BHT: 2536 psi @ 8800'SS NOTE: 3-16-13 DHD measured cellar depth to be @ 61'. Relevant Well History: DHD confirmed a starting head leak on the upper threads 2/17/11. The gas lift valves were dummied off and the well passed a MIT-IA to 3000 psi on 4-10-11. Several unsuccessful attempts were made to repair the SH leak with a Furmanite clamp (which was removed for the final time on 4-13-12). Prep work for the SH weld began 3-17-13 with a passing PPPOT-IC. A UT was done on a small section (1/2") of the SH 3-18-13 that showed no signs of corrosion. The well was secured with a TTP at 9673' on 6-22-14. PPPOT-OC passed 8-17-14. Please call Carrie Janowski at 564-5273 or 575-7336 with any questions or concerns regarding this program. 1 Special Projects / DHD: Prep for welding 1. Confirm the well and cellar is prepared for welding operations. Cut and remove 30" conductor to make room for installation of heat blankets during the SH welding operations. Recommend cutting approximately 24" of the conductor, final amount to be determined by WSL. 2 DHD: 1. Remove cement from around Surface Casing and clean for UT inspection & PMI. Note: UT from 3-18-13 covered small section of the surface casing. Once conductor and cement are removed, another UT is required over the areas to be welded. The structural analysis performed by EWI (based off UT results from 3-18-13)will be re-assessed if the more comprehensive UT comes back with varying results. 3 Special Projects: Weld 1. Attach thermal couplings and install tile heating blankets. 2. Weld the connection from wellhead to casing coupler and connection from the casing coupler to casing per specified procedure. Follow the RP: "SP—Wellhead Welding" 4 Special Projects: Post weld 1. Remove thermal couplings. 2. QC Post Weld Inspection & MPI (magnetic particle inspection). 5 DHD: Post weld 1. If NDT Passes MIT-00A with diesel to 600 psi, LLR if fails. (MITOOA post Furmanite wrap on 8-25-11 passed to 600 psi) 6 Slickline: 1. Contingent MIT-00A, pull/install GLVs & TTP. TREE= CNV OTES: LL ANGLE>70* M _O SAFETY C .1UATOR= BAKE C SCAB LNR HUNG OFF EMERGENCY SLIPS. ' OKB. ELEV= 58.15 Ll **4-112"CHROME TBG&MPPLES** ORIG WELL, BF.ELEV= 38.25' 1-05A&J-05B NOT SHOWN"' KOP= 3107 I Max Angie= 93"@ 10273' )1 Datum MD= NA Datum TVD= 8800'SS 30'CONDUCTOR —I 98' 2 -I PBR,D=? 13-3/8"CSG,68#,D=12.415" H 2151' ` ;------r _.°416. 2151' H 13-3/8-X 9-5/8"XO,D=8.681" 9-5/8°FOC —I 2197' — 2235' H41/2"I-ES XAV,D=3.813' 9-518°FOC —I 2359' — 18-5/8°CSG,96.5#/109#,K-55,BTRS, —I 2553' , , CAA=GAS LFT M AM3REL.S 13=17.655"/17.563"?? ST MD TVD DEV TY FE VLV LATCH PORT DATE 4 3095 3092 10 KGB2 DM' BK 0 04/10/11 Minimum ID = 3.80" ( 9823' 3 5468 5081 40 KGB2 DMY BK 0 04/10/11 4-1/2" HES XN NIPPLE 2 7346 6565 36 KGB2 DMY BK 0 01/19/09 1 8929 7837 34 KGB2 FLWSLV BEK 0 06/22/14 7"TEBK,26#,L-80 BTD•M,.0383 bpf,13=6.276' H 5802' 5790' —9-5/8'X 7"BKR ZXP TEBK PKR,D=6.313" TOP OF 7"LMR 5802' 1 � 5802' H9-5/8"X 7'BKR ZXP LTP,D=7.50' TOP WHPSTOCK — 5900' 5818' —I9-5/8"X 7"BKR FMC HGR,D=6.313" 9-5/8'EZSV —+ 59$6' \ ' 9628' —I 4-1/2'I-ES X NP,D=3.813' 9-5/8"CSG,47#, — 10510' •::,:::/ 71 X 9649' H7"x 4-1/2"BKR S-3 PIR,13=3.870" L-80,13=8.681' .%., 967$' —14-1/T HES X MP,D=3.813' 9673' —14-1/2"PX PLUG(06/22/14) 4-1/2'TBG,12.6#,13CR-80 VAM TOP, H 9736' .0152 bpf,13=3.958' 1 9751' H7"x 4-1/2'UNIQUE OVERSHOT 4-12"TBG STUB(01/09/09) 9725'ELME/ ' 9765' —14-12"HES XN MP,13=3.725' lg9778' H7"x 4-1/2'BKR S-3 PKR,D=3.875' 9802' H 41/2"HES X NIP,D=3.813" . 9823'--1--14-1/2"FES XN(MLLEO 0125/09)D=3.80" 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" H 9835' ‘ 9835' H4-12"WLEG,D=3.958" 7"LNR,26#,L-80,BTC-M.0383 bpf,D=6.276" --I 9985' 10110' H3-3/4"OPEN HOLE SCETRACK S ) J-06B OPEN HOLE TD —{ 11315' I—� J 3-3/4"OPEN HOLE TD 11740' -05C L 1 J-05C 4-1/8'OPEN HOLE TD --I 12070' }--v DATE REV BY COMM TS DATE REV BY COMMENTS N(TS PRUDHOE BAY UNIT 07/06/77 ORIGINAL COMPLETION 07/14/10 WEC/SV FULL TTP WB_L: J-05C/J-05L1 03/13/00 TWA SIDETRACK COMPLETION 09/07/10 SMIJMD CFL.G DRAFT CORRECTIONS PERMIT No: 2081710/2081720 02/01/09 NORDIC2 CTD ST&ML(J-05C/CL1) 04/22/11 MCMIPJC GLV C/O(04/10/11) API No: 50-029-20120-03/60 02/05/09 SV/PJC DRLG CORRECTIONS 06/24/14 DLWJMD SET PLUG/GLV C/O(0622/14) SEC 9,T11N,R13E,650'SNL&1245'WEL 02/13/09 /SV GLV C/O(02/13109) 03/19/10 JLW/SV CSG CORRECTION BP Exploration(Alaska) • i Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. r.! ~ ~ - ~ / ~ Well History File Identifier Organizing (done) RESCAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: „~.,aed iiiiuumiiuuii DIGITAL DATA Diskettes, No. ^ Other, No/Type: BY: ( Maria, Date: ~~ ~ Project Proofing BY: Maria Date: Scanning Preparation ~_ x 30 = DY: Maria Date: ~ Production Scanning Reu,~~,~~ iuuiuiruiiui OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: ~~ ~iiiuiuuiiWi~P + ~ =TOTAL PAGES_~ (Count does not include cover sheet) /s/ Stage 1 Page Count from Scanned File: (count does include cov r sheet) Page Count Matches Number in Scanning Pr partition: YES NO BY: Maria Date: ~ ~ `~ ~s~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s~ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I ~II ReScanned II I II II II I ~ III I I I II BY: Maria Date: /s~ Comments about this file: Quality Checked III IIIII'I) III III ~X 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA ',AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other Ell 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 ❑ r 208 -1710 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20120 -03 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028281 PBU J -05C 10. Field /Pool(s): L. PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12069 feet Plugs (measured) None feet true vertical 8707.88 feet urtk (measured) None feet c 6i 4. ` Effective Depth measured 12069 feet ''' Packer (measured) 5790, 5802 9649 9778 feet true vertical 8707.88 feet (true vertical) 5327. 5337 8441 8533 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 30" 28 - 106 28 - 106 Surface 1723' 18 -5/8" 109.3# K -55 27 - 1750 27 - 1750 2860 1270 Surface 811' 18 -5/8" 96.5# K -55 1750 - 2561 1750 - 2561 930 870 Intermediate 2133' 13 -3/8" 68# N -80 26 - 2159 26 - 2159 4930 2270 Intermediate 3741' 9 -5/8" 47# N -80 2159 - 5900 2159 - 5412 6870 4760 Production 5782' 7" 26# L -80 25 - 5807 25 - 5340 7240 5410 Liner 4171' 7" 26# L -80 5814 - 9985 5346 - 8653 7240 5410 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ - _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13CR80 24 - 9751 24 - 8514 4 -1/2" 12.6# L -80 9725 - 9835 8496 - 8569 Packers and SSSV (type, measured and true vertical depth) 7" ZXP TIEBACK PKR 5790 5327 7" BAKER ZXP PKR 5802 5337 4 -1/2" BAKER S -3 PKR 9649 8441 4 -1/2" BAKER S -3 PKR 9778 8533 12. Stimulation or cement squeeze summary: ^ . Intervals treated (measured): Treatment descriptions including volumes used and final pressure: p � "ti`' ° ,- s. -; :°,1i: ''s ['ar3:: i.,'Bfiti, ; e6:iiiSSIOfl 13. Representative Daily Avg¢fttion or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 740 28,968 242 1,339 Subsequent to operation: 564 22,561 150 1,596 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development © Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ,,,, 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGD GINJ ❑ SUSPE 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 Na- - Joe Lastuf� Title Petrotechnical Data Technologist Signat - IER Phone 564 -4091 Date 7/20/2011 Form 10 -404 Revised 10/2010 FIBDMS JUL 2 01011'7 7 Z P/ �/ e lbmit Original Only �r�i 'may J-05C • 208 -171 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base J-05C 3/13/00 OH 9,985. 11,315. 8,653.38 8,685.93 J -05C 1/26/09 OH 11,315. 12,069. 8,685.93 8,707.88 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 1111 • • J -05C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 6/19/2011 T /I /O /OO = 2000/360/0/0. Temp = SI. Clean WH w /solvent, bleed IA —0 psi (Furmanite Clamp). Cleaned WH w /solvent. Job complete. Final WHPs = 2000/360/0/0. SV, WV =C. SSV, MV =O. IA, OA =OTG. NOVP. � E i 6/ 21/2011T/I/O/00= 1950/340/Vac/0. Temp =SI. Bleed IAP to 0 psi. (Pre - Furmanite clamp). IA FL @ Surface. Bled IAP from 340 psi to 0 psi in 30 minutes, rig down & monitor for 30 minutes, no change in TP, OAP or OOAP during IAP bleed. No change in TP, OAP or OOAP, IAP increased 5 psi during 30 minute monitor. Final WHP's= 1950 /5/Vac /0. ** *NOTE*** cellar has 2" to 3" of water. SV & WV = C. MV & SSV = 0. IA, OA & OOA = OTG. NOVP. j E t � s 6/22/2011 T /I /0 /00= 1950 /10/Vac/Vac. Temp =SI. Assist Furmanite Crew (Install Furmanite 'Clamp). Cellar box is 5' deep, removed grating and vacced out all water from the cellar box. Assist Furmanite as directed. Installed 2 piece clamp around SH using a ;manual lift plan from the wellhouse grating to the cellar ( -47 lbs/piece). Finished !clamp instalation at 2:00 PM after 2 hours of compound injection. Left floor kit removed to inspect starting head clamp for leaks during MIT. SV,WV= Closed. SSV, MV =Open. IA,OA =OTG. i 1 i 6/23/2011;T/l/0/00= 1950 /10/Vac/Vac. Temp= SI. MIT-00A to 500 psi FAILED (Post furmanite). Vac truck evacuated all the fluid in cellar. Increased OOAP with 8 bbls of ;diesel from 0 psi to 500 psi. Start test. OOAP lost 9 psi in the first 15 min. & 6 psi in the 2nd 15 min, extend test 3rd mins OOAP lost 4 psi. Furminate clamp has small seapage from below the clamp in the 7 o'clock position. Bled OOAP to 0 psi. Final I WHPs 1950/10/vac/0. SV,WV=C SSV,MV =0 IA,OA,00A =OTG NOVP. { • • 6/24/2011T/I/O= 1950/6Nac/3. Temp= SI. MIT -OOA to 500 psi (Post Furmanite). No AL. Furmanite crew on site injecting sealant into clamp around surface casing starting "head. OOA FL @ surface. Used 1.25 bbls of diesel to increased OOAP from 3 psi to Itest pressure of 500 psi. Shut -in and started 30 minute monitor. In 1st 15 minutes !OOAP lost 20 psi and in 2nd 15 minutes lost 10 psi for a total of 30 psi in 30 minutes Itest. Furmanite clamp still had small signs of seapage, this time coming from the ' ;lower part of the clamp between the 12 & 6 o'clock position and upper clamp from 12 to 9 o'clock. Bled OOAP to 10 psi. See log for details. Final WHPs= 1950/6/0/10. ;Job incompleted. SV,WV= closed. SSV,MV =open. IA,OA,OOA =open to gauge. NOVP. 6/27/2011 T /I /O /OO = SSV /0/0/0. Temp = SI. Remove Furmanite Clamp. Attempted to drill into clamp to add ports and inject more compound without success. Removed clamp from SH. Drilled and tapped ports at wells support. No change in pressures. Well ' left SI and secured. Job to be continued 6/28/11. { 6/28/2011,T/I/O/OO = SSV /0/0/0. Temp = SI. Installed Furmanite clamp around the SH and 'injected compound to activate seals. No change in WHPs. Job to be continued 6/29/11. 6/29/201'1 'T/1/0/00= 1960/8Nac/0. Temp= SI. Assist Furmanite. MIT -OOA to 600 psi * *PASSED** (SH repair). No AL. OOA FL @ surface. Used 1 bbls. of diesel to 'increase OOAP from 0 psi to 500 psi. SI and start 30 min monitor. In 1st 15 min, OOAP lost 14 psi & in 2nd 15 min lost 5 psi for a total loss of 19 psi in 30 min. Pressured OOA an additional 100 psi to 600 psi. SI monitor for 30 min. OOAP lost 8 :psi in 1st 15 min & 4 psi in 2nd 15 min for a total loss of 12 psi in 30 min. Job complete. Final WHPs= 1960/8Nac/0. SV, WV= C. SSV, MV= O. IA, OA, OOA= OTG. NOVP FLUIDS PUMPED BBLS 1.25 DIESEL 1.25 TOTAL TREE= CM/ SAFETY TES: WELL ANGLE >700 @ 10015'. - WELLHEAD = CM/ li J-05C 7" SC HUNG OFF EMERGENCY SLIPS. ACTUATOR= BAKER C ***4-1/2" CHROME TBG & NIPPLES***ORIG WELL, KB. ELEV = 65.8 LI J-05A & J-05B NOT SHOWN*** BF. ELEV = 38.25' - - I KOP = 310T Max Angle = 93° @ 10273' Datum MD = NA Datum IV D = 8800' SS 130" CONDUCTOR H 98' ____.