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207-019
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 07-08B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-019 50-029-20296-02-00 11321 Conductor Surface Intermediate Liner Liner 9027 80 2682 8223 988 2398 9342 20" 13-3/8" 9-5/8" 7" 4-1/2" 8651 29 - 109 28 - 2710 26 - 8249 8094 - 9082 8924 -11321 29 - 109 28 - 2710 25 - 6870 7494 - 8408 8261 - 9027 11229, 11234 520 2670 4760 5410 7500 9342 1530 4930 8670 7240 8430 9084 - 11220 4-1/2" 12.6# 13Cr80 24 - 8933 8410 - 9026 Structural 4-1/2" Baker S-3 Perm Packer 8814 8158 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028309 24 - 8268 N/A N/A 527 117 56511 32489 115 19 366 377 1397 1202 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 8814, 8158 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:25 pm, May 20, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.05.20 13:21:12 - 08'00' Bo York (1248) RBDMS JSB 052325 JJL 6/13/25 ACTIVITY DATE SUMMARY 5/14/2025 *** WELL SHUT IN ON ARRIVAL*** ( DRIFT/PLUG SET ) CONTACT DSO, WORK ORDER SIGNED MIRU YELLOW JACKET E-LINE. PT PCE 300 PSI LOW./3000 PSI HIGH, FUNCTION TEST WIRELINE VALVES DRIFT RUN WITH 3.60" GAUGE RING TO 9440' NO TAG CORRELATED TO PROACTIVE DIAGNOSTICS SWERVICES COIL FLAG LOG DA TED 13-NOV-2015 SET THE CIBP AT 9342' CCL TO MID ELEMENT=12.7' CCL STOP DEPTH=9329.3' TAG AFTER SET RDMO YJOS ***WELL S/I ON DEPARTURE *** JOB COMPLETE Daily Report of Well Operations PBU 07-08B 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 07-08B Mill CIBPs Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-019 50-029-20296-02-00 11321 Conductor Surface Intermediate Tieback Liner Liner 9027 80 2682 8223 988 2398 11229 20" 13-3/8" 9-5/8" 7" 4-1/2" 9026 29 - 109 28 - 2710 26 - 8249 8094 - 9082 8924 -11321 29 - 109 28 - 2710 25 - 6870 7494 - 8408 8261 - 9027 11229 (2) , 11234 520 2670 4760 5410 7500 10005 1530 4930 8670 7240 8430 9084 - 11220 4-1/2" 12.6# 13Cr80 24 - 8933 8410 - 9026 Structural 4-1/2" Baker S-3 Perm , 8814 , 8158 No SSSV 8814 8158 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028309 24 - 8268 421 601 29910 15396 1 315 0 0 917 984 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations (2) By Grace Christianson at 10:13 am, Feb 29, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.02.29 07:51:45 - 09'00' Bo York (1248) DSR-3/4/24WCB 2024-06-25 RBDMS JSB 022924 ACTIVITYDATE SUMMARY 1/26/2024 CTU#9 1.75" CT. Job Scope: Mill CIBP's. MIRU CTU. Make up YJ Motor/Venturi BS. MPF pump went down during PT. Stand by for Slb to repair Coil pump. PERFORM WELL CONTROL, MAN DOWN, AND H2S DRILLS W/ CREW Temp dropped to -36 below. Switch to Weather Ticket. ***Swap to Weather Ticket*** 1/29/2024 CTU #9 1.75" CT. Job Objective: Mill Plug x2 End weather standby. Shut in well. PT surface equipment. Bullhead 140 bbls 1% KCL down Tbg. RIH w/ YJ 3-1/8" Venturi / 3.70" Burnshoe BHA. Tag Upper CIBP at 9515' e / 9560' m. Appeared to have counter slippage on electronic counter. Mill on CIBP for ~ 3hrs. Quit seeing motorwork and stalls. Pooh to inspect BHA. Milled off the cutting structure on bottom of burnshoe. Recovered rock like formation samples. Replace Burnshoe and Re-run. Tag CIBP at 9547'e / 9464'm. Work on milling upper CIBP ***In Progress*** 1/30/2024 CTU#9 1.75" CT. Job Scope: Mill CIBP's Continue Milling Upper CIBP at 9545' ctm. Mill on CIBP ~ 80 mins. Got full weight back. Begin pushing upper CIBP. Push to Lower CIBP at 9962' ctm. Attempt to burnover upper CIBP. Pooh. Freeze Protect Coil w/ Meth & Diesel. Successfully recovered the upper CIBP core. RIH w/ 5-Bladed Junk Mill. Tagged plug at 9965' CTM (+40' correction to be on depth 10005'). Mill on plug ~2hrs and start pushing downhole. Multiple stalls while pushing through perfs. Able to dry drift plug to bottom the last ~500'. Push plug to 11189' CTM (+40' Correction 11229'). PUH and confirm tag. Begin POOH and FP coil w/ diesel. Bit stuck several times coming OOH had to work pipe/pump. No issues once we got through the heel. FP Tbg w/ diesel. Rig Down CTU. ***Job Complete*** 2/1/2024 ***WELL S/I ON ARRIVAL*** SET 4 1/2" DREAM CATCHER IN X NIPPLE @ 8,847' MD RAN 4 1/2" CHECKSET TO DREAM CATCHER (SHEARED). ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU 07-08B Continue Milling Upper CIBP at 9545' ctm. Mill on CIBP ~ 80 mins. Got full weightgg back. Begin pushing upper CIBP. Push to Lower CIBP at 9962' ctm. Attempt togg burnover upper CIBP. Pooh. y RIH w/ 5-Bladed Junk Mill. Tagged plug at 9965'gg g CTM (+40' correction to be on depth 10005'). Mill on plug ~2hrs and start pushing()gg downhole. Multiple stalls while pushing through perfs. Able to dry drift plug to bottom the last ~500 Push plug to 11189' CTM (+40' Correction 11229'). gg y Tag Upper CIBP atgg 9515' e / 9560' m. Appeared to have counter slippage on electronic counter. Mill ong CIBP for ~ 3hrs. Quit seeing motorwork and stalls. Pooh to inspect BHA. Milled offg the cutting structure on bottom of burnshoe. Recovered rock like formation samples.g Replace Burnshoe and Re-run. Tag CIBP at 9547'e / 9464'm. Work on milling upper CIBP CIBP fish are correctly shown on the new WBS, below. -WCB STATE OF ALASKA t 0ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ® Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: j'rt-el 13 P 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-019 3. Address: P.O.Box 196612 Anchorage, Development VI Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20296-02-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PBU 07-08B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: k, fi 1 ,'.'w,' Total Depth: measured 11321 feet Plugs 0 measured 9585/10005 feet true vertical 9027 feet Junkfeet i C I ~ 7�}1 i measured t,U Effective Depth: measured 9585 feet Packer measured 8814 feet true vertical 8850 feet Packer true vertical 8157.88 feet ,' Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 29-109 29-109 1530 520 Surface 2683 13-3/8"72#N-80 28-2710 28-2710 4930 2670 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9084-9124 feet feet 9655-9670 feet 10065-10090 feet 10200-10400 feet 10500-11220 feet True vertical depth: 8410-8448 feet feet 8896-8905 feet 9022-9024 feet 9026-9026 feet 9026-9026 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 24-8933 24-8269 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCkNNEO FEL 62 3 alt Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 384 39655 18 1250 546 Subsequent to operation: 1128 37619 54 1250 540 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 121 Exploratory ❑ Development I 1 Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG ❑ GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer SignatureJotie4.4.1,... C14,6 .— Phone +1 907 564 4424 Date 10/5/16 ✓rL ic2/rl I(_. Form 10-404 Revised 5/2015 RBDMS (.`'OCT 1 0 2016 Submit Original Only . • m Q O 0 0 0 0 0 0 0 0 N N- C0 c0 C0 co O O ,nOo � oN � LOL) — 0 N LO L In N- N- U v) OOOOOOOOO CO CO IC) N- l() I- cr CO CO M LC) C)) .- CO — CO N - V CO V CO CO CO CO IN- CO CO O O CO CA N- O) to O) CO O N O IN- M V CO N O N N N N N IN- CO o) CO O r CO ,- CA CO CO CY) O) CO N N M N N N N I"- CO I c G) O O O a- (fl CA N N r I- O 00 M O r- M V �Y N O co 0) N N N N CO O) CO V CO co M I I I I I I Q O � CO "Cr C 07 CO CO r- cy) O) N C� N N N CO N N N CO CO) N c c aIn � O C) c) O 0) O Q O , 0000000 , 0 a) Z 0 Z 0 Z co _1 M = d = N k : : J O *k • O00 - CV co _ 2 ? CA LOo 4 C) CS) 7 t CO cr t() M O) O C 00 CO CO CO N M CO O a) N N It) O CV CO Z Z Z Z 00 0000 C I= I= I=" 'N 0 0 0 0 0 O O u 0 0 0 O CCrYZ W — O D CC Ct wm Z Z . • • Packers and SSV's Attachment PBU 07-08B SW Name Type MD TVD Depscription 07-08B PACKER 8094.37 7494.28 7" Baker ZXP Top Packer 07-08B TBG PACKER 8814.34 8157.88 4-1/2" Baker S-3 Perm Packer 07-08B PACKER 8936.24 8271.89 5" Baker ZXP Top Packer . • 0 co ui u) v 0) N as J � N U) Q � D Ni- co L w w o -1- 2E v O C) v- 0; o 0) m m co m Q LU w - m Z W LL J U) O Q O O Q rt 5 Q _ 0 0 O W 0 LL W J < Q - O w a 0 0z C) * O W W 0 ,; (90 C W 1- 0 a. W D a D a Q O 0 0_ O LL U LL W. p - Q F- 0 0r J 0 0 0 C CD m a) a ZQUpC) L O >- 1- w0G u) 00QUQUa o CO rn . N Uo_ aOaJ °) a) CD w °' � �LL LU W ZLOcOD MCL -101L- -- _ Ca D Q H O w O r W a p d p G > o CC 9 ~ p wZOW p Jww iOUQOQm � � LL J 2 Z W W CC F- F W J W J W C cn 0 p LL Q pO W WLL > II 14- Q � LLjW I= L. W c'lOOCCNO . a. 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R -1 0 R / / 2 ± S E R ƒ R ± ce 6 \ H - C ® / \ k ƒ 0k \ \ E \ EE \ $ 0 99 \ f Ow wz / / ƒ / % / \ / \ % / / E 1'- i._ \ 002 - ¥ ƒ / \ � ± 2 ± E > II 0 m < > LU G22 o2O2 $ I 't CO - D za / / : / � / „ / I // 0 � / R cc k 0 - coca / » ƒ � ƒ C E \ . ■ - z ,_,- < 0 r - J '- m \ ® / 2 Ce : < / 19 / / - / O L e CO o u y / < z O'- �- # � / / EGcecl �\ 0w ® - o O o / / 2 ? / / \ 2 ± / \ @ $ O R Q t g CI 2 _ @ O = o > 0 ° 2 2 w o o w o ® g 0 / r \ � E � ƒ IL D H_ OH_ / 0 ƒ _ w \ E / / � � cL / ® ® / Lii - _ / c0 1.00 ¥ £ > \ / / / I.,<00 JgJE / / R \ / 2 / / / / Ek / / cocacoca / / / / \ 0\ m \ / \ / / / - ± \ kO / / D ƒ D ƒ E \ / / - O \ : 00 : : __ 5 (/) .< i) : : CC CC 12 J : 6 CC a ± < o (0 e e >- \ / n — -- * _ / \ \ / \ < TRS= Clw • 1VVELLFEAD- Cir n ETY NOTES:VMELL ANGLE>70" 9810' ACTUATOR= BAKER. 0 7-08 B "`CHROME TBG"" IIITIAL KB.ELE 64' �✓ BF.ELEV= KOP= 4165' Max Angie= 91°@ 11321' Datum MD= 9592' I 1 1 2200'. .. 1_4-1/2' HES X NIP(9CR), ID=3.813" Datum TVD= 8800'SS GAS LET MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,MN-80,BTC,D=12.347" H 2713' 2 3566 3566 1 MMG DOME RK 16 12/05/15 1 6939 6485 33 MMG DOME RK 16 12/05/15 Minimum ID = 3.725" @ 8920' 8094• '9-518'BKR TIEBACK SLV HES XN NIPPLE 8105' {—9-5/8"x 7°BKR ZXP LT PKR,ID=6,281i 8110' H9-5/8"x 7'BKR HMC LNR HGR,ID=6.31" 9-5/8"CSG,47#,S00-95/N-80,BTC,D —=8.681" ' 8249' _ __-_ _ ___. 9-5/8"MILLOUT WINDOW(07-08B)8249'-8268' TOP OF WHIPSTOCK —I 8249• 9-518"EZSV 8270' 8784' —4-1/2'HES XNIP(9CR), I IID=3.813' 9'1•1•1•1�9 . 8814' —7'x 4-1/2'BKR S-3 PKR, _►11111111 = $ /�� - 1/111111111/1. ID=3.87' 11 1111 ►3e.t.�1 ,1•1y1•/4 ' 8847' J_4-1/2"HES XNIP(9CR),Wv /111111111/+� 110.4.�1111X1 ID=3.813" ..1/1f*I ...►111-.•.-. VA •1*.V**i ' 8920' H4-1/2'HES XN NP(9CR), �:.-••i•••••• ID=3.725" "iii•i�i�i•i•i•i••i ... t, 8924' —{7'BKR TIEBACK SLV, 4-1l2"TBG, 12.6#,13CR,VAM TOP,.0152 8933' j 4-112"WLEG, =3.958' bpf,D=3.958' ( 8933' / 8936' —7-x 5"BKR 2X3 LT PKR, ID=4.40" 8946' —7'x 5'BKR FLEX LOCK LNR HGR,ID=4.44' [7`LNR,26#,L-80, BTC-M. .0383 bpf,D=6.276' —I 9882. ' ® ! 8988. � 5"x 4-1/2"*3 396" PERFORATION SUMMARY REF LOG:MEM CNL ON 02/04/99 9585' I—4-1/2"IMI)CBF'(09/17/16) ANGLE AT TOP PERF:21'@ 9084' I Note:Refer to Production DB for historical perf data 10005' H4-1/2"BKR CEP(11/13/15) SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2-7/8" 6 9084-9124 0 09/18/16 ' 2-7/8" 6 9655-9670 C 11/14/15 ' 2-7/8" 6 10065-10090 C 02/04/14 2-7/8" 6 10200- 10400 C 02/07/09 I 11234' —FISH:4-1/2"WFD CIBP 2-7/8" 6 10500- 11220 C 02/07/09 pB413111238' ' 111111 MILLED OH(11!12115) 111111111 111111111 4-1/2"LNR,12.6#,L-80,BT-M,D=3.958' H 11321' 1.1.1.1.1.1 DATE REV BY COM ENTS DATE REV BY COMETS PRU)HOE BAY UNIT 01/09/79 ZOWAN34 ORIGINAL COMPLETION 10/03/14 I I WJWD SET WFD CBP(09/30/14) WELL: 07-08B 01/12/99 016 SIDETRACK(07-08A) 11/17/15 I I WJMuD MLL&SET CIBP/ADPERFS(11/14/15) PERMIT No."2070190 08/03/07 D14 RWO 12/08/15 GJB/JM)GLV CIO(12/05/15) AR No: 50-029-20296-02 02/07/09 NOES SIDETRACK(07-08B) 09/20/16 KFS/JM)SET CIBPIA DPERFS(09/17-18/16) SEC 33,T11 N,R14E,1215'FNL&166'FEL 02/06/14 BLS/JM3 ADPERFS(02/04/14) 06/16/14 SWC/JMC GLV GO(06/07/14) BP Exploration(Alaska) ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown ❑ Suspend 0 Perforate Ea Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Mill CI BP/5t t1J5P La 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-019 3. Address: P.O.Box 196612 Anchorage, Development p Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20296-02-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PBU 07-08B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 11321 feet Plugs measured 10005 feet true vertical 9027 feet Junk measured feet DEC 15 2015 Effective Depth: measured 10005 feet Packer measured 8816 feet true vertical 9015 feet Packer true vertical 8159.57 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 39-119 39-119 1530 520 Surface 2683 13-3/8"72#N-80 38-2721 38-2721 4930 2670 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9651 -9666 feet 10065-10090 feet 10200-10400 feet 10500-11220 feet True vertical depth: 8894-8903 feet 9022-9024 feet 9026-9026 feet 9026-9026 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr8 26-8935 26-8270 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): FEBS NE FEB 0 4 ?O 1'Cj Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 282 29348 115 20 393 Subsequent to operation: Shut-In 20 0 14.Attachments:(required per 20 AAC 25.07025.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development I1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature i C Phone +1 907 564 4424 Date 12/15/15 Form 10-404 Revised 5/20150. 01vit.V /z/2-3/1 77,/-6//fs' �t RBDMS DEC 2 2015 Submit Original Only � • • m • o• 0 0 0 0 0 0 0 0 N I- a) CO CO CO — O O (c) CO O O V LO LO O N Ll) LO Lf) I— N- U U V) 0 0 0 0 0 0 0 0 0 i cf) M IC) N- LC) N- ct CO CO V CO CO CO CO N- CO CCO r- N CO '— O N- O N CO CO O CO — N Ns CO Ln CO tt O N N N N N N- 00 O) 00 H •— N CO CO CO O) CO CO a) CO O CA CO CO CO CO CO CO LO N N N N N N- CO CD cy) M N (O O V Ln N CO O O CO N CO I� CO LO N O M 0) = N N N N CO 0) CO V Cl M i i i s i W Aw Q N CO CO CO 0 O) CO CO CO CO O O N CO CO CO CO MLO O O N co N N N co a0 m M WO a 1.0 O 0)) O O) O O W C r C r 0 0 0 � Z0Z0Zao, 0,-) 4t 4:k • O 00 d �0 V a0 N _ U O Lj Le N (4) LOLO N.- i 0 0 N 0) 0)i r+ O 00 V V •ct rr,ao 0) O C co CO co 00 V N- M 6) d N N LO O Na) J Z Z Z Z �p 0000 CF— WF- F- 1— H 2 0 0 0 0 0 0 cupDDU D u. D D O D W W Z W W cTo O D I CCW Z Z D U v) Q CL 0 O J J F— • • Packers and SSV's Attachment PBU 07-08B SW Name Type MD TVD Depscription 07-08B PACKER 8096.17 7495.89 7" Baker ZXP Top Packer 07-08B TBG PACKER 8816.14 8159.57 4-1/2" Baker S-3 Perm Packer 07-08B PACKER 8938.04 8273.58 5" Baker ZXP Top Packer • • I gi t EQ ro O / \ \ ® \ 2 0 / » ? 13 \ \ fga -) O 0)Z. / // \ \ E c mE$ � ® G o a _1 co & » _ § \ \ o R �/ G I $ c0 i � e / / I k D O -0 0) a2 � �� E / / 0 Ep 3 2 c E \ \co _ / \ _ \ f IP CC n \ C L- ? \ \ E co < t -0 o t Q / § , t I o_ E o @ 7 ƒ fes ƒ 2 _ - _ -0 ƒ O9 / % 0. n o \ o E o R O CO / < / f < § Ni-- = \ 7 / _ s _ N- E $ 7 ƒ � i / f - —.00 / � � 4 O » � Q \ E o 0 O [ i o � $ 2 \ $ _ �® � $ / ° may mb24r CO 0. o\ k 7/ / \ § . 0 C Ce - / Co R \ / 0)/ k 0 / \ / m OS 9 / / 9 / / / O 9 _/ F U / / 0 7 I » : ¥ ELI 0 0 _ . >- 7 \ t / \ \ I COI \ 7 I 00 -6 2 O r - - \ I Imo ¥ m R g - _, m R 0 c m / o e R g G 2 2 (_) __ CC 0E1.10 _ o = c o ® L U = o 5 $ / \ g e Lt _ - 001 N > Et - U C J g / O / 2 ./\ 2% / c N. 0)2 _c ,- $ 2 » \ � / e .( LcE , / 77q $ a © - g \ 9 y / / / \ 9 y $ 0 c ƒ .m 2 = Z g .e e T % = Z = o m 0 o R -0- c - R _0 o c 2 - c « R = P § 2 / 2 U O 2 et U O c e R U co : 0 o co o e m 2 ® r m in < 2 >- \ \ / ® co + R m # 7Aa / Q 7 p IAm R U ,- < TRS CNV VLSLHEAD= GFREYETY NOTES:WELL ANGLE>700 0 9810' ACTUATOR- BAKER 07-08 B "`CHROME TBG"` NTtAL KB.F1 F 64' BF.ELEV= KOP= 4165' Max Angle= 91'@11321' Datum MD= 9592' I 1 ( 2200' ' [4-1/2" HES XNIP(9CR),ID=3.813"i Datum 1VD= - 8800'SS GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-318"CSG,72#,MN-80,BTC,V=12.347" H 2713' --All 2 3566 3566 1 MMG DOME RK 16 12/05/15 t I il 1 6939 6485 33 ti/IMG DOME RK 16 12/05/15 Minimum ID = 3.725" ( 8920' 8094' 19-5/8"BKR'TIEBACK SLV � HES XN NIPPLE ►� ►� ---- - --_ t ' 8106' '—H9-5/8 x 7"BKR 2XP LT PKR, ID=6.28' 8110 1-19-5/8 x 7'BKR HMC LNR HGR,ID-5-.3-1-"-- . 9-518"CSG,47#,SOO-951N-80,BTC,N)=8.681' E-- 8249' 9-5/8'MILLOUT WINDOW(07.088)8249'-8268' TOP OF WHPSTOCK 1 8249' 9-5/8"EZSV --r-8270' ' i 8784' -4-1/2'HES X NIP(9CR), ID=3.813' trt'1#::::.�:♦ • 8814' —7"x 4-1/2'BKR S-3 PKR, . .►11111111_ . $ ►� �.���������.�0� ID=3.87' 14444A 44'4• , 11v1vi`� 4-1/2'HES X NIP(9CR �1111111101 884Tt ) 1111111 ID=3.813" 1.1111111�11� — - -- e.Ir114.4 ...,/..11-4...-. 8920' -4-1/2"HES XN NIP(9CR), �i�i�i 414��i�i�i I j •.Oiiii ID=3.725' -•'''i+ • 00000 iii�i�i�i�i�i�i �** •.A*•. 8924' 7"BKR TIEBACK SLV =,_,-,,141.10- - 8933' -L-4-1/2'WLEG,ID=3.958' L4-1/2-TBG,12.6#,13CR,VAN(TOP,.0152 bpf,ID=3.958"J--( 8933' --7 1 8936' -'7"x 5"BKR ZXP LT PKR, ID=4.40' 8946' ---7'x 5"BKR FLEX LOCK LNR HGR,ID=4.44' j T LNR,26# _J- 90x2• - i PERFORATION SURNARY ' REF LOG:MEM CX+L ON 02/04/99 10006' -{4-112"BKR CIBP(11/13115) ANGLE AT TOP FERE:53°@ 9655' I Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SCJZ^ ' 2-7/8" 6 9655-9670 0 11/14/15 2-7/8" 6 10065-10090 C 02/04/14 ' 2-7/8" 6 10200-10400 C 02/07/09 2-7/8" 6 10500-11220 C 02/07/09 11234' -FISH:4-1/2"WFD CIBP Ip8TD1 11238' I 1 MLLED DH(11/12/15) I 111111111 1111111i1 4-1/2"LNR, 12.6#,L-80,BT-M,H)=3.958"H- 11321' 1.4.44.4.1 DATE REV BY COM/MIS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/0917940WAN3a ORIGINAL COMPLETION 10/03/14 I 1 WJMD SET WFD C BP(09/30/14) WELL: 07-08B 01/12/99 D16 SIDETRACK(07-08A) 11/17/15 TTRIJMD MLL&SET CE3FYADPERFS(11/14/15) PERMIT No:"1070190 08/03/07 D14 RENO 12/08/15 GJB/JMD GLV C10(12/05/15) API No: 50-029-20296-02 02/07/09 MES SIDETRACK(07-08B) SEC 33,T11N,R14E,1215 FAl&166'Fa 02/06/14 BLS/JMD ADFBRFS(02/04/14) 06/16114 SWC'JM GLV C/O(06/07/14) BP Exploration(Alaska) 0 • 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. LD 7 - 0 _ Well History File Identifier Organizing (done) ❑ Two -sided 1111111111111111111 ❑ Rescan Needed ill 1111111111 RES N DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: ❑ Greyscale Items: ,✓Other, No/Type: CJ7 NO ik 1 ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: iO ! 3 1 / /s/ 11P Project Proofing 111 I BY: ( Mari.) Date: /0/13/11 /s/ rY)P Scanning Preparation - 3 x 30 = �' 0 + i = TOTAL PAGES � 0 Co unt does not include cover sheet) �p BY: t Maria ' Date: O/ 3 /s/ Production Scanning III 1111111111111111 Stage 1 Page Count from Scanned File: / 10 (Count does include cover heet) Page Count Matches Number in Scanning Pre aration: YES NO BY: Maria Date: /0/ 13 / 1 /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. 1 ReScanned 1111111111111111 111 BY: Maria Date: /s/ Comments about this file: Quality Checked III 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 9/27/2011 Permit to Drill 2070190 Well Name /No. PRUDHOE BAY UNIT 07 -08B Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 20296 -02 -00 MD 11321 TVD 9027 Completion Date 2/5 /2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Sury DATA INFORMATION Types Electric or Other Logs Run: DIR / GR / RES, DIR / GR / RES / NEU / DEN / ABI (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr III Digital Dataset Log Log Run Interval OH / Type edlFrmt Number Name Scale Media No Start Stop CH Received Comments LIS Verification 7962 11332 Open 4/14/2009 LIS Veri, GR, RPD, RPS, 1 RPM, RPX, FET, ROP, FCNT, NCNT, RHOB, DRHO, NPHI, PEF T C Lis 17842 Induction /Resistivity 7962 11332 Open 4/14/2009 LIS Veri, GR, RPD, RPS, RPM, RPX, FET, ROP, FCNT, NCNT, RHOB, DRHO, NPHI, PEF RL6g Induction /Resistivity C..,- .,.�,`4t 25 Col 8249 11321 Open 4/14/2009 MD ROP, EWR, DGR, ALD, CTN 2- Feb -2009 og Induction /Resistivity C II _ 25 Col 7631 9027 Open 4/14/2009 TVD ROP, EWR, DGR, 1 ALD, CTN 2- Feb -2009 Rpt LIS Verification 7945 11315 Open 5/21/2009 LIS Veri, GR, RPD, RPS, RPM, RPX, FET, ROP, FCNT, NCNT, RHOB, DRHO, NPHI, PEF **REDO** III D Lis 18053 eInduction /Resistivity 7945 11315 Open 5/21/2009 LIS Veri, GR, RPD, RPS, RPM, RPX, FET, ROP, FCNT, NCNT, RHOB, DRHO, NPHI, PEF * *REDO"" Induction /Resistivity 25 Col 8249 11321 Open 5/21/2009 MD ROP, EWR, DGR, r ALD, CTN 2- Feb -2009 **REDO *" clog Induction /Resistivity 25 Col 8249 9027 Open 5/21/2009 TVD EWR, DGR, ALD, CTN 2- Feb -2009 **REDO** Ed C Asc Directional Survey 28 11321 Open F) Directional Survey 28 11321 Open DATA SUBMITTAL COMPLIANCE REPORT 9/27/2011 Permit to Drill 2070190 Well Name /No. PRUDHOE BAY UNIT 07 -08B Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 20296 -02-00 MD 11321 TVD 9027 Completion Date 2/5/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N 1 C Pdf 17843 /Induction /Resistivity 7962 11332 Open 4/14/2009 Graphics PDF, CGM, EMF formats GR, RPD, RPS, RPM, RPX, FET, ROP, FCNT, NCNT, RHOB, DRHO, NPHI, PEF Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y l Daily History Received? N Chips Received? LLLL._ Formation Tops 0 N Analysis err Received? Comments: Compliance Reviewed By: _ _ _ Date: Z WELL LOG TRANSMITTAL To: State of Alaska May 12, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 07 -08B REDO AK -MW- 6119379 07 -08B REDO: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50- 029 - 20296 -02 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50- 029 - 20296 -02 Digital Log Images: 1 CD Rom 50- 029 - 20296 -02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling BP Exploration (Alaska) Inc. Attn: Bryan Burinda Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Office: 907 - 273 -3536 Fax: 907 - 273 -3535 Bryan u « (, 11ib�irton.com ._L-_ Date: Signed: Nub g MAY 2 khoil _ Anchorage 3 • 1 WELL LOG TRANSMITTAL To: State of Alaska April 12, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: 07 -08B AK -MW- 6119379 07 -08B: 1 LDWG formatted CD rom with verification listing. API #: 50- 029 - 20296 -02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling BP Exploration (Alaska) Inc. Attn: Bryan Burinda Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Office: 907 - 273 -3536 Fax: 907-273-3535 Bifyiiiii.B4iin_cla@fi'alliburton.com 7 ,, /1 / Date: Signed: / _ -- 1.9 g 0 ' 3 1 1 i WELL LOG TRANSMITTAL To: State of Alaska April 12, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: 07 -08B AK -MW- 6119379 07 -08B: 1 LDWG formatted CD rom with verification listing. API #: 50- 029 - 20296 -02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling BP Exploration (Alaska) Inc. Attn: Bryan Burinda Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Office: 907 - 273 -3536 Fax: 907 - 273 -3535. B, y .Bi}rrind alliburton.com ,,� f 71 1d � 7 Date: Signed: l , ( i' C:12-- ,019 ,L,r) • • WELL LOG TRANSMITTAL To: State of Alaska April 12, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 07 -08B AK- MW- 6119379 07 -08B: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50- 029 - 20296 -02 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50- 029 - 20296 -02 Digital Log Images: 1 CD Rom 50- 029 - 20296 -02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling BP Exploration (Alaska) Inc. Attn: Bryan Burinda Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 907 - 273 -3536 LL Fax 90727 -3535 j ry da @halliburton.com / B ari.Burm / 1 a Date: Signed: a` 3 o . • RECHVFD HALLIBURTON MA)-; 3 ;11H9 Drilling and Formation Evaluation Alaska Oil & Gas t;12-MAPIVion Anchorage State of Alaska AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 07-08k Dear Christine Mahnken Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie -on Survey: 8,241.30' MD Window / Kickoff Survey 8,260.00' MD (if applicable) Projected Survey: 11,321.00' MD Please confirm receipt of the survey data, either by post or e-mail, to the data owner at gancpdc @bp.com , or to BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2 -1 900 E. Benson Blvd. Anchorage, AK 99508 (An e-mail confirmation, citing the well, to James.Durand @Halliburton.com would be an additional courtesy.) Please call me at 273 -3537 if you have any questions or concerns. Thank you Jim Durand Survey Manager Attachment(s) RECEIVIbU • STATE OF ALASKA 35 - P9 ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 2709 WELL COMPLETION OR RECOMPLETION REPORT ANDfa9 Iii itt Gas Cons. Commission Anchorno 1 a. Well Status: ■- Oil ❑ Gas ❑ Plugged ❑ Abandoned ❑ Suspended 1 b. Well Class: 20AAC 25.105 20AAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other No. of Completions O�nne� ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., S sp., or Aban1 12. Permit to Drill Number BP Exploration (Alaska) Inc. 26 /2009 207 -019 . 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519 -6612 1/25/2009 50- 029 - 20296 -02-00 ' 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 2/2/2009 PBU 07 - 08B - 1215' FNL, 166 FEL, SEC. 33, T11N, R14E, UM Top of Productive Horizon: 8. KB (ft above MSL): 55.3' 15. Field / Pool(s): 1040' FSL, 1210' FWL, SEC. 27, T11 N, R14E, UM Ground (ft MSL): 26.8' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD) Oil Pool 22' FSL, 2153' FWL, SEC. 27, T11 N, R14E, UM 11238' 9026' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD) 16. Property Designation: Surface: x- 676036 y- 5949706 Zone- ASP4 11321' 9027' ADL 028309 - TPI: x- 677354 y- 5951993 Zone- ASP4 11. SSSV Depth (MD +TVD) 17. Land Use Permit: Total Depth: x- 678323 y- 5950997 Zone- ASP4 None 18. Directional Survey El Yes ❑ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 MC 25.050) N/A ft MSL 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 5.071): DIR / GR / RES, DIR / GR / RES / NEU / DEN / ABI f1/'A✓ ,fa4 7644 '7r ) 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE To _BOTTOM To 1 BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 119' Surface 119' 30" 271 sx Arcticset 13 -3/8" 72# N -80 Surface 2712' Surface 2712' 17 -1/2" 3700 sx Arcticset ll 9 -5/8" 47# N -80 / S00-95 Surface 8249' Surface 7631' 12 -1/4" 1200 sx Class 'G' 7" 26# L -80 8094' 9082' 7494' 8408' 8 -1/2" .213 sx Class 'G' 4 -1/2" 12.6# L -80 8924' 11321' 8260' 9027' 6 -1/8" 336 sx Class 'G' 23. Open to production or injection? ® Yes ❑ No 24. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD) (MD +TVD of Top & Bottom; Perforation Size and Number): 2 -7/8" Gun Diameter, 6 spf 4 -1/2 ", 12.6#, 13Cr80 8933' 8814' MD TVD MD TVD 10200' - 10400' 9026' - 9026' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10500' - 11220' 9026' - 9026' DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect w/ 152 bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): February 26, 2009 Flowing Date of Test: Hours Tested: PRODUCTION FOR OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: 2/26/2009 8 TEST PERIOD ♦ 1,062 1,965 137 85 1,851 Flow Tubing Casing Press: CALCULATED OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. -0- 1,500 24 RATE♦ 3,186 5,896 410 Not Available 27. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ 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. L.,.._, , „:":"IWN None ; o? 9 / t ' i Form 10 -407 Revised 02/2007 Co Ir ry,AEspsE SCI /i kil On 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Tested Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 9082' 8408' None Shublik A 9130' 8453' Shublik B 9155' 8477' Shublik C 9177' 8497' Sadlerochit 9192' 8511' Top CGL / Zone 3 9363' 8670' Base CGL / Zone 2C 9467' 8760' 23SB / Zone 2B 9543' 8820' 22TS 9623' 8876' 21TS / Zone 2A 9722' 8932' Zone 1B 9928' 9001' Formation at Total Depth (Name): Zone 1B 9928' 9001' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ing is true and correct to the best of my knowledge. 0� (�� Signed n Title Drilling Technologist Date /� ` 07 9 Terrie Hubble � 9 9 PBU 07 -08B 207 -019 Prepared By Name/Number. Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Frank Roach, 564 - 4373 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 la: 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 Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak -Off Test Summary Legal Name: 07 -08 Common Name: 07 -08 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 1/24/2009 LOT 8,288.0 (ft) 7,665.0 (ft) 10.10 (ppg) 1,025 (psi) 5,047 (psi) 12.67 (ppg) 1/28/2009 FIT 9,082.0 (ft) 8,408.0 (ft) 8.40 (ppg) 925 (psi) 4,594 (psi) 10.52 (ppg) • Printed: 2/23/2009 11:09:46 AM BP EXPLORATION Page 1 of 11 Operations Summary Report Legal Well Name: 07 -08 Common Well Name: 07 -08 Spud Date: 12/17/1978 Event Name: REENTER +COMPLETE Start: 1/18/2009 End: 2/7/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/7/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 1/18/2009 08:00 - 12:00 4.00 MOB P PRE Rig down - blow down pits and rig water system. Blow down steam lines. Bridle up. Lower cattle chute. 12:00 - 00:00 12.00 MOB P PRE Remove derrick pins. LD derrick. Move sub off well. Begin moving to DS 7 at 20:00 hrs. 1/19/2009 00:00 - 08:00 8.00 MOB P PRE Moving Nabors 2ES substructure, pit module, shops, and satellite camp from DS -1 to DS -7. 08:00 - 15:00 7.00 RIGU P PRE RU Nabors 2ES. Accept rig at 15:00 hrs on 01/19/2009. 15:00 - 16:00 1.00 WHSUR P DECOMP PJSM. Pre -spud meeting with all personnel. 16:00 - 17:00 1.00 WHSUR P DECOMP RU DSM Lubricator. Test to 300 psi. Good test. Pull BPV. 17:00 - 20:30 3.50 WHSUR P DECOMP Circ out freeze protect diesel from tubing and IA with seawater until returns are clean. 20:30 - 00:00 3.50 WHSUR P DECOMP Install BPV. Test from below to 1000 psi. Good test. Function all LDS. ND Xmas tree and remove from cellar. ND tubing head adapter. 1/20/2009 00:00 - 09:30 9.50 BOPSUF P DECOMP NU BOPE, install test dart, and test to 250 / 3500 psi. Test annular to 2500 psi. Test witness waived by AOGCC Rep Chuck Scheve. Test witnessed by WSL Dick Maskell and NAD Toolpusher Cleve Coyne. 09:30 - 11:00 1.50 BOPSUF P DECOMP LD BOP testing equipment. Clean and clear rig floor. 11:00 - 13:30 2.50 BOPSUF P DECOMP RU Lubricator and pull BPV. RD Lubricator and LD tools. 13:30 - 15:30 2.00 PULL P DECOMP PJSM. RU to pull 4 -1/2" tubing hanger and VamTop tubing. 15:30 - 17:00 1.50 PULL P DECOMP Screw into tubing hanger, back out lock -down screws and PU to 200k. No go. Steam wellhead for 30 mins. PU to 210k. No go. Steam wellhead for 15 mins. PU to 220K and pull hanger free. PU to floor 120k. 17:00 - 19:00 2.00 PULL P DECOMP Circulate CO 365 gpm surface to surface. UD hanger. 19:00 - 00:00 5.00 PULL P DECOMP POH with 4 -1/2" tubing from 8530' to 6242'. Checking OA hourly for 17.0 hours. 1/21/2009 00:00 - 09:30 9.50 PULL P DECOMP POH & LD 4 -1/2" VamTop tubing. Connections and tubulars showing severe external pitting starting at -60 joints out of hole. 198 jts, 3 pups, 6 GLMs, 1 cut jt out. 09:30 - 11:30 2.00 PULL P DECOMP RD casing equipment. RU to run DP. 11:30 - 13:00 1.50 PULL P DECOMP Test lower set of BOP rams. Test witness waived by AOGCC rep Chuck Sheve. Test witnessed by WSL Bill Decker and NAD Toolpusher Cleve Coyne. Good Test. 13:00 - 13:30 0.50 PULL P DECOMP RD BOP testing equipment. 13:30 - 15:30 2.00 CLEAN P DECOMP RU to run cleanout BHA. 15:30 - 19:00 3.50 CLEAN P DECOMP MU bit & cleanout BHA to 770'. Change out handling equipment for DP. 19:00 - 00:00 5.00 CLEAN P DECOMP TIH with DP singles from 770' to 6322'. Checking OA hourly for 41.0 hours. 1/22/2009 00:00 - 03:00 3.00 CLEAN P DECOMP RIH with cleanout BHA to 8530'. PU - 180; SO - 160. 03:00 - 05:00 2.00 CLEAN P DECOMP Displace well to 10.1 ppg LSND. Pump a dry job. 05:00 - 08:30 3.50 CLEAN P DECOMP POH with cleanout BHA to 770'. 08:30 - 10:30 2.00 CLEAN P DECOMP Lay down cleanout BHA. Clear rig floor. 10:30 - 12:00 1.50 DHB P DECOMP RU SWS E -line unit. 12:00 - 16:30 4.50 EVAL P DECOMP PU & run USIT /GR /CCL log. LD tools. 16:30 - 22:30 6.00 EVAL P DECOMP PU & run 40 -arm caliper log. LD tools and download data. 22:30 - 00:00 1.50 DHB P DECOMP PJSM. PU & start running EZSV. 1/23/2009 00:00 - 03:00 3.00 DHB P DECOMP RIH with EZSV. Tie in with USIT log. Set top of EZSV at 8270', 3 feet above 9 -5/8" collar. POH. 03:00 - 04:00 1.00 DHB P DECOMP Pressure test casing to 3500 psi. Test witnessed by WSL Travis Peltier and NAD Driller Matt Turcotte. Good test. 0 psi Printed: 2/23/2009 11:09:55 AM 411, 110 BP EXPLORATION Page 2 of 11 Operations Summary Report Legal Well Name: 07 -08 Common Well Name: 07 -08 Spud Date: 12/17/1978 Event Name: REENTER +COMPLETE Start: 1/18/2009 End: 2/7/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/7/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 1/23/2009 03:00 - 04:00 1.00 DHB P DECOMP lost in 30 minutes. 04:00 - 04:30 0.50 DHB P DECOMP RD SWS. 04:30 - 09:30 5.00 WHSUR P DECOMP ND BOPE. ND wellhead at flange between casing head and tubing spool. Replace 9 -5/8" pack -off. Install new tubing spool. 09:30 - 11:30 2.00 WHSUR P DECOMP Test void to 5000 psi for 30 minutes. Good test. Install secondary annulus valve on tubing spool. 11:30 - 13:30 2.00 BOPSUF P DECOMP NU BOP stack on tubing spool. Test BOPs to 250/3500 psi as per permit. Good test. 13:30 - 15:00 1.50 STWHIP P WEXIT RU to run whipstock BHA. P/U MWD tools from Beaver Slide. 15:00 - 19:00 4.00 STWHIP P WEXIT MU whipstock BHA to 858'. 19:00 - 00:00 5.00 STWHIP P WEXIT RIH with whipstock BHA to 8270'. Orient whipstock to 85 degress left of high side. PU - 180k. SO - 155k. 480 gpm C� 2080 psi. 1/24/2009 00:00 - 00:30 0.50 STWHIP P WEXIT Slack off 20k to set anchor. PU - 192k, good set. Slack off 50k to shear whipstock mill bolt, good shear. PU - 175k. TOW - 8249'. 00:30 - 11:00 10.50 STWHIP P WEXIT Mill window from 8249' to 8266'. Continue milling open hole to 8288'. 11:00 - 11:30 0.50 STWHIP P WEXIT Circulate super sweep @ 490 gpm - 2280 psi. 11:30 - 12:30 1.00 STWHIP P WEXIT LOT to EMW 12.68 ppq @ 7665' TVD. Surface pressure - 1025 psi. Monitor well for 10 minutes. MW 10.1 ppg in and out. 12:30 - 14:00 1.50 STWHIP P WEXIT MAD Pass to 8010' @ 300 fph, logging tool at 7950' MD. Pump a dry job. 14:00 - 17:00 3.00 STWHIP P WEXIT POH from 8010' to 836'. 17:00 - 22:00 5.00 STWHIP P WEXIT LD Drill Collars and Milling Assembly. Johnny Wack BOPE. 22:00 - 00:00 2.00 STWHIP P WEXIT Function test all rams and Hydril. Begin MU 8 -1/2" drilling BHA. 1/25/2009 00:00 - 02:00 2.00 STWHIP P WEXIT Finish MU 8 -1/2" drilling BHA. Perform shallow function test. 02:00 - 05:00 3.00 STWHIP P WEXIT RIH from 719' to 4155' picking up singles. 05:00 - 07:00 2.00 STWHIP P WEXIT RIH from 4155' to 8288' 07:00 - 09:30 2.50 DRILL P INT1 Drill from 8288' to 8305'. 09:30 - 10:30 1.00 DRILL N SFAL INT1 Leaking top cover of intake pod on #2 pump. Repair same. Circulate and reciprocate on #1 pump while reparing. 07:00 - 12:00 5.00 DRILL P INT1 Drill from 8305' to 8334'. PU - 175k. SO - 150k. 524 gpm C� 2830 psi. MW - 10.1 ppg. 12:00 - 00:00 12.00 DRILL P INT1 Drill from 8334' to 9023'. PU - 180k. SO - 155k. ROT - 165. 524 gpm @ 3320 psi. MW bumped to 10.35 ppg as some splintering was seen upon entering HRZ. 1/26/2009 00:00 - 01:00 1.00 DRILL P INT1 Drill from 9023' to 9082'. PU - 180k. SO - 155k. ROT - 165k. TQ - 7k. 3350 psi @ 521 gpm. MW - 10.4 ppg. 01:00 - 02:30 1.50 DRILL P INT1 CBU and take samples. Confirm TD. Circulate surface to surface sweep. Small splinters still appearing on shaker screens. Calculated ECD - 10.82 ppg. Actual ECD - 10.93 ppg. MW - 10.4 ppg. 02:30 - 03:30 1.00 DRILL P INT1 POH to 8220'. PU - 190k. No tight spots. 03:30 - 05:00 1.50 DRILL P INT1 Slip and cut drilling line. Service top drive. 05:00 - 06:00 1.00 DRILL P INT1 RIH from 8220' to 9082'. Hole slick, no obstructions. 06:00 - 07:30 1.50 DRILL P INT1 CBU 2x's @ 521 gpm - 3100 psi. Monitor well - static. 07:30 - 11:00 3.50 DRILL P INT1 POH from 9082' to 8247' - no drag. Pump dry job and drop rabbit. POH to 4993'. 11:00 - 11:30 0.50 DRILL P INT1 Swap DP joint with washout on stand #46. Printed: 2/23/2009 11:09:55 AM BP EXPLORATION Page 3 of 11 Operations Summary Report Legal Well Name: 07 -08 Common Well Name: 07 -08 Spud Date: 12/17/1978 Event Name: REENTER +COMPLETE Start: 1/18/2009 End: 2/7/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/7/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 1/26/2009 11:30 - 14:00 2.50 DRILL P INT1 POH from 4993' to 718' wet. 14:00 - 18:00 4.00 DRILL P INT1 LD BHA. 18:00 - 21:00 3.00 BOPSUF P INT1 Change top rams from 3 -1/2" to 7 ". Test BOPS - good test. 21:00 - 21:30 0.50 CASE P LNR1 RU to run 7" liner. 21:30 - 00:00 2.50 CASE P LNR1 Run 7" liner to 723' filling every 10 joints. MU torque - 7800 ft-Ibs. 1/27/2009 00:00 - 02:00 2.00 CASE P LNR1 RIH from 723' to top of C -2 running tool at 998'. Install HT -40 Box x 4.5" IF pin. PU & SO - 50k with blocks. 02:00 - 07:30 5.50 CASE P LNR1 RIH 2 single joints of DP and one full stand. Circulate 50 bbls. RIH on DP from 998' to 9082' filling every 20 joints. Once on bottom stage up the pumps to 5 bbls /min. 07:30 - 08:30 1.00 CEMT P LNR1 Circulate 230 bbls @ 250 GPM, 800 PSI 08:30 - 12:00 3.50 CEMT P LNR1 7" liner primary cement lob - Pump 5 bbls 11.5ppg mudpush @ 4 -6 bbls /min - PT lines to 4500 PSI - Pump remaining 15 bbls 11.5ppg mudpush @ 4 -6 bbls /min - Drop bottom plug and then pump 44 bbls of Batch Mixed 15.8ppg Class G tail cement @ 6 bbl /min - Drop top plug Kick out w/ 5 bbls water from SWS. - Switch to rig and displace. Bumped on schedule at 1830 stks - Pressured up to 3000 PSI, slacked off 70K and set hanger - Bled off pressure - Pressured up to 4200 PSI to release running tool - Checked floats. Checked good. - Picked up 6' to expose dogs and set down 50K to set packer - Unstung from liner top 12:00 - 13:00 1.00 CEMT P LNR1 CBU @ 500 GPM, 2840 PSI - Received approximately 16 bbls of cement back to surface 13:00 - 14:30 1.50 CEMT P LNR1 LD cement head and pumped dry job 14:30 - 18:00 3.50 CEMT P LNR1 POH from 7973' and LD liner running tool 18:00 - 18:30 0.50 BOPSUF P LNR1 Remove wear bushing, pull wear ring, and set test plug 18:30 - 19:30 1.00 BOPSUF P LNR1 Change rams from 7" to 3 1/2 "X6" 19:30 - 21:00 1.50 BOPSUF P LNR1 - Installed test plug - Test BOP top rams with 4" and 4 1/2" test joint to 250 PSI low and 3500 PSI high; install wear ring 31 03 21:00 - 22:00 1.00 CASE P LNR1 7" liner lap and & 7 %fpggyefpressure tested to 3500 PSI for 30 min; pressure tested good 22:00 - 00:00 2.00 DRILL P PROD1 PU and MU 6 1/8" BHA 1/28/2009 00:00 - 03:30 3.50 DRILL P PROD1 PU /MU 6 1/8" BHA - RIH to 401' - Shallow pulse test MWD @ 245 GPM, 1230 PSI; test good - Upload radioactive sources 03:30 - 05:15 1.75 DRILL P PROD1 RIH from 401' to 3250' 05:15 - 06:00 0.75 DRILL P PROD1 Perform Stripping Drill with Nix's Crew. 06:00 - 10:30 4.50 DRILL P PROD1 RIH from 3250' to 8676' 10:30 - 12:00 1.50 DRILL P PROD1 Washed down from 8676' to 8996', where we tagged cement 12:00 - 14:30 2.50 DRILL P PROD1 Drilled up plugs and cement, landing collar, and float collar from 8996' to 9075' - 250 GPM, 2170 PSI - Up wt 160K, Down wt 140K, Rot wt 155K - RPM 80 - TQ 5 -6K Printed: 2/23/2009 11:09:55 AM • • BP EXPLORATION Page 4 of 11 Operations Summary Report Legal Well Name: 07 -08 Common Well Name: 07 -08 Spud Date: 12/17/1978 Event Name: REENTER +COMPLETE Start: 1/18/2009 End: 2/7/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/7/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 1/28/2009 14:30 - 16:30 2.00 DRILL P PROD1 CBU and displace mud from 10.4ppg LSND to 8.4ppg Flo -pro - 280 GPM - 2310 PSI - Pumped 45 bbl steel lube sweep 16:30 - 17:00 0.50 DRILL P PROD1 Drilled out remaining cement, shoe, and 20' of new formation from 9075' to 9102' - Up wt 160K, Down wt 140K, Rot wt 160K - RPM 80 - TQ 2 -3K - 300 GPM, 1940 PSI off, 2090 PSI on 17:00 - 18:00 1.00 DRILL P PROD1 CBU - 300 GPM - 1950 PSI 18:00 - 19:00 1.00 DRILL P PROD1 FIT - 920 PSI _ - 10.5 EMW; test aood 19:00 - 00:00 5.00 DRILL P PROD1 Drilled ahead from 9102' to 9420' - 8722' TVD - Up wt 170K, Down wt 150K, Rot wt 160K - 270 GPM, 1650 PSI off, 1950 PSI on - RPM 90 - TQ 3 -4K - ART 1.28, AST 1.8 - MW 8.4ppg in and out 1/29/2009 00:00 - 01:00 1.00 DRILL P PROD1 Drill ahead from 9420' to 9451' - 8747' TVD - Having issues building angle - Decision made to POH and change bend of motor, - Up wt 175K, Down wt 150K, Rot wt 160K - 80 RPM - TQ 5K off, 4K on - WOB 15K 01:00 - 02:00 1.00 DRILL P PROD1 Circulate - 500 bbls @ 300 GPM, 1950 PSI - Rotated @ 80 RPM 02:00 - 02:30 0.50 DRILL P PROD1 POH from 9451' to 9048' - Up wt 180K, Down wt 145K 02:30 - 03:30 1.00 DRILL P PROD1 Circulate and condition - Drop ball and shear circ. sub. - Pump dry job 03:30 - 06:30 3.00 DRILL P PROD1 POH from 9048' to 401' 06:30 - 09:30 3.00 DRILL P PROD1 LD BHA from 401' - Remove radioactive sources 09:30 - 12:00 2.50 DRILL P PROD1 PU BHA - Adjusted motor from 1.5 to 2.23 degree bend - Adjusted 5 7/8" kick pad 12:00 - 16:00 4.00 DRILL P PROD1 PU BHA - MU bit, shallow test MWD - Load radioactive sources - Swap -out CCV 16:00 - 16:30 0.50 DRILL P PROD1 Service top drive and crown 16:30 - 17:00 0.50 DRILL P PROD1 RIH to 401' w /HWDP 17:00 - 23:30 6.50 DRILL P PROD1 RIH from 401' to 9451' Printed: 2/23/2009 11:09:55 AM • BP EXPLORATION Page 5 of 11 Operations Summary Report Legal Well Name: 07 -08 Common Well Name: 07 -08 Spud Date: 12/17/1978 Event Name: REENTER +COMPLETE Start: 1/18/2009 End: 2/7/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/7/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 1/29/2009 17:00 - 23:30 6.50 DRILL P PROD1 - Had issues while exiting the shoe; BHA hanging up on ledge - After pumping @ 100 GPM and oscillating the drill string, we were able to enter open hole - Wiped 3 times and saw no more drag - No losses on trip in 23:30 - 00:00 0.50 DRILL P PROD1 - Drilled ahead from 9451' to 9487' - 8769' TVD - Up wt 170K, Down wt 155K - 247 GPM, 1500/1600 PSI - AST .36 - MW 8.4ppg in and out 1/30/2009 00:00 - 12:00 12.00 DRILL P PROD1 Drilled ahead from 9487' to 9793' - 8962 TVD - AST7.67 - WOB 25K - Circulated @ 274 GPM w/1670 on, 1900 off PSI - Total losses for tour = 71 bbls 12:00 - 17:30 5.50 DRILL P PROD1 Drilled ahead from 9793' to 9980' - 9010' TVD - Up wt 180K, Down wt 145K - AST 2.98 - WOB 20K - Circulated @ 279 GPM w/1800 on, 2050 off PSI - MW 8.4ppg in and out 17:30 - 19:30 2.00 DRILL P PROD1 Circulate and condition - 553 bbls @ 300 GPM and 2100 PSI - MW 8.4ppg - Experienced loss rate of 24 bbls /hr 19:30 - 20:30 1.00 DRILL P PROD1 POH from 9980' to 9420' - Up wt 190K, Down wt 155K 20:30 - 22:00 1.50 DRILL P PROD1 Circulate and condition due to lost circulation - Opened CCV & isolated BHA - Spotted 40 Bbls @ 45 Ibs /bbl LCM pill @ 250 GPM and 550 PSI 22:00 - 23:00 1.00 DRILL P PROD1 POH from 9420' to 8118' - Pumped dry job and removed blower hose 23:00 - 00:00 1.00 DRILL P PROD1 POH from 8118' to 5979' 1/31/2009 00:00 - 03:00 3.00 DRILL P PROD1 POH from 5979' to 401' - Drop ball to close CCV - Pump down ball @ 2 bbls /min and pressure up to 1000 PSI - Hold 1000 PSI for 1 min and then pressure up to 1250 PSI, where pressure change is noticed, indicating CCV closure 03:00 - 06:00 3.00 DRILL P PROD1 LD BHA from 401' to rig floor - Downloaded MWD recorder - Dull grade of Smith XR2OTD -- 2- 4- LT- A- E -2 -BT -BHA 06:00 - 15:30 9.50 BOPSUF P PROD1 Test BOPE to 250 PSI low, 3500 PSI high and Hydril to 250 PSI low, 2500 PSI high as per AOGCC. Test witness waived by Bob Noble with AOGCC. Test witnessed by WSLs Bill Decker, Matt Martyn, and Ray Platt and Toolpusher Jon Castle. Tested upper and lower rams with 4.5" test joint. Tested upper rams with 4" test joint. Tested lower rams and Hydril with 2 7/8" test joint. All tests were charted for 5 minutes and were passing tests. Printed: 2/23/2009 11:09:55 AM • • BP EXPLORATION Page 6 of 11 Operations Summary Report Legal Well Name: 07 -08 Common Well Name: 07 -08 Spud Date: 12/17/1978 Event Name: REENTER +COMPLETE Start: 1/18/2009 End: 2/7/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/7/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 1/31/2009 15:30 - 16:30 1.00 DRILL P PROD1 PU BHA - Changed bit to PDC - Adjusted motor from 2.23 to 1.5 degree bend 16:30 - 19:30 3.00 DRILL P PROD1 PU BHA and shallow test MWD © 211 GPM and 540 PSI - Upload radioactive sources after MWD shallow test 19:30 - 23:30 4.00 DRILL P PROD1 RIH from 401' to 9048' - Test MWD every 3000' 23:30 - 00:00 0.50 DRILL P PROD1 Service rig - Top drive and drawworks 2/1/2009 00:00 - 03:00 3.00 DRILL P PROD1 Slip and cut drilling line - 96' slipped and cut - Drawworks inspected and serviced 03:00 - 04:30 1.50 DRILL P PROD1 RIH from 9048' to 9980' - Hit obstruction at 9780' - Washed down to bottom © 218 GPM, 1301 PSI - Up wt 190K, Down wt 150K - Pumped MWD survey 04:30 - 05:30 1.00 DRILL P PROD1 Took MWD rotational check shots - Took 4 shots @9986' 05:30 - 11:00 5.50 DRILL P PROD1 Slid from 9979' to 10095' - 257 GPM; 1499 off, 1690 on PSI - 10 -12K WOB - Up wt 180K, Down wt 148K - MW 8.5ppg in and out - AST 2.18 - 118 bbls losses this tour 11:00 - 12:00 1.00 DRILL P PROD1 Circulate and condition per geology - Looking for HOT samples, - 257 GPM, 1544 PSI 12:00 - 15:00 3.00 DRILL P PROD1 Slid from 10095' to 10165' - 257 GPM; 1499 off, 1690 on PSI - 10 -12K WOB - Up wt 180K, Down wt 148K - MW 8.5ppg in and out 15:00 - 17:30 2.50 DRILL P PROD1 Circulate and condition per geology - Looking for HOT samples - 274 GPM, 1600 PSI 17:30 - 00:00 6.50 DRILL P PROD1 Directionally drilled from 10165' to 10536' - 9024' TVD - 272 GPM; 1712 off, 2050 on PSI - 10KWOB - 90 RPM - TQ 5 -6K off, 6 -7K on - Up wt 175K, Down wt 143K, Rot wt 162K - MW 8.5ppg in and out - AST 2.18, ART 2.81 - 236 bbls losses this tour 2/2/2009 00:00 - 08:00 8.00 DRILL P PROD1 Directionally drilled from 10536' to 11221' - 274 GPM, 1780 off, 2150 on PSI - 2 -10K WOB - 90 RPM - TQ 4 -5K off, 5 -6K on - Up wt 180K, Down wt 145K, Rot wt 160K Printed: 2/23/2009 11:09:55 AM • • BP EXPLORATION Page 7 of 11 Operations Summary Report Legal Well Name: 07 -08 Common Well Name: 07 -08 Spud Date: 12/17/1978 Event Name: REENTER +COMPLETE Start: 1/18/2009 End: 2/7/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/7/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 2/2/2009 00:00 - 08:00 8.00 DRILL P PROD1 - MW 8.6ppg in and out 08:00 - 08:30 0.50 DRILL P PROD1 Circulated waiting on the town engineer and geologist to decide about whether or not to drill ahead 08:30 - 10:30 2.00 DRILL P PROD1 Directionally drilled from 11221' to TD @ 11321' - Received permission from town engineer and geologist to drill ahead from original proposed TD of 11221' to 11321' so that all of the good oav could be perforated - 274 GPM, 1780 off, 2150 on PSI - 2 -10K WOB - 90 RPM - TQ 4 -5K off, 5 -6K on - Up wt 180K, Down wt 145K, Rot wt 160K - 9027' TVD - AST 1.84, ART 4.45 this tour - Mud losses of 401 bbls this tour - MW 8.6 +ppg in and out 10:30 - 11:30 1.00 DRILL P PROD1 Circulated and conditioned hole - 323 GPM, 2293 PSI - 100 RPM - TQ 6K - Rotated and reciprocated pipe 11:30 - 13:30 2.00 DRILL P PROD1 Pumped out from 11321' to 10259' - Circulated @ 274 GPM, 1650 PSI - Up wt 175K, Down wt 150K - MW 8.6+ ppg in and out 13:30 - 14:00 0.50 DRILL N RREP PROD1 LD bad joint of drill pipe due to galled threads 14:00 - 16:30 2.50 DRILL P PROD1 Pumped out from 10259' to 9018' (right above 7" shoe @ 9082') - Circulated @ 274 GPM, 1650 PSI - Up wt 175K, Down wt 150K - MW 8.6+ ppg in and out 16:30 - 18:30 2.00 DRILL P PROD1 Circulate and condition - Dropped ball and opened CCV - CBU @ 500 GPM, 1450 PSI - Dropped ball and closed CCV 18:30 - 20:00 1.50 DRILL P PROD1 RIH from 9018' to 11321' 20:00 - 23:30 3.50 DRILL P PROD1 Circulate and condition - Circulated 42 bbl, 10.6ppg weighted mud sweep - 279 GPM, 1800 PSI - Circulated until the returns across the shakers cleaned up - Spotted 52 bbl, 4% lube liner running pill 23:30 - 00:00 0.50 DRILL P PROD1 POH from 11321' to 10909' - Up wt 180K, Down wt 145K - MW 8.6ppg in and out - Slick clean hole, no drag 2/3/2009 00:00 - 01:30 1.50 DRILL P PROD1 POH from 10909' to 9048' - Up Wt 180K / Down Wt 145K - No drag on the way out of the hole - Dropped the ball to open the CCV 01:30 - 02:00 0.50 DRILL P PROD1 Screwed into the top drive and pumped down the CCV opening ball - 2bpm @ 478 psi - Saw positive indication of CCV opening, 532 stks /1980 psi Printed: 2/23/2009 11:09:55 AM . . BP EXPLORATION Page 8 of 11 Operations Summary Report Legal Well Name: 07 -08 Common Well Name: 07 -08 Spud Date: 12/17/1978 Event Name: REENTER +COMPLETE Start: 1/18/2009 End: 2/7/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/7/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 2/3/2009 01:30 - 02:00 0.50 DRILL P PROD1 - Establish circulation @ 6 bpm and pump a dry job - Install the air slips and prepare to POH 02:00 - 06:00 4.00 DRILL P PROD1 POH from 9048' to 401' - LD BHA 06:00 - 07:00 1.00 DRILL P PROD1 LD BHA - Download radioactive sources 07:00 - 08:00 1.00 DRILL P PROD1 Download MWD recorder 08:00 - 08:30 0.50 DRILL P PROD1 Finish LD BHA to bit - Clean and clear the floor for casing run 08:30 - 09:00 0.50 CASE P RUNPRD Casing PJSM 09:00 - 10:00 1.00 CASE P RUNPRD RU to run casing 10:00 - 11:00 1.00 CASE P RUNPRD MU shoe track - Baker -Loc each connection - Check floats; checked good 11:00 - 12:00 1.00 CASE P RUNPRD RIH w/4 1/2" casing to 612' - MU TQ 3500 ft Ibs - Fill every 20 stands - MW 8 . 6 ppg - Losses of 110 bbls this tour 12:00 - 15:00 3.00 CASE P RUNPRD RIH w/4 1/2" casing from 612' to 2361' - MU TQ 3500 ft Ibs - Fill every 20 stands - MW 8 . 6 ppg - Liner wt 55K 15:00 - 16:00 1.00 CASE P RUNPRD MU LRT packer and hanger - Pour pal -mix in LRT and let set up for 30 min - PU LRT and 2 joints of DP and RIH to 2469' 16:00 - 16:30 0.50 CASE P RUNPRD Circulate and condition - 1 1/2 liner volume @ 211 GPM and 160 PSI 16:30 - 20:30 4.00 CASE P RUNPRD RIH w/4 1/2" casing from 2469' to 9070' - Fill every 20 stands 20:30 - 22:00 1.50 CASE P RUNPRD Circulate and condition - Circulate annular volume of 483 bbls - 294 GPM, 700 PSI 22:00 - 23:00 1.00 CASE P RUNPRD RIH w/4 1/2" casing from 9070' to 11302' 23:00 - 23:30 0.50 CASE P RUNPRD Install cement lines - MU TD head and hoses and PU single joint of DP 23:30 - 00:00 0.50 CEMT P RUNPRD Circulate and condition - 1 BPM, 350 PSI and tag bottom @ 11321' - Stage up pumps to 3 BPM, 650 PSI - Up wt 175K, Down wt 145K 2/4/2009 00:00 - 02:30 2.50 CEMT P RUNPRD Circulate and condition - Stage up pumps to 5 BPM, 897 PSI - Up wt 170K, Down wt 145K - Reciprocate pipe from 11310' to 11320' 02:30 - 05:00 2.50 CEMT P RUNPRD Production liner cement job - Pump 5 bbls 11.2ppg MudPush II - Pressure tested lines to 4500 PSI; tested good - Pumped 70 bbls /340 sks 15.8ppg GASBLOK tail at 5 BPM - Kick out DP wiper dart w/45 bbl pert pill - Displaced w /rig pumps - Dart latched at 1565 strokes (91.1 bbls) - Took 2600 PSI to unlatch liner wiper plug; due to this, hanger Printed: 2/23/2009 11:09:55 AM • BP EXPLORATION Page 9 of 11 Operations Summary Report Legal Well Name: 07 -08 Common Well Name: 07 -08 Spud Date: 12/17/1978 Event Name: REENTER +COMPLETE Start: 1/18/2009 End: 2/7/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/7/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 2/4/2009 02:30 - 05:00 2.50 CEMT P RUNPRD set - Bumped plug at 2174 strokes (126.5 bbls) - Pressured up to 2800 PSI to verify hanger is set - Slacked off 40K - Pressured up to 4200 PSI to release HR running tool - Bled pressure to 0 PSI to check floats; floats held - Pressured up to 700 PSI and slacked off 50K to set packer - Pulled up above liner top packer and circulated out excess cement - Received 20 bbls of cement to surface - Cement in place at 0312 05:00 - 06:30 1.50 CEMT P RUNPRD Displaced well to 8.5ppg seawater and prepared to POH - 446 GPM, 1712 PSI 06:30 - 10:00 3.50 CEMT P RUNPRD POH from 8876' to LRT 10:00 - 11:00 1.00 CEMT P RUNPRD LD Baker LRT 11:00 - 12:00 1.00 PERFOB P OTHCMP PU Schlumberger perforation equipment 12:00 - 13:00 1.00 PERFOB P OTHCMP RU to run Schlumberger perforating equipment - PJSM 13:00 - 15:00 2.00 PERFOB P OTHCMP RIH perforating guns to 1051' - MU firing head 15:00 - 18:00 3.00 PERFOB P OTHCMP RIH w/2 7/8" PAC from 1051' to 2430' - TO 3500 ft Ibs - BHA up and down wt 50K 18:00 - 22:00 4.00 PERFOB P OTHCMP RIH from 2430' to 11233' on 4" DP - Tag plugs @ 11233' - POH from 11233' to 11220' to get perforation guns on depth for shot - Up wt 170K, Down wt 145K 22:00 - 22:30 0.50 PERFOB P OTHCMP MU circulation line and head pin on stump to pressure test casing to 3500 PSI for 30 minutes 22:30 - 00:00 1.50 PERFOB P OTHCMP Pressure test 4 1/2" casino to 3500 PSI - Pressure tested good for 30 minutes at 3500 PSI. No drop in pressure. 