-----1, 2046' 1-1FBR, 0 = ? I 113-3/8" CSG, 68#, ID = 12.415" 1-1 2151' 1 )i 19-5/8 FOC 1-1 2197' 1 - 111 , , 2151' 1-113-3/8" X 9-5/8" X0, ID = 8.681" I 2235' H4-1/2" HES X NIP, ID = 3.813" I 19-5/8" FOC H 2359' I 18-5/8" CSG, 96,5# / 109#, K-55, BTRS, ---.1 2553' I A lk CAMCO GAS LIFT MANDRELS 0 = 17.655" / 17,563" ?? ST MD TVD DEV TYPE VLV LATCH PORT DATE ( 4 3095 3092 10 KGB2 DMY BK 0 04/10/11 Minimum ID = 3.80" @ 9823' 3 5468 5081 40 KGB2 DMY BK 0 04/10/11 4-1/2" HES XN NIPPLE 2 7346 6565 36 KGB2 DMY BK 0 01/19/09 1 8929 _ 7837 _ 34 KGB2 DMY _ BK _ 0 01/19/09 17" TIEBK, 26#, L-80 BTD-M, .0383 bpf, ID = 6.276' H 5802' 5790' 1-19-5/8" X 7" BKR ZXP TIEBK PKR, ID = 6.313" 1 ,.. 2 I TOP OF 7" LNR H 5802' 5802' H9-5/8" X 7" BKR ZXP LTP, ID = 7.50" I 5818' H9-5/8" X 7" BKR HMC HGR, ID = 6.313" I 1TOP OF WHIPSTOCK H 5900' I 19-5/8" EZSV H 5986' 1 9628' H4_1/2" HES X NIP, ID = 3.813" I 9 CSG, 47#, 10510' ,,,, % ` ',.;;- - 1:; /: ...! 9649 j---1!: x 4-1/2" BKR S-3 PKR, ID = 3.87V 1 L-80, ID = 8.681" • 9673' H4-1/2" HES X NIP, ID = 3.813" I 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, --I 9736' 1 .0152 bpf, ID = 3.958" 1 1 9751' H7" x 4-1/2" UNIQUE OVERSHOT 1 14-1/2" TBG STUB (01/09/09) H 9725' ELMD • 9765' H4-1/2" HES XN NIP, ID = 3.725" 57 _1 9778' I x 4-1/2" BKR S-3 PKR, ID = 3.875" I '... 1 9802' 1 HES X NIP, D = 3.813" I • 9823' H4-1/2" HES XN (MILLED 01/25/09) ID = 3.80" 1 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 9835' 1 . 9835' H4-1/2" WLEG, ID = 3.958" 1 1 7" LNR, 26#, L-80, BTC-M .0383 bpf, ID = 6.276" H 9985' f ■ 10110' H3-3,4" OPEN HOLE SIDETRACK 1 J-05B 'OPEN HOLE TD H 11315' I L-1 ..--.S 13-3/4" OPEN HOLE TD 1 11740' J -05CL1 J-05C 14-1/8" OPEN HOLE TD H 12070' DATE REV BY COMMENTS 1 DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/06/77 ORIGINAL COMPLETION 07/14/10 WEC/SV PULL TIP WELL: J-05C/ J-05L1 03/13/00 TWA SIDETRACK COMPLETION 09/07/10 SM/JMD DRLG DRAFT CORRECTIONS PERMIT No: 2081710 / 2081720 02/01/09 NORDIC2 CTD ST & ML (J-05C/CL1) 04/22/11 MCNVPJC GLV C/O (04/10/11) AR No: 50-029-20120-03 / 60 02/05/09 SV/PJC DRLG CORRECTIONS ' SEC 9, T11N, R13E, 650' SNL & 1245' WEL 02/13/09 /SV GLV C/O (02/13/09) 03/19/10 JLW/SV CSG CORRECTION BP Exploration (Alaska) DATA SUBMITTAL COMPLIANCE REPORT '~ 3/31 /2010 Permit to Drill 2081710 Well Name/No. PRUDHOE BAY UNIT J-05C Operator BP EXPLORATION (ALASKIy INC API No. 50-029-20120-03-00 ~, MD 12069 TVD 8708 Completion Date 2/1!2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey s 1 DATAINFORMATgN Types Electric or Other Logs Run: MWD, DIR, GR, RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Rpt LIS Verification 9881 12069 Open 4/20/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS D C Lis 17871 Induction/Resistivity 9881 12069 Open 4/20/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS og Induction/Resistivity 25 Col 11275 12069 Open 4/20/2009 MD MPR, GR 27-Jan-2009 II Log Induction/Resistivity 25 Col 9980 12069 Open 4/20/2009 MD MPR, GR 27-Jan-2009 o Gamma Ray 25 Col 11270 12069 Open 4/20/2009 MD GR 27-Jan-2009 D D Asc Directional Survey 26 12069 Open 4/16/2009 PBU J-05L1 (208-172) also on diskette Rpt Directional Survey 26 12069 Open 4/16!2009 Well Cores/Samples In#ormation: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMI~TION Well Cored? Y ! Daily History Received? N Chips Received? Y^ % N/_ Formation Tops ~~ Analysis 1~f'N Received? DATA SUBMITTAL COMPLIANCE REPORT 3/31 /2010 Permit to Drill 2081710 Well Name/No. PRUDHOE BAY UNIT J-05C Operator BP EXPLORATION (ALASKIy INC API No. 50-029-20120-03-00 MD 12069 TVD 8708 Completion Date 2/1/2009 Completion Status 1-OIL Current Status 1-OIL UIC N Comments: Compliance Reviewed By: I~ ~ Date: ~ ~ ° • i d. s BAKER Nt~6~iE5 Baker Atlas PRINT DISTRIBUTION LIST CUMYANY BP 1rXYLUKA'I lUN (ALASKA) 1NC WELL NAME J-OSC FIELD PRUDHOE BAY UNIT CUUN'1'Y NUK"1H SLUPE BURUUGH STATE ALASKA DATE 4/17/2009 CATRINA GUIDRY SO #:2429264 THIS DISTRIBUTION LIST AUTHORIZED BY: Copia of Copies Digital Copies of Copies Digital Each Log of Film Da[a Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine W"estfield. Houston, Texas 77073 This Distribution List Completed Bv: Y~ ~. ~,. Page I of I ~J INTE Log Data Transmittal Form To: State of Alaska -A®GCC 333 W. 7th Aae. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: J-OSC f 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 Measured Depth MADPASS Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) ~ ~~ a ~ LAC Job#: 2429264 Sent by: Catrina Guidry Date: 04/17/49 ~ - Received by: ~~/ .i '~ Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ~~.~~ `~` RIMES n~, a ~,~ Baker ~Iughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 -~ ~~ , .~, i ~L~ BAKER NUGNES ~1~~~~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: April 15, 2009 Please find enclosed directional survey data for the following wells: K-06B J-OSC E-34L1 J-05CL1 05-27BPB1 07-02B 05-27B 07-20B 07-29D Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: ~ ,State of Alaska AOGCC DATE: 2 C~ ~ Cc: State of Alaska, AOGCC ~~~~ I7c " STATE OF ALASKA 09 3~~ ~' ALASK~L AND GAS CONSERVATION COSIGN BAR ~ ~ 20 /`~~ ~~ WELL COMPLETION OR RECOMPLETION REPORT AND ~tas~CC~ iii ~ Gas C°as` CO~ruunission poc~lorage 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Strati raphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 2/1/2009 12. Permit to Drill Number 208-171 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/25/2009 13. API Number 50-029-20120-03-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 1/26/2009 14. Well Name and Number: PBU J-05C FEL, SEC. 09, T11 N, R13E, UM FNL, 1245 650 Top of Productive Horizon: 2676' FSL, 391' FWL, SEC. 03, T11 N, R13E, UM 8. KB (ft above MSL): 65.84' Ground (ft MSL): 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 3229' FSL, 2291' FWL, SEC. 03, T11 N, R13E, UM 9. Plug Back Depth (MD+TVD) 12069 8708 Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 643105 y- 5970695 Zone- ASP4 10. Total Depth (MD+TVD) 12069 8708 16. Property Designation: ADL028281 TPI: x- 644669 y- 5974052 Zone- ASP4 th: x- 646557 - 5974642 Zone- ASP4 Total De 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: y p 18. Directional Survey ®Yes ^ No Submit ele roni nd rin inf rm i n er 20 AAC 5.0 0 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information p 20 AAC 25.071): MWD, DIR, GR, RES ~/i~dasJ~ll3l.SiyD d~6 ~'~ ~'YD 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING: RECORD PULLED 2 " x 3 " rfa 118' Surface 11 ' 1 -/" /1 9# rf 25' rf 42 s I 1 - / " x -5/8" 68# N-80 rf 5956' Surfa 54' 17-1/2" 1550 sx CI 'G' S7 sx PF II 7" 2 L-80 2 ' 985' 28' S ' 8-1 /2" 1 sx las ' 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RecoRD If Yes, Ilst each I (MD+TVD of To & Bottom Pe ntefVal Open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD p ; None 4-1/2", 12.6#, 13Cr80 / L-80 9835' 9649' & 9778' MD TVD MD TVD 1/8" O 4 en Hole 25. ACID, FRACTURE, CEMENTSOUEEZE, ETC. - p 11315' - 12069' 8686' - 8708' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with 35 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOU('S Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE S2E: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. _.. z . None °~ ~ °~_. ~ . c ,off , Form 10-407 Revised 02/2007 CONTINUED UN KEVERSE SIDE ~. .a 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME . MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test ' rf needed, and submit results. Attach separate sheets to this form, Permafrost Base detailed test information per 20 AAC 25.071. (From J-05B) Top Sag River 9974' 8648' None Formation at Total Depth (Name): Sag River 9974' 8648' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. 1 hereby certify that th egoing is tru and correct to the best of my knowledge. Signed Son Ste Title Drilling Technologist Date ~~ '(~~-(~~ PBU J-OSC 208-171 Prepared ByName/Number. Sondra Stewman, 564-4750 Well Number Permit No. / A r val N OriBing Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 Litt, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only TREE = CNV WELLHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 58.15' BF. ELEV = 38.25' KOP = 3107' Max Angle = 93° @ 10273' Datum MD = NA Datum TV D = 8800' SS DRLG DRAFT 30" CONDUCTOR 98' 13-3/8" CSG, 68#, ID = 12.415" 2151' 9-518" FOC 2197' 9-5/8" FOC 2359' 18-5/8" CSG, 96.5# / 109#, K-55, BTRS, 2553' ID = 17.655" / 17.563" ?? Minimum ID = 3.80" @ 9823' HES XN NIPPLE 7" TIEBK, 26#, L-80 BTD-M, .0383 bpf, ID = 6.276' 5$02 TOP OF 7" LNR --~ 5$02 TOP OF WHIPSTOCK 9-5/8" EZSV 9-5/8" CSG, 47#; I 10510' L-80, ID = 8.681' 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" I-{ 9736' J-05C & CL1 NOTES: WELL ANGLE > 70° @ 10015' RIG WELLBORE NOT SHOWN BELOW "`" 7" SCAB LNR HUNG OFF EMERGENCY SLIPS 2046' ~ PBR, ID = ? I 2151' 13-3/8" X 9-5/8" XO, ID = 8.681" 2236' 4-1/2" HES X NIP, ID = 3.813" CAMCII (;AS I IFT MANf~RFLS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3095 3092 10 KBG-2 OM BK 16 02/13/09 3 5468 5081 40 KBG-2 SO BK 20 02/13/09 2 7346 6565 36 KBG-2 DMY BK 0 01/19/09 1 8929 7837 34 KBG-2 DMY BK 0 01/19/09 5790' --~ 9-5/8" X 7" BKR ZXP TIEBK PKR, ID = 6.313" 5802' 9-5/8" X 7" BKR ZXP LTP, ID = 7.50" 5818' 9-5/8" X 7" BKR HMC HGR, ID = 6.313" MILLOUT WINDOW (J-05B) 5956' - 5987' 962$' 4-1/2" HES X NIP, ID = 3.813" 9649' 7" x 4-1/2" BKR S-3 PKR, ID = 3.870" 9673' 4-1/2" HES X NIP, ID = 3.813" 9725' ELM TOP OF TUBING STUB (01!09/09) 9751' UNIQUE OVERSHOT, ID = 4.625" 9765' 4-1/2" HES X NIP, ID = 3.813" 977$' 7" x 4-1/2" BKR S-3 PKR, ID = 3.875" 9$Q2' 4-1 /2" HES X NIP, ID = 3.813" 14-1/2" HES XN (MILLED 01/25!09), ID = 3.80" I ~ 4-1/2" TBG, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" I 7" LNR, 26#, L-80, BTGM .0383 bpf, ID = 6.276" ~ 9985' B (previous openhole completion) I B Ooenhole TD I 11315' I 4-1/8" Openhole TD 12070' U C 9835' E-14-1/2" WLEG, ID = 3.958" 3-3/4" OH Sidetrack CL1 10110' 3-3/4" Openhole to TD 11740' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/06177 ORIGINAL COMPLETION 03113/00 N7ES SIDETRACK COMPLETION 02/01109 NORDIC 2 CTD SDTRCK (J-05C) 02/05/09 SV/PJC DRLG CORRECTIONS 02/13/09 /SV GLV C/O (02/13/09) PRUDHOE BAY UNIT WELL: J-OSC PERMIT No: 2081710 (20) API No: 50-029-20120-03 & O6? SEC 9, T11N, R13E, 650' FNL 8 1245' FEL BP Exploration (Alaska) • BP EXPLORATION Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Event Name: REENTER+COMPLETE Start: 1/14/2009 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 Page 1 of 13 °, I Spud Date: End: Date From - To Hours Task Code NPT Phase Description of Operations 1/14/2009 ~ 11:00 - 14:00 3.00 MOB P PRE Hold PJSM w/crew regarding moving rig. Perform final walk 14:00 - 00:00 10.00 MOB P PRE 1/15/2009 00:00 - 08:30 8.50 MOB P PRE 08:30 - 10:30 2.00 MOB P PRE 10:30 - 11:30 1.00 MOB N WAIT PRE 11:30 - 12:30 1.00 MOB P PRE 12:30 - 13:00 0.50 MOB P PRE 13:00 - 14:30 1.50 MOB P PRE 14:30 - 16:30 2.00 MOB P PRE 16:30 - 16:45 0.25 BOPSU P PRE 16:45 - 21:30 4.75 BOPSU P PRE 21:30 - 22:45 1.25 MOB P PRE 22:45 - 00:00 1.25 BOPSU P PRE 1/16/2009 00:00 - 01:30 ~ 1.50 BOPSUp P I PRE 01:30 - 11:00 ~ 9.50 ~ BOPSUp P ~ ~ PRE 11:00 - 13:00 2.00 BOPSUF~ P PRE 13:00 - 19:20 6.33 BOPSU P PRE 19:20 - 21:00 1.67 BOPSUF~ P PRE 21:00 - 00:00 3.00 BOPSU P PRE around. Back rig off well. Clean up location. Move rig to pad entrance. Move rig from MPC pad to spine road. Rig is at MPU spine road intersection at midnight. Move rig from MPU spine road intersection towards J pad. Arrive on J Pad and spot in front of well Fill out Location Condition report w/ DSO. DSO refused to sign Unit Work Permit until GC20TL approved the siting documents for the satellite office Lay herculite around wellhead. Chk IAP & OAP=O Set rig mats for height Drop 4" valve off 7-1/16" stack. Set stack on skid and remove from cellar CH2 140T crane arrived at 0940 hrs and begin to RU. Move RWO BOP skid for lift Safety mtg re: lift 13-5/8" stack off of skid and place behind the wellhead WO approval from GC20TL to begin wellwork. DSO signed Unit Work Permit Lift 13-5/8" stack off skid and place behind wellhead Remove Swaco MPD choke and panel off rig floor RDMO CH2 crane Safety mtg re: move over well Move over well and set down Accept riq for operations at 1430 hrs Berm cellar w/snow. Take on rig fuel and water. Set cuttings box, tree and Sarber spool. Swap satellite office trailer to rig power Safety mtg: RU DSM lubricator Load DSM lubricator to floor. PT 500 psi. Pull 4" BPV. Dry rod TWC. RU & test to 3500psi & chart same. RD DSM lubricator,. RD test hose. PJSM regarding moving rig. Jack up rig & center over well. Secure cellar w/ plywood. PJSM regarding ND tree & NU BOPE. Suck down tree. Split tree in 2 pieces & tail roll out of the cellar. RD tubing head adaptor. Continue to RD tree & tubing head adaptor. Inspect top hanger threads -good condition. MU NSCT xo to top hanger threads - 7-1/4 by hand. Cycle LDS -all functioned. Skid in & NU 13-5/8" BOP stack, torque all bolts to spec. Install blind & variable rams. NU HCR, Koomey lines, etc. Chk IAP, OAP=O NU Sarber spool on top of annular NU riser sections. Fill stack and riser w/ water - no leaks. RU 4-1/2" test joint w/ NSCT XO. SWS lower reel to ground to load out ODS reel drive components Function test BOPE. Shell test BOPE, grease leaking choke HCR stem. Shell test -holding. Perform weekly BOPE test per AOGCC regs to 250psf/3500psi - PASS. Jeff Jones waived witness to test. RU 2" circulation rnmeo: u i aiw~a w:vn. w „m • BP EXPLORATION Page 2 of 13 Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Spud Date: Event Name: REENTER+COMPLETE Start: 1/14/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 ' Date From - To Hours Task Code NPT Phase Description of Operations 1/16/2009 21:00 - 00:00 3.00 BOPSU P PRE loop to IA. 1/17/2009 00:00 - 01:30 1.50 BOPSU P PRE Continue to pressure test BOPE per AOGCC regs. 01:30 - 02:30 1.00 BOPSU P PRE RU CIW mandrel x 7" Otis connection w/ - 17ft of lubricator. Land inside CIW spool & RILDS. 02:30 - 03:15 0.75 BOPSU P PRE Pressure test CIW mandrel x 7" Otis. 03:15 - 06:45 3.50 BOPSU P PRE RU DSM lubricator. P.T. to 250psi. Pull 4" TWC, slight vac. RD u nca or. ac ou a on man rel. RD CIW mandrel & lubricator. RU 3-1/2" elevators. RU landing jt & floor valve. MU landing joint into hanger. RU circ hose to landing jt. P.T. IA circulation loop. Remove Nordic hardline from reel house for inspection 06:45 - 07:00 0.25 BOPSU P PRE Safety mtg re: circ wellbore 07:00 - 07:45 0.75 BOPSU P PRE Reverse circ 2.40/530 w/ SW down the IA and recover 54 bbls of diesel from the tubing (as measured on 'out' MM). Swap to tubing 07:45 - 08:30 0.75 BOPSU P PRE Circ initial 2.41/190 w/ SW w/ Safe Surf-O down the tubing taking diesel returns to the tiger tank 3.01/480 w/ one pump. Pump 300 bbls and SD pumping 08:30 - 10:40 2.17 BOPSU P PRE' Let Safe Surf-O soak while attempt to thaw tiger tank hose outlet. Then, WO CHILL pusher to okay using hose 'over the top'. Vac off 200 bbls of mostly diesel and send to GC2 10:40 - 13:00 2.331 BOPSUp P 13:00 - 13:15 0.25 PULL P 13:15 - 15:00 1.75 PULL P 15:00 - 21:20 I 6.331 PULL I P 21:20 - 21:30 0.17 PULL P 21:30 - 23:30 2.00 PULL P 23:30 - 00:00 0.50 PULL P 1/18/2009 00:00 - 00:30 0.50 PULL P 00:30 - 06:00 5.50 PULL P 06:00 - 09:30 3.50 WHSUR P 09:30 - 09:40 0.17 WHSUR P 09:40 - 14:00 4.33 WHSUR P 14:00 - 15:50 1.831 BOPSUp P SWS lower reel (for more room when picking up bearing assy) onto CHILL lowboy and park trailer on the side of pad Check derrick for ice-it's 28F! (and calm) PRE Resume circ remainder of Safe Surf 3.01/550. Incr rate to 4.75/1350 w/displacement fluid. Pumped 670 bbls total. RD circ hose. Blow down lines DECOMP Safety mtg re: pull tubing hanger DECOMP BOLDS, drain stack. Unseat hanger w/ 80k, clean. Pull hanger to floor w/ 98k max, then 88k steady. LD hanger and landing jt Now it's 41 F and 20-30 mph wind! DECOMP POOH LD 4-1/2" 12.6# L-80 IBT tubing. Pin ends on jts 40-80 were heavily corroded. Stop at jt 80. RD 4-1/2" elevators. RU 3-1/2" elevators. DECOMP PJSM regarding RU RTTS storm packer. DECOMP RU & run RTTS storm packer. Set RTTS storm packer 2ft below ground level. 55k up wt n wt. . two 500psi below packer & 1000psi above packer. DECOMP low down choke & kill line. Suck down stack. DECOMP Continue to suck down stack. PJSM regarding ND 130P's. DECOMP Pull upper & lower riser sections. Pull mouse hole. Install BOP lift plate. Disconnect Koomey lines. Hoist BOP's using bridge crane & ND BOP's at top of tubing spool. ND tubing spool. C/O casing packoffs. DECOMP NU new CIW to frig spool. PT packoffs ~ 5000 psi DECOMP Safety mtg re: NU 13-5/8" BOPE DECOMP NU 13-5/8" to tubing spool. NU riser sections. Install Koomey hoses. Set mousehole DECOMP Fill stack and riser w/ water. Function test rams and HCR. Set test plug. PT 250/3500 against blinds. Took several tries to get a test due to air in kill line Nnntea: ~iaizuua iu:aa:iuAnn • BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Spud Date: Event Name: REENTER+COMPLETE Start: 1/14/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 1/18/2009 15:50 - 16:00 0.17 WHSUR P DECOMP Safety mtg re: pull packer 16:00 - 16:45 0.75 WHSUR P DECOMP Pull HES Storm packer. LD running tools and load out 16:45 - 00:00 7.25 PULL P DECOMP RU to pull tubing. POOH LD 4-1/2"-12.6# L-80 IBT tubing. 1/19/2009 00:00 - 02:10 2.17 PULL P DECOMP Continue to POOH LD 4-1/2" 12.6# L-80 IBT tubing. Recovered 234 jts of 4-1/2" tubing. Cut was 10.5ft from top of jt 235 & was a good uniform cut. 02:10 - 04:00 1.83 BUNCO RUNCMP RU 13-5/8" mandrel by Otis xo w/ 17ft of lubricator. RU slickline. Simultaneously load new 4-1/2" tubing into pipeshed. 04:00 - 04:35 0.58 BUNCO RUNCMP RIH w/slickline w/ 6.05" gauge ring & junk basket to 9700ft. 04:35 - 05:35 1.00 BUNCO RUNCMP POH w slickline. 05:35 - 07:00 1.42 BUNCO RUNCMP Junk basket was empty. RDMO slickline. 07:00 - 07:30 0.50 BUNCO RUNCMP Pull mandrel and LD lubricator sections 07:30 - 17:00 9.50 BUNCO RUNCMP Load pipeshed w/ 4-1/2" chrome tubing, drift and strap SWS use ree crane to load in repaired reel drive bearing assy. Mount in place TS NORM tubulars 17:00 - 19:00 2.00 BUNCO WAIT RUNCMP Wait on jewelry/completion equipment. 19:00 - 22:00 3.00 BUNCO RUNCMP RU Doyon torque turn services. Hoist pup jts to RF, drift & tally same. Load completion jewelry in pipeshed, organize same. 22:00 - 23:00 1.00 BUNCO RUNCMP PJSM regarding handling running new completion. MU new 4-1/2" chrome tubing per summary, torqued to 4400ft/Ibs. BakerLok every jt below the packer. Can't get the overshot into the 7" casing -recovered ice on the overshot. 23:00 - 23:30 0.50 BUNCO P RUNCMP Suck down BOP stack. RU 3-1/2" DP & steam wellhead. LD 3-1/2" DP. 23:30 - 00:00 0.50 BUNCO RUNCMP Continue to run new 4-1/2" chrome tubing per summary, torqued to 4400fUlbs. 1/20/2009 00:00 - 16:00 16.00 BUNCO RUNCMP Continue to run new 4-1/2" chrome tubing per summary, torqued to 4400ft/Ibs. Tbg hanger arrived at 0945 hrs. Tag up w/ good indication of both sets of shear pins & no-go. pace out as required. RU an mg ~ anger. uc own stack. Land tubing. Pull LDS & visually see the hanger on seat. Break circulation - ok. RILDS & test hanger. 16:00 - 19:00 3.00 BUNCO WAIT RUNCMP Wait on completion fliud. The order that was placed in the morning got lost. SLB loaded the reel. Clean RF &pipeshed of misc RWO equipment. 19:00 - 20:40 1.67 BUNCO RUNCMP PJSM regarding handling corrosion inhibitor. Stinger in 1 drum of corrosion inhibitor onto 150bb1s of hot SW, going slow as the inhibitor is very cold. 20:40 - 22:05 1.42 BUNCO RUNCMP Reverse circulate in 150bb1s of inhibited SW ~ 120degF, 2.25bpm/615psi. 22:05 - 22:40 0.58 BUNCO RUNCMP PJSM w/ Hot Oil crew regarding pumping diesel & P.T.'n backside. P.T. lines to 3800psi. Reverse circulate in 40bbls of 90deg diesel. 22:40 - 23:10 0.50 BUNCO RUNCMP Drop ball & rod, let it fall. 23:10 - 00:00 0.83 BUNCO RUNCMP Pressure up tubing to 3500psi & set packer. P.T. packer at 3500psi for 30min -PASS. Lost 25psi in 1st 15min, 20psi 2nd 1 /21 /2009 100:00 - 01:00 ~ 1.00 ~ RU RUNCMP Attempt to test casing, slight graylock lea~C. Steam Hot Oil c ec va ve. Bleed off & tighten graylock fitting. Bleed off tbg to rnniea: u i aizwa i v.qa: w ruvi • BP EXPLORATION Page 4 of 13 Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Spud Date: Event Name: REENTER+COMPLETE Start: 1/14/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 Date From - To Hours Task Code NPT Phase' Description of Operations 1/21/2009 00:00 - 01:00 1.00 BUNCO RUNCMP 1500psi & test IA to 3500psi for 30min -PASS. lost 25psi in 1st 15min, 20psi in 2nd 15min. 01:00 - 02:00 1.00 BUNCO RUNCMP Bleed off IA & tubing to Opsi. LD landing jt. RD & release Hot Oil. 02:00 - 03:20 1.33 BOPSU P PRE Dry rod in & set 4" TW Retest, circle chart is not workin ,use SLB electronic sensor -PASS. 03:20 - 06:00 2.67 BOPSU P PRE Blow & suck down BOP stack. ND riser. Start ND BOP's. 06:00 - 12:15 6.25 BOPSU P PRE ND HCR, Kill line, drain and remove koomey hoses, open ram doors and remove blocks, grease stack, round trip dirty vac to empty pits. 12:15 - 13:45 1.50 BOPSU P PRE Open cellar doors, Lift BOP stack onto the lifting frame, skid out stack, load tree and adapter flange in the cellar. 13:45 - 18:00 4.25 BOPSU P PRE CIW tech and crew NU adapter and tree, test to 5k psi. 18:00 - 19:45 1.75 MOB P PRE Move cuttings box. Secure cellar. Disconnect office camp from rig power. Disconnect tiger tank line. Jack up & spin tires to warm up moving system. Open cellar doors. PJSM regarding moving rig. 19:45 - 19:50 0.08 MOB P PRE Move ri off well. 19:50 - 00:00 4.17 MOB P PRE PJSM regarding using crane w/high winds. RU CHILL crane & move 13-5/8" BOP's, Skid in & PU 7-1/16" w/ rig blocks. Attach koomey lines. /O 3" slip ram for a - coin i ram. 7-1/16"x4-1/16" Xo to bottom of BOP's. Take frequent warm up breaks. 1/22/2009 00:00 - 01:30 1.50 MOB P PRE Continue to C/O BOP rams & install Xo on bottom on BOP's. RU 10ft choke line to BOP stack. 01:30 - 02:30 1.00 MOB P PRE PJSM regarding moving rig. Move rig over well. 02:30 - 06:00 3.50 BOPSU P PRE Weather proof cellar. Pull tree cap. NU BOP's. Function test BOP's. Install 7" Otis riser to RF. RU tiger tank line to the rig. Spot cuttings box & hook up cuttings chute. Bring on fluids - 2%KCI with SAFEIube. 06:00 - 07:30 1.50 BOPSU P PRE Crew change. Secure stack and RU lubricator. 07:30 - 12:20 4.83 BOPSU N RREP PRE Test BOPE. Chuck Scheve waived witness to the BOP test. Fix leaking grayloc connection on choke line. Change blind rams, upper seals were tore up. Replace Grayloc connection on choke line, then retighteh again. 12:20 - 15:30 3.17 BOPSU P PRE All connection leaks fixed. Start testing rams and valves. 15:30 - 00:00 8.50 BOPSU N RREP PRE Upper 2-3/8" combi not holding. Open up and find 2" ram block w 2-3 8 inserts were installed. Change out ram blocks and still ail to test. Reopen doors to inspect. Swap lower rams for upper rams & test -upper set passed. Lower set failed. Swap out test joints -still failed on the lower set. Blow down stack. Remove lower set of rams. Install brand new rams from Nordic 1 into lower cavities. Test failed. Swap lower set for upper set. Test passed on both upper & lower 2-3/8" combi's. 1/23/2009 00:00 - 01:00 1.00 BOPSU P PRE Continue to test BOP's. 01:00 - 01:55 0.92 BOPSU P PRE PJSM regarding pulling TWC. RU DSM lubricator & test to 500psi. Pull TWC, lost seal 3.75"od,1/4"W,1 8"T. R DSM__ lubricator. 