2/5/2009 00:00 - 00:30 0.50 PERFOB P OTHCMP PJSM for perforation shot 00:30 - 01:00 0.50 PERFOB P OTHCMP Perforated 4 1/2" liner from 10200' to 10400' and 10500' to 11220' MD per revised well plan, - Pressured up to 400 PSI and held for 1 minute and immediately bled back down to 50 PSI per Schlumberger gun reps - Pressured up to 600 PSI and held for 1 minute and immediately bled back down to 50 PSI per Schlumberger gun reps - Pressured up to 1200 PSI and held for 2 minutes per Schlumberger gun reps - Immediately bled off pressure to 50 PSI and waited 5 minutes for detonation per Schlumberger gun reps - Saw top drive and entire rig move and felt extremely noticeable rumble at almost exactly the 5- minute mark, which indicated successful 9 un firing - Confirmed gun firing on Schlumberger seismograph - Initial fluid drop was 2 bbls 01:00 - 01:30 0.50 PERFOB P OTHCMP POH w /4" DP and 2 7/8" PAC and perforation guns from 11220' to 10085'; monitor hole Printed: 2/23/2009 11:09:55 AM • • BP EXPLORATION Page 10 of 11 Operations Summary Report Legal Well Name: 07 -08 Common Well Name: 07 -08 Spud Date: 12/17/1978 Event Name: REENTER +COMPLETE Start: 1/18/2009 End: 2/7/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/7/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 2/5/2009 01:00 - 01:30 0.50 PERFOB P OTHCMP - 36 bbls /hr static loss 01:30 - 07:00 5.50 PERFOB P OTHCMP POH and LD 4" DP from 10085' to 3700' 07:00 - 09:00 2.00 PERFOB P OTHCMP RIH w /remaining stands from the derrick to 7300' 09:00 - 13:30 4.50 PERFOB P OTHCMP POH and LD 4" DP from 7300' to 4321' 13:30 - 15:00 1.50 PERFOB P OTHCMP Slip and cut 95' of drilling line 15:00 - 15:30 0.50 PERFOB P OTHCMP Service top drive 15:30 - 17:00 1.50 PERFOB P OTHCMP POH and LD 4" DP from 4321' to 2430' 17:00 - 19:00 2.00 PERFOB P OTHCMP RU 2 7/8" handling equipment and POH and LD 2 7/8" PAC from 2430' to 1051' 19:00 - 00:00 5.00 PERFOB P OTHCMP RU perforating handling equipment and LD perforating guns from 1051' to the rig floor - Clean and clear rig floor -All shots fired 2/6/2009 00:00 - 02:30 2.50 RIGU P RUNCMP Rigging up to run 4.5" completion. - Organize jewelry in the shed and rig up double -stack tongs, compensator, etc. 02:30 - 18:30 16.00 RUNCOMP RUNCMP Run in hole with 4.5" 12.6# 13CR -80 Vam Ton completion to 8930'. Tagged on jt. 207, so we laid down jt. 207 and 206. Picked up 2 pups 5.77" and 9.68" and then picked up jt. 206, m/u hanger and landing jt. Then landed the tubing and ran in the Iockdown screws. WLEG 3' from being fully inserted. - Average make -up of 4,470ft/Ibs. Completion consists of: -WLEG -XN Nipple -(3) X Nipples -S -3 Packer -2 GLM's - 1 with dummy valve, 1 with DCR Shear Valve -(206) Jts. of 4.5" 12.6# 13Cr -80 Vam Top - Cameron 13 5/8" x 4.5" Tubing Hanger 18:30 - 22:30 4.00 RUNCOMP RUNCMP Circulate and condition - RU to reverse circulate 136 bbls clean seawater, 255 bbls of seawater with corrosion inhibitor, and 191 bbls of seawater to position inhibitor between GLM # 2 and the production packer - Max pump rate 122 GPM, 160 PSI 22:30 - 23:00 0.50 RUNCOMP RUNCMP Drop 1 7/8" ball and rod and let fall 30 mins - LD landing joint 23:00 - 00:00 1.00 RUNCOMP RUNCMP Pressure up to 3500 PSI for 10 minutes to set packer; hold for 30 minutes for tubing test; tested good - Bled pressure down to 1500 PSI - Pressured IA to 3500 PSI and held for 30 minutes; tested good - Bled IA and then tubing to 0 PSI - Pressured up IA to shear the DCR valve in GLM # 2 - DCR valve sheared right at 2500 PSI - Pumped each way through the sheared GLM to ensure the ability to pump and U -tube diesel freeze protect 2/7/2009 00:00 - 01:00 1.00 RUNCOMP RUNCMP Install TWC - Pressure test to 1000 PSI from above and below for 10 minutes; tested good 01:00 - 12:00 11.00 BOPSUF P RUNCMP ND BOPE and N/U the adaptor flange and tree. Test the adaptor flange, tree, and pack -off to 5000psi. Rig Up DSM lubricator and pull the TWC. Printed: 2/23/2009 11:09:55 AM • • • BP EXPLORATION Page 11 of 11 Operations Summary Report Legal Well Name: 07 -08 Common Well Name: 07 -08 Spud Date: 12/17/1978 Event Name: REENTER +COMPLETE Start: 1/18/2009 End: 2/7/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/7/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 2/7/2009 12:00 - 18:00 6.00 WHSUR P RUNCMP RIg up Little Red Services and reverse circulate 152 bbls of diesel for freeze protection to approx. 2200'. Allow diesel to U -tube from annulus to the tubing. Install the BPV and test from below to 1000psi. Good test. Secure the well with flanges, bull plugs with needle valves and pressure gauges. 18:00 - 19:00 1.00 WHSUR P RUNCMP Prepare to move to B -10A. Rig released @ 19:00 Printed: 2/23/2009 11:09:55 AM • • North America - ALASKA - BP Prudhoe Bay PB DS 07 07 -08 07 -08B Design: 07 -08B Survey Report - Geographic 11 March, 2009 c)7 - • BP Exploration Alaska • Survey Report - Geographic Company: North America - ALASKA - BP Local CO-ordinate Reference: Well 07 -08 Project: Prudhoe Bay TVD Reference: 26.8GL +28.5 @ 55.30ft (26.8GL +28.5) Site: PB DS 07 MD Reference: 26.8GL +28.5 @ 55.30ft (26.8GL +28.5) Well: 07 -08 North Reference: True Weltbore: 07 -08B Survey Calculation Method: Minimum Curvature Design: 07 -08B Database: EDM .16 - Anc Prod - WH24P Project Prudhoe Bay, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 07, TR -11 -14 Site Position: Northing: 5,948,144.78ft Latitude: 70° 15' 49.847 N From: Map Easting: 677,382.28ft Longitude: 148° 33' 56.934 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 1.35 ° I Well 07 -08, 5002920296 Well Position +N / -S 0.00 ft Northing: 5,949,705.67ft Latitude: 70° 16' 5.506 N +E / -W 0.00 ft Easting: 676,035.82 ft Longitude: 148° 34' 35.047 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 07 -08B Magnetics Model Name Satriple Date Declinatitrn Dip Angie Field Strength (°) (1 (nT) BGGM2008 1/28/2009 22.90 80.91 57,699 Design 07 -08B Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,241.30 Vertical Section: Depth From (TVD) +N!-S 44. Direction (ft) (ft) (ft) r) 28.30 0.00 0.00 190.00 Survey Program Date 2117/2009 From To (ft) (ft) Survey (Weiibore) Tool Name Description 91.30 8,241.30 2 : Gyrodata cont.drillpipe m/ (07 -08) GYD- CT -DMS Gyrodata cont.drillpipe m/s 8,260.00 11,278.23 07 -08B MWD +SAG +IIFR +MS (07 -08B) MWD +IFR +MS MWD + IFR + Multi Station 3/11/2009 1 :56 :20PM Page 2 COMPASS 2003.16 Build 70 I • BP Exploration Alaska • Survey Report - Geographic Company: North America - ALASKA - BP Local Co- ordinate ltelterence: Well 07 -08 Project: Prudhoe Bay TVD Reference: 26.8GL +28.5 @ 55.30ft (26.8GL +28.5) Site: PB DS 07 MD Reference: 26.8GL +28.5 @ 55.30ft (26.8GL +28.5) Wets: 07 -08 North Reference: True Welibore: 07 -08B Surrey Calculation Method: Minimum Curvature Design: 07 -08B Database: EDM .16 - Anc Prod - WH24P Survey Measured Vertical Map Map Depth inclination Azimuth Depth +N /-S +E/-W Northing Easting (ft) { °) {°) {ft) (ft) (ft) (ft) (ft) Latitude Longitude 28.30 0.00 0.00 28.30 0.00 0.00 5,949,705.67 676,035.82 70° 16' 5.506 N 148° 34' 35.047 W 91.30 0.16 269.21 91.30 0.00 -0.09 5,949,705.67 676,035.73 70° 16' 5.506 N 148° 34' 35.050 W 191.30 0.11 226.18 191.30 -0.07 -0.30 5,949,705.59 676,035.52 70° 16' 5.505 N 148° 34' 35.056 W 291.30 0.16 233.35 291.30 -0.22 -0.48 5,949,705.44 676,035.35 70° 16' 5.503 N 148° 34' 35.061 W 391.30 0.08 196.38 391.30 -0.37 -0.61 5,949,705.29 676,035.22 70° 16' 5.502 N 148° 34' 35.065 W 492.30 0.12 207.43 492.30 -0.53 -0.68 5,949,705.12 676,035.15 70° 16' 5.500 N 148° 34' 35.067 W 591.30 0.06 182.68 591.30 -0.68 -0.73 5,949,704.98 676,035.11 70° 16' 5.499 N 148° 34' 35.069 W 692.30 0.09 168.93 692.30 -0.81 -0.72 5,949,704.85 676,035.12 70° 16' 5.498 N 148° 34' 35.068 W 791.30 0.05 319.65 791.30 -0.85 -0.73 5,949,704.80 676,035.11 70° 16' 5.497 N 148° 34' 35.069 W 891.30 0.14 56.93 891.30 -0.75 -0.65 5,949,704.91 676,035.18 70° 16' 5.498 N 148° 34' 35.066 W 991.30 0.15 31.71 991.30 -0.57 -0.48 5,949,705.09 676,035.35 70° 16' 5.500 N 148° 34' 35.061 W 1,091.30 0.14 121.66 1,091.30 -0.52 -0.31 5,949,705.14 676,035.52 70° 16' 5.500 N 148° 34' 35.056 W 1,191.30 0.25 138.08 1,191.30 -0.75 -0.06 5,949,704.92 676,035.78 70° 16' 5.498 N 148° 34' 35.049 W 1,291.30 0.36 168.80 1,291.30 -1.22 0.15 5,949,704.45 676,035.99 70° 16' 5.494 N 148° 34' 35.043 W 1,391.30 0.37 166.58 1,391.29 -1.84 0.28 5,949,703.83 676,036.14 70° 16' 5.487 N 148° 34' 35.039 W 1,491.30 0.56 166.38 1,491.29 -2.63 0.47 5,949,703.05 676,036.35 70° 16' 5.480 N 148° 34' 35.034 W 1,591.30 0.71 157.48 1,591.28 -3.68 0.82 5,949,702.01 676,036.73 70° 16' 5.469 N 148° 34' 35.023 W 1,691.30 0.69 155.52 1,691.28 -4.80 1.31 5,949,700.90 676,037.24 70° 16' 5.458 N 148° 34' 35.009 W 1,791.30 0.71 161.14 1,791.27 -5.93 1.76 5,949,699.78 676,037.72 70° 16' 5.447 N 148° 34' 34.996 W 1,891.30 0.62 146.23 1,891.26 -6.97 2.26 5,949,698.75 676,038.24 70° 16' 5.437 N 148° 34' 34.982 W 1,991.30 0.33 138.34 1,991.26 -7.64 2.75 5,949,698.10 676,038.75 70° 16' 5.430 N 148° 34' 34.967 W 2,091.30 0.22 169.84 2,091.26 -8.04 2.98 5,949,697.70 676,038.99 70° 16' 5.426 N 148° 34' 34.961 W 2,191.30 0.22 140.74 2,191.26 -8.38 3.13 5,949,697.37 676,039.15 70° 16' 5.423 N 148° 34' 34.956 W 2,291.30 0.48 126.07 2,291.26 -8.77 3.59 5,949,696.98 676,039.62 70° 16' 5.419 N 148° 34' 34.943 W 2,391.30 0.46 128.00 2,391.25 -9.27 4.25 5,949,696.51 676,040.28 70° 16' 5.414 N 148° 34' 34.924 W 2,491.30 0.64 115.20 2,491.25 -9.75 5.07 5,949,696.04 676,041.12 70° 16' 5.410 N 148° 34' 34.900 W 2,591.30 0.69 110.12 2,591.24 -10.20 6.14 5,949,695.62 676,042.20 70° 16' 5.405 N 148° 34' 34.869 W 2,691.30 0.84 111.50 2,691.23 -10.67 7.39 5,949,695.17 676,043.46 70° 16' 5.401 N 148° 34' 34.832 W 2,791.30 0.76 84.15 2,791.22 -10.87 8.73 5,949,695.00 676,044.80 70° 16' 5.399 N 148° 34' 34.793 W 2,891.30 0.82 80.76 2,891.21 -10.69 10.10 5,949,695.22 676,046.16 70° 16' 5.400 N 148° 34' 34.754 W 2,991.30 0.84 76.39 2,991.20 -10.40 11.52 5,949,695.54 676,047.57 70° 16' 5.403 N 148° 34' 34.712 W 3,091.30 0.81 77.27 3,091.19 -10.07 12.92 5,949,695.90 676,048.97 70° 16' 5.406 N 148° 34' 34.671 W 3,191.30 0.86 68.88 3,191.18 -9.65 14.31 5,949,696.36 676,050.35 70° 16' 5.411 N 148° 34' 34.631 W 3,291.30 0.64 66.24 3,291.17 -9.15 15.52 5,949,696.88 676,051.55 70° 16' 5.416 N 148° 34' 34.596 W 3,391.30 0.57 54.98 3,391.17 -8.64 16.44 5,949,697.41 676,052.45 70° 16' 5.421 N 148° 34' 34.569 W 3,491.30 0.73 63.22 3,491.16 -8.07 17.41 5,949,698.01 676,053.42 70° 16' 5.426 N 148° 34' 34.541 W 3,591.30 0.68 60.35 3,591.15 -7.49 18.50 5,949,698.62 676,054.49 70° 16' 5.432 N 148° 34' 34.509 W 3,691.30 0.74 56.70 3,691.15 -6.84 19.55 5,949,699.29 676,055.53 70° 16' 5.438 N 148° 34' 34.478 W 3,791.30 0.50 50.89 3,791.14 -6.21 20.43 5,949,699.94 676,056.39 70° 16' 5.444 N 148° 34' 34.453 W 3,891.30 0.69 58.01 3,891.13 -5.62 21.28 5,949,700.55 676,057.22 70° 16' 5.450 N 148° 34' 34.428 W I 3,991.30 2.64 16.93 3,991.09 -3.09 22.46 5,949,703.10 676,058.35 70° 16' 5.475 N 148° 34' 34.394 W 4,040.30 5.83 6.64 4,039.95 0.46 23.08 5,949,706.67 676,058.88 70° 16' 5.510 N 148° 34' 34.376 W 4,091.30 7.98 4.52 4,090.58 6.56 23.66 5,949,712.78 676,059.31 70° 16' 5.570 N 148° 34' 34.359 W 4,141.30 10.71 5.93 4,139.91 14.64 24.41 5,949,720.88 676,059.88 70° 16' 5.650 N 148° 34' 34.337 W 4,191.30 13.06 6.21 4,188.83 24.88 25.50 5,949,731.14 676,060.73 70° 16' 5.750 N 148° 34' 34.305 W 4,241.30 16.42 6.90 4,237.18 37.52 26.96 5,949,743.80 676,061.90 70° 16' 5.875 N 148° 34' 34.263 W 4,291.30 18.71 7.54 4,284.85 52.48 28.86 5,949,758.81 676,063.45 70° 16' 6.022 N 148° 34' 34.207 W 4,341.30 20.18 7.88 4,331.99 68.98 31.10 5,949,775.35 676,065.29 70° 16' 6.184 N 148° 34' 34.142 W 4,391.30 21.39 8.33 4,378.74 86.54 33.60 5,949,792.97 676,067.39 70° 16' 6.357 N 148° 34' 34.069 W 4,441.30 22.42 8.75 4,425.13 104.99 36.37 5,949,811.47 676,069.73 70° 16' 6.538 N 148° 34' 33.989 W 4,491.30 23.62 9.46 4,471.15 124.30 39.47 5,949,830.85 676,072.37 70° 16' 6.728 N 148° 34' 33.899 W 4,541.30 24.51 10.00 4,516.80 144.39 42.92 5,949,851.01 676,075.35 70° 16' 6.926 N 148° 34' 33.798 W 4,591.30 25.54 11.44 4,562.11 165.17 46.86 5,949,871.88 676,078.80 70° 16' 7.130 N 148° 34' 33.683 W 4,641.30 26.61 12.67 4,607.02 186.66 51.45 5,949,893.47 676,082.89 70° 16' 7.341 N 148° 34' 33.550 W 4,691.30 27.20 12.91 4,651.60 208.72 56.46 5,949,915.64 676,087.38 70° 16' 7.558 N 148° 34' 33.404 W 3/11/2009 1 :56 :20PM Page 3 COMPASS 2003.16 Build 70 • BP Exploration Alaska • Survey Report - Geographic Company; North America - ALASKA - BP Local Co- ordinate Reference: Well 07 -08 Project: Prudhoe Bay TVD Reference: 26.8GL +28.5 @ 55.30ft (26.8GL +28.5) Site: PB DS 07 MD Reference: 26.8GL +28.5 @ 55.30ft (26.8GL +28.5) Well: 07 -08 North Reference: True Wellbore: 07 -08B Survey Calculation Method: Minimum Curvature Design: 07 -08B Database: EDM .16 - Anc Prod - WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +Nt S Ei VN Eating (ft) ( °) { } (ft) (ft) (ft) '(ft) (ft) Latitude Longitude 4,741.30 28.35 13.26 4,695.84 231.42 61.74 5,949,938.45 676,092.12 70° 16' 7.782 N 148° 34' 33.250 W 4,791.30 29.04 13.59 4,739.70 254.77 67.31 5,949,961.93 676,097.15 70° 16' 8.011 N 148° 34' 33.088 W 4,841.30 29.56 13.81 4,783.31 278.54 73.11 5,949,985.83 676,102.39 70° 16' 8.245 N 148° 34' 32.919 W 4,891.30 30.16 14.03 4,826.67 302.70 79.10 5,950,010.12 676,107.81 70° 16' 8.483 N 148° 34' 32.745 W 4,941.30 30.93 14.72 4,869.73 327.32 85.41 5,950,034.87 676,113.54 70° 16' 8.725 N 148° 34' 32.561 W 4,991.30 31.91 15.34 4,912.40 352.49 92.17 5,950,060.20 676,119.71 70° 16' 8.972 N 148° 34' 32.365 W 5,041.30 32.90 15.59 4,954.61 378.31 99.31 5,950,086.18 676,126.25 70° 16' 9.226 N 148° 34' 32.157 W 5,091.30 34.01 15.78 4,996.33 404.85 106.76 5,950,112.88 676,133.08 70° 16' 9.487 N 148° 34' 31.940 W 5,141.30 34.69 16.01 5,037.61 431.99 114.49 5,950,140.19 676,140.17 70° 16' 9.754 N 148° 34' 31.715 W 5,191.30 35.51 16.28 5,078.51 459.60 122.49 5,950,167.98 676,147.52 70° 16' 10.026 N 148° 34' 31.482 W 5,241.30 36.37 17.29 5,118.99 487.70 130.96 5,950,196.26 676,155.33 70° 16' 10.302 N 148° 34' 31.235 W 5,291.30 36.93 18.78 5,159.11 516.07 140.21 5,950,224.85 676,163.91 70° 16' 10.581 N 148° 34' 30.966 W 5,341.30 37.46 19.61 5,198.94 544.62 150.15 5,950,253.61 676,173.18 70° 16' 10.862 N 148° 34' 30.677 W 5,391.30 37.66 20.34 5,238.58 573.26 160.56 5,950,282.49 676,182.92 70° 16' 11.144 N 148° 34' 30.374 W 5,441.30 37.93 20.52 5,278.09 601.98 171.25 5,950,311.45 676,192.94 70° 16' 11.426 N 148° 34' 30.062 W 5,491.30 38.15 20.48 5,317.46 630.84 182.04 5,950,340.55 676,203.05 70° 16' 11.710 N 148° 34' 29.748 W 5,541.30 37.98 20.00 5,356.83 659.76 192.71 5,950,369.71 676,213.03 70° 16' 11.994 N 148° 34' 29.438 W 5,591.30 37.67 19.77 5,396.32 688.60 203.14 5,950,398.78 676,222.79 70° 16' 12.278 N 148° 34' 29.134 W 5,641.30 37.30 19.65 5,436.00 717.24 213.40 5,950,427.66 676,232.38 70° 16' 12.560 N 148° 34' 28.835 W 5,691.30 37.69 19.77 5,475.67 745.89 223.67 5,950,456.54 676,241.97 70° 16' 12.841 N 148° 34' 28.536 W 5,741.30 38.06 19.79 5,515.14 774.78 234.05 5,950,485.66 676,251.68 70° 16' 13.125 N 148° 34' 28.234 W 5,791.30 38.13 19.98 5,554.49 803.79 244.55 5,950,514.90 676,261.49 70° 16' 13.411 N 148° 34' 27.928 W 5,841.30 37.96 20.27 5,593.86 832.72 255.15 5,950,544.07 676,271.41 70° 16' 13.695 N 148° 34' 27.620 W 5,891.30 37.67 20.30 5,633.36 861.47 265.78 5,950,573.07 676,281.36 70° 16' 13.978 N 148° 34' 27.310 W 5,941.30 37.26 20.21 5,673.05 890.01 276.31 5,950,601.84 676,291.22 70° 16' 14.259 N 148° 34' 27.004 W 5,991.30 37.01 19.95 5,712.91 918.36 286.67 5,950,630.42 676,300.92 70° 16' 14.537 N 148° 34' 26.702 W 6,041.30 37.01 19.61 5,752.84 946.68 296.85 5,950,658.97 676,310.43 70° 16' 14.816 N 148° 34' 26.406 W 6,091.30 36.76 19.46 5,792.83 974.96 306.89 5,950,687.48 676,319.81 70° 16' 15.094 N 148° 34' 26.113 W 6,141.30 36.39 19.25 5,832.98 1,003.07 316.76 5,950,715.81 676,329.02 70° 16' 15.371 N 148° 34' 25.826 W 6,191.30 36.34 19.14 5,873.25 1,031.07 326.51 5,950,744.02 676,338.11 70° 16' 15.646 N 148° 34' 25.542 W 6,241.30 35.94 19.05 5,913.62 1,058.93 336.16 5,950,772.11 676,347.10 70° 16' 15.920 N 148° 34' 25.261 W 6,291.30 35.64 19.15 5,954.18 1,086.57 345.73 5,950,799.95 676,356.02 70° 16' 16.192 N 148° 34' 24.983 W 6,341.30 35.81 19.14 5,994.77 1,114.15 355.30 5,950,827.75 676,364.95 70° 16' 16.463 N 148° 34' 24.704 W 6,391.30 35.55 19.12 6,035.39 1,141.70 364.86 5,950,855.51 676,373.85 70° 16' 16.734 N 148° 34' 24.426 W 6,441.30 35.46 18.88 6,076.09 1,169.15 374.31 5,950,883.18 676,382.66 70° 16' 17.004 N 148° 34' 24.150 W 6,491.30 35.44 18.79 6,116.82 1,196.60 383.67 5,950,910.84 676,391.38 70° 16' 17.274 N 148° 34' 23.878 W 6,541.30 35.40 18.73 6,157.57 1,224.04 392.99 5,950,938.49 676,400.06 70° 16' 17.544 N 148° 34' 23.606 W 6,591.30 35.38 18.36 6,198.33 1,251.49 402.20 5,950,966.14 676,408.62 70° 16' 17.814 N 148° 34' 23.338 W 6,641.30 35.15 18.44 6,239.16 1,278.89 411.32 5,950,993.74 676,417.09 70° 16' 18.083 N 148° 34' 23.073 W 6,691.30 34.87 18.44 6,280.11 1,306.10 420.39 5,951,021.16 676,425.52 70° 16' 18.351 N 148° 34' 22.809 W 6,741.30 34.45 18.41 6,321.23 1,333.08 429.38 5,951,048.33 676,433.88 70° 16' 18.616 N 148° 34' 22.547 W 6,791.30 34.34 18.47 6,362.49 1,359.87 438.31 5,951,075.33 676,442.18 70° 16' 18.880 N 148° 34' 22.287 W 6,841.30 33.87 18.68 6,403.89 1,386.45 447.24 5,951,102.10 676,450.49 70° 16' 19.141 N 148° 34' 22.027 W 6,891.30 33.48 18.70 6,445.50 1,412.71 456.12 5,951,128.57 676,458.75 70° 16' 19.399 N 148° 34' 21.768 W 6,941.30 33.20 18.90 6,487.27 1,438.72 464.98 5,951,154.78 676,467.00 70° 16' 19.655 N 148° 34' 21.510 W 6,991.30 32.84 18.98 6,529.20 1,464.49 473.82 5,951,180.75 676,475.24 70° 16' 19.909 N 148° 34' 21.253 W 7,041.30 32.33 19.05 6,571.33 1,489.95 482.60 5,951,206.40 676,483.41 70° 16' 20.159 N 148° 34' 20.997 W 7,091.30 31.90 19.38 6,613.68 1,515.05 491.34 5,951,231.70 676,491.57 70° 16' 20.406 N 148° 34' 20.743 W 7,141.30 31.24 19.65 6,656.28 1,539.72 500.09 5,951,256.57 676,499.73 70° 16' 20.649 N 148° 34' 20.488 W 7,191.30 30.50 19.97 6,699.19 1,563.86 508.78 5,951,280.90 676,507.86 70° 16' 20.886 N 148° 34' 20.235 W 7,241.30 30.11 19.98 6,742.36 1,587.57 517.40 5,951,304.80 676,515.92 70° 16' 21.119 N 148° 34' 19.984 W 7,291.30 29.59 20.02 6,785.73 1,610.96 525.91 5,951,328.38 676,523.88 70° 16' 21.349 N 148° 34' 19.736 W 7,341.30 29.05 19.76 6,829.32 1,633.98 534.24 5,951,351.59 676,531.67 70° 16' 21.576 N 148° 34' 19.493 W 7,391.30 28.47 19.80 6,873.15 1,656.62 542.38 5,951,374.41 676,539.28 70° 16' 21.798 N 148° 34' 19.256 W 7,441.30 28.23 19.88 6,917.16 1,678.95 550.44 5,951,396.93 676,546.81 70° 16' 22.018 N 148° 34' 19.022 W 3/11/2009 1 :56 :20PM Page 4 COMPASS 2003.16 Build 70 • BP Exploration Alaska • Survey Report - Geographic • • Company: North America - ALASKA - BP Local Co- ordinate R Well 07 - 08 Project: Prudhoe Bay TVD Referents: 26.8GL +28.5 @ 55.30ft (26.8GL +28.5) •Side: PB DS 07 -MD Reference: 26.8GL +28.5 @ 55.30ft (26.8GL +28.5) Well: 07 -08 .North Reference: True Welibore: 07 -08B Survey Calculation Method: Minimum Curvature Design: 07 -08B - Database: EDM .16 - Anc Prod - WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N!-S +E/ tv NOtthing: Easting (ft) (4) r) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 7,491.30 28.32 20.09 6,961.19 1,701.21 558.54 5,951,419.37 676,554.39 70° 16' 22.237 N 148° 34' 18.786 W 1 7,541.30 28.40 20.52 7,005.19 1,723.49 566.78 5,951,441.83 676,562.10 70° 16' 22.456 N 148° 34' 18.546 W 7,591.30 28.51 20.85 7,049.15 1,745.77 575.19 5,951,464.30 676,569.99 70° 16' 22.675 N 148° 34' 18.301 W 7,641.30 28.42 21.42 7,093.11 1,768.00 583.79 5,951,486.73 676,578.06 70° 16' 22.894 N 148° 34' 18.051 W 7,691.30 28.45 21.88 7,137.07 1,790.13 592.57 5,951,509.05 676,586.33 70° 16' 23.111 N 148° 34' 17.795 W 7,741.30 28.63 22.41 7,181.00 1,812.26 601.58 5,951,531.38 676,594.81 70° 16' 23.329 N 148° 34' 17.533 W 7,791.30 28.40 23.49 7,224.93 1,834.24 610.88 5,951,553.57 676,603.60 70° 16' 23.545 N 148° 34' 17.262 W 7,841.30 28.36 24.24 7,268.92 1,855.97 620.50 5,951,575.52 676,612.70 70° 16' 23.759 N 148° 34' 16.982 W 7,891.30 27.76 25.45 7,313.05 1,877.31 630.38 5,951,597.09 676,622.08 70° 16' 23.969 N 148° 34' 16.694 W 7,941.30 27.30 26.71 7,357.38 1,898.07 640.53 5,951,618.08 676,631.75 70° 16' 24.173 N 148° 34' 16.398 W 7,991.30 26.54 27.98 7,401.97 1,918.18 650.93 5,951,638.42 676,641.67 70° 16' 24.370 N 148° 34' 16.095 W 8,041.30 26.23 29.35 7,446.76 1,937.67 661.59 5,951,658.16 676,651.87 70° 16' 24.562 N 148° 34' 15.785 W 8,091.30 26.62 30.96 7,491.54 1,956.91 672.76 5,951,677.65 676,662.59 70° 16' 24.751 N 148° 34' 15.460 W 8,141.30 27.39 32.99 7,536.08 1,976.16 684.79 5,951,697.18 676,674.16 70° 16' 24.941 N 148° 34' 15.109 W 8,191.30 28.21 34.86 7,580.31 1,995.51 697.81 5,951,716.82 676,686.73 70° 16' 25.131 N 148° 34' 14.730 W 8,241.30 28.74 36.13 7,624.27 2,014.92 711.65 5,951,736.55 676,700.11 70° 16' 25.322 N 148° 34' 14.327 W 8,260.00 28.95 36.59 7,640.65 2,022.18 717.00 5,951,743.93 676,705.29 70° 16' 25.393 N 148° 34' 14.172 W 8,267.88 29.57 30.56 7,647.52 2,025.39 719.12 5,951,747.19 676,707.34 70° 16' 25.425 N 148° 34' 14.110 W 8,298.35 27.21 30.56 7,674.32 2,037.86 726.49 5,951,759.83 676,714.41 70° 16' 25.548 N 148° 34' 13.895 W 8,329.47 24.57 30.56 7,702.32 2,049.56 733.40 5,951,771.69 676,721.04 70° 16' 25.663 N 148° 34' 13.694 W 8,360.23 23.50 33.00 7,730.41 2,060.21 739.99 5,951,782.49 676,727.38 70° 16' 25.767 N 148° 34' 13.502 W 8,391.04 21.96 33.00 7,758.83 2,070.20 746.47 5,951,792.62 676,733.63 70° 16' 25.865 N 148° 34' 13.313 W 8,484.23 19.34 37.30 7,846.03 2,097.09 765.32 5,951,819.95 676,751.84 70° 16' 26.130 N 148° 34' 12.764 W 8,577.17 18.29 37.82 7,934.00 2,120.85 783.59 5,951,844.13 676,769.55 70° 16' 26.364 N 148° 34' 12.232 W 8,669.88 18.74 37.78 8,021.91 2,144.12 801.63 5,951,867.81 676,787.04 70° 16' 26.592 N 148° 34' 11.707 W 8,761.97 20.04 37.24 8,108.78 2,168.37 820.24 5,951,892.49 676,805.08 70° 16' 26.831 N 148° 34' 11.165 W 8,855.84 21.09 36.75 8,196.66 2,194.71 840.08 5,951,919.28 676,824.29 70° 16' 27.090 N 148° 34' 10.587 W 8,949.05 20.10 36.78 8,283.92 2,220.97 859.71 5,951,946.00 676,843.30 70° 16' 27.348 N 148° 34' 10.016 W 9,040.76 20.96 35.84 8,369.80 2,246.89 878.75 5,951,972.35 676,861.73 70° 16' 27.603 N 148° 34' 9.461 W 9,095.39 20.69 34.92 8,420.86 2,262.73 889.99 5,951,988.44 676,872.60 70° 16' 27.759 N 148° 34' 9.134 W 9,188.98 20.24 40.45 8,508.55 2,288.60 909.96 5,952,014.78 676,891.95 70° 16' 28.013 N 148° 34' 8.552 W 9,219.76 20.27 44.03 8,537.43 2,296.49 917.12 5,952,022.83 676,898.93 70° 16' 28.091 N 148° 34' 8.344 W 9,251.16 20.96 51.22 8,566.82 2,303.92 925.28 5,952,030.45 676,906.91 70° 16' 28.164 N 148° 34' 8.106 W 9,282.64 21.75 57.25 8,596.15 2,310.60 934.58 5,952,037.35 676,916.05 70° 16' 28.230 N 148° 34' 7.835 W 9,313.49 22.81 60.54 8,624.69 2,316.64 944.59 5,952,043.61 676,925.92 70° 16' 28.289 N 148° 34' 7.544 W 9,345.07 25.34 64.59 8,653.53 2,322.55 956.03 5,952,049.79 676,937.21 70° 16' 28.347 N 148° 34' 7.211 W 9,374.26 27.36 68.66 8,679.68 2,327.67 967.92 5,952,055.19 676,948.98 70° 16' 28.398 N 148° 34' 6.865 W 9,406.96 29.21 72.05 8,708.48 2,332.86 982.51 5,952,060.72 676,963.45 70° 16' 28.449 N 148° 34' 6.440 W 9,438.55 30.92 75.11 8,735.82 2,337.33 997.69 5,952,065.54 676,978.52 70° 16' 28.492 N 148° 34' 5.998 W 9,469.21 34.08 81.62 8,761.68 2,340.60 1,013.81 5,952,069.19 676,994.55 70° 16' 28.525 N 148° 34' 5.528 W 9,499.02 37.25 86.27 8,785.91 2,342.41 1,031.08 5,952,071.40 677,011.78 70° 16' 28.542 N 148° 34' 5.025 W 9,530.20 40.51 89.71 8,810.18 2,343.07 1,050.64 5,952,072.52 677,031.31 70° 16' 28.549 N 148° 34' 4.456 W 9,561.05 43.11 89.57 8,833.17 2,343.20 1,071.20 5,952,073.13 677,051.86 70° 16' 28.550 N 148° 34' 3.857 W 9,591.74 46.02 89.96 8,855.03 2,343.29 1,092.73 5,952,073.72 677,073.39 70° 16' 28.551 N 148° 34' 3.230 W 9,623.92 49.43 91.59 8,876.68 2,342.96 1,116.54 5,952,073.95 677,097.19 70° 16' 28.548 N 148° 34' 2.537 W 9,653.85 53.19 94.02 8,895.38 2,341.80 1,139.86 5,952,073.34 677,120.53 70° 16' 28.536 N 148° 34' 1.858 W 9,686.29 56.76 97.17 8,914.00 2,339.20 1,166.29 5,952,071.35 677,147.01 70° 16' 28.511 N 148° 34' 1.089 W 9,717.03 60.44 99.85 8,930.02 2,335.30 1,192.23 5,952,068.06 677,173.03 70° 16' 28.472 N 148° 34' 0.333 W 9,747.80 63.74 103.44 8,944.42 2,329.81 1,218.85 5,952,063.19 677,199.77 70° 16' 28.418 N 148° 33' 59.558 W 9,782.28 68.11 108.55 8,958.49 2,321.11 1,249.08 5,952,055.21 677,230.20 70° 16' 28.333 N 148° 33' 58.678 W 9,809.88 70.29 112.34 8,968.30 2,312.10 1,273.25 5,952,046.76 677,254.57 70° 16' 28.244 N 148° 33' 57.974 W 9,841.11 72.39 115.83 8,978.29 2,300.02 1,300.25 5,952,035.32 677,281.85 70° 16' 28.125 N 148° 33' 57.188 W 9,873.03 73.68 119.74 8,987.61 2,285.79 1,327.26 5,952,021.72 677,309.17 70° 16' 27.985 N 148° 33' 56.402 W 9,904.50 75.72 124.93 8,995.92 2,269.56 1,352.89 5,952,006.09 677,335.18 70° 16' 27.825 N 148° 33' 55.656 W 9,936.28 78.75 128.70 9,002.94 2,250.98 1,377.69 5,951,988.11 677,360.40 70° 16' 27.643 N 148° 33' 54.934 W 3/11/2009 1 :56 :20PM Page 5 COMPASS 2003.16 Build 70 • BP Exploration Alaska Survey Report - Geographic Company; North America - ALASKA - BP Local Co- ordinate, R.efereirce: Well 07 -08 Project: Prudhoe Bay tilt k ifereence: 26.8GL +28.5 @ 55.30ft (26.8GL +28.5) Site: PB DS 07 'MD Reference: 26.8GL +28.5 @ 55.30ft (26.8GL +28.5) Welt: 07 -08 'North Reference: True Welibore: 07 -08B Survey Calculation Mjiioth Minimum Curvature Design: 07 -08B Database: EDM .16 - Anc Prod - WH24P Survey 1 Measured Vertical Map Map Depth Inclination Azimuth Depth' +Nt -S +E.PW 'Northing ..Easting (ft) (°} ( °) (ft) (ft) (ft) Oft) (ft) Latitude Longitude 9,966.86 79.63 131.92 9,008.68 2,231.55 1,400.59 5,951,969.22 677,383.75 70° 16' 27.452 N 148° 33' 54.267 W 9,996.48 80.70 133.91 9,013.74 2,211.68 1,421.96 5,951,949.86 677,405.58 70° 16' 27.256 N 148° 33' 53.645 W 10,025.21 82.70 134.76 9,017.88 2,191.82 1,442.30 5,951,930.47 677,426.37 70° 16' 27.061 N 148° 33' 53.053 W 10,058.40 84.87 135.26 9,021.48 2,168.48 1,465.62 5,951,907.69 677,450.23 70° 16' 26.831 N 148° 33' 52.374 W 10,091.18 86.67 136.28 9,023.90 2,145.06 1,488.42 5,951,884.81 677,473.58 70° 16' 26.601 N 148° 33' 51.710 W 10,122.33 88.77 136.84 9,025.13 2,122.46 1,509.82 5,951,862.72 677,495.50 70° 16' 26.378 N 148° 33' 51.087 W 10,152.06 89.63 136.54 9,025.55 2,100.83 1,530.21 5,951,841.57 677,516.39 70° 16' 26.166 N 148° 33' 50.494 W 10,184.23 89.14 136.18 9,025.89 2,077.55 1,552.41 5,951,818.82 677,539.12 70° 16' 25.937 N 148° 33' 49.847 W 10,214.87 88.83 136.14 9,026.44 2,055.45 1,573.63 5,951,797.23 677,560.85 70° 16' 25.719 N 148° 33' 49.230 W 10,245.04 90.00 136.05 9,026.75 2,033.72 1,594.55 5,951,775.99 677,582.27 70° 16' 25.505 N 148° 33' 48.621 W 10,307.44 90.31 136.09 9,026.58 1,988.78 1,637.84 5,951,732.07 677,626.60 70° 16' 25.063 N 148° 33' 47.361 W 10,399.87 90.43 136.57 9,025.98 1,921.92 1,701.67 5,951,666.73 677,691.97 70° 16' 24.406 N 148° 33' 45.503 W 10,491.55 89.57 134.47 9,025.98 1,856.51 1,765.90 5,951,602.85 677,757.71 70° 16' 23.762 N 148° 33' 43.633 W 10,583.99 90.06 134.40 9,026.28 1,791.80 1,831.90 5,951,539.70 677,825.20 70° 16' 23.126 N 148° 33' 41.712 W 10,678.14 90.43 135.89 9,025.88 1,725.06 1,898.31 5,951,474.53 677,893.14 70° 16' 22.469 N 148° 33' 39.779 W 10,771.08 90.12 138.53 9,025.43 1,656.86 1,961.44 5,951,407.84 677,957.85 70° 16' 21.798 N 148° 33' 37.942 W 10,865.01 89.69 138.43 9,025.59 1,586.53 2,023.70 5,951,338.99 678,021.73 70° 16' 21.106 N 148° 33' 36.129 W 10,958.49 90.12 138.69 9,025.74 1,516.46 2,085.57 5,951,270.38 678,085.22 70° 16' 20.417 N 148° 33' 34.329 W 11,051.12 90.00 140.52 9,025.64 1,445.91 2,145.60 5,951,201.27 678,146.88 70° 16' 19.723 N 148° 33' 32.582 W 11,144.76 90.06 140.85 9,025.59 1,373.46 2,204.92 5,951,130.23 678,207.88 70° 16' 19.010 N 148° 33' 30.855 W 11,236.83 89.20 140.19 9,026.19 1,302.40 2,263.46 5,951,060.56 678,268.06 70° 16' 18.311 N 148° 33' 29.151 W 11,278.23 89.26 140.96 9,026.75 1,270.43 2,289.75 5,951,029.21 678,295.09 70° 16' 17.997 N 148° 33' 28.386 W 11,321.00 89.26 140.96 9,027.30 1,237.21 2,316.69 5,950,996.64 678,322.79 70° 16' 17.670 N 148° 33' 27.602 W 3/11/2009 1:56 :20PM Page 6 COMPASS 2003.16 Build 70 TREE = CIW • S Y NOTES: WELL ANGLE > 70° @ 9810' ACTUATO = GREY = BAKER 07-08 ...___ CTUATOR KB. ELEV = 64BF. ELEV KOP = 4165': Max Angle = 91° @ 11321' Datum MD = 9592' ' I 2200' H4 -1/2" HES X NIP (9CR), ID = 3.813" Datum TVD = 8800' SS GAS LIFT MANDRELS ■ ST MD TVD DEV TYPE VLV LATCH PORT DATE 13 -3/8" CSG, 72#, MN -80, BTC, ID = 12.347" H 2713' I 2 3566 3566 1 MMG DCR RKP 0 02/07/09 I 11 1 6939 6485 33 MMG DMY RKP 0 02/07/09 Minimum ID = 3.725" @ 8920' l 8094' H9 -5/8" BKR TIEBACK SLV HES XN NIPPLE ►' 0 8105' H9-5/8" x 7" BKR ZXP LT PKR, ID = 6.28" 8110' H9 -5/8" x 7" BKR HMC LNR HGR, ID = 6.31" 9 -5/8" CSG, 47 #, SOO- 95/N -80, BTC, ID = 8.681" H 8249' I--- 9 -5/8" MILLOUT WINDOW (07 -08B) 8249' -8268' TOP OF WHIPSTOCK I 8249' 9-5/8" EZSVH 8270' ' 8784' H4 -1/2" HES XNIP (9CR), _ Ilk 1 I ID= 3.813" ..�11111111s�. 1 ► 8814' 7" x 4 -1/2" BKR S -3 PKR, 111111 111111111111V.i : 1D 03.87" 11 1N 1 1 :: ". .,1 ' 884T H 4 -1/2" HES XNIP (9CR), ∎4 I ID = 3.813" i.a .11111 i.o 1 � � ! '' •: H 4 -1/2" HES XN NIP (9CR), I , ( )' •• ∎•••••• ID = 3.725" ►� i ..i ..i ..i ..i :i ..i. � ••i .. �������� 8924' H 7 " BKR TIEBACK SLVI 8933' H4 -1/2" WLEG, ID = 3.958" 4 -1/2" TBG, 12.6#, 13CR, VAM TOP, .0152 bpf, ID = 3.958" H 8933' ° 1 8936' I-- 7" x 5" BKR ZXP LT PKR, ID = 4.40" TOP OF 4-1/2" LINER H 8956' 8946' X1 x 5" BKR FLEX LOCK LNR HGR, ID = 4.44" 7" LNR, 26 #, L -80, BTC-M, .0383 bpf, ID = 6.276" —I J082' I 4 ' 8956' H 5" x 4 -1/2" XO, ID = 3.96" I PERFORATION SUMMARY REF LOG: MEM CNL ON 02/04/99 ANGLE AT TOP PERF: 89° @ 10200' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 10200 - 10400 O 02/07/09 2 -7/8" 6 10500 - 11220 0 02/07/09 PBTDI—I 11238' 1 1 1.0.4 4 -1/2" LNR, 12.6#, L -80, IBT -M, ID = 3.958" H 11321' ►.i i iii i DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/09/79 ROWAN34 ORIGINAL COMPLETION WELL: 07 -08B 01/12/99 D16 SIDETRACK (07 -08A) PERMIT No: 8 2070190 08/03/07 D14 RWO API No: 50- 029 - 20296 -02 02/07/09 N7ES SIDETRACK (07 -08B) SEC 33, T11N, R14E, 1215' FNL & 166' FEL 03/03/09 FR/SV DRLG CORRECTIONS BP Exploration (Alaska) • 1111 • '"s.) oL fir . l l SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 Greg Hobbs PHONE (907) 279 -1433 Engineering Team Leader FAx (907) 276-7542 BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07 -08B BP Exploration Alaska Inc. Permit No: 207 -019 (revised) Surface Location: 1215' FNL, 166' FEL, SEC. 33, T1 IN, R14E, UM Bottomhole Location: 70' FSL, 2110' FWL, SEC. 27, T11N, R14E, UM Dear Mr. Hobbs: Enclosed is the revised approved application for permit to drill the above referenced service well. This revision was necessary due to revision of the well design to allow employing a rotary rather then coil tubing as originally proposed. All requirements contained in the Commission's letter of February 14, 2007 apply. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, /32ee,/,74%._ Cathy P Foerster f� Commissioner DATED this / , day of September, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALAS KA(' c `resT .0 ,; ALASK IL AND GAS CONSERVATION COMMI -fi. t ' n ' s ' �''' PERMIT TO DRILL p , 1as a � � g p C- s,�?' J 20 AAC 25.005 Revised: Originally Permitted for CTD, Now Rotary Rig 1a. Type of work 1 b. Current Well Class ❑ Exploratory ❑ Development Gas 1 c. Specify if well is proposed for: ❑ Drill : Redrill ❑ Service ❑ Multiple Zone ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -Entry ❑ Stratigraphic Test ® Development Oil ❑ Single Zone ❑ Shale Gas 2. Operator Name: 5. Bond: Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 PBU 07 - 08B 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 -6612 MD 11124' TVD 9016' Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028309 1215' FNL, 166' FEL, SEC. 33, T11N, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 934' FSL, 1327' FWL, SEC. 27, T11N, R14E, UM October 10, 2008 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 70' FSL, 2110' FWL, SEC. 27, T11N, R14E, UM 2560 36,300' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Plan 15. Distance to Nearest Well Within Pool: Surface: x- 676036 y- 5949706 Zone -ASP4 (Height above GL): 55.5' feet 800' 16. Deviated Wells: Kickoff Depth: 8260 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3462 Surface: 2622 18. Casino P roaram: Specifications Top - Settina Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8 -1/2" 7" 26# L -80 BTC -M 988' 8100' 7500' 9088' 8397' 206 sx Class 'G' 6 -1/8" 4-1/2" 12.6# L -80 IBT -M 2184' 8940' 8267' 11124' 9016' 256 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 10948' 902$' 9920' 9920' 8949' 8937' Casing Length Size Cement Volume MD TVD Conductor / Structural 119' 20" 271 sx Arcticset 119' 119' Surface 2712' 13 -3/8" 3700 sx Arcticset I I 2712' 2712' Intermediate 9610' 9 -5/8" 1200 sx Class 'G' 9610' 8781' Production Liner 1978' 3 -1/2" x 3- 3/16" 96 sx LARC 8968' - 10946' 8250' - 9022' Perforation Depth MD (ft): 9760' - 9802' (above CIBP) Perforation Depth TVD (ft): 8878' - 8899' 20. Attachments ❑ Filing Fee, $100 ❑ BOP Sketch CI Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat ❑ Diverter Sketch ❑ Seabed Report ® Drilling Fluid Program ® 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Eleazar 'Eli' Vazquez, 564 Printed Name Gr -,a • • •s Title Engineering Team Leader / %/r/ Prepared By Name/Number: Signature Phone 564 -4191 Date 0;42 Terrie Hubble, 564 -4628 • Commission Use On! < ` Permit To Drill API Number: Permit Approval See cover letter for Number: 207- 019 50 - 029 20296 - - Date: • / • 07 other reauirements 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: Er 35C `S'i p kt., \-- Samples Req'd: 0 Yes «No Mud Log Req'd: 0 Yes ffi No H Measures: ['Yes ❑ No Directional Survey Req'd: Er ❑ No j Other: % hZS S%(?ct:t S- 1 ) N1 I'S"")'■ ' 1 — WI . 9 e A721 1 PROVED BY THCOMMISSIONER ION 9.10.4e Date Form 10-401 Revised 12/2005 ®R I I ICI A L Submit In Duplicate by • r 0 To: Alaska Oil & Gas Conservation Commission From: Eli Vazquez, ODE Date: August 25, 2008 Re: 07 -08B Sidetrack Permit to Drill The 07 -08B well is scheduled to be drilled by Doyon Rig 14 which is currently scheduled to move onto the location -10/10/08. The plan is to exit the parent 07 -08A wellbore from the 9 -5/8" casing at —8260' MD with an 8 -1/2" BHA. The 8 -1/2" hole will then be drilled to the top of the Sag River formation where a 7" drilling liner will be run and cemented. A 6 -1/8" hole will then be drilled building to horizontal in the Ivishak Zone 1B. The planned well then runs horizontally for approximately 1,168' to a final well TD at 11,123' MD. A solid 4 -1/2" production liner will be run and cemented in place. Please note the following Well Summary as detailed on the next few pages: I 07 -08B Permit to Drill Application Page 1 •Planned Well Summary. Well 07 -08B Well Horizontal Target Zone Type Sidetrack Objective 1B API Number: 50- 029 -20296 Current Status 07 -08A Shut -In and P &A Procedures commencing Estimated Start Date: 10- Oct -2008 Time to Complete: 25.1 Days Surface Northing Easting Offsets TRS Location 5,949,705 676,035 1215' FNL / 5113' FWL 11N, 14E, 33 Northing Easting TVDss Offsets TRS Target 5,951,890 677,474 -8,960 4345' FNL / 1327' FWL 11N, 14E, 27 Locations 5,951,045 678,278 -8,960 5209' FNL / 2109' FWL 11N, 14E, 27 Bottom Northing Easting TVDss Offsets TRS Location 5,951,045 678,278 -8,960 5209' FNL / 2109' FWL 11N, 14E, 27 Planned KOP: 8260'MD / 7585'TVDss Planned TD: 11,123'MD / 8,960' TVDss Rig: Doyon 14 GL: 27.0 RTE: 55.5' Directional — Sperry P02 KOP: 1 8260' MD Maximum Hole Angle: -29.24° in the 8 -1/2" intermediate section -.90° in the 6 -1/8" horizontal section Close Approach Wells: All wells pass major risk criteria for close approach. Survey Program: MWD Standard + IFR + MS Nearest Property Line: 36,300' (North) Nearest Well within Pool: Well 07 -17 located 800' away, center to center. Contacts Name Phone # E -mail Drilling Engineer Eli Vazquez 564 -5918 vazge0 @bp.com Geologist Doug Stoner 564 -5652 Doug.Stoner @bp.com Pad Engineer Alice Kaminski 564 -5676 Alice.Kaminski @bp.com 07 -08B Permit to Drill Application Page 2 Formation Markers 07•B (Based on SOR) 0 Est. Formation Tops Est. Pore Press. Formation (TVDss) (TVDrkb) (MDrkb) (Psi) /ppg EMV CM3 6128 6173 6581 CM2 6637 6692 7192 CM1 7226 7281 7865 KOP 7585 7640 8260 THRZ 7666 7721 8352 BHRZ 7824 7880 8527 LCU/TJD 7849 7905 8554 TJC 8019 8079 8744 TJB 8157 8213 8888 TJA 8255 8311 8995 TSGR 8341 8397 9088 3462 psi / 7.9 ppg TSHU 8373 8429 9123 TSAD 8450 8506 9206 TCGL 8612 8669 9383 BCGL 8692 8749 9470 - 3269psi @ 8800' / 7.2 ppg 23SB 8748 8802 9528 22TS 8792 8854 9590 21TS 8858 8915 9672 TZ1B 8930 8987 9806 HOT 8963 9018 9950 TDF 8966 9121 NR Casing/Tubing Program Hole Csg / Wt/Ft Grade Conn Burst Collapse Length Top Bottom Size Tbg O.D. (psi) (psi) MD / MD /TVDrkb TVDrkb 8 -'/2" 7" 26# L -80 BTC -M 7,240 5,410 988' 8 100' / 9088' / 8,397' 7,500' 6 -1/8" 41" 12.6# L -80 IBT -M 8,430 7,500 2,184 8,940' / 11,124' / 8,267' 9,015' Tubing 4'h" 12.6# 13Cr- Vam Top 8,430 7,500 8,930' Surface 8,930' / 80 8,257 07-08B Permit to Drill Application Pa e 3 0 pp 9 Mud Program • • Whipstock Milling Mud Properties: LSND ) Whip Stock Window 9 -5/8 ", 47# Density (ppg) PV YP API FL HTHP FL MBT PH 10.1 16 -30 30 -35 <6.0 <12 NA 9.0 -9.5 Intermediate Mud Properties: LSND 1 8 -1/2" hole section Depth Interval Density (ppg' PV YP API FL HTHP FL MBT PH 8,260'- 9,088' (Top HRZ to 10.1 15 -25 25 - 30 < 5.5 <12 <20 9.0 -9.5 Sag) Production Mud Properties: FLOPRO SF Reservoir Drill -in Fluid 1 6 -1/8" hole section Depth Interval Density (ppg) PV YP LSVR API Fl pH MBT 9,088'- 11,124' 8.4 — 8.7 8 -12 22 -28 >20,000 6.0 -8.0 9.0 -9.5 < 3 Logging Program 8 -1/2" Intermediate: Sample Catchers — none. Drilling: Dir /GR/Res — Run resistivity in intermediate section to pick Kingak B marker for casing point and isopach down. Open Hole: None Cased Hole: None 6 -1/8" Production: Sample Catchers — as required by Geology Drilling: Dir /GR/Res/Neu /Den/ABI - Pick up Neu /Den tool after drilling build section and MAD pass build in "UP" direction. Or tool may be picked up if we trip out for another bit in the Z3 conglomerates. Require "realtime" Res. For fault/fracture identification and HOT detection. Send MWD log and directional data(e -mail) to PDC and town geologist ASAP after reaching TD. Open Hole: None Cased Hole: None Cement Program Casing Size: 7" 26 #, L -80 Intermediate Liner Basis: Lead: None Tail: Based on 828' of open hole with 30% excess, plus 80' shoe track, 150' 7" x 9 -5/8" Liner lap, and 200' 4" DP x 9 -5/8" casing excess. Tail TOC: 8,110' MD (TOL) Total Cement Spacer 30 bbls of Viscosified Spacer weighted to 11.5 ppg (Mud Push II) Volume: Lead N/A Tail 42.8 bbls, 239 cuft, 206 sks 15.8 lb/gal Class G + adds — 1.16 cuft/sk Temp BHST = 195° F, BHCT TBD by Schlumberger Casing Size 4.5" 12.6 #, L -80 Production Liner Basis: Lead: None Tail: Based on 2,036' of open hole with 30% excess, plus 80' shoe track, 150' 7" x 4-1/2" Liner lap, and 200' 4" DP x 7" liner excess. Tail TOC: 8,940' MD (TOL) Total Cement Spacer 30 bbls of Viscosified Spacer weighted to 9.6 ppg (Mud Push II) Volume: Lead None Tail 52.9 bbls, 296 cuft, 256 sks 15.8 lb/gal Class G + adds — 1.16 cuft/sk Temp BHST =195° F, BHCT TBD by Schlumberger 07 -08B Permit to Drill Application Page 4 • Surface and Anti - Collision Issues Surface Shut -in Wells: There are no wells requiring surface shut -in in order to move onto the well. At surface 07 -09 to the north and 07- 07 to the south are nearest at 120' centers. Close Approach Shut -in Wells: All wells pass major risk criteria. Hydrogen Sulfide DS 07 is not designated as an H2S site. Recent H2S data from the pad is as follows: Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level 07 -09 10 ppm 12/11/82 #2 Closest SHL Well H2S Level 07 -07B NA NA #1 Closest BHL Well H2S Level 07 -17 10 ppm 01/05/07 #2 Closest BHL Well H2S Level 07 -06B NA NA Max. Recorded H2S on Pad/Facility 07 -24 50 ppm 05/15/05 Other Relevant H2S Data measured at 20 ppm on 1/10/2006. DS 7 is not a HAS pad and values are generally <30 ppm. (H2S alarms from rigs, etc.) Faults The 07 -08B wellpath is not expected to intersect any mapped faults. However, the well plan runs parallel to a fault ranging from 60 —175 feet to the northeast and the polygon line is a strict hardline in this direction. This fault dies out upwards into Zone 1 with no connection to gas. Additional faults are also present 130 feet and 190 feet to the southwest of the planned well. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind /shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP regular test frequency for 07 -08B will be 14 days during drilling phase and 7 days during decompletion and surface casing work. BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum anticipated BHP 3462 psi @ 8341' TVDss (7.9 ppg EMW) Maximum surface pressure 2622 psi (.10 psi /ft gas gradient to surface) Kick tolerance Infinite over 10.4 ppg FIT (FIT to 11.7 ppg f /ECD management) The plan is to perform a full leak off test. Planned BOP test pressure Rams test to 3,500 psi /250 psi. Annular test to 2,500 psi /250 psi 9 -5/8" Casing Test 3500 psi surface pressure Integrity Test — 8 -1/2" hole LOT after drilling 20' from middle of window. 7" Drilling Liner The VBRs will be changed to 7" rams to accommodate the 7" drilling liner. 07 -08B Permit to Drill Application Page 5 Production Interval • • Maximum anticipated BHP 3269 psi @ 8800' TVDss (7.2 ppg EMW) Maximum surface pressure 2382 psi (.10 psi /ft gas gradient to surface) Kick tolerance Infinite over 9.5 ppg FIT (FIT to 10.5 ppg f /ECD management) Planned BOP test pressure Rams test to 3,500 psi /250 psi. Annular test to 2,500 psi /250 psi 7" Liner / 4 -1/2" Liner 3500 psi surface pressure Integrity Test — 6 -1/8" hole 10.5 ppg FIT after drilling 20' of new hole Planned completion fluids 8.5 ppg Seawater / 7.2 ppg Diesel Variance Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA requests a variance to the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams. If the lower set of pipe rams cannot be tested during the primary BOP test, that set of rams will be tested at the earliest opportunity during path - forward de- completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the BOP stack. Disposal • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS -04 for injection. Haul all Class I waste to Pad 3 for disposal. 07 -08B Permit to Drill Application Page 6 Drillirt Hazards and Continciencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Ivishak in this fault block is expected to be under - pressured at 7.2 ppg EMW. This pressure is estimated based on offset well pressures. 3500 psi test pressure is in accordance with the RP for Prudhoe production well casing tests. II. Lost Circulation /Breathing A. The 07 -08B is not expected to intersect any mapped faults. However, the well plan runs parallel to a fault ranging from 60 -175 feet to the northeast and the polygon line is a strict hardline in this direction. This fault dies out upwards into Zone 1 with no connection to gas. Additional faults are also present 130 feet and 190 feet to the southwest of the planned well. B. The proposed 07 -08B well lies in a moderate risk province of the field for lost circulation at faults. Nine loss circulation events were encountered in the Sadlerochit in 7 of the surrounding 24 wells (16 %), as detailed below, and the loss circulation risk for the planned well is low. Well Type Loss (bbl) MD SSTVD Formation Fault? 07 -06B Riq 315 8825 -8398 Sag River No (run liner) 07 -06B Rig 1431 8869 -8434 Shublik No 07 -08A Coil 6 10150 -8962 Zone 1 Yes 07 -14B Coil -70 10668 -8770 Zone 2 No 07 -15 Rig 180 9425 -9132 Below Bsad Yes lo inq) 07 -16 Riq 350 10680 -8950 Below Bsad No 07 -32A Coil 49 10200 -8938 Zone 1 No (seepage) 07 -32A Coil 6 10240 -8947 Zone 1 No 07 -35 Riq 150 8660 -8422 Sag River No III. Kick Tolerance /Integrity Testing A. The Kick Tolerance for both the intermediate and production hole sections is infinite with planned mud weights. B. Integrity Testing Test Point Test Depth Test type EMW (lb /gal) 9-%" window 20 -ft minimum from the 9-%" window LOT 10.4 minimum 7" shoe 20 -ft minimum from the 7" shoe FIT 10.5 minimum IV. Stuck Pipe A. Significant directional work will be required in the production hole section. Hole cleaning and differential sticking tendency will be of concern. Watch for signs of tight hole and short trip / back ream as required to avoid stuck pipe. VI. Hydrogen Sulfide A. DS 07 is not designated as an H2S site and values are generally below 30 ppm. H2S last reading was 20 ppm on 1/10/2006. VII. Faults A. No faults are expected to be encountered by the planned well. See Section II on lost circulation for more details. VIII. Anti - Collision Issues A. All wells pass major risk criteria for close approach. 07 -17 is the closest well at 800' center to center. CONSULT THE DS 07 DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 07 -08B Permit to Drill Application Page 7 Operations Summary WELL STATUS ✓ Caliper tubing and liner 07/01/06 ✓ MIT -OA Failed to 2000 psi 03/15/07 ✓ PPPOT-T & IC Passed, LDS OK 07/01/07 ✓ Obstruction @ 8836' slm 08/19/07 ✓ MIT -IA Passed to 3000 psi 04/03/08 ✓ 07 -08B is currently shut -in Scope Notify the field AOGCC representative with intent to plug and abandon PRE -RIG OPERATIONS 1. S: RU, drift for cement retainer. 2. F: Fluid pack the tubing and inner annulus w /seawater /diesel. 3. F: Conduct Injectivity Test down tubing for P & A cement design. 4. E: Set a cement retainer inside the 4 -1/2" tubing at -8,780' MD. Cement retainer is desired to be placed in the middle of the first full 4 -1/2" joint above the XN Nipple. 5. C: P &A the perforations thru the cement retainer. Squeeze -10 bbls of cement into perfs and fill the tubing from 9,920' MD up to 8,780' MD. Unsting and lay 100' of cement ( -1.5 bbls) on top of retainer. a. 15.8 ppg class G cement calculations: i. 4 -1/2" tubing above cement retainer = 100' x 0.1521 = 1.52 bbls ii. 4-1/2" tubing = 8843' - 8780.4', 63.4' x 0.01521 = 0.965 bbls iii. 5 -1/2" tubing = 8914.7' - 8843.4', 71.25' x 0.0232 = 1.66 bbls iv. 4 -1/2" tubing = 8961' - 8914.7', 46.3' x 0.01521 = 0.705 bbls v. 4 -1/2" tbg x 3 -1/2" = 8998' - 8961', 37' x 0.0033 = 0.123 bbls vi. 4 -1/2" tbg x 3- 3/16" = 9024' - 8998', 26' x 0.0053 = 0.139 bbls vii. 3 -1/2" liner = 8998' - 8961', 37' x 0.0087 = 0.322 bbls viii. 3 -3/16' liner = 9920' - 8998', 922' x 0.0076 = 7.01 bbls ix. Cement squeezed into perfs = 10 bbls x. Total (with 0.6 bbls excess) = 23 bbls 6. S: RU, drift for Jet Cutter 7. E: Jet cut the 4 -1/2" tubing in the middle of a full joint at -8310' MD. 8. F: Circulate the well to sea water and freeze protect with diesel to 2,200' MD. 9. F: CMIT - T x IA to 3,000 psi for 30 minutes. MIT - OA to 2,000 psi for 30 minutes (previous test failed 3/13/07) and conduct an injectivity test to obtain a LLR. 10. D: Bleed all casing and annulus pressures to zero psi. 11. W: Function all tubing and casing lock down screws. Repair and replace as necessary. PPPOT - IC and PPPOT - T. 12. W: Set a BPV. Remove well house and flow line. Level the pad as needed. Provide total well preparation cost on the handover form. RIG OPERATIONS: 1. MI / RU Doyon rig 14. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. 3. Set BPV using a T -bar and test from below to 1,000 psi for 10 minutes. 4. Nipple down tree. Install a test dart in the top of the BPV so the plug can hold pressure from above. Nipple up and test BOPE to 3,500 psi. Pull test dart and BPV. 07 -08B Permit to Drill Application Page 8 5. RU and pull the 4 -1/2 , 2.6 #, 13Cr Vam Top tubing from the pre let cut at 8310' MD. Test the lower set of pipe rams. 6. RU E -line. MU 8 -1/2" GR /JB & GR /CCL. RIH and tag tubing stump at 8310' MD to confirm access to run an EZSV bridge plug. If gauge ring / junk basket indicates a scraper run is needed, PU 4" drillpipe and 9 -5/8" clean -out assembly and clean -out well to 8280' MD. POOH. 7. With E -line, set a 9 -5/8" EZSV bridge plug at -8284' MD to allow for a -8260' MD whipstock KOP. 8. Pressure -test the 9 -5/8" casing to 3,500 psi for 30 charted minutes. 9. Bleed 9 -5/8" annulus pressure. 10. ND BOPE and set back. 11. ND and remove the tubing spool. 12. Pull existing pack -off. Install Gray Gen 2 to New Standard Conversion pack -off. 13. Install new tubing spool and test to 5,000 psi or as recommended by Cameron Rep. 14. NU and test BOP. 15. P/U and RIH with 9 -5/8" Baker bottom -trip anchor whipstock assembly on 4" drill pipe. Orient whipstock per Schlumberger Rep and set on EZSV bridge plug. Shear off the whipstock. 16. Displace the well to 10.1 ppg LSND based milling fluid. Completely displace the well prior to beginning the milling operations. 17. Mill window in 9 -5/8" casing at ± 8,260'MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 18. Pull up into 9 5/8" casing and conduct an LOT. POOH. 19. M/U 8 -1" GR /RES /MWD assembly. RIH, kick off and drill the 81/2" intermediate section with 10.1 ppg LSND drilling fluid. 20. Drill ahead to the 7" liner point at top of the Sag River, as per the directional plan. Circulate the well clean, short trip to THRZ or higher as needed. POOH. 21. Change out to 7" rams, and test. 22. MU and run 980' of 7 ", 26 #, L -80, BTC -M liner to bottom on drill pipe. Circulate and condition the hole. 23. Cement the entire 7" liner through the 8 -1/2" hole and back 150' into the 9 -5/8" casing at 8,110' MD. Set the hanger and packer, displace cement with mud. 24. Circulate bottoms up, POOH, L/D liner running tool (LRT). 25. M/U the first 6 -W Dir /GR /Res assembly with a roller cone bit and RIH. Wash down to the cement plug in the 7" liner. 26. Test the liner to 3,500 psi for 30 charted minutes. 27. Drill out of cement and float equipment to shoe. 28. Displace to 8.4 ppg Flo Pro Fluid. 29. Drill out the 7" shoe plus -20' new formation, pull up into the shoe and conduct an FIT. Drill the 6- 1/8" production interval as per directional plan to end of the build section. 