01:55 - 03:45 1.83 RIGU P PRE PJSM regarding slickline ops. Spot slickline unit. RU slickline w/full pressure gear. P.T. lubricator to 500psi, slight leak, C/O o-ring & re-test. 03:45 - 05:00 1.25 CLEAN P WEXIT Open well & RIH w/ slickline. Recovered ball & rod. rnnieo: u i aicwa i u.v~. w r.rvi • BP EXPLORATfON Page 5'of 13 `Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Spud Date: Event Name: REENTER+COMPLETE Start: 1/14/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 Date_ From - To Hours Task Code NPT Phase Description of Operations 1/23/2009 05:00 - 07:00 2.00 CLEAN P WEXIT SL run #2 -recover RHC sleeve 07:00 - 07:20 0.33 CLEAN P WEXIT SL crew change 07:20 - 07:45 0.42 CLEAN P WEXIT PJSM for picking up the pump bailer and slickline operations 07:45 - 11:00 3.25 CLEAN P WEXIT SL run #3 - 3.5" x 10' pump bailer. Recover -20# of sluggits + 1/3 of the TWC seal. 11:00 - 12:50 1.83 CLEAN P WEXIT SL run #4 -rerun bailer. Recover -20# 12:50 - 15:10 2.33 CLEAN P WEXIT 15:10 - 17:00 1.83 CLEAN P WEXIT 17:00 - 19:00 2.00 CLEAN P WEXIT 19:00 - 19:45 0.75 CLEAN P WEXIT 19:45 - 21:05 1.33 CLEAN P WEXIT 21:05 - 00:00 2.92 CLEAN P WEXIT 1/24/2009 00:00 - 00:40 0.67 CLEAN P WEXIT 00:40 - 01:15 0.58 CLEAN P WEXIT 01:15 - 04:10 2.92 CLEAN P WEXIT 04:10 - 04:50 0.67 CLEAN P WEXIT 04:50 - 06:00 1.17 CLEAN P WEXIT 06:00 - 06:30 0.50 CLEAN P WEXIT 06:30 - 08:10 1.67 CLEAN P WEXIT 08:10 - 09:50 ~ 1.67 ~ CLEAN ~ P ~ ~ W EXIT 09:50 - 11:45 ~ 1.92 ~ CLEAN ~ N ~ DFAL ~ W EXIT 11:45 - 12:30 ~ 0.75 ~ CLEAN ~ N ~ DFAL ~ WEXIT 12:30 - 13:00 ~ 0.50 ~ CLEAN ~ N ~ DFAL ~ W EXIT Test reel manifold to 4500psi. SL run #5 -rerun bailer. Recover -5#. Geo confirmed sample is calcium carbonate (sluggits) SL run #6 -sharpen mule shoe and rerun 3.5" bailer. Recover 10#. Marks on mule shoe that indicate the XN plug is near. SL run #7 -rig up 2.25" x 11' bailer. RIH filling across top. Make 20 pump strokes & lubricator o-ring started to leak, POH. Recover 5#. Drop tool string & inspect rope socket & tools. SL run #8 -rerun 2.25" bailer. Recover 3/4 cup. SL run #9 -equalizing device. Good indication that plug was ie SL run #10 -pull plug. Jar up for 1 hr. Attempt to disconnect from plug. Beat down for 1 hr & release from plug. PJSM regarding handling slickline. RD slickline. PJSM regarding handling coil. RD DS & ODS tongs. RU stuffing box to the injector. MU stabbing winch. RU & pull coil across. RD stabbing winch. Fill coil w/ 2% KCL+safelube. Pump slack forward. Pressure test packoffs & inner hardline reel 250psU3500psi. Crew change and PJSM Cut 22' of cable, seal end of eline, dress coil tubing, Install BOT coil connector, Pull test to 40k, pressure test to 3500 psi. MU XN plug fishing BHA #1 -CTC, 1 jt PH6, DFCV, Accelerator, 13' of 3.625" wt bar, Bowen jar, Disco, Circ sub, 4" GS spear. RIH with fishing BHA#1. Load coil with 20 bbl viscous pill at minimum rate. At 7863' circ pressure spiked to 800 psi. Stop coil and walk up pressure to 2000 psi, slow bleed of. Do not want to risk latching up with an open circ sub. POH to BHA. Isolate reel manifold and verify the strainer is clean and in place. Double check SLB reel log and verify 490' of slack was pumped out on previous well. Pop off and pull 71' of cable from the BHA. Position the injector over the bung hole and pump out another 142' of slack (total recovery of 213' of cable). LD BHA and find the missing heat shrink rubber in the DFCV sub. The SLB reel log is inaccurate. DIMS doesn't record any slack being pumped out at the end of the previous well. MU XN plug fishing BHA #2 -CTC, 2 jts PH6, DFCV, Accelerator, 13' of 3.625" wt bar, Bowen jar, Disco, Circ sub, 4" GS spear. 13:00 - 14:40 1.67 CLEAN N DFAL WEXIT RIH with fishing BHA #2. 14:40 - 15:00 0.33 CLEAN P WEXIT Resume productive time. Continue to RIH. 15:00 - 16:15 1.25 FISH P WEXIT Dry PU weight - 44k. Pump 2.62/2.64 2050 psi_ the fishing neck at 9833' two times with hi-vis it . • BP EXPLORATION Page 6 of 13 Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Spud Date: Event Name: REENTER+COMPLETE Start: 1/14/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 Date From - Ta Hours Task Code ' NPT .Phase Description of Operations 1/24/2009 15:00 - 16:15 1.25 FISH P WEXIT solids recovery. 16:15 - 17:15 1.00 FISH N SFAL WEXIT Troubleshoot, remove, then install new SLB depth counter. 17:15 - 17:30 0.25 FISH P WEXIT Set down 6k, PU to 48k and let the jars bleed. Straight pull to 55k. Cock jars and pull to 55k. Jars fired hold 52k then pull to 60k. Broke free and pulling heavy at 50k (6k over). Pull heavy through the first nipple. Fill across the top, the well is taking all of the fluid. 17:30 - 20:45 3.25 FISH P WEXIT _ POH. Flow check at 5000ft - 1.5bpm loss rate. PJSM regarding handling BHA while POH. Lost 122bb1s on trip out of the hole. 20:45 - 21:50 1.08 CLEAN P WEXIT LD BHA lost 4 packing elements from XXI lug, 3.75"o.d., 1/8"w, 1/8"t. Fill hole across the top 0.6bpm loss rate. Fill coil 40bbls & attempt to pump out more stack -none. Cut off CTC. Cut Eft of wire & seal end of wire. MU LH CTC, pull test to 40k, P.T. to 3500psi. MU LH BHA #3 -CTC, DFCV, Disco, Circ Sub, Motor, 3.80"go DSM. 21:50 - 00:00 0.00 CLEAN P WEXIT Stab onto well. Tag up, set counters. RIH w/ LH BHA #3. Pump min rate while RIH - 0.5bpm losses. 1/25/2009 00:00 - 00:05 0.08 CLEAN P WEXIT Continue to RIH. Lost 49 bbls on trip in the hole. 00:05 - 00:15 0.17 CLEAN P WEXIT Slowly RIH thru overshot area -clean. 00:15 - 00:20 0.08 CLEAN P WEXIT Dry tag XN profile at 9827', paint yellow flag. PUW=46k, =27k. et parameters. 2.5bpm/2050psi w/ 2.1 bpm out. 00:20 - 00:45 0.42 CLEAN P WEXIT ill XN profile_ 00:45 - 01:00 0.25 CLEAN P WEXIT Ream & backream thru XN profile until clean. 01:00 - 01:15 0.25 CLEAN P WEXIT RIH to 9980' -clean. 01:15 - 03:35 2.33 CLEAN P WEXIT POH. PJSM while POH regarding handling BHA. Lost 55bbls on the tri out of the hole. 03:35 - 04:00 0.42 CLEAN P WEXIT Pop off well. LD BHA, 4' of wire sticking out end of CTC. Mill was 3.79"go & 3.78" no-go. Clear RF of BOT fishing & milling tools. 04:00 - 04:45 0.75 DRILL P PROD1 Cut off CTC. Cut 4' of wire & seal the end. Stab onto well. Fill hole - 15bbls, 1/2bpm loss rate. Close master & pump slack back into the coil. 04:45 - 05:40 0.92 DRILL P PROD1 Pop off well. Install night cap & fill across the top PVT=281 at Sam. RU coil cutter. Cut coil to find wire, cut 338'. RD coil cutter. Test wire, insulation test was good & good resistivity 45ohms. 05:40 - 06:00 0.33 DRILL P PRODi Crew change and PJSM 06:00 - 09:00 3.00 DRILL P PROD1 PVT=257 at Gam. Dress end of coil. Install CTC. Pull test to 40k -good. P.T. to 3500psi -good. MU BHA #4. HCC bicenter, 1.2 deg motor, RES tool, CoiITRAK assembly. 09:00 - 10:50 1.83 DRILL P PROD1 PVT=189 at gam. Open EDC and pump slack forward at 3 bpm. RIH with BHA #4 pumping min rate thru open EDC. 10:50 - 12:00 1.17 DRILL P PROD1 Tie-in log from 9700' to 10050'. -11' correction. Start swap to Flo-Pro. 12:00 - 13:00 1.00 DRILL P PROD1 Weight check at shoe - 48k at 1 bpm. Run in 6.125" open hole at 1 bpm and HS TF. Run to bottom unobstructed. Losses healed u with the Flo-Pro. 13:00 - 14:15 1.25 DRILL P PROD1 Drill 110 fph from 11,315ft at 2.57 / 2.46 bpm. FS=2500psi CP=2850psi ECD=9.6 ppg DWOB is 2.32 Klbs with Ct wt 24 Klbs. Black crumbly chunks of old rubber? (size up to 1 "x1/2"x3/4") over shakers. Drill to 11,450 tt. Printed: 2/19/2009 10:49:10 AM ~] ~I 'BP EXPLORATION Page 7 of 1 ~ Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Spud Date: Event Name: REENTER+COMPLETE Start: 1/14/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 Date From- - To Hours Task Code NPT Phase Description of Operations 1/25/2009 14:15 - 14:30 0.25 DRILL P PROD1 14:30 - 15:15 0.75 DRILL P PROD1 15:15 - 15:45 0.50 DRILL N STUC PROD1 15:45 - 17:40 1.92 DRILL P PROD1 17:40 - 18:35 0.92 DRILL P PROD1 18:35 - 19:00 0.42 DRILL P PROD1 19:00 - 19:35 0.58 DRILL P PROD1 19:35 - 22:00 2.42 DRILL P PROD1 Wiper to 11315. Drill 120 fph from 11,450ft at 2.57 / 2.48 bpm. PVT = 281 bbls. FS=2650psi CP=2970psi ECD=9.99 ppg DWOB is 1.6 Klbs with Ct wt 19 Klbs. Drill to 11,532 ft. Circ pressure dropped and differential stuck when PU off bottom. Pull max to 90k several times. Stuck above DGS sub. Shut down pump and let hole relax for 10 min. ECD dropped from 8.66 to 8.23 ppg. Pull to 85k and hold, it popped free after 1.5 minutes. W iper to tubing tail clean. Good amount of cuttings unloaded across shaker. Log GR tie-in +7'. Wiper to bottom clean. Drill 140 fph from 11,532 ft at 2.60 / 2.59 bpm. PVT = 267 bbls. FS=2750psi CP=3080 psi ECD=10.04 ppg DWOB is 1.6 Klbs with Ct wt 19 Klbs. Drill to 11,650 ft. Wiper to 11315ft -clean. Slight set down at 11,320ft, otherwise clean to TD. Drill 120 fph from 11,650 ft at 2.60 / 2.56 bpm. PVT = 259 bbls. FS=2700psi CP=3080 psi ECD=10.10 ppg DWOB is 1.6-1.8 Klbs with Ct wt 20 Klbs. Drill to 11,705 ft. Mini wiper to 11,550ft. Can't seem to RIH & have 25k overpulls. Continue to wiper to 11,315ft. CTD screen went blank, stopped at 11,345ft & were stuck. Pulled free, but very ratty -seems like a cuttings bed. Continue to wiper to 4-1/2" Tbg tail. The shaker decided to quit working. Open EDC & jet to 9000ft. Getting close to 10ppg out MW. Stop at 9900ft & close EDC, blow down kill line & across the stack w/ air to clean the choke line - 22:00 - 22:10 0.17 DRILL P PROD1 Log down for tie-in from 9980ft using reduced pump rate, (+5.5ft corr. 22:10 - 23:00 0.83 DRILL P PROD1 Wiper to 11,315ft. 23:00 - 00:00 1.00 DRILL P PROD1 MAD pass up from 11,315ft to 10,010ft at 500ft/hr. 1/26/2009 00:00 - 01:40 1.67 DRILL P PROD1 Continue to MAD pass to 10,O10ft. 01:40 - 02:35 0.92 DRILL P PROD1 Wiper to TD -very smooth, 24k RIW. ~ 02:35 - 03:40 1.08 DRILL P PROD1 Drill 120 fph from 11,705 ft at 2.44 / 2.44 bpm. PVT = 267 bbls (topping off). FS=2500psi CP=3080 psi ECD=9.90 ppg DWOB is 1.6-1.9 Klbs with Ct wt 20.5 Klbs. Drill to 11,850 ft. 03:40 - 06:15 2.58 DRILL P PROD1 Wiper to 9840ft -clean. Wiper to TD. 06:15 - 07:30 1.25 DRILL P PROD1 Drill 120 fph from 11,850 ft at 2.45 / 2.44 bpm. PVT = 412 bbls FS=2500psi CP=3020 psi ECD=9.99 ppg DWOB is 2.6 Klbs with Ct wt 20.8 Klbs. Drill to 11,953 ft. ROP down to 40 f h. Start stackin wei ht and sticking. 07:30 - 09:45 2.25 DRILL P PROD1 iper to 9800' -clean both ways. Normal amount of cutting over the shakers. Plan to pump a HI-VIS sweep on the next wiper. 09:45 - 11:10 1.42 DRILL P PROD1 Drill 90 fph from 11,953 ft at 2.42 / 2.40 bpm. PVT = 392 bbls PtintBtl: 1/19/LUU9 l U:49a U AM • ao` BP EXPLORATION Page 8 of 13 Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Spud Date: Event Name: REENTER+COMPLETE Start: 1/14/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 Date From - To Hours Task Code _NPT Phase Description of Operations 1/26/2009 09:45 - 11:10 1.42 DRILL P PROD1 FS=2860 psi CP=3180 psi ECD=10.00 ppg DWOB is 1.71 Klbs with Ct wt 19.3 Klbs. Start 20 pill of 150LSRV Fol-Pro down the coil. ROP slowed to 55 fph at 12061'. Drill to 12,065 ft. 11:10 - 14:20 3.17 DRILL P PROD1 Wiper to 9800'. Normal cuttings load ahead of the HI-VIS pill. Log GR Tie-in +8.5' correction. Wiper to TD clean. TD well at 12 070' 14:20 - 15:30 1.17 DRILL P PROD1 MAD pass at 600 fph w/ RES to 11,315'. 15:30 - 16:45 1.25 DRILL P PROD1 Wiper to 9800' -Clean. 