30. POOH for PDC bit. 31. POOH, PU second 6 -1/8" Neu /Den /GR /Res BHA with PDC. 32. RIH, MAD pass build section in "UP" direction. Drill ahead to TD. 33. POOH. L/D BHA. 34. Run and fully cement 2,180' of 4 -1/2 ", 12.6 #, L -80 solid liner. This will include 150' liner lap inside the 7" drilling liner. Cement the liner. A perf pill will be left in the 4 -1/2" liner. 35. Set liner top packer and displace well to clean seawater above the liner top. 36. POOH, L/D LRT. 37. Pressure test casing and liner to 3,500 psi for 30 minutes. 38. RU DPC pert guns, RIH and perforate. Perf intervals to be supplied by asset. 39. R/U and run a 41/2", 12.6 #, 13Cr, VamTop tubing completion, stinging into the 4 -1/2" liner tie back sleeve. 40. Space out and make up tubing hanger per Cameron Rep. 41. Land the tubing hanger, and run in lock down screws. 42. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. Record each test. 43. Set a BPV. 44. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. 45. Freeze protect the well to -2,200' TVD. Secure the well. 07 -08B Permit to Drill Application Page 9 46. RD and Move Off. 111 4110 POST -RIG OPERATIONS 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Install well house and instrumentation. 3. The S -Riser will need to be modified. Estimated Pre -rig Start Date: 09/15/2008 Estimated Spud Date: 10/10/2008 07 -08B Permit to Drill Application Page 10 TREE = GRAY GEN 2 WELLHEAD = GRAY SAFETI(K7iP�5C ACTUATOR = AXELSON 07-084 11111 1 1 KB. ELEV = 64' BF.ELEV= KOP= 4165 DRLG DRAFT 2090' H 4 -1/2"X -NIP ID =3.813 Max Angle = 96 @ 10444' GAS LIFT MANDRELS Datum MD = 9736' ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum TVD = 8800' SS 5 3329 3328 1 410SS DMY RK 0 08/01/07 4 4783 4733 29 410SS DMY RK 0 08/01/07 13 -3/8" CSG, 72 #, N-80, ID = 12.347" H 2712' 3 6323 5982 36 410SS DMY RK 0 08/01/07 2 7528 6994 28 410SS DMY RK 0 08/01/07 1 8644 7971 31 410SS DCR RK 0 08/01/07 Minimum ID = 2.80" @ 8998' 8683' 4 -1/2" X -NIP ID =3.813 I MI TOP OF 3- 3/16" LNR 8713' 9 5/8" x 4-1/2" BAKERS 3 Cr PKR I 8748' — 4 -1/2" X -NIP ID =3.813 I 1 4 1/2" 12.6 # /ft 13Cr Vam Top I-I 8843' 8821' -I 4 -1/2" XN-NIP (MILLED 12/5/07), ID= 3.80" I 8843' — 9 -5/8" x 4 -1/2" UMI Chrome Overshot I , 8853' -I 5 -1/2" BAKER SBR ASSY, ID = 4.875" I e 8903' H9-5/8" X 5-1/2" BAKER SAB PKR, ID = 4.223" I 'TOP OF 4 -1/2" TBG H 8915' I , 8915' H 5-1/2" X 4 -1/2" XO I 1 5 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.95" H 8915' ' 18937' SLM I -IJUNK FROM 8/2007 RWO (TAGGED 09/29/07) I 1 8961' 3 -3/4" X 3" BAKER DEPLOY SLV, ID = 3.000" I ITOPOF3- 1 /2 " LNR H 8965' 1 1 8975' I 4 -1/2" BAKER NIP, ID = 3.759" (BEHIND 3 -1/2" LNR) 3 -1/2" LNR, 9.3 #, L -80, .0087 bpf, ID = 2.992" I-f 8998' I N L 8998' H 3 -1/2" X 3- 3/16" XO, ID = 2.992" I 'TOP OF 3- 3/16" LNR H 8998' TOP OF CEMENT H 9024' 1 1 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 9036' �•v � • •∎ 9035' _I — 4 -1/2" SHEAR OUT SUB, ID = 4.125" • • • •∎�• • ∎1 • (BEHIND 3- 3/16" LNR), 1 9 -5/8" CSG, 47 #, N-80, ID = 8.681" 1-1 9610' I- A i •••• • • • � MILLOUT WINDOW - 9610' - 9620' PERFORATION SUMMARY ••�•�•�•�•�•�•. ` 9920' H CIBP SET 05/31/03 I REF LOG: MEM CNL ON 02/04/99 • : : : : : : : : : : : : : : : :$ ��i�i�i�i�i�i�i�i ANGLE AT TOP PERF: 59 @ 9760' •�•�•�•�•�••••••• I • 10903' PBTD - BAKER LANDING Note: Refer to Production DB for historical perf data 4 p �•�j�•�•�j�•�j�•�4 COLLAR, ID = 2.992" SIZE SPF INTERVAL Opn /Sqz DATE � 2-1/4" 6 9760 - 9779 0 07/20/03 ke.e.•_•_•_•,•_•.•4 2 -1/4" 6 9782 - 9802 0 05/31/03 10937' BAKER FLOAT SHOE 2" 4 10299 - 10576 C 02/05/99 !� 2" 4 10768 - 10907 C 02/05/99 ....owe � 1 TD H 10948' 1 13- 3/16" LNR, 6.2 #, L -80, .0076 bpf, ID = 2.80" I-I 10937' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/09/79 ORIGINAL COMPLETION 08/02/07 SV DRLG CORRECTIONS WELL: 07 -08A 01/12/99 SIDETRACK (07 -08A) 09/29/07 RCT/TLH JUNK FROM RWO PERMfT No: '1982440 05/15/01 RN/TP CORRECTIONS 12/19/07 NORDICI MILLED XN NIP (12/5/07) API No: 50- 029 - 20296 -01 05/31/03 SRB/TLP CLOSE/NEW PERFS, CIBP SEC 33, T11 N, R14E, 2905.82' FEL & 4275.96' FNL 07/20/03 SRB /TLH ADD PERFS 08/03/07 D14 RWO BP Exploration (Alaska) TREE = GRAY GEN 2 07-08A SAFETY NOTES: WELLHEAD = GRAY ACTUATOR = AXELSONj PR E -RIG I KB. ELEV = 64' BF. ELEV = KOP = 4165' 2090' J—I 4-1/2" X-NIPID=3.813 Max Angle = 96 @ 10444'1 GAS LIFT MANDRELS Datum MD = 9736'! ST MD WD DEV TYPE VLV LATCH PORT DATE Datum TVD = 8800'SS1 5 3329 3328 1 410SS DMY RK 0 08/01/07 L 13 -3/8" CSG, 72 #, N -80, ID = 12.347" H 2712' I EP 4 4783 4733 29 410SS DMY RK 0 08/01/07 3 6323 5982 36 410SS DMY RK 0 08/01/07 Minimum ID = 2.80" @ 8998' 2 7528 6994 28 410SS DMY RK 0 08/01/07 TOP OF 3 -3/16" LNR 1 8644 7971 31 410SS DCR RK 0 08/01/07 I Pre -rig tubing jet cut J 8310' I 8683' IR 4-1/2" X-NIPID=3.813 I I Expected Top of Cement J—{ 8680' •■- 8713' JR 9 5/8" X 4 -1/2" BAKER S -3 Cr FKR 8748' — J 4 -1/2" X -NIP ID =3.813 I Cement Retainer H 8780' J 8821' H 4 -1/2" XN-NIP (MILLED 12/5/07), I0= 3.80" I I 4 1/2" 12.6 # /ft 13Cr VamTop J-J 8843' I 884 3' —J 9 -5/8" x 4 -1/2" UMI Chrome Overshot I 8853' H 5 -1/2" BAKER SBR ASSY, ID = 4.875" I ■ 0 8903' F-1 95/8'X51'2" BAKER SA B PKR, ID = 4.223" I ITOP OF 4 -1/2" TBG H 8915' I 8915' H 5 -1/2" X 4 -1/2" XO I I 5 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.95" I 8915' 1 8937' SLM H JUNK FROM 8/2007 RWO (TAGGED 09/29/07) I I I 8961' H 3-3/4" X 3" BAKER DEPLOY SLV, ID = 3.000" J TOP OF 3-1/2" LNR H 8965' J • 8975' I 4 -1/2" BAKER NIP, ID = 3.759" (BEHIND 3-1/2" LNR) 3 -1/2" LNR, 9.3 #, L -80, .0087 bpf, ID = 2.992" J-{ 8998' J 8998' 1R 3 -1/2" X 3- 3/16" XO, ID = 2.992" I TOP OF 3- 3/16" LNR I 8998' I I TOP OF CEMENT H 9024' J ♦0 .A./ mo t ♦ ► - . 9035' , � 4 -1/2" SHEAR OUT SUB, ID = 4.125" 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" J 9036' y � � ��� • (BEHIND 3- 3/16" LNR), 9 -5/8" CSG, 47 #, N -80, ID = 8.681" I—{ 9610' }-- � ► • *V • MILLOUT WINDOW - 9610' - 9620' • ` 9920' H CIBP SET 05/31/03 I PERFORATION SUMMARY ♦�����\� REF LOG: MEM CNL ON 02/04/99 ANGLE AT TOP PERF: 59 @ 9760' ���������4 I 10903' 1 PBTD - BAKER LANDING Note: Refer to Production DB for historical perf data j ♦�������� COLLAR, ID= 2.992" SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/4" 6 9760 - 9779 0 07/20/03 kt . .4. . _ _ _ . 4 2 -1/4" 6 9782 9802 0 05/31/03 10937' H BAKER FLOAT SHOE I 2" 4 10299 - 10576 C 02/05/99 !``k, 2" 4 10768 - 10907 C 02/05/99 I TD H 10948' I 3- 3/16" LNR, 6.2 #, L -80, .0076 bpf, ID = 2.80" JR 10937' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/09/79 ORIGINAL COM PLETION 08/02/07 SV DRLG CORRECTIONS WELL: 07 -08A 01/12/99 SIDETRACK (07 -08A) 09/29/07 RCT/TLH JUNK FROM RWO PERMIT No: 1982440 05/15/01 RN/TP CORRECTIONS 12/19/07 NORDIC1 MILLED XN NIP (12 /5/07) API No: 50- 029 - 20296 -01 05/31/03 SRB /TLP CLOSE/NEW PERFS, CIBP 08/12/07 EV Proposed Pre -rig SEC 33, T11 N, R14E, 2905.82' FEL & 4275.96' FNL 07/20/03 SRB /TLH ADD PERFS 08/03/07 014 RWO BP Exploration (Alaska) • TREE = 4- 1 /165KGray 07-08 B SAFETY NOTES' WELLHEAD =Grey New Std ACTUATOR= • PROPOSED • KB. ELEV = 55.5' BF. api = _ ' , I 2100' H 4 -1/2" X -NIP ID =3.813 KOP= 8260' Max Angle = 90 © 9955' GAS LIFT MANDRELS Datum MD = 9736' ST MD TV D DEV TYPE V LV LATCH PORT DATE Datum TV D = 8800' SS I 1 1 13 - 3/8" CSG, 724, N - 80, ID = 12.347" H I 2712' 8110' (-i7" LNR Top Packer (BOT HCM/ZXP) I I 8260' I — I KOP / Top 9-5/8" Window I \ 4.5 ", 12.6#, 13-CR, VAM TOP, TBG. I `Fully Cemented Liner 15.8 ppg Class GI 9 5/8" EZSV Bridge Plug I-i 8284' I — ' Pre -Rig Jet Cut H 8310' I /I 8830' I — i4.5" HES X Landing Nipple ID= 3.813" I Expected Top of Cement I 8680' I I! I r 8870' I -17" x 4-1 /2' Baker 3-3 Packer I t Z 9 5/8" X 4 -1/2" BAKER S -3 Cr PKR H 8713' 1_ 1 I 8900' I —I4.5" HES X Landing Nipple ID 3.813" I I Cement Retainer I-L 8780' I 1 it L I 8930' I — I4.5" HES XN Landing Nipple ID= 3.75" / — ( 8940' H4.5' LNR Top Packer (BOT HCM/ZXP) I 9088' H7", 26#, L -80, BTC-M, Liner Ill I 9 -5/8" CSG, 47 #, N-80, ID = 8.681" H 9610' ♦ ♦ ♦ ♦ • • ♦ ♦ ♦ ♦ ♦ ♦♦ PERFORATION SUMMARY ♦ ♦ ♦ ♦ ♦ ♦ ♦♦ I 11124' I—I4.5 ", 12.6 #, L -80, Solid Liner I REF LOG: MEM CNL ON 02/04/99 ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ i / • ANGLE AT TOP PERF: 59 @ 9760' ♦ ♦ ♦ ♦♦ ♦ ♦ ♦ ♦ ♦♦ ♦♦ ♦♦ ♦♦ Note: Refer to Production DB for historical perf data 4 SIZE SPF INTERVAL Opn/Sqz DATE ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦4 I CIBP SET 05/31/031 9920' 4,, TD I--I 10948' I 3- 3/16" LNR, 6.2 #, L -80, .0076 bpf, ID = 2.80" H 10937' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/09/79 ORIGINAL COMPLETION 08/02/07 SV DRLG CORRECTIONS WELL: 07 -08A 01/12/99 SIDETRACK (07 -08A) 09/29/07 RCT /TLH JUNK FROM RWO PERMIT No: 1 982440 05/15/01 RN/TP CORRECTIONS 12/19/07 NORDIC1 MILLED XN NIP (12/5/07) API No: 50- 029 - 20296 -01 05/31/03 SRB /TLP CLOSE/NEW PERFS, CIBP 05/13/08 EV 07 -088 PROPOSED SIDETRACK SEC 33, T1 1 N, R14E, 2905.82' FEL & 4275.96' FNL 07/20/03 SRB /TLH ADD PERFS 08/03/07 D14 RWO BP Exploration (Alaska) COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM • BP Amoco 2o- ordinate (N /E) Reference: Well Centre: 07 -08, True North Depth Fm Depth To Survey/Plan Tool Plan: 07 -08A Wp 2.0 (07 -08 /Plan 07 -08C RST) Vertical (TVD) Reference: 27.OGL +28.5KB 55.50 • Calculation Method: Minimum Curvature Section (VS) Reference: Slot -08 (0.00N,0.00E) 8260.00 11123.76 Planned: 07 -08A Wp 2.0 V5 MWD +IFR +MS Created By Sperry Drilling Date: 4/22/2008 Error System: ISCWSA Measured Depth Reference: 27.0GL +28.5KB 55.50 \ Scan Method: Tray Cylinder North Calculation Method: Minimum Curvature • Error Surface: Elliptical + Casing WELL DETAILS Warning Method: Rules Based Name +N / -S +E / -W Northing Easttng Latitude Longitude Slot ■ RT _ ■ I - 07 -08 1592.28 - 1309.40 5949705.67 676035.82 70 °16'05.506N 148 °34'35.047W 08 ,v � i jI TARGET DETAILS Sperry Drilling Services I 1 - - _. Name TVD +N / -S +E/-W Northing Easting Shape 07 -08A T1 9015.50 2150.24 1488.96 5951890.00 677474.00 Point 2521 ' ' 07 -08A T2 9015.50 1311.86 2305.64 5951071.00 678310.00 Point t __ 07 -08A T2 rev 1 9015.50 1286.61 2273.03 5951045.00 678278.00 Point - - - -- - -. - - -- -- + ._ --- -. _! 07 - 08 (0 i 90(0 9000 CASING DETAILS Start [a No. TVD MD Name Size rt Dir 16° /100' : 9476.04' MD, 8754'9'TVD _ 2268 - 1 8396.50 9088.00 7" 7 ■ 2 9015.50 11123.75 4 1/2" 4.5 ��� .---- 8500 9 000 __ 0 7 -08A TI _. ._ _ - -'■ - - - -- End Dir : 8594.94' MD, 794L8V " REM IMO End Dir : - -_. - -'- - - - - -. .- - - -�� 1007 ".22' MD, 9015.5' TVD ME MEM _ 8000 _ . .. - t - - - I - -- Start Dir 4°/100' : 1280' MD,7658.15'TVD - - -_ __ -..•_, 2016 I III 1 _ - MEIN Start Dir 12° /100: 8:60' MD, 7640.67TVD - -- - ••••• -. low , o - --- I- 500 i M _ E MIME - .c - a - 0 O 1764 - I- 000 .. - -- -- - 11 1512 i , : - - -' -- -- -:_' -' ! - - - r - - - - -- - -�_ ��■ _ : f ���� . M . 'a - .. � � i •••�■ r II. 07-08A �■ ! :soo 1 f 1 1 t 1 11111 1 ■ ■ ■ CI • ■� I • � NO - : 111111 FORMATION TOP DETAILS 1111 I - Plan )7 -08C RST Total Dc No TVDPath MDPath Formation Depth :11123.76 MD, 9015.5' TVD j �_� = �8A T2 rev 1 0 - (18A Wn2 (1 1 7721.50 8351.97 THRZ i i 1 1 i ' 1 2 7879.50 8527.04 BHRZ r . SECTION DETAILS 3 7904.50 8554.31 LCU/TJD - 4 8079.50 8744.19 TJC - 1 - -mo Sec MD Inc Azi TVD +N / - S +E/ - W DLeg TFace VSec Target 5 8212.50 8888.44 TJB - �- I 6 8310.50 8994.73 TJA ' 1 8260.00 28.95 36.58 7640.67 2022.10 716.94 0.00 0.00 1620.00 ----- - - - - -- - - - - -_ - _ - - - - -- - 2 8280.00 29.24 41.48 7658.15 2029.65 723.06 12.00 85.00 1629.05 8 8505.50 9206.21 TSAD 7 8396.50 9088.00 TSGR -- -- - F I I 3 8594.94 22.77 66.47 7941.89 2111.95 830.34 4.00 1 31.42 1762.95 I 4 9476.04 22.77 66.47 8754.29 2248.11 1143.07 0.00 9 8668.50 9383.00 TCGL F-{ 5 9955.39 90.00 120.00 9015.50 2150.24 1488.96 16.00 55.72 2354.98 07-08A TI I 10 8748.50 9469.76 BCGL + I 6 10072.22 90.00 138.69 9015.50 2076.50 1578.91 16.00 90.00 2396.93 11 8801.50 9528.33 23SB I - J I 7 11123.76 90.00 138.69 9015.50 1286.61 2273.03 0.00 0.00 2611.91 07 -08A T2 rev I 12 8853.50 9589.78 22TS ' ' ' ' 13 8914.50 9671.72 21TS 756 1008 1260 1512 14 8986.50 9806.26 TZ1B West( -) /East( +, COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM • BP Amoco Co-ordinate (N /E) Reference: Well Centre: 07 -08, True North epth Fm Depth To Survey /Plan Tool Plan: 07 - 08A Wp 2.0 (07 - /Plan 07 - 08C RST) bP Vertical (TVD) Reference: 27.OGL +28.5KB 55.50 , Iculation Method: Minimum Curvature Section (VS) Reference: Slot - 08 (0.00N,0.00E) 260.00 I 1 123.76 Planned: 07 -08A Wp 2.0 V5 M W D +IFR +MS Created By Sperry Drilling Date: 4/22/2008 Error System: ISCWSA Measured Depth Reference: 27.0GL +28.5KB 55.50 Scan Method: Tray Cylinder North Calculation Method: Minimum Curvature s Error Surface: Elliptical + Casing WELL DETAILS CASING DETAILS Name +N / -S +E / -W Northing Easting Latitude Longitude Slot No. TVD MD Name Size 07 -08 1592.28 - 1309.40 5949705.67 676035.82 70 °16'05.506N 148 °34'35.047W 08 1 8396.50 9088.00 7" 7.000 SECTION DETAILS 2 9015.50 11123.75 41/2" 4.500 Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target I- IALLIBURTON 1 8260.00 28.95 36.58 7640.67 2022.10 716.94 0.00 0.00 1620.00 2 8280.00 29.24 41.48 7658.15 2029.65 723.06 12.00 85.00 1629.05 3 8594.94 22.77 66.47 7941.89 2111.95 830.34 4.00 131.42 1762.95 Sperry Drilling Services 4 9476.04 22.77 66.47 8754.29 2248.11 1143.07 0.00 0.00 2102.17 5 9955.39 90.00 120.00 9015.50 2150.24 1488.96 16.00 55.72 2354.98 07 -08A TI 6 10072.22 90.00 138.69 9015.50 2076.50 1578.91 16.00 90.00 2396.93 - 7 11123.76 90.00 138.69 9015.50 1286.61 2273.03 0.00 0.00 2611.91 07 -08A T2 rev I 7000 .. i - 7500 Start Dir 12 "/1 JO' : 8260' MD, 7640.67'T\ D i Start Dir 4 " /1(0' : 8280' MD, 7658.15'TV D rr -- - . - THRZ - BHRZ - `. End D r : 8594.94' MD, 7941,89' TVD - LCU/TJD c 8000 - __ ' I I - E I - TJC " 1 ] _ _ TJA k3 - 900 C > TSGR 2 8500 TSAD - . FORMATION TOP DETAILS I Start Dir le/100' : 9476.04' MD, 8754 29'TVD No. TVDPath MDPath Formation t TCGL - i 1 7721.50 8351.97 THRZ BCC- ,5c End Dir : 10072.22' MD, 9015.5' TVD 2 7879.50 8527.04 BHRZ 23 (B 3 7904.50 8554.31 LCU /TJD 22TS 4 8079.50 8744.19 TJC 2 P ITS �' g�� Total Depth : 11123.76' MD, 9015.5' TV ) 5 8212.50 8888.44 TJB TZ1D -' T2 rev I 6 8310.50 8994.73 TJA 07- 08(07 -08A) 7 8396.50 9088.00 TSGR 10000 4 I h t 1 i ' . Plan 07 -08C RS T 8 8505.50 9206.21 TSAD 07 -08A Wp 2.0 9 8668.50 9383.00 TCGL 07 -0$ (07 -OS) 10 8748.50 9469.76 BCGL 11 8801.50 9528.33 23SB 12 8853.50 9589.78 22TS 13 8914.50 9671.72 21TS 14 8986.50 9806.26 TZ I B TARGET DETAILS Name TVD +N / -S +E/ -W Northing Easting Shape 1 07 -08A TI 9015.50 2150.24 1488.96 5951890.00 677474.00 Point , , , , 1 , , , , i ∎ ∎ ∎ ∎ ∎ ∎ 1 I t I I I .."1" I ' ,, r_ 7 .... T 1"1"T 07 -08A T2 9015.50 1311.86 2305.64 5951071.00 678310.00 Point 07 -08A T2 rev I 9015.50 1286.61 2273.03 5951045.00 678278.00 Point 2000 2500 3000 1 " .1 ^0" Vertical Section at 60.49° [500ft/in] MIIIIMMIM Sperry -Sun • BP Planning Report Company: BP Amoco Date: 4/22/2008 Time: 14:43:52 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 07 -08, True North Site: PB DS 07 Vertical (TVD) Reference: 27.0GL +28.5KB 55.5 Well: 07 -08 Section (VS) Reference: Well (0.00N,0.00E,60.49Azi) Wellpath: Plan 07 -08C RST Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 07 -08A Wp 2.0 Date Composed: 4/3/2008 Version: 5 Principal: Yes Tied -to: From: Definitive Path 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 DS 07 TR -11 -14 UNITED STATES : North Slope Site Position: Northing: 5948144.78 ft Latitude: 70 15 49.847 N From: Map Easting: 677382.28 ft Longitude: 148 33 56.934 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.35 deg Well: 07 -08 Slot Name: 08 07 -08 Well Position: +N / -S 1592.28 if Northing: 5949705.67 ft Latitude: 70 16 5.506 N +E / -W - 1309.40 ft Easting : 676035.82 ft Longitude: 148 34 35.047 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 9088.00 8396.50 7.000 8.500 7" 11123.75 9015.50 4.500 6.125 4 1/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 CM1 0.00 0.00 8351.97 7721.50 THRZ 0.00 0.00 8527.04 7879.50 BHRZ 0.00 0.00 8554.31 7904.50 LCU/TJD 0.00 0.00 8744.19 8079.50 TJC 0.00 0.00 8888.44 8212.50 TJB 0.00 0.00 8994.73 8310.50 TJA 0.00 0.00 9088.00 8396.50 TSGR 0.00 0.00 9206.21 8505.50 TSAD 0.00 0.00 9383.00 8668.50 TCGL 0.00 0.00 9469.76 8748.50 BCGL 0.00 0.00 9528.33 8801.50 23SB 0.00 0.00 9589.78 8853.50 22TS 0.00 0.00 9671.72 8914.50 21 TS 0.00 0.00 9806.26 8986.50 TZ1B 0.00 0.00 0.00 HOT 0.00 0.00 Targets Map Map <- Latitude - - -> < -- Longitude ---> Name Description TVD +N / -S +E / -W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 07 -08A T1 9015.50 2150.24 1488.96 5951890.00 677474.00 70 16 26.652 N 148 33 51.694 W 07 -08A T2 9015.50 1311.86 2305.64 5951071.00 678310.00 70 16 18.404 N 148 33 27.924 W 07 -08A T2 rev 1 9015.50 1286.61 2273.03 5951045.00 678278.00 70 16 18.156 N 148 33 28.873 W Sperry -Sun • BP Planning Report Company: BP Amoco Date: 4/22/2008 Time: 14:43:52 Page: 2 Field: Prudhoe Bay Co- ordinate(NE) Reference: Well: 07-08, True North Site: PB DS 07 Vertical (TVD) Reference: 27.0GL +28.5KB 55.5 Well: 07 -08 Section (VS) Reference: Well (0.00N,0.00E,60.49Azi) Wellpath: Plan 07 -08C RST Survey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD Incl Azim TVD +N / -S +E / -W DLS Build Turn TFO Target ft deg deg ft ft ft deg /100ft deg /100ft deg /100ft deg 8260.00 28.95 36.58 7640.67 2022.10 716.94 0.00 0.00 0.00 0.00 8280.00 29.24 41.48 7658.15 2029.65 723.06 12.00 1.49 24.49 85.00 8594.94 22.77 66.47 7941.89 2111.95 830.34 4.00 -2.05 7.94 131.42 9476.04 22.77 66.47 8754.29 2248.11 1143.07 0.00 0.00 0.00 0.00 9955.39 90.00 120.00 9015.50 2150.24 1488.96 16.00 14.02 11.17 55.72 07 -08A T1 10072.22 90.00 138.69 9015.50 2076.50 1578.91 16.00 0.00 16.00 90.00 11123.76 90.00 138.69 9015.50 1286.61 2273.03 0.00 0.00 0.00 0.00 07 -08A T2 rev 1 Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Co ment ft deg deg ft ft ft ft ft deg/100ft ft ft 8260.00 28.95 36.58 7640.67 7585.17 1620.00 2022.10 716.94 0.00 5951743.85 676705.23 Start Dir 1 .'M 8280.00 29.24 41.48 7658.15 7602.65 1629.05 2029.65 723.06 12.00 5951751.54 676711.17 Start Dir 4° 13 8300.00 28.72 42.73 7675.64 7620.14 1638.24 2036.84 729.56 4.00 5951758.88 676717.50 MWD +IFR MS 8351.97 27.42 46.17 7721.50 7666.00 1661.73 2054.30 746.66 4.00 5951776.73 676734.19 THRZ 8400.00 26.29 49.62 7764.36 7708.86 1682.90 2068.85 762.75 4.00 5951791.66 676749.93 MWD +IFR ly1S 8500.00 24.26 57.70 7854.80 7799.30 1725.18 2094.19 797.00 4.00 5951817.79 676783.57 MWD +IFR MS 8527.04 23.78 60.09 7879.50 7824.00 1736.18 2099.87 806.42 4.00 5951823.69 676792.86 BHRZ 8554.31 23.35 62.59 7904.50 7849.00 1747.08 2105.10 815.98 4.00 5951829.14 676802.30 LCU/TJD 8594.94 22.77 66.47 7941.89 7886.39 1762.95 2111.95 830.34 4.00 5951836.32 676816.49 End Dir ::. 14 8600.00 22.77 66.47 7946.55 7891.05 1764.90 2112.73 832.14 0.00 5951837.15 676818.27 MWD +IFR MS 8700.00 22.77 66.47 8038.75 7983.25 1803.40 2128.19 867.63 0.00 5951853.42 676853.39 MWD +IFR PIS 8744.19 22.77 66.47 8079.50 8024.00 1820.41 2135.02 883.31 0.00 5951860.62 676868.91 TJC 8800.00 22.77 66.47 8130.96 8075.46 1841.90 2143.64 903.12 0.00 5951869.70 676888.51 MWD +IFR MS 8888.44 22.77 66.47 8212.50 8157.00 1875.95 2157.31 934.51 0.00 5951884.10 676919.57 TJB 8900.00 22.77 66.47 8223.16 8167.66 1880.40 2159.09 938.62 0.00 5951885.98 676923.63 MWD +IFR MS 8994.73 22.77 66.47 8310.50 8255.00 1916.87 2173.73 972.24 0.00 5951901.40 676956.89 TJA 9000.00 22.77 66.47 8315.36 8259.86 1918.90 2174.55 974.11 0.00 5951902.26 676958.75 MWD +IFR MS 9088.00 22.77 66.47 8396.50 8341.00 1952.78 2188.14 1005.34 0.00 5951916.58 676989.65 7 9100.00 22.77 66.47 8407.57 8352.07 1957.40 2190.00 1009.60 0.00 5951918.54 676993.87 MWD +IFR PIS 9200.00 22.77 66.47 8499.77 8444.27 1995.90 2205.45 1045.09 0.00 5951934.82 677028.99 MWD +IFR MS 9206.21 22.77 66.47 8505.50 8450.00 1998.29 2206.41 1047.30 0.00 5951935.83 677031.17 TSAD 9300.00 22.77 66.47 8591.97 8536.47 2034.40 2220.91 1080.59 0.00 5951951.09 677064.10 MWD +IFR MS 9383.00 22.77 66.47 8668.50 8613.00 2066.35 2233.73 1110.05 0.00 5951964.60 677093.25 TCGL 9400.00 22.77 66.47 8684.18 8628.68 2072.90 2236.36 1116.08 0.00 5951967.37 677099.22 MWD +IFR MS 9469.76 22.77 66.47 8748.50 8693.00 2099.76 2247.14 1140.84 0.00 5951978.73 677123.72 BCGL 9476.04 22.77 66.47 8754.29 8698.79 2102.17 2248.11 1143.07 0.00 5951979.75 677125.93 Start Dir 1 :11 9500.00 25.12 73.95 8776.19 8720.69 2111.74 2251.37 1152.21 16.00 5951983.22 677134.99 MWD +IFR MS 9528.33 28.30 81.16 8801.50 8746.00 2123.87 2254.06 1164.63 16.00 5951986.21 677147.35 23SB 9589.78 36.12 92.44 8853.50 8798.00 2152.94 2255.54 1197.20 16.00 5951988.44 677179.87 22TS 9600.00 37.50 93.90 8861.68 8806.18 2158.09 2255.20 1203.31 16.00 5951988.24 677185.99 MWD +IFR MS 9671.72 47.59 102.04 8914.50 8859.00 2196.26 2248.17 1251.15 16.00 5951982.33 677233.97 21 TS 9700.00 51.69 104.53 8932.81 8877.31 2212.05 2243.21 1272.11 16.00 5951977.86 677255.04 MWD +IFR MS 9800.00 66.52 111.57 8984.05 8928.55 2269.44 2216.33 1353.26 16.00 5951952.89 677336.80 MWD +IFR MS 9806.26 67.46 111.95 8986.50 8931.00 2273.05 2214.19 1358.61 16.00 5951950.88 677342.20 TZ1B 9900.00 81.61 117.14 9011.45 8955.95 2325.81 2176.64 1440.50 16.00 5951915.26 677424.93 MWD +IFR MS 9955.39 90.00 120.00 9015.50 8960.00 2354.98 2150.24 1488.96 16.00 5951890.00 677474.00 07 -08A T1 10000.00 90.00 127.14 9015.50 8960.00 2375.16 2125.59 1526.11 16.00 5951866.23 677511.70 MWD +IFR MS 10072.22 90.00 138.69 9015.50 8960.00 2396.93 2076.50 1578.91 16.00 5951818.39 677565.63 End Dir : 1 X17 10100.00 90.00 138.69 9015.50 8960.00 2402.61 2055.63 1597.25 0.00 5951797.96 677584.45 MWD +IFR S 10200.00 90.00 138.69 9015.50 8960.00 2423.06 1980.51 1663.26 0.00 5951724.41 677652.20 MWD +IFR S 10300.00 90.00 138.69 9015.50 8960.00 2443.50 1905.40 1729.27 0.00 5951650.86 677719.94 MWD +IFR MS 10400.00 90.00 138.69 9015.50 8960.00 2463.94 1830.28 1795.28 0.00 5951577.31 677787.69 MWD +IFR MS 10500.00 90.00 138.69 9015.50 8960.00 2484.39 1755.16 1861.29 0.00 5951503.76 677855.43 MWD +IFR MS • Sperry -Sun • • BP Planning Report Company: BP Amoco Date: 4/22/2008 Time: 14:43:52 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 07 -08, True North Site: PB DS 07 Vertical (TVD) Reference: 27.0GL +28.5KB 55.5 Well: 07 -08 Section (VS) Reference: Well (0.00N,0.00E,60.49Azi) Wellpath: Plan 07 -08C RST Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Intl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Co nent ft deg deg ft ft ft ft ft deg/100ft ft ft 10600.00 90.00 138.69 9015.50 8960.00 2504.83 1680.05 1927.30 0.00 5951430.22 677923.18 MWD +IFR MS 10700.00 90.00 138.69 9015.50 8960.00 2525.27 1604.93 1993.31 0.00 5951356.67 677990.92 MWD +IFR MS 10800.00 90.00 138.69 9015.50 8960.00 2545.72 1529.81 2059.32 0.00 5951283.12 678058.67 MWD +IFR NIS 10900.00 90.00 138.69 9015.50 8960.00 2566.16 1454.69 2125.33 0.00 5951209.57 678126.41 MWD +IFR MS 11000.00 90.00 138.69 9015.50 8960.00 2586.61 1379.58 2191.34 0.00 5951136.02 678194.16 MWD +IFR IfIS 11100.00 90.00 138.69 9015.50 8960.00 2607.05 1304.46 2257.35 0.00 5951062.47 678261.90 MWD +IFR MS 11123.76 90.00 138.69 9015.50 8960.00 2611.91 1286.61 2273.03 0.00 5951045.00 678278.00 07 -08A T2 ev 1 WELL DETAILS ANTI - COLLISION SETTINGS COMPANY DETAILS SURVEY PROGRAM • Name -N / -S -FJ -W Northing Easing Latitude Longitude Slot BP Amoco Depth Fm Depth To Survey /Plan Tool Interpolation Method:MD Interval: 25.00 07 - 08 1592.28 - 1309.40 5949705.67 676035.82 70 148 °34'35.047W 08 Depth Range From: 8260.00 To: 11123.76 Calculation Method: Minimum Curvatmc 8260.00 1112376 Planned: 07 - 08A Wp 20 V5 MWD• IFR . MS Maximum Range: 1309.53 Reference: Plan: 07 - 08A Wp 2.0 Emir system: ISCWSA Scan Method: Trav Cylinder Nonh Error Surface: Elliptical Casing Warring Method: Rules Based ` 0 WF.LLPATII DETAILS - 160 V i Plan 07 -08C RST Fr om Colour To MD - 150 liftiiiiiipip 250 Paente 07 -08 250 SOO Tie on MD: 8260.00 331 0 500 750 Ref Dann. 27.OGL- 28.5KB 55.508 750 1000 V.Sectioe Origin Origin Starting 1000 1250 Angie +N / -S -FJ -W From TVD -125 um 1500 60.49° 0.00 0.00 28.50 1500 1750 1750 2000 2000 2250 2250 2500 LEGEND - . 