16:45 - 19:00 2.25 DRILL P PROD1 POH for OHST/Turn assembl . PJSM while POH regarding handling BHA. Bit graded 1-1 & plugged w/ motor rubber. 19:00 - 20:55 1.92 STKOH P PROD1 Tag up. Pop off well & place injector over bung hole. LD BHI coil track tools on the catwalk. Remove MPR & test tools. MU new motor w/ 3.8deg AKO & new 3.75" M609 bit. Attempt to place BHA in hole, can't make it past the hanger. 3 chipped teeth, dial down motor to 3.6 AKO. Tight going, assume it's the wear pad in the chrome tubing. Stab onto well. Power up & test tools. Set counters. 20:55 - 23:35 2.67 STKOH P PROD1 RIH w/ OHST BHA. Tagged GLM#4,#2 & #1 -orientate passed all of them. 23:35 - 23:55 0.33 STKOH P PROD1 Log down for tie-in from 9980ft (-13ft corr. 23:55 - 00:00 0.08 STKOH P PROD1 RIH 10,080ft. 1/27/2009 00:00 - 00:25 0.42 STKOH P PROD1 Log down from 10,080ft to 10,150ft to aid in OHST log comparison. _, . 00:25 - 03:00 2.58 STKOH P PROD1 Trough three times at 50ft/hr from 10,110ft to 10,070ft using , -, '~ L 2.5b m/2500psi. 03:00 - 05:40 2.67 STKOH P PROD1 Drill LS OHST with 180 TF from 10,110 at ~6pm. ~~ PVT = 344 bbls _`,~~ FS=2500 psi CP=2500 psi ECD=10.02 ppg DWOB is 0.2-0.4 Klbs with Ct wt 24.7 Klbs. Drill the first 1.5ft at 0.1ft every 6min. Drill for the next Oft at O.ift every 3min. At 10,116ft drill at 0.3fUhr with good WOB. Drill to 10,118.6ft, getting too much WOB. 05:40 - 06:00 0.33 STKOH P PROD1 Backream & ream 45 deg L & R of LS to permit tools to enter new OHST. 06:00 - 08:00 2.00 STKOH P PROD1 Observe good WOB and 2deg drop at the NBI. Slowly start turning to the right to avoid Shublik. Drill to 10124.9' and 135R TF 10 fph. PUH to roll TF around. - 10126ft; 90R TF; 20 fph; 2.44k WOB; NBI 88.73 deg. - 10132ft; 50R TF; 15 fph; 4.5k WOB; NBI 86.07 deg. - 10136ft; 20R TF; 15 fph; 3.3k WOB; NBI 85.33 deg. - 10145; 20R TF; 30 fph; 4.03 WOB; NBI 84.68 deg. - 10160; 75R TF; 30 fph 3.56 WOB; NBI 87.6 deg. 08:00 - 10:15 2.25 DRILL P PROD1 Drill from 10160 ft at 2.46/ 2.50 bpm. PVT = 370 bbls FS=2600 psi CP=2930 psi ECD=10.03 ppg DWOB is 3.2 Klbs with Ct wt 20.2 Klbs. Increase pump rate to 2.8 bpm. FS= 2850; CP = 3200 psi. Drill to 10180' and observe DLS around 20. GR increase at 10150' and 10169'. Drill ahead with right TF and away from possible geometry or formation problems. Drill to 10,218'. Only getting -20 DLS and it doesn't seem to be improving. 10:15 - 13:10 2.92 DRILL N DPRB PROD1 POH to BHA pumping thru open EDC at 3 bpm. Weight bobble Printetl: 2/19/2009 10:49:10 AM BP Alaska ~ ~- ~~~ by ~Il~t~s Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date 2/2/2009 Time 12:33:21 Page: 1 ~ Field: Prudhoe Bay Co-ordmate(NE) Refereuce: Well. J-05, True North Site: PB J Pad Verticat(TVD) Reference: J-056 : 65.8 Well: J-05 Section (VS) Reference: Well (O:OON,O.OOE,42.26Azi) Wellpath: J-05C Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2007 J, - -- _ _ - _...._ II Site: PB J Pad _ i TR-11-13 ' ~ UNITED STATES :North Slope ' ' Site Position: Northing: 5968224.22 ft Latitude: 70 19 14.845 N From: Map Easting: 641155.79 ft Longitude: 148 51 20.092 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.08 deg ell. J-05 Slot Name: 05 ' 5002920120 Well Position: +N/-S 2433.87 ft Northing: 5970695.00 ft Latitude: 70 19 38.779 N +E/-W 1995.49 ft Easting : 643105.00 ft Longitude: 148 50 21.840 W Position Uncertainty: 0.00 ft - Wellpath: J-05C Drilled From: J-058 500292012003 Tie-on Depth: 11240.40 ft I Current Datum: J-056: Height 65.84 ft Above System Datum: Mean Sea Level ~; Magnetic Data: 10/20/2008 Declination: 22.92 deg i 'I Field Strength: 57677 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ~ ft ft ft deg 26.34 0.00 0.00 42.26 ~ j Survey Program for Definitive Wellpath __ ' Date: 1/27/2009 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name i I ft ft - _ ___ 100.00 5950.00 J-05B GYD-CT-CMS Gyrodata Top GYD-CT-CMS Gyrodata cont.casing m/s 5956.00 6000.00 J-056 GYD-CT-CMS Gyrodata Btm GYD-CT-CMS Gyrodata cont.casing m/s 6050.96 11240.40 J-056 MWD Speny (6050.96-1124 MWD MWD -Standard 11280.74 12069.00 MWD (11280.74-12069.00) MWD MWD -Standard ', Annotation MD TVD ft ft 11240.40 8683.90 TIP !, 11280.74 8684.87 KOP j 112069.00 8707.88 TD ~ - -- - -- - -- y -- __ Surve : MWD - Start Date• 1/27/2009 Company: Baker Hughes INTEQ Engineer: th fi i i P Tool: MWD;MWD -Standard Tied-to: n ve a From: De t ~~ ~ BP Ala ka i x by S Baker Hughes INTEQ Survey Report N.Lr 6AKER HUGHES INTEQ ~ Company: BP Amoco Date: 2/2/2009 Tim e: 12:.33: 21 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Refereuce: Well: J-05, True North Site: PB J Pad Vertical (TVD) Re ference: J=056:65.8 Well: J-05 Section (VS) Reference: Well (O.OON,O.OOE,42:26Azi) Wellpath: J-0 5C Survey Calculation Method: Minimum Curvature Db: Oracle 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 ~ i, 11240. 40 88.89 76. 57 8683. 90 8618. 06 3770 .69 2711 .61 5974516. 44 645743 .99 4614 .20 0.00 MWD 11280. 74 88.37 73. 15 8684. 87 8619. 03 3781 .23 2750 .53 5974527 .71 645782 .70 4648 .17 8.57 MWD ~ 11315. 32 88.07 74. 11 8685. 94- 8620. 10 3790 .97 2783 .69 5974538 .08 645815 .67 4677 .68 2,91 MWD 11357. 45 88.16 80. 78 8687. 33 8621. 49 3800 .11 2824 .77 5974548 .01 645856 .56 4712 .08 15.82 MWD 11386. 01 88.62 85. 84 8688. 13 8622. 29 3803 .44 2853 .11 5974551 .87 645884 .84 4733 .60 17.78 MWD 11415. 88 88.93 90. 67 8688. 77 8622. 93 3804 .35 2882 .95 5974553 .35 645914 .65 4754 .34 16.20 MWD 11451. 26 88.53 95 .79 8689. 55 8623. 71 3802 .36 2918 .26 5974552 .03 645949 .98 4776 .61 14.51 MWD 11482. 02 88.44 92. 25 8690. 37 8624. 53 3800 .20 2948 .93 5974550 .46 645980 .69 4795 .64 11.51 MWD 11511. 92 89.36 88 .74 8690. 94 8625. 10 3799 .94 2978 .82 5974550 .77 646010 .57 4815 .55 12.13 MWD 11545. 84 89.94 84 .95 8691. 15 8625. 31 3801 .81 3012 .68 5974553 .28 646044 .39 4839 .71 11.30 MWD 11576. 36 89.29 81 .52 8691. 36 8625. 52 3805 .40 3042 .98 5974557 .46 646074 .61 4862 .75 11.44 MWD 11613. 25 88.53 77 .36 8692. 06 8626. 22 3812 .16 3079 .23 5974564 .90 646110 .73 4892 .13 11.46 MWD 11646. 03 88.28 73 .32 8692. 97 8627. 13 3820 .45 3110 .92 5974573 .80 646142 .25 4919 .58 12.34 MWD i 11676. 45 88.04 70 .90 8693. 95 8628. 11 3829 .79 3139 .86 5974583 .69 646171 .00 4945 .95 7.99 MWD 11708. 40 87.67 74 .91 8695. 14 8629. 30 3839 .18 3170 .37 5974593 .65 646201 .32 4973 .42 12.60 MWD ~ 11746. 48 87.36 79 .59 8696. 80 8630. 96 3847 .57 3207 .46 5974602 .75 646238 .25 5004 .58 12.31 MWD 11779. 73 .87.42 83 .65 8698. 31 8632. 47 3852 .41 3240 .32 5974608 .21 646271 .00 5030 .25 12.20 MWD ~ 11819. 37 88.10 89 .90 8699. 86 8634. 02 3854 .64 3279 .84 5974611 .19 646310 .48 5058 .49 15.85 MWD 11851. 19 88.34 92 .79 8700. 85 8635. 01 3853 .89 3311 .64 5974611 .05 646342 .28 5079 .32 9.11 MWD 11883. 46 89.20 89 .05 8701. 54 8635. 70 3853 .37 3343 .89 5974611 .15 646374 .53 5100 .63 11.89 MWD ~I 11911. 88 89.29 86 .97 8701. 92 8636. 08 3854 .36 3372 .29 5974612 .68 646402 .90 5120 .46 7.33 MWD 11942. 66 89.88 83 .68 8702. 14 8636 .30 3856 .87 3402 .96 5974615 .77 646433 .52 5142 .94 10.86 MWD 11971. 13 88.13 81 .41 8702. 63 8636 .79 3860 .56 3431 .18 5974620 .00 646461 .66 5164 .65 10.07 MWD 12002. 47 86.68 78 .47 8704. 05 8638 .21 3866 .03 3462 .00 5974626 .06 646492 .37 5189 .43 10.45 MWD ', 12021. 71 86.71 77 .03 8705. 16 8639 .32 3870 .10 3480 .77 5974630 .49 646511 .06 5205 .07 7.47 MWD 12069. 00 86.71 77 .03 8707. 88 8642 .04 3880 .70 3526 .78 5974641 .96 646556 .86 5243 .85 0.00 MWD Saltmarsh, Arthur C (DOA) • Page 1 of 1 From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, March 09, 2009 12:05 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU J-05C /PTD # 208-171 & J-05CL1 /PTD # 208-172 Hi Art, Please reference the following well: Well Name: PBU J-05C & PBU J-05CL1 Permit #: 208-171 & 208-172 API #: 50-029-20120-03-00 & 50-029-20120-60-00 Top Perf MD: N/A, Open Hole Bottom Perf MD: N/A, Open Hole This well began Production on March 7, 2009 Method of Operations is: Flowing Date of Test: 03/07/09 Hours Tested: 8 24-Hour Rate /Oil-Bbl: 1,483 24-Hour Rate /Gas-Mcf: 31,279 24-Hour Rate /Water-Bbl: 63 Test Rate /Oil-Bbl: 494 Test Rate /Gas-Mcf: 10,426 Test Rate /Water-Bbl: 21 Choke Size: 123 Gas-Oil Ration: 21,092 Flow Tubing Pressure: 1,160 Casing Pressure: 1,400 Oil Gravity-API: Not Available zi4i~nn4 i..~ ALASFiA OIL A1~TD GA.S C01~T5ERRA7'IO1~T COM1~II55IOr1T John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH PAL/N, 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 J-05C BP Exploration Alaska Inc. Permit No: 208-171 Surface Location: 650' FNL, 1245' FEL, SEC. 09, T11N, R13E, UM Bottomhole Location: 3227' FSL, 2247' FWL, SEC. 03, T11N, R13E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. V1When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). incerely, Daniel T. Seamount, Jr. Chair DATED this l~ day of November, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. b g STATE OF ALASKA /~~ ~ ~ ' +,~ ~/ ~ ALA OIL AND GAS CONSERVATION COMI1~1 N U PERMIT TO DRILL ~~~, 20 AAC 25.005 4~ ~'~'~~ ,.~ 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 proposed 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 J-05C 3. Address: P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Proposed Depth: MD 12025' TVD 8640' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe BayQ 4a. Location of Well (Governmental Section): Surface: 650' FNL 1245' FEL SEC 09 T N R 3E M 7. Property Designation: ADL028281 Pool , , . , 11 , 1 , U Top of Productive Horizon: 2660' FSL, 408' FWL, SEC. 03, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: February 1, 2009 Total Depth: 3227' FSL, 2247' FWL, SEC. 03, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 13230' 4b. Location of Well (State Base Plane Coordinates): Surface: x-643105 y-5970695 Zone-ASP4 10. KB Elevation (Hei ht above GL): 65.84' feet 15. Distance to Nearest Well Within Pool: 413' 16. Deviated Wells: Kickoff Depth: 11315 feet Maximum Hole An le: 89 d rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3018 Surface: 2158 1 'n r m: ifi i n T in D h- n i of nt .f r Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 19, PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11315 Total Depth TVD (ft): Plugs (measured): 9823 Effective Depth MD (ft): 11315 Effective Depth TVD (tt): 8685 Junk (measured): N/A Casing ' Len th ize Cement Volume MD TVD Conductor /Structural 11 ' Surface 1 - F I ' Intermediate P I I ' Liner 7' 7" 1 x I ' Perforation Depth MD (ft): 9985' - 11315' Perforation Depth TVD (ft): 8653' - 8685' 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the fore oiny is tr a and correct. Printed Name John c ~ J Si nature ~ ~ Contact Sean McLaughlin, 564-4387 Title En ineerin Team Leader Prepared By Name/Number. Phone 564-4711 Date 1 ~~ t~` Sondra Stewman, 564-4750 Commission Use Onl Permit To Dri ~ Num API Number: 50-029-20120-03-00 Permit Approval. ~ ~ See cover letter for i 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 .lNlVo ~~ T~ ' s HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No Other: J~~ p~j i \.~~ ~ ~ 5~ ~~; ~ /~ APPROVED BY THE COMMISSION ~' Date COMMISSIONER Form 10-401 Revised1272005 ~ ~ ~ ~ ~ ~ ~ Submit In Duplicate L L_J • by CTD RWO + Sidetrack Summary BPXA Prudhoe Bay J-05C CTD Sidetrack October 20, 2008 Pre-Rig Work: 1. O Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. 2. O CMIT-TxIA to 3500 psi 3. S Pull PXN plug, set XXN plug, dump sluggits 4. E Chemical cut @ 9725', 10' from the top of the 1st full joint above the packer (Ref: 03/13/00 tubing tally). 5. F Circulate bullhead seawater thru the cut. Bleed WHP's to 0 psi. 6. O Blind and bleed lines, remove well house, level pad Rig Work: (Scheduled to begin on February O1, 2009) Tubing Swap 1. MIRU, Set TWC, ND Tree, NU BOPE and test BOPE to 250 psi low and 3500 psi high. 2. Pu114-1/2" L-80 tubing 3. Replace 7" packoffs ,-.- 4. Run 4-1/2" Chrome completion ~ ~~ ~ ~~~~- C Lateral 5. ND RWO BOPE, NU Tree, NU CT Drilling BOPE and test. 6. Pull ball and rod, RHC plug, and XXN plug 7. Drill wellbore extension with 4.125" bicenter bit to 12025'. CLl Lateral 8. OH sidetrack at 10,080' 9. Drill 3.75" lateral section to 11,900'. 10. FP well to 2000' with diesel. 11. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 12. RDMO. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run live gas lift design. 4. Flow well to test separator Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.6 ppg 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: 4.125" (bi-center bits used) Casing Program: None- Open hole • Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 89 deg'. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property -13,230 ft. • Distance to nearest well within pool - 413 ft. (J-13) Anti-Collision • No anti-collision issues Logging • MWD directional, Gamma Ray, Resistivity will be run over all of the open hole section. Hazards • The maximum recorded H2S level on J pad is 110 ppm on well J-26. • No planned fault crossings Reservoir Pressure • The reservoir pressure on J-05C is expected to be 3,018' psi at 8,600' TVDSS. (6.8 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to surface is 2,158 psi. Sean McLaughlin CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble TREE = 4-1 /8" CM! • WELLHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 65.8' BF. ELEV = 38.25' KOP = 3107' Max Angle = 93 @ 10119' Datum MD = NA Datum ND = 8800' SS 30" CONDUCTOR 98' 13-3/8" CSG, 68#, ID = 12.415" 2151' o_Gin~~ rnr 9'IQT Imo- "I ~ s-5/8° Foc 2359' 18~5l8" CSG, 96.5# / 109#, K-55, BTRS, 2553' ID - 17.655" i 17.563" ?? .Minimum ID = 3.725" @ 9823' 4-1/2" HES XN NIPPLE 7" TIEBK, 26#, L-80 BTD-M, .0383 bpf, ID = 6.276' TOP OF 7" LNR OF WHIPSTOCK (-{ 5900' s-5/8" ¢sv ~-~ 5986' L-80, ID = 8.681" 4-1/2" HES X NIP, ID = 3.813" 977$' I--17" x 4-1/2" BKR S-3 PKR, ID = 3.875" 4-1/2" HES X NIP, ID = 3.813" ~4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 7" LNR, 26#, L-80, BTGM .0383 bpf, ID = 6.276" I OPEN HOLETD I-I 11315' S NOTES: NOTE: ORIGINAL WELLBORE J -O ~ ~ MOWN. 7" SCAB LNR HUNG OFF EMERGENCY SLIPS. 2046' PBR ID = ? 2151' 1 13-318" X 9-5/8" XO, ID = 8.681" 4-1/2" HES X NIP, ID = 3.813" C`AMC'.h GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3053 3051 9 KGB2 DMY INT 0 03/10/07 3 5442 5062 40 KGB2 DMY INT 0 03/10/07 2 7348 6567 36 KGB2 DMY INT 0 03/13/00 1 8920 7813 34 KGB2 DMY INT 0 03/13/00 5790' 9-5/8" X 7" BKR ZXP TIEBK PKR, ID = 6.313" 5802' 9-5/8" X 7" BKR ZXP LTP, ID = 7.50" 5818' 9-5/8" X 7" BKR HMC HGR, ID = 6.313" i MILLOUT WINDOW (J-05B) 5956' - 5987' 9823' -~4-1/2" HES XN NIP, ID = 3.725" 9823' 4-1/2" PXN PLUG (07/08/08) 9835' 4-1/2" WLEG, ID = 3.958" ~--~MD TT NOT LOGGED DATE REV BY COMMENTS DATE REV BY COMMEMS 07/06/77 ORIGINAL COM PLEI'ION 7/5/2007 SWGSV SET PXN PLUG (03/16/07) 03/13/00 TWA SIDETRACK COM PLETION 08/22/07 CAZ/PJC 7" TIEBK CORRECTIONS 07/15/03 CMO/TLP KB ELEVATION, MAX ANGLE 07/22/08 JRS/SV RESET PXN PLUG (07/08/08) 05/29/06 CO/DTM TREE CORRECTIONS (06/13/04) 03/10/07 CJN/PAG GLV GO 03/13/07 ALHIPJC CSG 8~ LTP CORRECTIONS PRUDHOE BAY UNIT WELL: J-05B PERMfT No: RL000180 API No: 50-029-20120-02 SEC 9, T11 N, R13E, 650' SNL & 1245' WEL BP Exploration (Alaska) TREE= 4-1/8"CM/ WELLHEAD= MCEVOY ACTUATOR = OTIS KB. ELEV = 65.8' BF. ELEV = 38.25' KOP = 3107' Max Angle = 93 @ 10119' Datum MD = NA Datum TV D = 8800' SS ~J 0 5 C& C L 1 ~~' NOTE: ORIGINAL WELLBORE T SHOWN. 7" SCAB LNR HUNG OFF Proposed CTD Extension and Lateral ENERGENCYSLIPS. 30" CONDUCTOR 98' 13-3/8" CSG, 68#, ID = 12.415" 2151' 9-5/8" FOC 219T 9-5/8" Foc 2359' 18-5/8" CSG, 96.5# / 109#, K-55, BTRS, 2553' ID = 17.655" / 17.563" ?? Minimum ID = _ .276' 580s' - BTD-M .0383 b f ID 6 7" TIEBK 26# L 80 , P -C TOP OF 7" LNR ~80's TOP OF WHIPSTOCK ~-~ 5900' 9-5/8" EZSV L-80, ID = 8.681" A I4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 7" LNR, 26#, L-80, BTGM .0383 bpf, ID = 6.276" I 9985' B (current openhole completion) Openhole TD 11315' 4-1/8" Openhole TD 12025' U C PBR, ID = ? 13-3/8" X 9-5/8" XO, ID = 8.681" 4-1/2" HES X NIP, ID = 3.813" CAMCO GAS LIFT MANDRELS 4 3 2 1 5790' 9-5/8" X 7" BKR ZXP TIEBK PKR, ID = 6.313" 5802' 9-5l8" X 7" BKR ZXP LTP, ID = 7.50" 5818' 9-5/8" X 7" BKR HMC HGR, ID = 6.313" MILLOUT WINDOW (J-056) 5956' - 5987' 9765' - 14-1/2" HES X NIP, ID = 3.813" 977$' 7" x 4-1/2" BKR S-3 PKR, ID = 3.875" 9802' 4-1/2" HES X NIP, ID = 3.813" 9823' I~4-1/2" HES XN NIP, ID =milled to 3.80" { 9835' H4-1/2" WLEG, ID = 3.958" ELMD TT NOT LOGGED CL1 3-3/4" Openhole to TD 11900' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/06/77 ORIGINAL COMPLETION 7/5/2007 SWGSV SET PXN PLUG (03/16/07) 03/13/00 TWA SIDETRACK COM PLETION 08/22!07 CAZ/PJC 7" TIEBK CORRECTIONS 07/15!03 CMO/TLP KB ELEVATION, MAX ANGLE 07/22/08 JRS/SV RESET PXN PLUG (07/08/08) 05/29/06 CO/DTM TREE CORRECTIONS (06/13104) 08/06/08 MSE PROPOSED CTD SIDETRACKS 03/10/07 CJNIPAG GLV GO 03/13/07 ALWPJC CSG ii LTP CORRECTIONS PRUDHOE BAY UNIT WELL: J-05C & CL1 PERMIT No: API No: 50-029-20120-03 & 06? SEC 9, T11 N, R13E, 650' SNL & 1245' WEL BP Exploration (Alaska) • by BP Alaska Baker Hughes INTEQ Planning Report ~Lr ~s INTEQ II~~ - -...-- I Company: BP Amoco - --- - _- Date: 10/21!2008 Time. 14a3:14 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: J-05, True North ~ Site: PB J Pad ' Vertical (TVDj Reference: J-056:65.8 Well: J-05 Section (VS) Reference: Well (O:OON,O.OOE,85.OOAzi) ' Wellpath: Plan 1, J-05C _._ _ Survey Calculation Method: Minimum Curvature Db: Sybase J Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 ~ Site: PB J Pad _ - - TR-11-13 UNITED STATES :North Sl ope Site Position: Northing: 5968224. 22 ft Latitude: 70 19 14.845 N From: Map Fasting: 641155. 79 ft Longitude: 148 51 20.092 W ~'i Position Uncertainty: 0.00 ft North Reference: True i Ground Level: 0.00 ft Grid Convergence: 1.08 deg ; Well: J-05 Slot Name: 05 5002920120 Well Position: +N/-S 2433.87 ft Northing: 5970695. 00 ft Latitude: 70 19 38.779 N +E/-W 1995.49 ft Fasting : 643105. 00 ft Longitude: 148 50 21.840 W j Position Uncertainty: 0.00 ft Wellpath: Plan 1, J-05C Drilled From: J-05B 500292012003 Tie-on Depth: 11315.00 ft Current Datum: J-056: Height 65. 84 ft Above System Datum: Mean Sea Level Magnetic Data: 10/20/2008 Declination: 22.92 deg Field Strength: 57677 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg - - --- 26.34 --- 0.00 0.00 85.00 Plan: Plan #1 Date Composed: 10/20/2008 copy Sean's plan 1, extention of B leg Version: 5 Principal: Yes Tied-to: From: Definitive Path Targets Map - Map <---- Latitude ----> <--- Longitude ---> j i Name Description TVD +N/-S +E/-W Northing ..Fasting Deg biro Sec Ueg blin Sec Dip. Dir. ft ft ft `ft ft J-05C Polygon 65.84 3653.20 2765.39 5974400.00 645800.00 70 20 14.703 N 148 49 1.073 W Polygon 1 65.84 3653.20 2765.39 5974400.00 645800.00 70 20 14.703 N 148 49 1.073 W _ Polygon 2 65.84 3728.32 3547.03 5974490.00 646580.00 70 20 15.439 N 148 48 38.243 W -Polygon 3 65.84 4009.24 3502.37 5974770.00 646530.00 70 20 18.202 N 148 48 39.544 W -Polygon 4 65.84 3943.56 2750.93 5974690.00 645780.00 70 20 17.559 N 148 49 1.492 W l J-05C Fault 2 65.84 1384.13 798.61 5972094.00 643877.00 70 19 52.392 N 148 49 58.522 W -Polygon 1 65.84 1384.13 798.61 5972094.00 643877.00 70 19 52.392 N 148 49 58.522 W -Polygon 2 65.84 1629.36 1471.46 5972352.00 644545.00 70 19 54.803 N 148 49 38.875 W -Polygon 3 65.84 1842.89 1708.59 5972570.00 644778.00 70 19 56.902 N 148 49 31.950 W -Polygon 4 65.84 2483.45 1897.86 5973214.00 644955.00 70 20 3.201 N 148 49 26.419 W -Polygon 5 65.84 2871.00 2293.35 5973609.00 645343.00 70 20 7.012 N 148 49 14.866 W -Polygon 6 65.84 2959.77 2726.16 5973706.00 645774.00 70 20 7.884 N 148 49 2.226 W -Polygon 7 65.84 2898.76 2883.03 5973648.00 645932.00 70 20 7.283 N 148 48 57.646 W -Polygon 8 65.84 2994.10 3653.05 5973758.00 646700.00 70 20 8.217 N 148 48 35.157 W -Polygon 9 65.84 2898.76 2883.03 5973648.00 645932.00 70 20 7.283 N 148 48 57.646 W -Polygon 10 65.84 2959.77 2726.16 5973706.00 645774.00 70 20 7.884 N 148 49 2.226 W -Polygon 11 65.84 2871.00 2293.35 5973609.00 645343.00 70 20 7.012 N 148 49 14.866 W I ~ -Polygon 12 65.84 2483.45 1897.86 5973214.00 644955.00 70 20 3.201 N 148 49 26.419 W ' -Polygon 13 65.84 1842.89 1708.59 5972570.00 644778.00 70 19 56.902 N 148 49 31.950 W -Polygon 14 65.84 1629.36 1471.46 5972352.00 644545.00 70 19 54.803 N 148 49 38.875 W J-05C Target 8705.84 3874.64 3479.80 5974635.00 646510.00 70 20 16.878 N 148 48 40.205 W _- ~ C~ bP BP Alaska Baker Hughes INTEQ Planning Report ~.r sus INTEQ Co pang: BP Amoca Date. 1.0!21/2008. Time: 14:13:14 Page:. 2 Field Prudhoe Bay Co-ordinate(NE) Reference: Well: J-05, True North Site: P B J Pad Vertical (TVD) Reference; J-056: 65.8 i ': Well: J-05 Section (VS) Reference: Well (t) .OON{O.OOE,85.OOAzi) 'i Wellpath: L-- - P lan 1, J-05C _ - ' ---` _ -- _ -_ Survey Calculation Method:. Minimu __- -- --- m Curvature: Dbe Sybase __ -- Annotation - .- - MD - -- TVD -- -- _ ft _ _ 11315.00 8685.35 KOP 11465.00 8688.61 2 665.00 8693.96 3 11845.00 8699.61 4 12025.00 8706.04 TD Plan Section Information MD Inc!' Az~m TVD +N/-S +E!-W DLS Build Turn TFO Ta rget ft deg deg ft ft ft deg/t00ft deg/100ft deg/100ft deg 11315.00 88.89 76.57 8685.35 3788.02 2784.15 0.00 0.00 0.00 0.00 11465.00 88.64 94.57 8688.61 3799.55 2933.06 12.00 -0.17 12.00 91.00 11665.00 88.35 70.57 8693.96 3825.22 3129.86 12.00 -0.14 -12.00 269.00 11845.00 88.09 92.17 8699.61 3852.05 3306.68 12.00 -0.14 12.01 91.00 12025.00 87.86 70.56 8706.04 3878.89 3483.48 12.00 -0.13 _ -12.01 269.00 Survey VID Inc! Azim SS TVD N!S E/W Maps' MapE DLS VS TFO Too I ft deg .deg' ft ft ft ft ft deg/100ft ft deg 11315. 00 88.89 76.57 8619.51 3788.02 2784. 15 5974535.14 645816.19 0.00 3103.71 0.00 MWD: 11325. 00 88.87 77.77 8619.70 3790.24 2793. 90 5974537.54 645825.89 12.00 3113.61 91.00 MWD 11350. 00 88.82 80.77 8620.21 3794.89 2818. 46 5974542.66 645850.35 12.00 3138.48 90.98 MWD 11375. 00 88.77 83.77 8620.73 3798.25 2843. 22 5974546.50 645875.05 12.00 3163.44 90.92 MWD 11400. 00 88.73 86.77 8621.28 3800.31 2868. 13 5974549.03 645899.91 12.00 3188.43 90.85 MWD 11425. 00 88.69 89.77 8621.84 3801.07 2893. 11 5974550.26 645924.86 12.00 3213.38 90.79 MW D 11450. 00 88.66 92.77 8622.42 3800.51 2918. 09 5974550.18 645949.85 12.00 3238.22 90.72 MWD 11465. 00 88.64 94.57 8622.77 3799.55 2933. 06 5974549.51 645964.83 12.00 3253.05 90.65 MWD 11475. 00 88.61 93.37 8623.01 3798.86 2943. 03 5974549.01 645974.82 12.00 3262.92 269.00 MWD 11500. 00 88.57 90.37 8623.63 3798.04 2968. 01 5974548.67 645999.80 12.00 3287.73 269.03 MWD 11525. 00 88.52 87.37 8624.26 3798.53 2992. 99 5974549.64 646024.77 12.00 3312.66 269.10 MWD ~ 11550. 00 88.48 84.37 8624.92 3800.33 3017. 91 5974551.91 646049.65 12.00 3337.65 269.18 MWD 11575. 00 88.44 81.37 8625.59 3803.44 3042. 71 5974555.48 646074.38 12.00 3362.62 269.26 MWD 11600. 00 88.41 78.37 8626.28 3807.83 3067. 31 5974560.35 646098.89 12.00 3387.51 269.34 MWD 11625. 00 88.38 75.37 8626.98 3813.51 3091. 64 5974566.49 646123.11 12.00 3412.24 269.42 MWD 11650. 00 88.36 72.37 8627.69 3820.45 3115. 64 5974573.88 646146.97 12.00 3436.76 269.50 MWD i 11665. 00 88.35 70.57 8628.12 3825.22 3129. 86 5974578.92 646161.09 12.00 3451.34 269.59 MWD 11675. 00 88.33 71.77 8628.41 3828.44 3139. 32 5974582.33 646170.49 12.00 3461.04 91.00 MWD 11700. 