1 OO • • 2750 2775 80 ■ 57-32 07 -f 07A 017- 07AMMaj Risk 2750 300 00 07-07A ( -078), Ma r Risk 07 -08 (07 -08), NOERRORS 3000 3250 -� 07 -08 (07 -08AL NOERRORS - 07.06 Plan 5, 07 -08B CTD1, NOERRORS 351 �� ,1 ..00-' ..00-' � � 4000 - •• 3250 -. - 3500 - o7- 1sio7- 1sk Major wsk 732APB1 -75 17 07.171, a jor Risk 07.27 07 -27 , Major Risk � . �+ � 07 � or Risk 07 -32 07.32.0), Major Risk •' ( ), Major Risk • • • (:505 s275 0 07- 32(07 -328), Major Risk 07 -32 (07 -32PB 11. Major Risk • 0 8500 - 0736 (07-36), Major Risk -50 - Plan 07 -O8C RST i` I I 0775 - 07 -08A Wp 2.0 8 14, 9 505 9011 9250 F:86 92'0 9500 951 9750 1 25 97511 10000 Il ly ii 0 270 90 -25 ; . • y \ \ \v y \� - 50 s -75 • 240 120 - 100 I , Pre Plans Removed. See AC Scan for Plans Parents Profile @ No Errors - 125 SECTION DETAILS Sec MI) Inc Azi TVD -N / -9 +E/ -W DLeg TFace VS. Target 211 50 I 8260.00 28.95 36.58 7640.67 2022.10 716.94 0.00 0.00 1620.00 2 828000 29.24 41.48 7658.15 2029.65 723.06 1200 85.00 1629.05 3 859494 22.77 6647 7 2111.95 830.34 4.00 131.42 1762.95 -150 1 4 9476.04 22.77 6647 875429 224811 1143.07 0.01 0.01 2102.17 5 9955.39 90.00 120.00 9015.50 2150.24 1488.96 16.00 55.72 2354.98 07 -08A TI 6 1007222 90.60 138,69 9015.50 2076.50 1578.91 16.00 90.00 2396.93 -160 181 3 , 7 11 123.76 v90.00 138.69 9015.50 1286.61 2273.03 0.00 0.00 2611.91 07 -08A T2 rev 1 • Travelling Cylinder Azimuth (TFO +AZI) [deg] vs Centre to Centre Separation '[5oft/in] • W Sperry -Sun Anticollision Report Company: BP Amoco Date: 4/22/2008 Time: 13:36:59 Page: 1 Field: Prudhoe Bay Reference Site: PB DS 07 Co- ordinate(NE) Reference: Well: 07 -08, True North Reference Well: 07 -08 Vertical (TVD) Reference: 27.0GL +28.5KB 55.5 Reference Wellpath: Plan 07 -08C RST Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100 /1000 of reference - There are TklSidlraails in this fRtiticipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 8260.00 to 11123.76 ft Scan Method: Trav Cylinder North Maximum Radius: 1309.53 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 4/3/2008 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 91.50 8260.00 2 : Gyrodata cont.drillpipe m/ (91.50- 9991.50)IP)D- CT -DMS Gyrodata cont.drillpipe m/s 8260.00 11123.76 Planned: 07 -08A Wp 2.0 V5 MWD +IFR +MS MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft if in in 9088.00 8396.50 7.000 8.500 7" 11138.00 0.00 4.500 6.125 4 1/2" Summary <--- - - - - -- Offset Wellpath ---- - - - - -> Reference Offset Ctr -Ctr No -Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning if ft ft ft ft PB DS 07 07 -06 07 -06B V6 10626.17 10401.00 843.83 133.10 710.73 Pass: Major Risk PB DS 07 07 -07A 07 -07A V2 Out of range PB DS 07 07 -07A 07 -07B V4 Out of range PB DS 07 07 -08 07 -08 V2 8266.50 8275.00 0.04 0.65 -0.61 FAIL: NOERRORS PB DS 07 07 -08 07 -08A V2 8266.50 8275.00 0.04 0.65 -0.61 FAIL: NOERRORS PB DS 07 07 -08 Plan 5, 07 -08B CTD V4 10708.99 10850.00 0.38 3.17 -2.78 FAIL: NOERRORS PB DS 07 07 -15 07 -15 V1 8276.83 8425.00 1189.81 175.12 1014.69 Pass: Major Risk PB DS 07 07 -17 07 -17 V1 Out of range PB DS 07 07 -27 07 -27 V1 8267.08 8225.00 1045.25 112.71 932.54 Pass: Major Risk PB DS 07 07 -32 07 -32 V1 8260.00 8350.00 1105.65 152.16 953.49 Pass: Major Risk PB DS 07 07 -32 07 -32A V1 8260.00 8350.00 1105.65 152.16 953.49 Pass: Major Risk PB DS 07 07 -32 07- 32APB1 V1 8260.00 8350.00 1105.65 152.13 953.52 Pass: Major Risk PB DS 07 07 -32 07 -32B V2 8260.00 8350.00 1105.65 152.03 953.62 Pass: Major Risk PB DS 07 07 -32 07 -32PB1 V1 8260.00 8350.00 1105.65 151.98 953.67 Pass: Major Risk PB DS 07 07 -36 07 -36 V2 9600.00 13650.00 1056.52 214.77 841.75 Pass: Major Risk Site: PB DS 07 Well: 07 -06 Rule Assigned: Major Risk Wellpath: 07 -06B V6 Inter -Site Error: 0.00 ft Reference Offset Semi -Major Axis Ctr -Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO +AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11121.54 9015.50 9900.00 9024.00 14.74 17.84 229.25 90.56 4.500 918.47 130.13 788.34 Pass 11096.88 9015.50 9925.00 9024.39 14.63 17.95 229.28 90.59 4.500 914.38 130.11 784.27 Pass 11072.18 9015.50 9950.00 9024.71 14.52 18.08 229.30 90.61 4.500 910.56 130.16 780.40 Pass 11047.44 9015.50 9975.00 9024.97 14.41 18.21 229.32 90.63 4.500 906.93 130.21 776.72 Pass 11022.71 9015.50 10000.00 9025.09 14.30 18.34 229.33 90.64 4.500 903.27 130.27 773.00 Pass 10998.00 9015.50 10025.00 9025.05 14.18 18.48 229.33 90.64 4.500 899.46 130.32 769.14 Pass 10973.32 9015.50 10050.00 9024.82 14.08 18.61 229.32 90.63 4.500 895.50 130.38 765.12 Pass 10948.66 9015.50 10075.00 9024.45 13.97 18.75 229.30 90.61 4.500 891.42 130.46 760.96 Pass 10923.98 9015.50 10100.00 9024.10 13.86 18.89 229.28 90.59 4.500 887.42 130.56 756.86 Pass 10899.29 9015.50 10125.00 9023.81 13.76 19.04 229.26 90.57 4.500 883.53 130.67 752.86 Pass 10874.58 9015.50 10150.00 9023.58 13.66 19.19 229.25 90.56 4.500 879.74 130.78 748.96 Pass 10849.85 9015.50 10175.00 9023.36 13.56 19.37 229.24 90.55 4.500 876.06 131.00 745.05 Pass 10825.12 9015.50 10200.00 9023.07 13.45 19.56 229.22 90.53 4.500 872.42 131.26 741.17 Pass 10800.38 9015.50 10225.00 9022.69 13.35 19.75 229.20 90.51 4.500 868.84 131.51 737.33 Pass 10775.63 9015.50 10250.00 9022.22 13.26 19.94 229.17 90.48 4.500 865.31 131.77 733.53 Pass 10750.89 9015.50 10275.00 9021.78 13.16 20.15 229.14 90.45 4.500 861.79 132.10 729.69 Pass 10726.14 9015.50 10300.00 9021.47 13.06 20.36 229.12 90.43 4.500 858.25 132.42 725.83 Pass Alaska Department of Natural Resources Land Administration System Page 1 of 2 • Records/Status Plats Recorder's Search State Cabins Natural Rasou Imes Alaska DNR Case Summary File Type: ADL File Number: I 28309 a Printable Case File Summary See Township, Range, Section and Acreage? NOW Search a Yes No LAS Menu !Case Abstract 1 Case Detail 1 Land Abstract A kt, File: ADL 28309 ',AJ Search for Status Mat Updates As of 09/04/2008 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 . Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primaty Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA ASSIGNMENT APPROVED Meridian: U Township: 011N Range: 014E Section: 27 Section Acres: 640 Search Plats Meridian: U Township: 01 IN Range: 014E Section: 28 Section Acres: 640 Meridian: U Township: 01 IN Range: 014E Section: 33 Section Acres: 640 Meridian: U Township; 01 IN Range: 014E Section: 34 Section Acres: 640 Legal Description 05-28-1965 * * *SALE NOTICE LEGAL DESCRIPTION* * * C14-130 I 1N 14E UM 27,28,33,34 2560.00 U- 3- 7 12-01-1986 ***LISBURIVE PARTICIPATING AREA *** T 111V.,R. 14E., UM SECTION 27: ALL 640 ACRES http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=-28309&... 9/4/2008 1 TRANSMITTAL LETTER CHECKLIST WELL NAME '4'4" O.reg PTD# 472070/ 99' �� / �� � 9-4/-or gel / Development, Service Exploratory Stratigraphic Test Non- Conventional Well FIELD: . Xfy POOL: _ f .4,4/4E__XVY• Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT 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 No. 50- - API number are 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(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject 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. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 07 -08B Program DEV Well bore seg ❑ PTD#: 2070190 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV / 1 -OIL _GeoArea 890 Unit 11650 On /Off Shore On Annular Disposal ❑ Administration '1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well narne and number Yes 4 Well located in a defined pool Yes Prudhoe Bay Field _/ Prudhoe Bay Pool. 5 Well located proper distance from drilling unitboundary Yes 6 Welllocated proper distance from other wells Yes 7 Sufficient acreage ayail_able in_drilling unit Yes 2560 acres. 8 lf_deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has. appropriate bond in force Yes Blanket Bond # 6164193. 11 Permit can be issued without conservation order Yes Appr Date 112 Permit can be issued without administrative_approval Yes ACS 9/4/2008 13 Can permit be approved before 15-day wait Yes 14 Welllocated within area and_strata authorized by Injection Order # (put IO# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre- produced injector: duration of pre - production less than 3 months (For service well only) _ _ _NA 17 Nonconven, gas_conforrns to AS31,05 030(ta.A),(j_.2.A -D) NA Engineering 18 Conductor string_provided NA Conductor set in 07 -08 078 -016). 19 Surface_casingproteets all known USDWs NA Surface casing set in 07 -08. 20 CMT v_ol adequate to circulate_on conductor & surf csg NA Surface casing set in 07 -08. 21 CMT_vol adequate to tie- inlong string to surf csg NA Production casing set in 07 -08. 22 CMT will cover all knownproductive horizons Yes 23 Casing designs adequate for C,_T, B & permafrost Yes 24 Adequate tankage_or reserve pit Yes Rig is equipped with steel_pits. No reservepitplanned, All waste to_approved disposal well(s). 25 if_a_re- drill, has 10-403 for abandonment been approved Yes 307 -051 26 Adequate wellbore separationproposed Yes Proximity analysis performed, Close approaches identified._ Nearest segment is existing well &_ paths diverge._ 27 if_diverter required, does _it _meet regulations NA BOP stack will be in place. Appr Date 28 Drilling fluid program schematic_$ equip list adequate Yes Maximum expected formation pressure 7.9 EMW in 8.5" hole. Planned MW 10.1 ppg, 8,7 ppg in zone. TEM 9/10/2008 29 BOPEs,_do they meet regulation Yes • A � 30 BOPE_press rating appropriate; test to_(pot psig in _comments) Yes MASP calculated at 2622 psi. 3500 psi BOP test planned. 31 Choke_manifold complies w /API_ RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 is presence of H2S gas probable Yes H2S is reported on DS 07. Mud should preclude on rig. Rig has sensors and alarms. 34 Mechanical_condition of wells within AOR verified (For service well only NA Geology 35 Permit can be issued w/o hydrogen sulfide measures Nio Max Level H2S Pad P3 7 =50ppm well 07-24(5/15/05). 36 Data_presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones NA ACS 9/4/2008 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekiy_progress reports [exploratory only] NA Geologic Date: Engineering Date ublic Date This is a Revised Permit to Drill original PTD 2070190 from 2/14/07 (ACS). Commissioner: Commissioner: Co' C ' '•ner 411 .. ._ S 117E [11.! /4\[LASEA SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALAS ' !9501-3539 PHONE (907) 279 433 FAX (907) -7542 Garret Staudinger CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, P l VI i ' -08B BP Exploration (Alaska), Inc. ' I Permit No: 207 -019 Surface Location: 1215' FNL, 166' F kitC. 33, T11N, R14E, UM Bottomhole Location: 89' FSL, 212 ; L, SEC. 27, T11N, R14E, UM a Dear Mr. Staudinger: Enclosed is the approved applica o or permit to redrill the above referenced development well. O This permit to drill does no - mpt you from obtaining additional permits or an approval required by om other governmental agencies and does not authorize conducting dr* li 4 operations until all other required permits and approvals have been is d. In addition, the Commission reserves the right to withdraw the permit . event it was erroneously 'issued. Operations must • . 1 onducted in accordance with AS 31.05 and Title 20, Chapter 25 of + . Alaska Administrative Code unless the Commission specifically a t.17zes a variance. Failure to comply with an applicable provision of 0 .05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Com s . order, or the terms and conditions of this permit may result in the re on or suspension of the permit. When providing notice for a represe . a e of the Commission to witness any required test, contact the Com 'ssi 's petroleum field inspector at (90 6.9 -3607 (pager). d or / l Jo ' � � . . rman hai - . n DATED this /� day of February, 2007 cc: Department of Fish as Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA �- 7-07 RECEIVED AND GAS CONSERVATION COMMI�)N PERMIT TO DRILL t FEB 0 6 2001 20 AAC 25.005 Alaska Oil & Gas Cons. Commjss,on 1 a. Type of work 1 b. Current Well Class ❑ Exploratory ❑ Development Gas 1 c. Specify if well is proposklitgorage ❑ Drill IEI Redrill ❑ Service ❑ Multiple Zone ❑ Coalbed Methane ❑ Gas Hydrates 1:1 Re-Entry ❑ Stratigraphic Test ® Development Oil ❑ Single Zone ❑ Shale Gas 2. Operator Name: 5. Bond: ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 PBU 07 - 08B 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 -6612 MD 11250 TVD 8960ss Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028309 1215' FNL, 166' FEL, SEC. 33, T11N, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1079' FSL, 984' FWL, SEC. 27, T11N, R14E, UM May 10, 2007 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 89' FSL, 2122' FWL, SEC. 27, T11N, R14E, UM 2560 36,300' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool: Surface: x - 676036 y- 5949706 Zone -ASP4 (Height above GL): 64 feet 800' 16. Deviated Wells: Kickoff Depth: 9685 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 95 degrees Downhole: 3270 Surface: 2390 18. Casino Proaram: Specifications Top - Bettina Depth - Bottom Quantity of Cement. c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2 -3/8" 4.7# L -80 TCII / STL 1850' 9400' 8550' 11250' 8960' 44 sx Class 'G' 19, PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re - entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 10948 9023 9920 9920 8949 None Casing Length ize Cement Volume MD TVD Conductor / Structural 119' 20" 271 sx Arcticset 119' 119' Surface 2712' 13 - 3/8" 3700 sx Arcticset II 2712' 2712' Intermediate 9610' 9 -5/8" 1200 sx Class 'G' 9610' 8781' Production Liner 1978' 3 -1/2" x 3- 3/16" 96 sx LARC 8968' - 10946' 8250' - 9022' Perforation Depth MD (ft): 9760' - 10907' Perforation Depth TVD (ft): 8878' - 9017' 20. Attachments ® Filing Fee, $100 ® BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat ❑ Diverter Sketch ❑ Seabed Report ® Drilling Fluid Program CO 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Garret Staudinger, 564 - 4242 Printed Name Garret Staudinger Title CT Drilling Engineer Prepared By Name /Number: Signature 14 a Z Phone 564 -4242 Date � 6,�0 7 Terrie Hubble, 564 -4628 \ Commission Use On! Permit To Drill API Number: Permit Approval See cover letter for Number: c.7O,'0/9 50 - 029 - 20296 - - Date: 2/ 14/(37 other requirements Conditions of Approval: 1 If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: u �� � Samples Req'd: Di Yes 1 No Mud Log Req'd: ❑ Yes IiNo t V H Measures: Ye ❑ , o Directional Survey Req'd: til Yes ❑ No Other: /4 APPROVED BY THE COMMISSION I� Date Q) ` 07°'.--- if dri , COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate Li RIG1\ L ♦ 1 0 BP Prudhoe Bay 07 -08B CTD Sidet •k CTD Sidetrack Summary Pre -Rig Work: (Scheduled to begin March 15, 2007) 1) S Drifted liner to 9801' SLM July 1, 2006 2) S Passed tubing caliper inspection July 1, 2006 3) 0 Passed MIT -IA and MIT -OA. July 11, 2006 4) 0 AC –LDS; AC- PPPOT -IC, T 5) E Set Cast Iron Bridge Plug at 9750' �10� 6) E Set 3- 3/16" Baker Monobore WS w/ LS orientation at 9685' 3 0\A— (35 \ ` 7) 0 Set BPV 8) 0 PT MV, SV, WV 9) 0 Bleed gas lift and production flowlines down to zero and blind flange 10) 0 Remove wellhouse, level pad - Rig Work: (Scheduled to begin May 10, 2007) 1) MIRU Nordic 1 and test BOPE to 250psi low and 3500psi high. vii, Mill 2.74" window at 9685' and 10' of rathole. Swap the well to Flo -Pro. 3) Drill Build: 3.0" OH, 465' (30 deg /100 planned) 1 '7 4) Drill Lateral: 3.0" 011, 1100' (12 deg /100 planned) 5) MAD pass with resistivity tools in memory mode CiArj 6) Run 2 -3/8" solid liner leaving TOL at 9400' 7) Pump cement leaving TOC at 9400' 8) Cleanout liner and MCNL /GR/CCL log 9) Test liner lap to 2000 psi 10) Perforate liner per asset instructions ( -800') 11) Well will be left with extra diesel in the fluid column to lighten the load for initial kickoff. 12) Freeze protect well and RDMO Post -Rig Work: 1) Install well house, flow line and gas lift valves. 2) Test Separator (-800' of perfs) Mud Program: • Well kill: 8.6 ppg brine • Milling /drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole Size: • 3.0" Casing Program: Fully cemented liner • 2 -3/8 ", 4.7 #, L -80, TCII or STL 9400'MD – 11250'MD • A minimum of 9 bbls 15.8 ppg cement will be used for liner cementing. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • • See attached directional plan. Max. planned hole angle is 95 deg/ • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - • Distance to nearest property — 36,300 ft. North • Distance to nearest well within pool — 800 ft. (07 -17) - Logging • MWD directional, gamma ray, and resistivity will be run over all of the open hole section. • A cased hole MCNL /GR/CCL log will be run Hazards • The maximum recorded H2S level on A Pad is 75 ppm (07 -22 on 02/13/01)./ • Lost circulation risk is low. Reservoir Pressure • Res. press. is estimated to be 3270 psi at 8800'TVDss (7.2 ppg EMW). Max. surface pressure with gas (0.10 psi /ft) to surface is 2390 psi. ° TREE =' ;RAY GEN 2 WELLHEAD = GRAY 0 � 0 8A SAFETY NOTES: ACTUATOR = AXELSON KB. ELEV = 64' BF. ELEV = KOP= 4165' Max Angle = 36 @ 10444' Datum MD= 9736' Datum TVD = 8800' SS ® I 2151' H5 -1/2" CAMCO BAL -O SSSV NIP, ID= 4.581" I I 13 -3/8" CSG, 72#, N-80, ID = 12.347" H 2712' Minimum ID = 2.80" @ 8998' I 8718' H 5 -1/2" BAKER SLIDING SLV, ID = 4.313" I TOP OF 3- 3/16" LNR 1 1 1 8804' H 5-1/2" BAKER LANDING NIP, ID = 4.223" I 1 8853' H 5 -1/2" BAKER SBR ASSY, ID = 4.875" CI 1 8903' 1-19-5/8" X 5-1/2" BAKER SA B PKR, ID = 4.223" I (TOP OF 4-1/2" TBG H 8915' I 8915 H 5 -1/2" X 4.1/2" XO I I 5-1/2" TBG, 17 #, L -80, .0232 bpf, ID= 4.95" H 8915' I 8981' H 3-314" X 3" BAKER DEPLOY SLV, ID = 3.000" I 'TOP OF3 - 1/2" LNR H 8965' 1--i , I 8975' H4 -1/2" BAKER NIP, ID = 3.759" (BEHIND 3-112" LNR) 13 -1 /2" LNR, 9.3#, L -80, .0087 bpf, ID = 2.992" H 8998' 1 . 8998' H 3 X 3 - 3/16" XO, ID = 2.992" I 'TOP OF 3 3/16" LNR H 8998' I TOP OF CEMENT H 9024' I •♦ V4, 1 4-1/2" TBG, 12.6#, L -80, .0152 bpf, ID = 3.958" H 9036' t V I 9035' I 4 -1 /2" SHEAR OUT SUB, ID = 4.125" • • ' ► i (BEHIND 3- 3/16" LNR), 9-5/8" CSG, 47 #, N-80, ID = 8.681" H 9610' 1 ♦A•4 ► -• -• • • ∎∎ '��� MLLOUT WINDOW - 9610' - 9620' PERFORATION SUMMARY * * * * * * * * * ** / REF LOG: MEM CNL ON 02104/99 �••••••••••••••. 9920' H CIBP SET 05/31/03 I ANGLE AT TOP PERF: 59 @ 9760' • ■ • •• •• •• •• •• • ••/ 10903' — PBTD - BAKER LANDING Note: Refer to Production DB for historical perf data • • ♦ • SIZE SPF INTERVAL OpnlSgz DATE •j•�•�•�•�•�•�• •• COLLAR, ID = 2.992" 2 -1/4" 6 9760 - 9779 0 07/20/03 • • • • • • • • • 1 2 -1/4" 6 9782 -9802 0 05/31/03 nt∎Wetet i A N 2" 4 10299 -10576 C 02/05/99 41,, 10932" I BAKER FLOAT SHOE I 2 4 10768 -10907 C 02/05/99 ! 0���, 1 TD H 10948' 1 13-3/16" LNR. 6.2#. L- 80..0076 bof. R= 2.80" H 10937' I ATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/09179 ORIGINAL COMPLETION 12/21/06 OOBIPAG CORRECT 9-5/8" CSG DEPTH WELL: 07 -08A 01112/99 SIDETRACK (07 -08A) PERMIT No: 1982440 05/15/01 RNITP CORRECTIONS API No: 50 -029- 20296 -01 05/31/03 SRB/TLP CLOSE/NEN PERFS, CIBP SEC 33, T11 N, R14E, 2905.82' FEL & 4275.96' FNL 07/20/03 SRBI LH ADD PERFS 09/10/03 CMO/TLP FERF ANGLE CORRECTION BP Exploration (Alaska) TREE _' 3RAY GEN 2 • 0 7 -0 8 B • SAFETY NOTES: WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 64' Proposed CTD Sidetrack BF. ELEV = KOP = 4165' Max Angle = 36 @ 10444' Datum MD = 9736' Datum TVD= 8800' SS O 2151' H5-1/2" CAMCO BAL -O SSSV NIP, ID= 4.581" 13 -3/8" CSG, 72 #, N -80, ID = 12.347" H 2712' I 8718' H 5 -1/2" BAKER SLIDING SLV, ID = 4.313" • 8804' — 1 5-1/2" BAKER LANDING NIP, ID = 4.223" / — I 8853' H 5 -1/2" BAKERSBRASSY, ID= 4.875" H 8903' H 9-5/8"x5-112' BAKER SAB PKR, ID = 4.223" TOP OF 4-1/2" TBG 8915' 8915' H 5 -1 /2" X 4-12" XO 5 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.95" — 8915' Il 8961' HI 3 -3/4" X 3" BAKER DEPLOY SLV, ID = 3.000" TOP OF 3-1/2" LNR H 8965' 8975' _I 4-1/2" BAKER NIP, ID = 3.759" 3-1/2" LNR, 9.3#, L -80, .0087 bpf, ID = 2.992" H 8998' I 8998' I (B +0 H+1§9 ID = 2.992" MI TOP OF 3 -3116" LNR — 8998' • 11 ∎•••. L 9035' I 4 -1/2" SHEAR OUT SUB, ID = 4.125" TOP OF CEMENT — 9024 'Si ��� )�'�'��1 4 •• (BEHIND 3- 3/16" LNR), 4 -12" TBG, 12.6#, L -80, .0152 bpf, ID = 3.958" H 9036' ♦�4�i ��•�' ♦•••••• ���� 9400' — Top of 2 -3/8" Liner �����.411 '•• *1 9 -5/8" CSG, 47 #, N 80, ID = 8.681" 9610' ( ♦�iiii••ii ∎iii 9400' — Top of Cement ����������� *It�� ** * *���:4 d • " 2 -3/8" cmt'ed and perfect 11250' M IL LO UT WINDOW - 9610' - 9620' � i � � i i ilt O iill teRRITAPPStOCk W / t;A tags PERFORATION SUMMARY 1 REF LOG: MEM CNL ON 02/04/99 ANGLE AT TOP PERF: 59 @ 9760' I Note: Refer to FYoduction DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/4" 6 9760 - 9779 solated propose() ■ 2-1/4" 6 9782 - 9802 solated proposed 9920' CIBP SET 05/31/03 I 2" 4 10299 - 10576 solated proposed 2" 4 10768 - 10907 solated proposed 10903' PBTD - BAKER LANDING COLLAR, ID = 2.992" 3 -3/16" LNR, 6.2#, L -80, .0076 bpf, ID = 2.80" 10937' r��� I 10937' — BAKER FLOAT SHOE TD 10948' ��a DATE REV BY COMMENTS " DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/09179 ORIGINAL COMPLETION 12/ 21 /06OOB /PAG CORRECT 9- 5 /8 " CSG DEPTH WELL 07 -08A 01/12/99 SIDETRACK(07 - 08A) PERMTNo: 1982440 05/15/01 RN/TP CORRECTIONS API No: 50- 029 - 20296 -01 05/31/03 SRB/TLP CLOSE/NEW PERFS, CIBP SEC 33, T11 N, R14E, 2905.82' FEL & 4275.96' FNL 07/20/03 SRB/TLH ADD PERFS 09/10/03 CMO/TLP PERF ANGLE CORRECTION BP Exploration(Alaska) • • 0 bp BP p BP Al BAKER Baker Hughes INTEQ Planning Report 1NTEQ Company: BP Amoco Date: 1/18/2007 Time: 14:54:27 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 07 -08, True North Site: PB DS 07 Vertical (TVD) Reference: 13 : 08 12/17/1978 00:00 64.0 Well: 07 -08 Section (VS) Reference: Well (0.00N,0.00E,150.00Azi) Wellpath: Plan 3, 07 -088 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: bggm2006 Site: PB DS 07 TR -11 -14 UNITED STATES : North Slope Site Position: Northing: 5948144.78 ft Latitude: 70 15 49.847 N From: Map Easting: 677382.28 ft Longitude: 148 33 56.934 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.35 deg Well: 07 -08 Slot Name: 08 07 -08 Well Position: +N / -S 1592.28 ft Northing: 5949705.67 ft Latitude: 70 16 5.506 N +E / - - 1309.40 ft Easting : 676035.82 ft Longitude: 148 34 35.047 W Position Uncertainty: 0.00 ft Wellpath: Plan 3, 07 -08B Drilled From: 07 -08A 500292029602 Tie -on Depth: 9645.77 ft Current Datum: 13 : 08 12/17/1978 00:00 Height 64.00 ft Above System Datum: Mean Sea Level Magnetic Data: 1/18/2007 Declination: 24.13 deg Field Strength: 57659 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N /-S +E/ -W Direction ft ft ft deg 37.00 0.00 0.00 150.00 Plan: Plan #3 Date Composed: 1/18/2007 copy Lamar's plan 3 Version: 6 Principal: Yes Tied -to: From: Definitive Path Targets Map Map <--- Latitude -> <--- Longitude ---> Name Description TVD +N / -S +E / -W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 07 -08B Polygon 64.00 2270.40 1697.84 5952015.00 677680.00 70 16 27.833 N 148 33 45.612 W - Polygon 1 64.00 2270.40 1697.84 5952015.00 677680.00 70 16 27.833 N 148 33 45.612 W - Polygon 2 64.00 1845.81 1887.98 5951595.00 677880.00 70 16 23.657 N 148 33 40.079 W - Polygon 3 64.00 1443.64 2188.68 5951200.00 678190.00 70 16 19.701 N 148 33 31.327 W - Polygon 4 64.00 1257.83 2434.41 5951020.00 678440.00 70 16 17.872 N 148 33 24.175 W - Polygon 5 64.00 1135.54 2316.51 5950895.00 678325.00 70 16 16.670 N 148 33 27.608 W - Polygon 6 64.00 1524.70 1930.48 5951275.00 677930.00 70 16 20.499 N 148 33 38.844 W - Polygon 7 64.00 1910.50 1474.35 5951650.00 677465.00 70 16 24.294 N 148 33 52.121 W - Polygon 8 64.00 2207.19 1406.27 5951945.00 677390.00 70 16 27.212 N 148 33 54.102 W 07 -08B Faultl 64.00 2534.17 1754.03 5952280.00 677730.00 70 16 30.427 N 148 33 43.974 W - Polygon 1 64.00 2534.17 1754.03 5952280.00 677730.00 70 16 30.427 N 148 33 43.974 W - Polygon 2 64.00 1777.49 2456.57 5951540.00 678450.00 70 16 22.983 N 148 33 23.525 W 07-08B Fault2 64.00 2052.28 1827.79 5951800.00 677815.00 70 16 25.688 N 148 33 41.830 W - Polygon 1 64.00 2052.28 1827.79 5951800.00 677815.00 70 16 25.688 N 148 33 41.830 W - Polygon 2 64.00 1849.64 1938.09 5951600.00 677930.00 70 16 23.694 N 148 33 38.620 W - Polygon 3 64.00 1453.40 2198.91 5951210.00 678200.00 70 16 19.797 N 148 33 31.029 W - Polygon 4 64.00 1849.64 1938.09 5951600.00 677930.00 70 16 23.694 N 148 33 38.620 W I 07 -088 Fault3 64.00 1745.07 2345.78 5951505.00 678340.00 70 16 22.665 N 148 33 26.751 W - Polygon 1 64.00 1745.07 2345.78 5951505.00 678340.00 70 16 22.665 N 148 33 26.751 W - Polygon 2 64.00 1316.82 2905.95 5951090.00 678910.00 70 16 18.451 N 148 33 10.446 W 07 -08B Faults 64.00 1597.06 1617.07 5951340.00 677615.00 70 16 21.211 N 148 33 47.968 W - Polygon 1 64.00 1597.06 1617.07 5951340.00 677615.00 70 16 21.211 N 148 33 47.968 W - Polygon 2 64.00 1451.01 1873.74 5951200.00 677875.00 70 16 19.774 N 148 33 40.496 W • • 4) bp BP Alaska $ Baker Hughes INTEQ Planning Report 1NTEQ Company: BP Amoco Date: 1/18/2007 Time: 14:54:27 Page: 2 Field: Prudhoe Bay Co- ordinate(NE) Reference: Well: 07 -08, True North Site: PB DS 07 Vertical (TVD) Reference: 13 : 0812/17/1978 00:00 64.0 Well: 07-08 Section (VS) Reference: Well (0.00N,0.00E,150.00Azi) Wellpath: Plan 3, 07-08B Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <---- Latitude - --> <-- Longitude --> Name Description TVD +N /-S +E/ -W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 07 -08B Fauit4 64.00 1275.55 2104.72 5951030.00 678110.00 70 16 18.048 N 148 33 33.773 W - Polygon 1 64.00 1275.55 2104.72 5951030.00 678110.00 70 16 18.048 N 148 33 33.773 W - Polygon 2 64.00 866.22 2070.13 5950620.00 678085.00 70 16 14.022 N 148 33 34.783 W 07 -08B Targetl 9024.00 2147.76 1594.94 5951890.00 677580.00 70 16 26.627 N 148 33 48.609 W 07 -08B Target2 9024.00 1311.86 2305.64 5951071.00 678310.00 70 16 18.404 N 148 33 27.924 W Annotation MD TVD ft ft 9674.00 8826.59 TIP 9685.00 8833.70 KOP 9705.00 8846.72 End of 9 Deg /100' DLS 9735.00 8868.03 5 10075.40 9028.13 End of 30 Deg /100' DLS 10175.40 9024.19 7 10575.40 9024.15 8 10895.40 9024.13 9 11250.00 9024.11 TD Plan Section Information MD Intl Azim TVD +N / -S +E / -W DLS Build Turn TFO Target ft deg deg ft ft ft deg /100ft deg /100ft deg /100ft deg 9645.77 45.88 69.80 8807.52 2357.30 1355.67 0.00 0.00 0.00 0.00 9674.00 49.13 67.90 8826.59 2364.82 1375.07 12.54 11.51 -6.73 336.03 9685.00 50.31 67.12 8833.70 2368.03 1382.83 12.01 10.73 -7.09 332.99 9705.00 48.51 67.12 8846.72 2373.94 1396.82 9.00 -9.00 0.00 180.00 9735.00 40.90 73.98 8868.03 2381.03 1416.65 30.00 -25.36 22.87 150.00 10075.40 94.50 177.33 9028.13 2188.37 1576.40 30.00 15.75 30.36 97.20 10175.40 90.01 166.19 9024.19 2089.66 1590.71 12.00 -4.49 -11.14 248.30 10575.40 90.00 118.19 9024.15 1782.81 1828.84 12.00 0.00 -12.00 270.00 10895.40 90.00 156.59 9024.13 1551.69 2041.46 12.00 0.00 12.00 90.00 11250.00 90.00 114.04 9024.11 1305.35 2285.14 12.00 0.00 -12.00 270.00 Survey MD Intl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg /100ft ft deg 9645.77 45.88 69.80 8743.52 2357.30 1355.67 5952093.88 677335.90 0.00 - 1363.65 0.00 MWD 9650.00 46.36 69.50 8746.46 2358.36 1358.53 5952095.00 677338.74 12.54 - 1363.14 336.03 MWD 9674.00 49.13 67.90 8762.59 2364.82 1375.07 5952101.85 677355.13 12.54 - 1360.46 336.24 MWD 9675.00 49.24 67.83 8763.25 2365.11 1375.77 5952102.15 677355.82 12.01 - 1360.35 332.99 MWD 9685.00 50.31 67.12 8769.70 2368.03 1382.83 5952105.24 677362.80 12.01 - 1359.36 333.03 MWD 9700.00 48.96 67.12 8779.42 2372.47 1393.35 5952109.92 677373.22 9.00 - 1357.95 180.00 MWD 9705.00 48.51 67.12 8782.72 2373.94 1396.82 5952111.47 677376.65 9.00 - 1357.48 180.00 MWD 9725.00 43.39 71.48 8796.62 2379.03 1410.25 5952116.88 677389.95 30.00 - 1355.18 150.00 MWD 9735.00 40.90 73.98 8804.03 2381.03 1416.65 5952119.02 677396.31 30.00 - 1353.71 146.96 MWD 9750.00 40.54 80.86 8815.41 2383.16 1426.19 5952121.37 677405.80 30.00 - 1350.78 97.20 MWD 9775.00 40.86 92.36 8834.39 2384.12 1442.40 5952122.71 677421.98 30.00 - 1343.50 91.98 MWD 9800.00 42.28 103.47 8853.12 2381.82 1458.78 5952120.79 677438.40 30.00 - 1333.33 83.25 MWD 9825.00 44.71 113.79 8871.28 2376.30 1475.02 5952115.66 677454.77 30.00 - 1320.43 74.93 MWD 9850.00 47.98 123.13 8888.55 2367.67 1490.87 5952107.40 677470.82 30.00 - 1305.02 67.43 MWD 9875.00 51.93 131.46 8904.65 2356.06 1506.04 5952096.15 677486.26 30.00 - 1287.39 60.97 MWD 9900.00 56.41 138.89 8919.29 2341.68 1520.28 5952082.11 677500.83 30.00 - 1267.81 55.60 MWD 9925.00 61.28 145.56 8932.23 2324.77 1533.35 5952065.51 677514.29 30.00 - 1246.63 51.25 MWD 9950.00 66.46 151.61 8943.25 2305.62 1545.02 5952046.64 677526.40 30.00 - 1224.22 47.79 MWD • by BP Alaska BAKER Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco Date: 1/18/2007 Time: 14:54:27 Page: 3 Field: Prudhoe Bay Co- ordinate(NE) Reference: Well: 07 -08, True North Site: PB DS 07 Vertical (TVD) Reference: 13 : 08 12/17/1978 00:00 64.0 Well: 07-08 Section (VS) Reference: Well (0.00N,0.00E,150.00Azi) Wellpath: Plan 3, 07 -08B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inca Azim SS TVD N/S ENV MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 9975.00 71.84 157.20 8952.15 2284.56 1555.08 5952025.82 677536.95 30.00 - 1200.94 45.12 MWD 10000.00 77.38 162.44 8958.78 2261.95 1563.38 5952003.41 677545.77 30.00 - 1177.21 43.13 MWD 10025.00 83.02 167.47 8963.04 2238.17 1569.76 5951979.79 677552.71 30.00 - 1153.43 41.74 MWD 10050.00 88.71 172.37 8964.84 2213.64 1574.12 5951955.37 677557.64 30.00 - 1130.01 40.88 MWD 10075.00 94.41 177.25 8964.16 2188.77 1576.38 5951930.56 677560.48 30.00 - 1107.34 40.53 MWD 10100.00 93.40 174.58 8962.44 2163.89 1578.13 5951905.73 677562.81 11.38 - 1084.92 249.42 MWD 10125.00 92.28 171.79 8961.20 2139.10 1581.09 5951881.02 677566.36 12.00 - 1061.97 248.11 MWD 10150.00 91.15 169.01 8960.45 2114.47 1585.26 5951856.49 677571.10 12.00 - 1038.55 247.97 MWD 10175.00 90.02 166.23 8960.19 2090.05 1590.62 5951832.21 677577.02 12.00 - 1014.73 247.89 MWD 10200.00 90.01 163.24 8960.19 2065.94 1597.20 5951808.26 677584.17 11.99 - 990.55 269.65 MWD 10225.00 90.01 160.24 8960.18 2042.20 1605.03 5951784.71 677592.55 12.00 - 966.08 270.00 MWD 10250.00 90.01 157.24 8960.18 2018.90 1614.10 5951761.63 677602.16 12.00 - 941.37 270.00 MWD 10275.00 90.01 154.24 8960.18 1996.11 1624.37 5951739.09 677612.96 12.00 - 916.50 270.00 MWD 10300.00 90.01 151.24 8960.18 1973.89 1635.82 5951717.15 677624.93 12.00 - 891.53 270.00 MWD 10325.00 90.01 148.24 8960.17 1952.30 1648.42 5951695.86 677638.03 12.00 - 866.53 270.00 MWD 10350.00 90.01 145.24 8960.17 1931.40 1662.13 5951675.29 677652.22 12.00 - 841.58 270.00 MWD 10375.00 90.01 142.24 8960.17 1911.25 1676.92 5951655.48 677667.48 12.00 - 816.73 270.00 MWD 10400.00 90.01 139.24 8960.17 1891.89 1692.74 5951636.51 677683.74 12.00 - 792.06 270.00 MWD 10425.00 90.01 136.24 8960.16 1873.39 1709.55 5951618.41 677700.98 12.00 - 767.63 270.00 MWD 10450.00 90.01 133.24 8960.16 1855.80 1727.31 5951601.23 677719.15 12.00 - 743.52 270.00 MWD 10475.00 90.00 130.24 8960.16 1839.16 1745.96 5951585.04 677738.18 12.00 - 719.78 270.00 MWD 10500.00 90.00 127.24 8960.16 1823.52 1765.46 5951569.86 677758.04 12.00 - 696.48 270.00 MWD 10525.00 90.00 124.24 8960.15 1808.92 1785.75 5951555.74 677778.67 12.00 - 673.69 270.00 MWD 10550.00 90.00 121.24 8960.15 1795.40 1806.78 5951542.72 677800.00 12.00 - 651.47 270.00 MWD 10575.00 90.00 118.24 8960.15 1783.00 1828.48 5951530.83 677821.99 12.00 - 629.88 270.00 MWD 10600.00 90.00 121.14 8960.15 1770.64 1850.21 5951518.98 677844.00 11.61 - 608.31 90.00 MWD 10625.00 90.00 124.14 8960.15 1757.16 1871.26 5951505.99 677865.36 12.00 - 586.11 90.00 MWD 10650.00 90.00 127.14 8960.15 1742.59 1891.58 5951491.91 677886.00 12.00 - 563.34 90.00 MWD 10675.00 90.00 130.14 8960.14 1726.99 1911.10 5951476.76 677905.89 12.00 - 540.06 90.00 MWD 10700.00 90.00 133.14 8960.14 1710.38 1929.78 5951460.59 677924.95 12.00 - 516.34 90.00 MWD 10725.00 90.00 136.14 8960.14 1692.81 1947.57 5951443.45 677943.14 12.00 - 492.23 90.00 MWD 10750.00 90.00 139.14 8960.14 1674.34 1964.41 5951425.38 677960.41 12.00 - 467.82 90.00 MWD 10775.00 90.00 142.14 8960.14 1655.01 1980.27 5951406.43 677976.71 12.00 - 443.15 90.00 MWD 10800.00 90.00 145.14 8960.14 1634.88 1995.09 5951386.66 677992.00 12.00 - 418.31 90.00 MWD 10825.00 90.00 148.14 8960.13 1614.01 2008.83 5951366.11 678006.23 12.00 - 393.35 90.00 MWD 10850.00 90.00 151.14 8960.13 1592.44 2021.47 5951344.84 678019.36 12.00 - 368.36 90.00 MWD 10875.00 90.00 154.14 8960.13 1570.24 2032.95 5951322.92 678031.37 12.00 - 343.39 90.00 MWD 10895.40 90.00 156.59 8960.13 1551.69 2041.46 5951304.58 678040.30 12.00 - 323.08 90.00 MWD 10900.00 90.00 156.04 8960.13 1547.48 2043.31 5951300.41 678042.25 12.00 - 318.51 270.00 MWD 10925.00 90.00 153.04 8960.13 1524.91 2054.05 5951278.10 678053.52 12.00 - 293.59 270.00 MWD 10950.00 90.00 150.04 8960.13 1502.94 2065.97 5951256.41 678065.94 12.00 - 268.60 270.00 MWD 10975.00 90.00 147.04 8960.13 1481.62 2079.02 5951235.40 678079.48 12.00 - 243.61 270.00 MWD 11000.00 90.00 144.04 8960.12 1461.01 2093.16 5951215.13 678094.11 12.00 - 218.69 270.00 MWD 11025.00 90.00 141.04 8960.12 1441.17 2108.37 5951195.65 678109.77 12.00 - 193.90 270.00 MWD 11050.00 90.00 138.04 8960.12 1422.15 2124.59 5951177.02 678126.43 12.00 - 169.32 270.00 MWD 11075.00 90.00 135.04 8960.12 1404.01 2141.79 5951159.29 678144.05 12.00 - 145.01 270.00 MWD 11100.00 90.00 132.04 8960.12 1386.79 2159.91 5951142.50 678162.57 12.00 - 121.04 270.00 MWD 11125.00 90.00 129.04 8960.12 1370.54 2178.90 5951126.70 678181.94 12.00 -97.47 270.00 MWD 11150.00 90.00 126.04 8960.12 1355.31 2198.73 5951111.94 678202.11 12.00 -74.37 270.00 MWD 11175.00 90.00 123.04 8960.11 1341.14 2219.32 5951098.25 678223.03 12.00 -51.80 270.00 MWD 11200.00 90.00 120.04 8960.11 1328.07 2240.62 5951085.68 678244.63 12.00 -29.83 270.00 MWD 11225.00 90.00 117.04 8960.11 1316.13 2262.58 5951074.26 678266.86 12.00 -8.51 270.00 MWD . • 0 bp BP Alaska B ps Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amoco Date: 1/18/2007 Time: 14:54:27 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 07 -08, True North Site: PB DS 07 Vertical (TVD) Reference: 13 : 08 12/17/1978 00:00 64.0 Well: 07 -08 Section (VS) Reference: Well (0.00N,0.00E,150.00Azi) Welipath: Plan 3, 07-08B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inel Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg /100ft ft deg 11250.00 90.00 114.04 8960.11 1305.35 2285.14 5951064.02 678289.66 12.00 12.10 270.00 2 3/8" cam BP Alaska 11741111 feD,� o efe,aw_ Y .�, BAKER :2200,. „1.r,fe .nEl..,«e��.. IWGNES t p : e?, !7 ZILZiniZI 0 0 0 0. D &fe,,,M CM (9 _—. Mel. wDDx23m a. �23orrmo1 :�o; ” ,fees 232323!.,, 1NTE:Q D.. ®,meecorn ILL Pa:A. 13 :11.12/1V111711 00.00 IMLOOM CoarlvWelWE)RarorREFERENCE INFORMATION moo s ^ gLe "era: NM vMUUIrvo)RefereDm ys Dsee0 � ,y1 , ,, , M ' ew Reference ( nu. E00 .00 ' 0 - Reference M M on. Moo L i •• MD lac •. .. SECT ID;o! . 1 D re.• •• n 1220 / E=1 00 -0 23 „ 1123.:23 2323A23 1112323 23232323.11 1!23! ?23 !22323.6 1!.2323 ,123A23 1!011 = / rv mvnne TVD Mot. :.1.11.,. a ♦ n1,s �� ,WO / \ tlw r D 23 w! orp9 � R teoo \ 2323 23 0.11 g21::: 10 i \ \ \ \ \-. \ IM\ y 1.4 \ \ \ • MOO Imo 1 \ moo • • MOO 11.8'a q boo S _. _ . 2360 o- .00 ,00 230 10 !oe ,000 „ 4. 1, 00 00 b 7! 0 ,220 123 ,220 6w esq•V[asy +l (lo0tain] 0 1100 2200 2200 moo 1200 X00 0220 3000 2100 3202 moo moo rvm moo 2100 e Mb0 • li 19;. 4 -0 .� -. _. __ 5055_. _— 0 000.. .... 1150 .1100 . lobo 1 - 15W .5.050. -. - -. 250 300 250 zoo 50 .,m SO o 50 103 ,m 2310 2223 100 -um -,s» -u s0 -1.00 -1ss0 7000 nm0 7220 -nw nm noso 7220 ebo s00 eS Vortical Section at 1 so.00• ISOtNIni .550 ,a. .0 .023 1/18/2007 3.43 PM • • 0 by BP Alaska s Anticollision Report 1NTEQ Company: BP Amoco Date: 1/18/2007 Time: 14:09:27 Page: 1 Field: Prudhoe Bay Reference Site: PB DS 07 Co- ordinate(NE) Reference: Well: 07 -08, True North Reference Well: 07 -08 Vertical (TVD) Reference: 13 : 08 12/17/1978 00:00 64.0 Reference Wellpath: Plan 3, 07 -088 Db: Oracle GLOBAL SCAN APPLIED: AU wellpaths within 200'+ 100 /1000 of reference - There are REIR jueells in this lMeht iipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 9645.77 to 11250.00 ft Scan Method: Tray Cylinder North Maximum Radius: 1500.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 1/18/2007 Validated: No Version: 1 Planned From To Survey Toolcode Tool Name ft ft 100.00 9598.00 2 : Gyrodata cont.drillpipe m/ GYD- CT -DMS Gyrodata cont.drillpipe m/s 9598.00 9645.77 2 : MWD - Standard (9645.77 -10 MWD MWD - Standard 9645.77 11250.00 Planned: Plan #3 V4 MWD MWD - Standard Casing Points MD TVD Diameter Hole Size Name ft ft in in 11250.00 9024.11 2.375 3.000 2 3/8" Summary <---- - - - - -- Offset Wellpath ------- ---- -> Reference Offset Ctr -Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft 07- 08,Plan 3, 07 -08B,P 11200.00 11200.00 0.00 118.17 - 118.17 FAIL: Major Risk PB DS 07 07 -06 07 -06B V6 10525.00 10410.00 850.57 156.14 694.43 Pass: Major Risk PB DS 07 07 -07 07 -07 V1 Out of range PB DS 07 07 -07A 07 -07A V2 Out of range PB DS 07 07 -07A 07 -07B V4 Out of range PB DS 07 07 -08 07 -08 V2 9799.91 9800.00 18.42 130.26 - 111.84 FAIL: Major Risk PB DS 07 07 -08 07 -08A V1 9699.99 9700.00 0.40 105.94 - 105.54 FAIL: Major Risk PB DS 07 07 -17 07 -17 V1 Out of range PB DS 07 07 -36 07 -36 V2 9777.02 13400.00 930.32 218.58 711.74 Pass: Major Risk Site: Well: Rule Assigned: Major Risk Wellpath: 07-08,Plan 3, 07-08B,Plan #3 Inter -Site Error: 0.00 ft Reference Offset Semi -Major Axis Ctr -Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9645.77 8807.52 9645.77 8807.52 17.82 0.00 69.80 0.00 3.000 0.00 86.51 -86.51 FAIL 9700.00 8843.42 9700.00 8843.42 17.90 0.61 67.12 0.00 3.000 0.00 87.34 -87.34 FAIL 9800.00 8917.12 9800.00 8917.12 15.81 1.77 103.47 0.00 3.000 0.00 82.37 -82.37 FAIL 9900.00 8983.29 9900.00 8983.29 15.32 2.89 138.89 0.00 3.000 0.00 83.54 -83.54 FAIL 10000.00 9022.78 10000.00 9022.78 16.52 3.43 162.44 0.00 3.000 0.00 88.34 -88.34 FAIL 10100.00 9026.44 10100.00 9026.44 17.75 3.95 174.58 0.00 3.000 0.00 92.30 -92.30 FAIL 10200.00 9024.19 10200.00 9024.19 16.82 5.67 163.24 0.00 3.000 0.00 90.16 -90.16 FAIL 10300.00 9024.18 10300.00 9024.18 15.96 7.39 151.24 0.00 3.000 0.00 88.31 -88.31 FAIL 10400.00 9024.17 10400.00 9024.17 15.50 8.92 139.24 0.00 3.000 0.00 87.72 -87.72 FAIL 10500.00 9024.16 10500.00 9024.16 15.51 10.14 127.24 0.00 3.000 0.00 88.62 -88.62 FAIL 10600.00 9024.15 10600.00 9024.15 16.20 11.41 121.14 0.00 3.000 0.00 91.62 -91.62 FAIL 10700.00 9024.14 10700.00 9024.14 18.03 13.58 133.14 0.00 3.000 0.00 98.01 -98.01 FAIL 10800.00 9024.14 10800.00 9024.14 19.99 15.11 145.14 0.00 3.000 0.00 104.82 - 104.82 FAIL 10900.00 9024.13 10900.00 9024.13 21.68 16.01 156.04 0.00 3.000 0.00 110.84 - 110.84 FAIL 11000.00 9024.12 11000.00 9024.12 22.28 18.19 144.04 0.00 3.000 0.00 113.61 - 113.61 FAIL 11100.00 9024.12 11100.00 9024.12 22.79 19.64 132.04 0.00 3.000 0.00 116.15 - 116.15 FAIL 11200.00 9024.11 11200.00 9024.11 23.13 20.28 120.04 0.00 3.000 0.00 118.17 - 118.17 FAIL I • • 0 by BP Alaska s Anticollision Report INTEQ Company: BP Amoco Date: 1/18/2007 Time: 14:09:27 Page: 2 Field: Prudhoe Bay Reference Site: PB DS 07 Co-ordinate(NE) Reference: Well: 07 -08, True North Reference Weli: 07 -08 Vertical (TVD) Reference: 13 : 08 12/17/1978 00:00 64.0 Reference Wellpath: Plan 3, 07 -08B Db: Oracle Site: PB DS 07 Well: 07 -06 Rule Assigned: Major Risk Wellpath: 07 -06B V6 Inter -Site Error: 0.00 ft Reference Offset Semi -Major Axis Ctr -Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSUistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11225.00 9024.11 9100.00 8672.70 23.18 27.73 193.02 75.98 4.500 1450.64 180.23 1270.41 Pass 11215.99 9024.11 9500.00 8937.33 23.16 27.27 203.71 85.60 4.500 1130.06 184.67 945.39 Pass 11200.00 9024.11 9600.00 8988.97 23.13 26.31 208.13 88.10 4.500 1059.25 182.47 876.78 Pass 11175.00 9024.11 9700.00 9022.86 23.06 24.88 212.96 89.93 4.500 996.94 178.03 818.91 Pass 11150.00 9024.12 9800.00 9031.49 22.99 23.50 216.48 90.44 4.500 949.44 173.08 776.36 Pass 11117.52 9024.12 9900.00 9032.83 22.86 21.82 220.48 90.55 4.500 914.19 167.05 747.13 Pass 11084.15 9024.12 10000.00 9034.07 22.72 20.34 224.58 90.64 4.500 887.23 161.60 725.62 Pass 11050.00 9024.12 10100.00 9033.22 22.55 19.10 228.64 90.60 4.500 866.85 157.32 709.53 Pass 11014.23 9024.12 10200.00 9032.18 22.36 18.24 232.87 90.54 4.500 854.34 154.07 700.26 Pass 10975.00 9024.13 10300.00 9030.56 22.13 17.88 237.47 90.43 4.500 850.21 152.26 697.95 Pass 10942.44 9024.13 10400.00 9030.15 21.93 17.89 241.35 90.40 4.500 853.50 151.69 701.81 Pass 10525.00 9024.15 10410.00 9030.13 15.58 26.15 214.64 90.40 4.500 850.57 156.14 694.43 Pass Site: PB DS 07 Well: 07 -08 Rule Assigned: Major Risk Wellpath: 07 -08 V2 Inter -Site Error: 0.00 ft Reference Offset Semi -Major Axis Ctr -Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO -HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9698.74 8842.59 9700.00 8851.31 17.90 18.20 234.24 167.12 11.83 108.52 -96.69 FAIL 9799.91 8917.05 9800.00 8929.40 15.82 16.39 287.84 184.41 18.42 130.26 - 111.84 FAIL 9873.34 8967.62 9900.00 9008.95 15.19 15.58 344.75 213.81 63.43 98.72 -35.30 FAIL 9918.15 8992.87 10000.00 9089.34 15.46 15.84 359.13 215.33 136.65 79.28 57.38 Pass 9945.79 9005.54 10100.00 9169.98 15.75 16.15 5.88 215.25 221.19 63.91 157.28 Pass 9946.87 9005.98 10105.00 9174.02 15.76 16.17 6.13 215.25 225.60 62.99 162.61 Pass Site: PB DS 07 Well: 07 -08 Rule Assigned: Major Risk Wellpath: 07 -08A V1 Inter -Site Error: 0.00 ft Reference Offset Semi -Major Axis Ctr -Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HS)istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9699.99 8843.41 9700.00 8843.12 17.90 17.91 52.12 345.00 0.40 105.94 - 105.54 FAIL 9790.35 8909.94 9800.00 8898.33 16.07 16.10 43.24 303.98 31.29 106.58 -75.30 FAIL 9855.50 8956.20 9900.00 8941.06 15.18 15.21 47.76 282.71 91.50 105.96 -14.45 FAIL 9907.72 8987.48 10000.00 8984.11 15.38 15.38 52.50 271.47 154.96 108.19 46.77 Pass 9948.28 9006.56 10100.00 9019.75 15.78 15.77 57.54 266.33 225.27 113.28 111.99 Pass 9967.32 9013.65 10200.00 9025.34 16.02 16.02 63.27 267.75 315.94 118.88 197.06 Pass 9985.37 9019.18 10300.00 9023.42 16.28 16.28 68.78 269.38 404.88 123.93 280.96 Pass 9998.30 9022.41 10400.00 9025.47 16.49 16.50 71.73 269.64 498.71 126.76 371.95 Pass 10010.54 9024.87 10500.00 9017.61 16.70 16.72 75.30 270.72 590.83 129.68 461.16 Pass 10023.95 9026.91 10600.00 9020.27 16.94 16.98 77.82 270.56 681.34 132.11 549.22 Pass 10641.28 9024.15 10700.00 9017.63 16.92 17.34 36.59 270.50 754.47 132.78 621.70 Pass 10679.31 9024.14 10800.00 9014.98 17.63 18.12 41.34 270.68 769.42 137.75 631.67 Pass 10717.30 9024.14 10900.00 9016.08 18.37 18.93 45.81 270.59 778.10 142.76 635.34 Pass 10735.25 9024.14 10948.00 9019.24 18.73 19.31 47.73 270.36 785.40 145.06 640.34 Pass • 0 bp BP Alaska S Anticollision Report 1NTEQ Company: BP Amoco Date: 1/18/2007 Time: 14:09:27 Page: 3 Field: Prudhoe Bay Reference Site: PB DS 07 Co- ordinate(NE) Reference: Well: 07 -08, True North Reference Well: 07 -08 Vertical (TVD) Reference: 13 : 08 12/17/1978 00:00 64.0 Reference Wellpath: Plan 3, 07 -08B Db: Oracle Site: PB DS 07 Well: 07 -36 Rule Assigned: Major Risk Wellpath: 07 -36 V2 Inter -Site Error: 0.00 ft Reference Offset Semi -Major Axis Ctr-Ctr No-Go Allowable j MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9890.00 8977.63 12200.00 9001.23 15.26 39.69 45.09 269.07 7.000 1482.78 174.61 1308.17 Pass 9880.00 8971.70 12300.00 9000.53 15.21 39.88 42.15 269.13 7.000 1414.65 175.13 1239.52 Pass 9874.29 8968.21 12400.00 8997.80 15.20 40.09 39.64 268.40 7.000 1347.06 176.42 1170.65 Pass 9865.83 8962.90 12500.00 8995.55 15.18 40.24 36.62 268.10 7.000 1279.72 177.71 1102.02 Pass 9857.21 8957.33 12600.00 8995.41 15.18 40.38 33.25 267.62 7.000 1215.97 179.49 1036.47 Pass 9850.00 8952.55 12700.00 8997.11 15.19 40.53 29.69 266.56 7.000 1156.74 181.62 975.12 Pass 9840.00 8945.77 12800.00 9001.47 15.23 40.64 25.39 265.88 7.000 1101.77 184.63 917.15 Pass 9830.00 8938.81 12900.00 9004.94 15.31 40.74 20.82 265.08 7.000 1050.85 188.66 862.19 Pass 9820.00 8931.71 13000.00 9006.44 15.43 40.85 15.95 264.14 7.000 1006.89 193.57 813.31 Pass 9810.00 8924.47 13100.00 9004.86 15.60 40.99 10.83 263.12 7.000 972.18 199.25 772.93 Pass 9800.00 8917.12 13200.00 9003.55 15.81 41.14 5.40 261.93 7.000 947.11 205.24 741.87 Pass 9790.00 8909.68 13300.00 9002.35 16.07 41.51 -0.24 260.66 7.000 931.61 211.56 720.06 Pass 9777.02 8899.92 13400.00 9001.46 16.47 42.87 353.69 260.41 7.000 930.32 218.58 711.74 Pass 9766.08 8891.63 13500.00 9002.70 16.83 44.10 347.82 259.54 7.000 940.05 224.48 715.57 Pass 9755.04 8883.24 13600.00 9002.31 17.20 45.25 342.16 258.98 7.000 958.62 229.72 728.90 Pass 9743.88 8874.76 13700.00 8999.47 17.58 46.24 336.86 258.82 7.000 987.26 233.96 753.31 Pass 9731.02 8865.05 13800.00 8995.80 17.87 47.05 331.96 259.00 7.000 1026.23 237.06 789.17 Pass 9711.32 8850.97 13887.50 8993.24 17.91 47.41 327.88 259.46 7.000 1065.21 246.11 819.09 Pass T Plan. Plan 83 (07-08/Plan 3. 07 -0881 . Alaska ✓• 4461141at to BP Alaska w T,Ay, : j 1 ,,. Fak� IA Magrelk N°M North Created B Y BP Date:1 /18/2007 � i.w Checked: Date WO k.are pEr� a „ 2 a T 20 26..77 2200 21002190 2 """":.1•2.L°:::,': 07.2.1, hl [ If.() 1.1. 0.12 13.06 1217 00.00 64.00ft 160.00 0.00 0.00 37.00 REFERENCE REFERENCE INFORMATION Co-ordinate (N /E) Reference'. Well Centre: 07-08. True North Vertical (TVD) Reference: 13'. 08 12/17/1978 00:00 6400 Section (VS) Reference'. Slot -08 000N0.00E) Measured Depth Reference'. 13 : 08 12/17/1978 00.00 64.00 Calculation Method Minimum Curvature on= aa.m 11aw 623211 10°6.2: molt 1100 x112° 11:11 • 2800 2700 2600 \ 2500 _, 9000 2400 , - ' 9000 1 07 - (07 - 08) 9000 107-07i (07 -0' • 2300 _ 8700 -8400 / 8100 2200 ' 8100 107 - 08(07 -08A)1 7800 O i y 2100 7800 /� 7500 1 O 0 -36 ( 07 -36)�o w, 2000 7 i 8100 6600 • 7500 / 8900 /7800 i law 7200 ee % 6300 7 j / 0 1700 i ■ • 7500 6900 6000 1600 � / 7200 to �' 1500 6600 6900 5700 1400 1300. r 6300 / 7 /0 '6600 , • Plan 3, 07- 088 5400 1200 - I 07 -06 (07-068 /300 1100 76000 5700 5100 ) 07 -07A(0 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 West( -) /East( +) [100ft /in] 1/18/2007 3.43 PM • S All Measurements are from top of Riser 2/2/2007 L— a) CC top of bag l Schlumberger BAG Dowell bttm of bag middle of slips I Blind /Shears I I TOTs I middle of pipes 2" combi ram /slips I I Mud Cross Mud Cross middle of flow cross I I middle of blind /shears I 2 3/8" ram i.............. I I TOTs middle of pipe /slips 2" combi ram /slips 1 1 Swab Valve . i I I Flow Tee A Alaska Department of Natural Resources Land Administration System Page 1 of 2 • • J# ,. r Land Records/Status Plats Recorder's Search State Cabins Natural Resources r� Alaska DNR Case Summary File Type: ADL File Number:1 28309 a-+ Printable Case File Summary See Township, Range, Section and Acreage? Yes {' No New Smolt LAS Menu 'Case Abstract 1 Case Detail i Land Abstract File: ADL 28309 Search for Status Mat Updates As of 02/07/2007 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISS /APPRV /ACTV AUTH Status Date: 08/19/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: 011N Range: 014E Section: 27 Section Acres: 640 Search Plats Meridian: U Township: 011N Range: 014E Section: 28 Section Acres: 640 Meridian: U Township: 01 IN Range: 014E Section: 33 Section Acres: 640 Meridian: U Township: 011N Range: 014E Section: 34 Section Acres: 640 Legal Description 05 -28 -1965 ***SALE NOTICE LEGAL DESCRIPTION* * * C14- 13011N14E UM 27,28,33,34 2560.00 U- 3- 7 12 -01 -1986 * * *LISB URNE PARTICIPATING AREA T. 11N.,R. 14E., U.M. SECTION 27: ALL 640 ACRES http: / /www.dnr. state. ak. us /las /Case_Summary.cfm ?FileType= ADL &FileNumber =28309 &... 2/7/2007 Alaska Department of Natural Resources Land Administration System Page 2 of 2 • • SECTION 28: ALL 640 ACRES SECTION 34: ALL 640 ACRES CONTAINING 1,920 ACRES, MORE OR LESS. End of Case Summary Last updated on 02/07/2007. Not sure who to contact? Have a question about DNR? Visit the Public Information Center. Report technical problems with this page to the Webrnaster. Site optimized for Netscape 7, IE 6 or above. This site also requires that all COOKIES must be accepted. State of Alaska Natural Resources LAS Home Copyright Privacy System Status II I http://www.dnr.state.ak.us/las/Case Summary.cfm?FileType=ADL&F ileNumber= 28309 &... 2/7/2007 " • Terri L. Hubble 89- 6/1252 321 BP Exploration AK Inc. "Mastercard Check" 4 . PO Box 196612 MB 7 -5 Anchorage, AK 99519 DATE OZ ' 0 / 1 1 l PAY TO THE 110 * ��� , f , ♦ .(,�� $ O `D ORDER OF NOT' .4� _A �_���lar 4� / 11Pro DOLLARS First National :ank Alaska - - Anchorage, AK 99501 RR MEMO O� • & • O / 14 _ rr l/l� 1 : 125 2000601 :99 /4622?L556 032L • TRANSMITTAL LETTER C}IECKLIST WELL NAME ",el/ .07- czerter PTD# o? ' l- D/9 ✓ Development Service Exploratory Stratigraphic Test Non- Conventional Well Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS ! TEXT FOR APPROVAL LETTER WHAT I (OPTIONS) APPLIES f � I MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in I Permit No. , API No. 50- - - API number are 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 ( PH) and API number j I (50- - - ) from records, data and logs j i I acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent I upon issuance of a conservation order approving a spacing j ' I exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH Al[ dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. � I Please note the following special condition of this permit: Non- Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev. 1'25/06 C. 'Jody '\transmittal_checkl ist WELLARMrt, 'fain Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 07-08B Program DEV Well bore seg L -I PTD#: 2070190 Company BP EXPLORATION (ALASKA) INC _ Initial Class/Type DEV / PEND GeoArea 890 -__ __ _ _ Unit 11650 _____ On /Off Shore On Annular Disposal ❑ Administration 11 Permit fee attached Yes I i2 Lease number appropriate Yes ;3 Unique well name and number Yes ; 4 Well located in a defined pool Yes PRUDHOE BAY POOL ; 5 Well located proper distance from drilling unit boundary Yes 16 Well located proper distance from other wells Yes .7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes i 9 Operator only affected party Yes 110 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes ACS 2/7/2007 13 Can permit be approved before 15 day wait Yes • 14 Well located within area and strata authorized by Injection Order # (put 1O# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 116 Pre - produced injector: duration of pre-production less than 3 months (For service well only) NA - 17 Nonconven. gas conforms to AS31.05.0300.1.A)42.A -D) No Engineering :18 Conductor string provided NA Conductor set in 07 -08 (178 -016). i19 Surface casing protects all known USDWs NA Surface casing set in 07 -08, 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing set in 07 -08. . 1 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in 07 -08. 22 CMT will cover all known productive horizons Yes 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig is equipped with steel pits. No reserve pitplanned. All waste to approved disposal well(s). 25 If a re- drill, has a 10-403 for abandonment been approved Yes 307 -051 126 Adequate wellbore separation proposed Yes Proximity analysis performed. Close approaches identified. Nearest segment is existing well & paths diverge. 27 If diverter required, does it meet regulations NA BOP stack will be in place. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Maximum expected formation pressure 7.2 EMW. Planned MW 8.6 ppg. TEM 2/13/2007 129 BOPEs, do they meet regulation Yes 0 P 1� � / n, 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP calculated at 2390 psi. 3500 psi BOP testplanned. ' 1 1 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S is reported on DS 07. Mud should preclude on rig. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA Geology 35 Permit can be issued w/o hydrogen sulfide measures No. MAX. H2S LEVEL ON PAD A IS 75PPM (RECORDED 2/13/01.) I 36 Data presented on potential overpressure zones NA Appr Date '37 Seismic analysis of shallow gas zones NA ACS 2/7/2007 ;38 Seabed condition survey (if off- shore) - NA 39 Contact name /phone for weekly progress reports [exploratory only] Yes GARRET STAUDINGER 564 -4242 Geologic Engineering Public Commissioner: Date: Commissioner: Date sinner Date ,,,,,i, Did' .241 ( I-17 4 ,,,,,,--,,, ,v-ice- o 7- , • • 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. . . 