00 88.28 74.77 8629.15 3835.64 3163. 25 5974589.98 646194.28 12.00 3485.51 90.97 MWD 11725. 00 88.23 77.77 8629.91 3841.57 3187. 52 5974596.37 646218.43 12.00 3510.20 90.88 MWD 11750 .00 88.20 80.77 8630.69 3846.22 3212. 07 5974601.49 646242.88 12.00 3535.06 90.78 MWD 11775 .00 88.16 83.77 8631.48 3849.58 3236. 82 5974605.32 646267.57 12.00 3560.02 90.69 MWD 11800 .00 88.13 86.77 8632.29 3851.64 3261. 72 5974607.85 646292.42 12.00 3585.00 90.60 MWD 11825 .00 88.11 89.77 8633.11 3852.39 3286. 70 5974609.08 646317.37 12.00 3609.95 90.50 MWD 11845 .00 88.09 92.17 8633.77 3852.05 3306. 68 5974609.12 646337.36 12.00 3629.83 90.40 MWD : 11850 .00 88.08 91.57 8633.94 3851.89 3311 .67 5974609.06 646342.35 12.00 3634.79 269.00 MWD 11875 .00 88.04 88.57 8634.79 3851.86 3336 .66 5974609.50 646367.33 12.00 3659.67 269.02 MWD 11900 .00 87.99 85.57 8635.65 3853.14 3361 .61 5974611.25 646392.25 12.00 3684.64 269.12 MWD 11925 .00 87.95 82.57 8636.54 3855.72 3386 .45 5974614.31 646417.04 12.00 3709.62 269.23 MWD . 11950 .00 87.92 79.57 8637.44 3859.59 3411 .13 5974618.65 646441.64 12.00 3734.54 269.33 MWD ' 11975 .00 87.90 76.57 8638.35 3864.76 3435 .57 5974624.28 646465.98 12.00 3759.34 269.44 MWD 12000 .00 87.88 73.56 8639.27 3871.20 3459 .71 5974631.18 646489.98 12.00 3783.94 269.55 MWD . i 12025 .00 87.86 70.56 8640.20 3878.89 3483 .48 5974639.32 646513.60 12.00 3808.29 269.66 4.5" • • [•vuotl .oo•sa 3• ••o~•s 1•~li,•n we~•t Aso-r oso-r'1. xna 0 c~ [u1MOS) (+ll•a311•li••M (B50•f) So•f 6 ' L d011 3•o,ry aso-r ~~so•r'3 ••la ..~ie.~. i i. oz uNy I=aorv oa w~~~ea x„a;,;,,g,x° Lq Nlld OSUf -t Orld aiaso-r'z ~Ildl so-r t ~ dq -- - °°"°" "'""°"""'""" so-r eso-r aedvso-rlso-r lvso-r) so-r " °" (so-rlso-r ~~ N 2 ea Z P n i • Y Y S S M 0~,t p C S 0=ic Z ~ o N e 0 ~e' o' czar ea u i d~ o r nor no s,c„ 5c SLLr i ~Lgaa . _ _< _ , " eNNr .+ ~ y.., s" uva "or I.i..L wa «.. L .»u rn. .L.n. w r a L .. ao~. ....w r=claw ~aln"a=~ = eso-r ~ ~==ur Iaoo~oerioo~m so-ias m a,ai=a rsni=o was 054 ee~se esor a,va,=.=a (aw I~fuan 4u^N =^LL'SPf a~lu=~ 14M '.mu ,ales 13m) alewp,oa~ NOLLIrtNtlOtlN13~N3a313a ~_~_ . .. ~ ~ _- - m.v 00'0 ILLt 0L YY130 • •n r 4 ~ ~ ~ I!,O O i YIL eY!4~1 I : e r .e ~O iM•'Lf "i / tl 'P 4 la L Oo'SL[LL ^~la ~~ MI•M iu.,.~ fso- LLLOOS R L • f'I a9~ .l S nna•• xarni3r e~seld d8 ~Lr by BP Alaska BMYGNES Anticollision Report INTEQ Company:. BP Amoco Date: 10/22/2008 Time: 09:34:49 Page: 1 ', Fieh1: Prudhoe Bay Reference Site: PB J Pad Co-ordinate(NE) Reference: Well: J-05, True North Reference Well: J-05 ~Refereuce Wellpath: Plan 1; J-05C Vertical (TVD) Reference: J-056:65.8 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are'Ri~de"fiaerlls in this115tihL'i pal Plan & PLANNED PROGRAM Interpolation Method: MD Inte rval: 25.00 ft Erro r Model: ISCW SA Ellipse ', Depth Range: 11315.00 to 12025.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1399.87 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 10/20/2008 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft - -- - 100.00 5955.00 J-056 GYD-CT-CMS Gyrodata Top GYD-CT-CMS Gyrodata cont.ca sing m/s -Used in Preference 5956.00 6000.00 J-056 GYD-CT-CMS Gyrodata Btm GYD-CT-CMS Gyrodata cont.ca sing m/s -Used in Preference 6050.96 11315.00 J-056 MWD Spe rry (6050.96-1124 MWD MWD -Standard 11315.00 12025.00 Planned: Plan #1 V5 MWD MWD -Standard ~ Casing Points - - - --- ------ ------ ---- MD TVD .Diameter: Hole Size .Name -- 1 ft ft in in 12025.00 8706.04 4.500 4.500 4.5" Summary - - -- ~ -- ----------- Offset Wellpath --- -> Reference .Offset Ctr-Ctr \o-Go Allowable t Site Well Wellpath MD MD Distance :area Deviation R'arnit-g ft ft ft ft ft PB J Pad J-05 J-05B V14 11315.00 11315.00 0.00 153.91 -153.91 FAIL: Major Risk PB J Pad J-05 Plan 2, J-05CL1 VO Pla Out of range PB J Pad J-O8 J-08A V8 11317.73 11075.00 919.59 160.45 759.15 Pass: Major Risk ', PB J Pad J-13 J-13 V3 11997.67 10575.00 413.70 194.09 219.61 Pass: Major Risk PB J Pad J-19 J-19 V1 Out of range PB J Pad J-24 J-24 V3 Out of range PB J Pad J-24 J-24A V9 Out of range PB J Pad J-24 J-24AP61 V7 Out of range PB J Pad J-24 J-24AP62 V5 Out of range l Site: PB J Pad Well• J-05 Rule Assigned: Major Ris k Wellpath: J-05B V14 inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis : Ctr-Ctr No-Go :Ulowxble MD TVD MD TVD Ref Offset TFO+AZI. TF0-H5 Casing/t 1~Distance :area Deviation 1'i'arning ft' ft ft ft R ft deg 'deg in ` ft ft ft 111315.00 8685.35 11315.00 8685.35 30.08 29.11 76.57 0.00 0.00 153.91 -153.91 FAIL ~ Site: PB J Pad Well: J-08 Rule Assigned: Major Risk Wellpath: J-08A V8 Inter-Site Error: 0.00 ft -Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD ;Ref Qffset TFO+AZI TFO-H5 Casing/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11317.73 8685.40 11075.00 8349.10 29.97 13.96 8.35 291.46 7.000 919.59 160.45 759.15 Pass 11322.20 8685.49 11100.00 8367.79 29.79 13.88 7.56 290.12 7.000 923.53 160.45 763.08 Pass 11325.00 8685.54 11125.00 8386.50 29.68 13.85 6.58 288.81 7.000 928.06 160.68 767.38 Pass 11330.91 8685.66 11150.00 8405.22 29.42 13.72 5.97 287.49 7.000 933.19 160.19 773.00 Pass 11335.18 8685.75 11175.00 8423.88 29.23 13.64 5.19 286.20 7.000 938.94 159.93 779.00 Pass 11339.40 8685.83 11200.00 8442.48 29.05 13.57 4.42 284.92 7.000 945.30 159.61 785.69 Pass 11343.57 8685.92 11225.00 8461.02 28.86 13.49 3.66 283.66 7.000 952.27 159.21 793.06 Pass 11350.00 8686.05 11250.00 8479.52 28.58 13.35 3.19 282.42 7.000 959.80 158.27 801.54 Pass 11350.00 8686.05 11275.00 8498.04 28.58 13.40 1.98 281.21 7.000 967.79 158.63 809.16 Pass ' 11355.80 8686.17 11300.00 8516.56 28.32 13.27 1.47 280.01 7.000 976.22 157.65 818.57 Pass 11359.78 8686.25 11325.00 8535.10 28.14 13.20 0.77 278.83 7.000 985.09 157.01 828.08 Pass 11363.69 8686.33 11350.00 8553.71 27.96 13.13 0.08 277.67 7.000 994.39 156.32 838.06 Pass 11367.49 8686.41 11375.00 8572.41 27.78 13.06 359.39 276.52 7.000 1004.14 155.61 848.53 Pass 111375.00 8686.57 11400.00 8591.11 27.44 12.88 359.16 275.39 7.000 1014.41 153.99 860.43 Pass ~ i urem are i ~ J-05C and ~ CL1 BAG 7 1 /16" 5000 psi. of bag of pipes of flow cross of blind/shears Blind/Shears TOTs 2 3/8" combi ram/slips ~ 1/i s" 5ooopsi Mud Cross I I Mud Cross 7 1 /16" 5000psi variable bore pipe 3 1/2"-2 3/8" TOTs 2 3/8" combi ram/slips ~ ~ i/16" 5ooopsi Swab Valve Flow Tee Alaska Department of Natural Resources Land Administration System :. ~ ,>~::a ~ ~ 7~, ~~~,_~ ~ ~ . .a.~w ;Fiats ~;e%t~rc~€~~s Sea;cli State Cabins Page 1 of,~ j ICs r File Type: ADL File Number: .28281. ~ Printable Case Fife_Summary See Township, Range, Section and Acreage? New Search Yes ~` No _~.._.--- ~ _.. LAS Menea ~ Case Abstract ~ Case detail ~ tuanci Abstract M. bile: AUL 28281 `"~~ Search for Status °IaL Updates 1~ cif l ]!0,i~'OOti Custo~TZer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: ~~ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Dote: 08/19/1965 Total Acr°es: 2560.000 Date Initialed: 05/28/1965 Offrc°~ of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/0/2006 Case Subtype : ~tS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Ilc~rfcfhrr~: U 7inrtrshi/,: U I l \ R<ru~~E~: O1 ~E. .~~ertsorz: 03 ~'<~c[i~»r : 1~ r2s: 640 Searcl-~ ;'iii t:i a~i:'Yltjltlll.~ ~.~ ~UlFi1.1'~llj): O~ 1N R(ln,L'C: ~1~iI:_. .ti~NClIU//.~ O'~ tir'~'llUi7.-~CY'('.C.' 640 1lrrr~/iuit: t_I %uu~rshr/~: Ol1N il~r~r,~,rc.~ 013E Sr~c~~lr>r~.~ 119 ,ti~c~c~tiun lcrc~: 6-~~) 1LIc~i~ic/rin.~ U' l ~nr~~~{trj~ 01 1N R~rnge: 013E S~~~~ric~~i.~ I [1 S'c~c~iru~~ .9cres.~ (.~-1(1 Lcgal Description 0~-28-196 ~** SALEN~>[ICELEGAL DESCRIPTION ~"~ C1=1- 9? TIIN, R13E, UM 3, 4. 9, 102,60.00 Last updated on 11/05/2008.. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28281 &... 11 /5/2008 TRANSMITTAL LETTER CHECKLIST WELL NAME _ %~/,3C/.~" Off" PTD# o~©~- f ~J / Developments _____ Service _____ Exploratory Strap ____ Non-Conventional Well graphic Test FIELD: - %U.e~/D.S/~E .4y POOL: __~.PC1D.5/o~' /?.~1~ ©/G Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) ~~. FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. _ API number are . AP[ No. SO- between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PIS and AP[ number (S~ = _..,_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with ZO AAC EXCEPTION 25.055. Approval to perforate and yroduce /_ i,~nixt is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. "'" "" `'" All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the from where samples are first caught and 10' sample intervals throe ct zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed me}hane is not allowed for jn_ame of weln until after (Coniaanv Nahas designed and implemented a water well testing program to provide baseline data on water quality and quantity. lCom4any,Name) must contact the Commission to obtain advance approve! of such water well testing nmo~rn R~~: in ~nooa WELL PERMIT CHECKLIST Field & Paol PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT J-05C Program DEV Well bore seg ^ PTD#~ 2081710 Company BP EXPLORATION ALASKA) iNC Inftial Classll'ype DEV 11-OIL GeoArea 890 Una 11650 ONOff Shore Qn___ Annular Disposal ^ Administration 1 PetmitfQeettached---- ------- --- --- -~- - -- - -- NA- - -- -- - - - - --- ----- ----- - ---- - ---- 2 Lease number appropriate- - ---- ---- ---- -- ---- Yes- ---- -- - --- --- - -------- -- - - -- -- -- 3 Uniquewell_nameandnumber--- ----- --- -- --- - -- --Yes -- - -- - --- -- ----- ---- --- - -- - -- ---- -- 4 Well located in.a_definedpool_.___---------------------- ---__ --Yes-- --Prudhoe Bay Oil Pool._-__-___._._______-_________.-----_------------- 5 Well located proper distance from drilling unit_boundsry--------------- ---- ----Yes----- -------------------------------------------- -- - - - 6 Well loc;~ted proper distance from Qther wells - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 Sufficient acreageayailable in drilling unit - - - - - - - - - - - Yes - - - - 2560 acres. - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - 8 If-deviated, iswellboreplatincluded- ---- -- - ------ -Y~ - - -- ---- ---- -- --- ---- -- - -- ----- 9 Qpetatotonlyagec~dparfY -- -- --- -- --- - ---- -Yes - --- --- ---- ---- ---- ---- - ----- -- -- - ----- 10 Operatorhas_appropriatebond in foroe_____.__--__-________ ___------Yes_____ --Blanket@ond#619419$•--------------------------------------------------- 11 Pero]itcanbeissuedwithoutconservationorder_-____--_________ _______Yes----- ----------------------------------------------- -- -- - --- --- Appr Date 12 Pero]itcanbeissuedwiihoutadminisitative_app[oval--------------- ---__ _--Yes---- ------------------------------------------ -- -- -- ----- 13 Can permit be approved before 1$-day_wait - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ACS 1115!2008 14 Welllocat~withinareaandstrataauthprizedby_InjectionOrdet#(put1O#in_comments)_(For_ NA______ __________________--________._____._____._____--______-_______ 15 Allwelis-within1l4_roileareaofreviewideniified(Fotservicewellonly)___-_. _______ NA______ ________________________________________________________________ __- 16 Pre-producediojector, duration ofpn?-praduciionlessthan3months_(Forservicewelioniy)---NA----- ----------------------------------------------- -- ---- 17 _Ptonconven,gas_confgnnstoAS31,05.0$OQ.1.A),(1.2.A-D)------------ --------- NA------ ------------------------------------------------------------------ Engineering 18 Conductor stringptovided________________-_---_.-------- --------- NA------ --Ccnduct4rsetinJ-05(172.0~4)._-__-.__________________-__--_____---_----- 19 SutfacecasingprQtQCtsallknownUSDWS--------------------- ---------NA------ --Alla4uifers exempted,AEO1.----------------------------------------------- 20 CMT-voladequatetocirculate_onconductor$surf_ag___-_____--__ ______NA____ __Surfacecasingsetin J-05...__________________________-___-_.-._--__ -- 21 CMT_voladequatetotie-ialQngstringtosurfcsl~_--__.__--_____- -_______ NA _____ _Production_casingsetinJ-05b(200-11$).___-_________________-__-___--______-__-_ 22 CMT_willcoverallknown_Ptoduotiveborizons------------------- --------- ~t°------ --Open-holecompistions Rlanned•--------.--------------------------------------- 23 Casing desgns adequate forC~ T B &.permafrost- - - - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Z4 Adequate iankage_or reserve pit _ _ ___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Rig equipped with steel piss. No_reserve pit planned.- All waste to approved disposal well(s), _ _ _ _ _ _ _ _ 25 If a- re-drill, hes_a 10.40$ for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ . New segment will exit J-0$B bottom hole_ ldo sundry_required. _ . _ _ _ - _ - - _ _ . - _ _ _ _ _ _ _ _ _ 26 Adsqu_ate wehbore separationproposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ _ _ _ _ _ _ _ Yes _ _ _ _ -Proximity analysis performed, Close approaches are in zone.. _ _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ 27 IfdNertQr-required,d2esi#meetnsg~tlati9ns---------------------- --------- NA------ --t3OPstack_willalready_beinpl$ee,---------------------------------------------- Appr Date 28 Drilling fluid program sohemailc.& equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Maximum expected formation pressure 6,8_ EMW._ MW planned $.6 ppg. . _ _ _ - - _ _ . _ _ _ - _ _ _ _ _ _ _ _ TE 1111012008 29 BOP)=s,_dothey-meetreyulation. --- ---- - - -- - ---Yes ---- -- --- - - ---- -- --- -- ---- -- --- 30 BOPS-press rating appropriate; lest ka_(put prig in cpmments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - _ _ _ _ _ MASP calculated at Z15$psi, 3500_psi_BOPlest-planned. _ _ _ _ _ - - _ _ - - _ _ _ _ _ - 31 Choke-manifold complieswlAPLRP-5$(May$4)___--____________ _________Yes__.-- ._ -- - --- 32 Work will occur without operation shutdown- - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is presence- of N?S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ . _ _ _ H2S is reported_ai J pad. _Mud should preclude H2S on rig. _ Rig has-sensors and ala[ms.. _ - _ _ _ _ _ _ - _ _ _ - - 34 Mechanical_c9nditionotwellswithinAORverified(Forseruicewellpnry~_____ _______NA______ ____________--__--______________ Geology 35 Permit can be issuedwlohydrogensuKdemeasutes_______________ _.______No_____ __MaxlevelH2SonJpadis110ppmonwellJ-26,____________-_________-__.______-_-- 36 Da#a-presented on potentialovetpressurezones___________________ ________.NA----- --------------------- ---- ---- - ---- ------ - -- - -- Appr Date 37 Seismic.anaysisofshallowgaszones------ -- -- ----- --- -NA----- ---- - -- -- - ----- ----- --- -- - --- - -- - - --- ACS 1115!2008 38 Seabed_conditionsurvey_(ifoff-shore)________________________ _________NA-_.-__ ____-------- 39 Contactnamelphonefor!aeekiy-P_rg9ressrep9rts_fexploraioryonly]-------- ---------Yes----- -_Sean_McLaughrn--.5$4~$87,------------------.------.---_----.--------------- Geologic Commissioner: Date: Engineering Date Public Commissioner: C er Date C~~~~- ~~ ~~.~~ ~1-13-a8 r Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~ ~ **** REEL HEADER **** MWD 09/04/13 BHI Ol LIS Customer Format Tape **** TAPE HEADER **** MWD 09/02/27 2429264 O1 3.0" CTK *** LTS 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 Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 9981.0000: Starting Depth STOP. FT 12069.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: J-05C FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 19' 38.779"N 148 deg 50' 21.840"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ 'POOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 27 Jan 2009 API API NUMBER: 500292012003 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 09 TOWN.N T11N RANG. R13E PDAT. MSL EPD .F 0 LMF DF FAPD.F 65.84 DMF DF EKB .F 0 EDF .F 65.84 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 ~~~-=t-~-~ ~ ~~-~~r Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and depth shifting has been waived by Roger Sels with BP Exploration (Alaska), Inc. The MWD data is the PDC (Primary Depth Control) log for J-05C. (8) The sidetrack was drilled as an extension of J-05B at 11315 feet MD (8620.1 feet TVDSS). (9) Tied to J-05B at 11240 feet MD (8618.1 feet TVDSS). (10) The interval from 12029 feet to 12069 feet MD (8639.7 feet to 8642.1 feet TVDSS) was not logged due to sensor to bit offset. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected (OHMM) (OHMM) (OHMM) (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 73 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and depth shifting has been waived by Roger Sels with BP Exploration (Alaska), Inc. The MWD data is the Primary Depth Control (PDC) for well J-05C. * 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-t ype is: 1 FRAME SPACE = 0. 500 * 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: 45 Tape File Start Depth = 11274.000000 Tape File End Depth = 12069.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 58 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and depth shifting has been waived by Roger Sels with BP Exploration (Alaska), Inc. The MWD data is the Primary Depth Control (PDC) for well J-05C. * 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 S ub-type is: 1 FRAME SPACE = 0. 500 * 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: 117 Tape File Start Depth = 9981.000000 Tape File End Depth = 12069.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 130 records... Minimum record length: 34 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!~!~~~!!!! Remark File Version 1.000 This file contains the raw-unedited field MADPass data. * 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 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: 233 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 9980.750000 Tape File End Depth = 12069.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 4 246 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 • *** LIS COMMENT RECORD *** !!!!!!!!!!!~~~~~!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. * 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 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 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 89 Tape File Start Depth = 11274.000000 Tape File End Depth = 12069.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 5 102 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 09/02/27 2429264 O1 **** REEL TRAILER **** MWD 09/04/13 BHI 01 Tape Subfile: 6 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP RPD RPS 11274.0000 -999.2500 -999.2500 -999.2500 -999.2500 11274.5000 -999.2500 -999.2500 -999.2500 -999.2500 11300.0000 75.2000 -999.2500 8.9970 6.6540 11400.0000 77.1000 103.4000 15.9640 15.1230 11500.0000 81.5000 128.9000 14.7790 13.6730 11600.0000 79.7000 116.0000 15.4760 14.6160 11700.0000 89.5000 117.3000 13.5970 12.5460 11800.0000 93.2000 138.3000 12.8430 11.9070 11900.0000 78.6000 96.2000 13.5970 12.8150 12000.0000 77.9000 79.3000 14.2770 13.8240 12069.0000 -999.2500 34.8000 -999.2500 -999.2500 Tape File Start Depth = 11274.000000 Tape File End Depth = 12069.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet RAD -999.2500 -999.2500 13.5360 15.3360 14.8420 14.9820 14.3770 13.6550 13.5360 13.4900 -999.2500 RAS -999.2500 -999.2500 12.5430 17.0170 15.9860 16.5240 14.7820 14.0590 14.4850 15.4840 -999.2500 Tape Subfile 3 is type: LIS DEPTH GR RPD RPS 9981.0000 -999.2500 -999.2500 -999.2500 9981.5000 -999.2500 10.4960 9.0960 10000.0000 -999.2500 14.4190 11.8530 10100.0000 -999.2500 10.3450 8.6310 10200.0000 -999.2500 9.2660 7.1950 10300.0000 -999.2500 9.7670 7.6690 10400.0000 -999.2500 9.7530 7.3680 10500.0000 -999.2500 9.2190 6.8240 10600.0000 -999.2500 10.0160 7.3050 10700.0000 -999.2500 8.4410 6.0780 10800.0000 -999.2500 9.0700 6.5450 10900.0000 -999.2500 8.3090 6.0060 11000.0000 -999.2500 8.2440 5.8000 11100.0000 -999.2500 9.5610 6.9910 11200.0000 -999.2500 9.6420 7.0700 11300.0000 75.2000 8.7830 6.4900 11400.0000 77.1000 15.7460 14.7820 11500.0000 81.5000 14.6860 13.4010 11600.0000 79.7000 15.3180 14.2920 11700.0000 89.5000 13.5970 12.4140 11800.0000 93.2000 ROP -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 103.4000 128.9000 116.0000 117.3000 138.3000 RAD -999.2500 11.4900 16.0350 12.3130 12.9770 13.8400 14.0110 13.8210 15.0980 13.4900 14.0680 13.3310 13.7250 14.3630 14.4390 13.3540 15.5400 15.2350 15.1940 14.5770 13.9920 RAS -999.2500 12.0390 20.1570 13.6640 12.1170 12.4540 12.8960 12.3950 14.4660 11.6870 12.8800 11.6480 11.9370 14.0170 13.7960 12.0530 17.0940 16.1710 16.4370 14.9130 14.1610 • • 12.9640 11.8450 11900.0000 78.6000 96.2000 13.7050 13.5970 12.9520 12000.0000 77.9000 79.3000 13.6980 14.2770 13.8240 12069.0000 -999.2500 34.8000 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9981.000000 Tape File End Depth = 12069.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 14.5910 15.4360 -999.2500 Tape Subfile 4 is type: LIS DEPTH GR RPD RPS 9980.7500 -999.2500 -999.2500 -999.2500 9981.0000 -999.2500 -999.2500 -999.2500 10000.0000 -999.2500 14.4190 11.8530 10100.0000 -999.2500 10.3450 8.6310 10200.0000 -999.2500 9.2660 7.1950 10300.0000 -999.2500 9.7670 7.6.690 10400.0000 -999.2500 9.7530 7.3680 10500.0000 -999.2500 9.2190 6.8240 10600.0000 -999.2500 10.0160 7.3050 10700.0000 -999.2500 8.4410 6.0780 10800.0000 -999.2500 9.0700 6.5450 10900.0000 -999.2500 8.3090 6.0060 11000.0000 -999.2500 8.2440 5.8000 11100.0000 -999.2500 9.5610 6.9910 11200.0000 -999.2500 9.6420 7.0700 11300.0000 75.2000 8.7830 6.4900 11400.0000 77.1000 15.7460 14.7820 11500.0000 81.5000 14.6860 13.4010 11600.0000 79.7000 15.3180 14.2920 11700.0000 89.5000 13.5970 12.4140 11800.0000 93.2000 ROP -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 103.4000 128.9000 116.0000 117.3000 138.3000 • RAD -999.2500 -999.2500 16.0350 12.3130 12.9770 13.8400 14.0110 13.8210 15.0980 13.4900 14.0680 13.3310 13.7250 14.3630 14.4390 13.3540 15.5400 15.2350 15.1940 14.5770 13.9920 RAS -999.2500 -999.2500 20.1570 13.6640 12.1170 12.4540 12.8960 12.3950 14.4660 11.6870 12.8800 11.6480 11.9370 14.0170 13.7960 12.0530 17.0940 16.1710 16.4370 14.9130 14.1610 • 12.9640 11.8450 11900.0000 78.6000 96.2000 13.5970 12.9520 12000.0000 77.9000 79.3000 14.2770 13.8240 12069.0000 -999.2500 34.8000 -999.2500 -999.2500 Tape File Start Depth = 9980.750000 Tape File End Depth = 12069.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 13.7050 13.6980 -999.2500 14.5910 15.4360 -999.2500 Tape Subfile 5 is type: LIS DEPTH GR ROP RPD RPS 11274.0000 -999.2500 -999.2500 -999.2500 -999.2500 11274.2500 -999.2500 -999.2500 -999.2500 -999.2500 11300.0000 75.2000 -999.2500 8.9970 6.6540 11400.0000 77.1000 103.4000 15.9640 15.1230 11500.0000 81.5000 128.9000 14.7790 13.6730 11600.0000 79.7000 116.0000 15.4760 14.6160 11700.0000 89.5000 117.3000 13.5970 12.5460 11800.0000 93.2000 138.3000 12.8430 11.9070 11900.0000 78.6000 96.2000 13.5970 12.8150 12000.0000 77.9000 79.3000 14.2770 13.8240 12069.0000 -999.2500 34.8000 -999.2500 -999.2500 Tape File Start Depth = 11274.000000 Tape File End Depth = 12069.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet M RAD -999.2500 -999.2500 13.5360 15.3360 14.8420 14.9820 14.3770 13.6550 13.5360 13.4900 -999.2500 RAS -999.2500 -999.2500 12.5430 17.0170 15.9860 16.5240 14.7820 14.0590 14.4850 15.4840 -999.2500 r~ u Tape Subfile 6 is type: LIS