7- 08b.tapx Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Apr 07 08:24:28 2009 Reel Header Service name LISTPE Date 09/04/07 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 09/04/07 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PBU MWD /MAD LOGS WELL NAME: 07 -08B API NUMBER: 500292029602 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 07- APR -09 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: W- 0006119379 W- 0006119379 W- 0006119379 LOGGING ENGINEER: T. ONYEKWELU J. PEREZ J. PEREZ OPERATOR WITNESS: B. DECKER B. DECKER B. DECKER MWD RUN 4 MWD RUN 5 JOB NUMBER: W- 0006119379 w- 0006119379 LOGGING ENGINEER: J. PEREZ J. PEREZ OPERATOR WITNESS: B. DECKER B. DECKER SURFACE LOCATION SECTION: 33 TOWNSHIP: 11N RANGE: 14E FNL: 1215 FSL: FEL: FWL: 5113 Page 1 • • 7- 08b.tapx ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 55.30 GROUND LEVEL: 26.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 8249.0 2ND STRING 6.125 7.000 9082.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS DRILLED OFF OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 8249'MD/7624'TVD IN 7 -08A. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 1. 4. MWD RUNS 1 -5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR), UTILIZING GEIGER - MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR4). MWD RUNS 1,2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD) AND DRILLSTRING DYNAMICS SENSOR (DDSR). MWD RUNS 3 -5 ALSO INCLUDED DRILLSTRING DYNAMICS SENSOR (DDS), COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO - DENSITY (ALD), AND AT -BIT INCLINATION (ABI). 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER OPEN HOLE GAMMA RAY LOG RUN ON 1 JANUARY 1979. THESE DIGITAL DATA WERE PROVIDED BY D. DORTCH (SAIC /BP) ON 26 MARCH 2009, PER DOUG STONER (BP). AFTER THE DATA WERE SHIFTED TO THE PROVIDED REFERENCE LOG, THEY WERE BULK - SHIFTED 8.7' TO ACCOUNT FOR THE DIFFERENT DFE'S. LOG HEADER AND ANNOTATION DATA RETAIN ORIGINAL DEPTH REFERENCES. THIS SHIFTED MWD LOG IS THE PDCL FOR 7 -08B. 6. MWD RUNS 1 -5 REPRESENT WELL 7 -08B WITH API# 50- 029 - 20296 -02. THIS WELL REACHED A TOTAL DEPTH OF 11321'MD /9027'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (SHALLOW Page 2 7- 08b.tapx SPACING). SEMP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED -HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED (LOW -COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW -COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW -COUNT BIN). DENSLIDE = NON - ROTATED INTERVALS REFLECTING ALD SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" BIT MUD WEIGHT: 8.4 - 8.55 PPG MUD SALINITY: 1100 - 5400 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G /CC MATRIX DENSITY: 2.65 G /CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/04/07 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 7962.5 11268.0 RPD 8245.0 11275.0 RPS 8245.0 11275.0 RPM 8245.0 11275.0 RPX 8245.0 11275.0 FET 8245.0 11275.0 ROP 8260.5 11332.0 FCNT 9086.0 11240.0 Page 3 7- 08b.tapx NCNT 9086.0 11240.0 RHOB 9086.0 11255.0 DRHO 9086.0 11255.0 NPHI 9086.0 11240.0 PEF 9086.0 11255.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 7956.0 7953.5 7965.0 7963.0 7970.0 7968.0 7972.5 7969.5 7979.0 7978.5 7985.5 7983.0 7989.5 7988.0 7995.0 7993.5 8004.0 8002.5 8008.5 8006.5 8018.0 8015.0 8020.0 8017.0 8024.5 8022.0 8030.5 8027.5 8037.0 8035.0 8045.5 8039.0 8054.0 8047.5 8066.0 8059.5 8097.0 8090.5 8103.5 8097.0 8112.5 8107.5 8122.5 8117.0 8125.5 8120.5 8143.5 8137.0 8150.0 8143.5 8158.5 8153.0 8164.5 8158.0 8168.0 8162.0 8171.5 8165.0 8178.0 8172.5 8182.0 8176.0 8185.0 8179.0 8188.5 8183.0 8192.0 8186.5 8195.5 8189.5 8201.0 8196.5 8226.0 8223.0 8233.0 8230.0 8238.5 8236.0 8247.0 8245.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 7951.0 8288.0 MWD 2 8288.0 9082.0 MWD 3 9082.0 9451.0 MWD 4 9451.0 9979.0 MWD 5 9979.0 11321.0 REMARKS: MERGED MAIN PASS. Page 4 i 7- 08b.tapx $ # Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record undefined Absent value -999 Depth Units Datum specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G /CC 4 1 68 12 4 DRHO MWD G /CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MWD PU -S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7962.5 11332 9647.25 6740 7962.5 11332 FCNT MWD CP30 104.4 1573.06 598.191 4309 9086 11240 NCNT MWD CP30 13255.1 36185.8 26416.5 4309 9086 11240 RHOB MWD G /CC 2.027 2.869 2.35508 4339 9086 11255 DRHO MWD G /CC -0.727 0.522 0.0969511 4339 9086 11255 RPD MWD OHMM 0.49 2000 56.8161 6061 8245 11275 RPM MWD OHMM 0.5 2000 28.8945 6061 8245 11275 RPS MWD OHMM 0.46 1789.9 17.6862 6061 8245 11275 RPX MWD OHMM 0.51 1823.76 14.1795 6061 8245 11275 FET MWD HR 0.27 67.62 4.17175 6061 8245 11275 GR MWD API 12.17 504.07 74.1088 6612 7962.5 11268 PEF MWD B/E 0.97 12.67 2.28842 4339 9086 11255 ROP MWD FPH 0.28 376.35 117.728 6144 8260.5 11332 NPHI MWD Pu -S 10.24 65.1 23.2568 4309 9086 11240 First Reading For Entire File 7962.5 Last Reading For Entire File 11332 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/04/07 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.002 Page 5 7- 08b.tapx Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/04/07 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 7951.0 8220.5 SROP 8249.5 8288.0 LOG HEADER DATA DATE LOGGED: 24- JAN -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 8288.0 TOP LOG INTERVAL (FT): 8249.0 BOTTOM LOG INTERVAL (FT): 8288.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 66259 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8249.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 10.10 MUD VISCOSITY (S): 62.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 1800 FLUID LOSS (C3): 5.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 108.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 Page 6 I 4 7- 08b.tapx NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD010 API 4 1 68 4 2 ROP MWD010 FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7951 8288 8119.5 675 7951 8288 GR MWDO10 API 63.72 135.63 95.6019 540 7951 8220.5 ROP MWD010 FPH 0.3 15.17 5.12269 78 8249.5 8288 First Reading For Entire File 7951 Last Reading For Entire File 8288 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/04/07 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/04/07 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.002 Page 7 • 4 7- 08b.tapx Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 8221.0 9034.0 SFXE 8233.0 9026.5 SEXP 8233.0 9026.5 SESP 8233.0 9026.5 SEDP 8233.0 9026.5 SEMP 8233.0 9026.5 SROP 8288.5 9082.0 LOG HEADER DATA DATE LOGGED: 26- JAN -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 9082.0 TOP LOG INTERVAL (FT): 8288.0 BOTTOM LOG INTERVAL (FT): 9082.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 18.3 MAXIMUM ANGLE: 27.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 66259 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8249.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 10.20 MUD VISCOSITY (S): 52.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 2600 FLUID LOSS (C3): 10.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .880 75.0 MUD AT MAX CIRCULATING TERMPERATURE: .490 140.0 MUD FILTRATE AT MT: .910 75.0 MUD CAKE AT MT: .900 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): Page 8 . S 7- 08b.tapx EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type 0 Data specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .AIN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8221 9082 8651.5 1723 8221 9082 RPD MWD020 OHMM 0.49 2000 37.0722 1588 8233 9026.5 RPM MWD020 OHMM 0.5 1310.93 3.92407 1588 8233 9026.5 RPS MWD020 OHMM 0.56 1789.9 4.40451 1588 8233 9026.5 RPX MWD020 OHMM 0.51 1823.76 4.35712 1588 8233 9026.5 FET MWD020 HR 0.33 35.43 3.1805 1588 8233 9026.5 GR MWD020 API 41.73 416.44 154.702 1627 8221 9034 ROP MWD020 FPH 2.9 290.26 116.444 1588 8288.5 9082 First Reading For Entire File 8221 Last Reading For Entire File 9082 File Trailer Service name STSLIB.003 Service Sub Level Name version Number 1 0 0 Date of Generation 09/04/07 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/04/07 Page 9 7- 08b.tapx Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEXP 9027.0 9395.0 SFXE 9027.0 9395.0 SESP 9027.0 9395.0 SEMP 9027.0 9395.0 SEDP 9027.0 9395.0 SGRC 9034.5 9388.0 SNP2 9075.0 9375.0 CTFA 9075.0 9360.0 SCO2 9075.0 9375.0 TNPS 9075.0 9360.0 5E02 9075.0 9375.0 CTNA 9075.0 9360.0 SROP 9082.5 9451.0 LOG HEADER DATA DATE LOGGED: 29- JAN -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 9451.0 TOP LOG INTERVAL (FT): 9082.0 BOTTOM LOG INTERVAL (FT): 9451.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 20.2 MAXIMUM ANGLE: 29.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 CTN COMP THERMAL NEUTRON 10508998 EWR4 Electromag Resis. 4 156404 ALD Azimuthal Litho -Dens 10859715 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9082.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 8.50 MUD VISCOSITY (S): 49.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 2800 FLUID LOSS (C3): 9.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) Page 10 . . • 7- 08b.tapx MUD AT MEASURED TEMPERATURE (MT): .600 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .410 104.0 MUD FILTRATE AT MT: .800 58.0 MUD CAKE AT MT: .700 58.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (Hz): # REMARKS: $ # Data Format specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .AIN Max frames per record undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD030 CP30 4 1 68 4 2 NCNT MWD030 CP30 4 1 68 8 3 RHOB MWD030 G /CC 4 1 68 12 4 DRHO MWD030 G /CC 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 B/E 4 1 68 44 12 ROP MWD030 FPH 4 1 68 48 13 NPHI MWD030 PU -S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9027 9451 9239 849 9027 9451 FCNT MWD030 CP30 104.4 1323.53 699.007 571 9075 9360 NCNT MWD030 CP30 13255.1 32916.8 25555.7 571 9075 9360 RHOB MWD030 G /CC 2.027 2.869 2.28759 601 9075 9375 DRHO MWD030 G /CC -0.727 0.371 0.0340782 601 9075 9375 RPD MWD030 OHMM 1.24 2000 266.494 737 9027 9395 RPM MWD030 OHMM 1.25 2000 122.943 737 9027 9395 RPS MWD030 OHMM 0.46 238.49 53.4783 737 9027 9395 RPX MWD030 OHMM 0.84 723.62 40.5859 737 9027 9395 FET MWD030 HR 0.37 67.62 11.1691 737 9027 9395 GR MWD030 API 14.04 504.07 75.4162 708 9034.5 9388 PEF MWD030 B/E 1.19 12.67 2.68101 601 9075 9375 ROP MWD030 FPH 12.33 287.31 133.458 738 9082.5 9451 NPHI MWD030 Pu -S 10.44 65.1 21.0672 571 9075 9360 Page 11 . . 7- 08b.tapx First Reading For Entire File 9027 Last Reading For Entire File 9451 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/04/07 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.005 Physical EOF File Header Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/04/07 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CTFA 9360.5 9888.0 TNPS 9360.5 9888.0 CTNA 9360.5 9888.0 SNP2 9375.5 9903.0 SCO2 9375.5 9903.0 SBD2 9375.5 9903.0 SGRC 9388.5 9916.0 SESP 9395.5 9923.0 SEMP 9395.5 9923.0 SEXP 9395.5 9923.0 SEDP 9395.5 9923.0 SFXE 9395.5 9923.0 SROP 9451.5 9979.0 LOG HEADER DATA DATE LOGGED: 31- JAN -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 9979.0 TOP LOG INTERVAL (FT): 9451.0 BOTTOM LOG INTERVAL (FT): 9979.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 12 • . • 7- 08b.tapx MINIMUM ANGLE: 34.1 MAXIMUM ANGLE: 78.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 CTN COMP THERMAL NEUTRON 10508998 EWR4 Electromag Resis. 4 156404 ALD Azimuthal Litho -Dens 10859715 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9082.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 8.45 MUD VISCOSITY (S): 51.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 5200 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.960 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.280 111.2 MUD FILTRATE AT MT: 1.940 70.0 MUD CAKE AT MT: 1.930 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .AIN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD040 CP30 4 1 68 4 2 NCNT MWD040 CP30 4 1 68 8 3 RHOB MWD040 G /CC 4 1 68 12 4 DRHO MWD040 G /CC 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 Page 13 . I r 7- 08b.tapx PEF MWD040 B/E 4 1 68 44 12 ROP MWD040 FPH 4 1 68 48 13 NPHI MWD040 PU -S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9360.5 9979 9669.75 1238 9360.5 9979 FCNT MWD040 CP30 409.04 1573.06 677.809 1056 9360.5 9888 NCNT MWD040 CP30 21408.3 36185.8 26686.1 1056 9360.5 9888 RHOB MWD040 G /CC 2.058 2.868 2.33974 1056 9375.5 9903 DRHO MWD040 G /CC -0.067 0.467 0.100043 1056 9375.5 9903 RPD MWD040 OHMM 5.77 286.63 58.9387 1056 9395.5 9923 RPM MWD040 OHMM 4.76 223.47 46.837 1056 9395.5 9923 RPS MWD040 OHMM 4.34 109.29 31.8463 1056 9395.5 9923 RPX MWD040 OHMM 3.9 72.28 21.9087 1056 9395.5 9923 FET MWD040 HR 1.16 24.36 4.43575 1056 9395.5 9923 GR MWD040 API 12.17 118.24 30.982 1056 9388.5 9916 PEF MWD040 B/E 0.97 9.16 1.9989 1056 9375.5 9903 ROP MWD040 FPH 0.44 320.97 75.2637 1056 9451.5 9979 NPHI MWD040 PU -S 10.24 29.33 20.4624 1056 9360.5 9888 First Reading For Entire File 9360.5 Last Reading For Entire File 9979 File Trailer Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/04/07 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.006 Physical EOF File Header Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/04/07 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.005 Comment Record 1 FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CTFA 9888.5 11229.0 CTNA 9888.5 11229.0 TNPS 9888.5 11229.0 Page 14 • 4 7- 08b.tapx SCO2 9903.5 11244.0 SNP2 9903.5 11244.0 SBD2 9903.5 11244.0 SGRC 9916.5 11257.0 SEMP 9923.5 11264.0 SEXP 9923.5 11264.0 SESP 9923.5 11264.0 SEDP 9923.5 11264.0 SFXE 9923.5 11264.0 SROP 9979.5 11321.0 LOG HEADER DATA DATE LOGGED: 02- FEB -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 11321.0 TOP LOG INTERVAL (FT): 9979.0 BOTTOM LOG INTERVAL (FT): 11321.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.7 MAXIMUM ANGLE: 90.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 CTN COMP THERMAL NEUTRON 10508998 EWR4 Electromag Resis. 4 156404 ALD Azimuthal Litho -Dens 10859715 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9082.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 8.50 MUD VISCOSITY (S): 50.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 29000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .500 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .250 125.6 MUD FILTRATE AT MT: .750 60.0 MUD CAKE AT MT: .540 60.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Page 15 , 410 ill 7- 08b.tapx Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .AIN Max frames per record undefined Absent value -999 Depth units Datum Specification Block sub- type...0 Name Service order units Size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD050 CP30 4 1 68 4 2 NCNT MWD050 CP30 4 1 68 8 3 RHOB MWD050 G /CC 4 1 68 12 4 DRHO MWD050 G /CC 4 1 68 16 5 RPD MWD050 OHMM 4 1 68 20 6 RPM MWD050 OHMM 4 1 68 24 7 RPS MWD050 OHMM 4 1 68 28 8 RPX MWD050 OHMM 4 1 68 32 9 FET MWD050 HR 4 1 68 36 10 GR MWD050 API 4 1 68 40 11 PEF MWD050 B/E 4 1 68 44 12 ROP MWD050 FPH 4 1 68 48 13 NPHI MWD050 PU -S 4 1 68 52 14 Fi rst Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 9888.5 11321 10604.8 2866 9888.5 11321 FCNT MWD050 CP30 330.6 804.41 545.379 2682 9888.5 11229 NCNT MWD050 CP30 20381.9 31444.2 26493.6 2682 9888.5 11229 RHOB MWD050 G /CC 2.113 2.823 2.37624 2682 9903.5 11244 DRHO MWD050 G /CC -0.14 0.522 0.109823 2682 9903.5 11244 RPD MWD050 OHMM 5.67 26.42 11.4658 2682 9923.5 11264 RPM MWD050 OHMM 4.99 23.43 10.7512 2682 9923.5 11264 RPS MWD050 OHMM 4.99 19.8 10.1278 2682 9923.5 11264 RPX MWD050 OHMM 5.24 20.9 9.68607 2682 9923.5 11264 FET MWD050 HR 0.27 39.21 2.75346 2682 9923.5 11264 GR MWD050 API 18.26 110.59 37.6128 2682 9916.5 11257 PEF MWD050 B/E 1.08 6.46 2.31443 2682 9903.5 11244 ROP MWD050 FPH 0.28 376.35 134.143 2684 9979.5 11321 NPHI MWD050 PU - 17.76 35.47 24.8232 2682 9888.5 11229 First Reading For Entire File 9888.5 Last Reading For Entire File 11321 File Trailer Service name STSLIB.006 Service Sub Level Name version Number 1 0 0 Date of Generation 09/04/07 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.007 Physical EOF Page 16 I I • 7- 08b.tapx Tape Trailer Service name LISTPE Date 09/04/07 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 09/04/07 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 17 7- 08b.tapx Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue May 05 12:34:30 2009 Reel Header Service name LISTPE Date 09/05/05 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. scientific Technical Services Tape Header Service name LISTPE Date 09/05/05 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PBU MWD /MAD LOGS WELL NAME: 07 -08B API NUMBER: 500292029602 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 05- MAY -09 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: Mw0006119379 Mw0006119379 MW0006119379 LOGGING ENGINEER: T. ONYEKWELU J. PEREZ J. PEREZ OPERATOR WITNESS: B. DECKER B. DECKER B. DECKER MWD RUN 4 MWD RUN 5 JOB NUMBER: MW0006119379 MW0006119379 LOGGING ENGINEER: J. PEREZ J. PEREZ OPERATOR WITNESS: B. DECKER B. DECKER SURFACE LOCATION SECTION: 33 TOWNSHIP: 11N RANGE: 14E FNL: 4276 FSL: FEL: 2906 FWL: Page 1 Dad - Olt ' / 6C3 ! 4 7- 08b.tapx ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 55.30 GROUND LEVEL: 26.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 8249.0 2ND STRING 6.125 7.000 9082.0 3RD STRING PRODUCTION STRING REMARKS: 1. THIS DATA SET SUPERCEDES ALL PREVIOUSLY - ISSUED DATA SETS, SPECIFICALLY THE ONE DATED 4/7/2009. THIS RE -ISSUE INCORPORATES A RE- SHIFTING OF THE MERGED DATA. 2. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 3. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 4. THIS WELLBORE WAS DRILLED OFF OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 8249'MD/7624'TVD IN 7 -08A. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 1. 5. MWD RUNS 1 -5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR), UTILIZING GEIGER - MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR4). MWD RUNS 1,2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD) AND DRILLSTRING DYNAMICS SENSOR (DDSR). MWD RUNS 3 -5 ALSO INCLUDED DRILLSTRING DYNAMICS SENSOR (DDS), COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO - DENSITY (ALD), AND AT -BIT INCLINATION (ABI) . 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER OPEN HOLE GAMMA RAY LOG RUN ON 1 JANUARY 1979. THESE DIGITAL DATA WERE PROVIDED BY D. DORTCH (SAIC /BP) ON 26 MARCH 2009, PER DOUG STONER (BP). AFTER THE DATA WERE SHIFTED TO THE PROVIDED REFERENCE LOG, THEY WERE BULK - SHIFTED 8.7' TO ACCOUNT FOR THE DIFFERENT DFE'S. LOG HEADER AND ANNOTATION DATA RETAIN ORIGINAL DEPTH REFERENCES. THIS SHIFTED MWD LOG IS THE PDCL FOR 7 -08B. 7. MWD RUNS 1 -5 REPRESENT WELL 7 -08B WITH API# 50- 029 - 20296 -02. THIS WELL REACHED A TOTAL DEPTH OF 11321'MD /9027'TVD. Page 2 7- 08b.tapx SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT- DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT- DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT- DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED -HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED (LOW -COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW -COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW -COUNT BIN). DENSLIDE = NON - ROTATED INTERVALS REFLECTING ALD SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" BIT MUD WEIGHT: 8.4 - 8.55 PPG MUD SALINITY: 1100 - 5400 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G /CC MATRIX DENSITY: 2.65 G /CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 service Sub Level Name Version Number 1 0 0 Date of Generation 09/05/05 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 7945.5 11251.0 RPD 8228.0 11258.0 Page 3 7- 08b.tapx RPS 8228.0 11258.0 RPM 8228.0 11258.0 RPX 8228.0 11258.0 FET 8228.0 11258.0 ROP 8243.5 11315.0 FCNT 9069.0 11223.0 NCNT 9069.0 11223.0 RHOB 9069.0 11238.0 DRHO 9069.0 11238.0 NPHI 9069.0 11223.0 PEF 9069.0 11238.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 7953.5 7956.0 7963.0 7965.0 7968.0 7970.0 7969.5 7972.5 7978.5 7979.0 7983.0 7985.5 7988.0 7989.5 7993.5 7995.0 8002.5 8004.0 8006.5 8008.5 8015.0 8018.0 8017.0 8020.0 8022.0 8024.5 8027.5 8030.5 8035.0 8037.0 8039.0 8045.5 8047.5 8054.0 8059.5 8066.0 8090.5 8097.0 8097.0 8103.5 8107.5 8112.5 8117.0 8122.5 8120.5 8125.5 8137.0 8143.5 8143.5 8150.0 8153.0 8158.5 8158.0 8164.5 8162.0 8168.0 8165.0 8171.5 8172.5 8178.0 8176.0 8182.0 8179.0 8185.0 8183.0 8188.5 8186.5 8192.0 8189.5 8195.5 8196.5 8201.0 8223.0 8226.0 8230.0 8233.0 8236.0 8238.5 8245.0 8247.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 7951.0 8288.0 MWD 2 8288.0 9082.0 Page 4 Ili 7- 08b.tapx MWD 3 9082.0 9451.0 MWD 4 9451.0 9979.0 MWD 5 9979.0 11321.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .AIN Max frames per record undefined Absent value -999 Depth units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G /CC 4 1 68 12 4 DRHO MWD G /CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MWD PU -S 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 7945.5 11315 9630.25 6740 7945.5 11315 FCNT MWD CP30 104.4 1573.06 598.191 4309 9069 11223 NCNT MWD CP30 13255.1 36185.8 26416.5 4309 9069 11223 RHOB MWD G /CC 2.027 2.869 2.35508 4339 9069 11238 DRHO MWD G /CC -0.727 0.522 0.0969511 4339 9069 11238 RPD MWD OHMM 0.49 2000 56.8161 6061 8228 11258 RPM MWD OHMM 0.5 2000 28.8945 6061 8228 11258 RPS MWD OHMM 0.46 1789.9 17.6862 6061 8228 11258 RPX MWD OHMM 0.51 1823.76 14.1795 6061 8228 11258 FET MWD HR 0.27 67.62 4.17175 6061 8228 11258 GR MWD API 12.17 504.07 74.1088 6612 7945.5 11251 PEF MWD B/E 0.97 12.67 2.28842 4339 9069 11238 ROP MWD FPH 0.28 376.35 117.728 6144 8243.5 11315 NPHI MWD Pu - 10.24 65.1 23.2568 4309 9069 11223 First Reading For Entire File 7945.5 Last Reading For Entire File 11315 File Trailer Service name STSLIB.001 Service Sub Level Name Page 5 . 410 7- 08b.tapx version Number 1 0 0 Date of Generation 09/05/05 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/05/05 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 7951.0 8220.5 SROP 8249.5 8288.0 LOG HEADER DATA DATE LOGGED: 24 - JAN - SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 8288.0 TOP LOG INTERVAL (FT): 8249.0 BOTTOM LOG INTERVAL (FT): 8288.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8249.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 10.10 MUD VISCOSITY (5): 62.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 1800 FLUID LOSS (C3): 5.2 Page 6 7- 08b.tapx RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 108.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .AIN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service order Units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWD010 FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7951 8288 8119.5 675 7951 8288 GR MWD010 API 63.72 135.63 95.6019 540 7951 8220.5 ROP MWD010 FPH 0.3 15.17 5.12269 78 8249.5 8288 First Reading For Entire File 7951 Last Reading For Entire File 8288 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/05/05 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 service Sub Level Name Page 7 7- 08b.tapx Version Number 1 0 0 Date of Generation 09/05/05 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 8221.0 9034.0 SFXE 8233.0 9026.5 SEXP 8233.0 9026.5 SESP 8233.0 9026.5 SEDP 8233.0 9026.5 SEMP 8233.0 9026.5 SROP 8288.5 9082.0 LOG HEADER DATA DATE LOGGED: 26- JAN -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 9082.0 TOP LOG INTERVAL (FT): 8288.0 BOTTOM LOG INTERVAL (FT): 9082.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 18.3 MAXIMUM ANGLE: 27.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 66259 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8249.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 10.20 MUD VISCOSITY (5): 52.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 2600 FLUID LOSS (C3): 10.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .880 75.0 MUD AT MAX CIRCULATING TERMPERATURE: .490 140.0 MUD FILTRATE AT MT: .910 75.0 MUD CAKE AT MT: .900 75.0 NEUTRON TOOL Page 8 . • • 7- 08b.tapx MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .1IN Max frames per record undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8221 9082 8651.5 1723 8221 9082 RPD MWD020 OHMM 0.49 2000 37.0722 1588 8233 9026.5 RPM MWD020 OHMM 0.5 1310.93 3.92407 1588 8233 9026.5 RPS MWD020 OHMM 0.56 1789.9 4.40451 1588 8233 9026.5 RPX MWD020 OHMM 0.51 1823.76 4.35712 1588 8233 9026.5 FET MWD020 HR 0.33 35.43 3.1805 1588 8233 9026.5 GR MWD020 API 41.73 416.44 154.702 1627 8221 9034 ROP MWD020 FPH 2.9 290.26 116.444 1588 8288.5 9082 First Reading For Entire File 8221 Last Reading For Entire File 9082 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/05/05 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.004 Physical EOF Page 9 7- 08b.tapx File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/05/05 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEXP 9027.0 9395.0 SFXE 9027.0 9395.0 SESP 9027.0 9395.0 SEMP 9027.0 9395.0 SEDP 9027.0 9395.0 SGRC 9034.5 9388.0 SNP2 9075.0 9375.0 CTFA 9075.0 9360.0 SCO2 9075.0 9375.0 TNPS 9075.0 9360.0 SBD2 9075.0 9375.0 CTNA 9075.0 9360.0 SROP 9082.5 9451.0 LOG HEADER DATA DATE LOGGED: 29- JAN -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 9451.0 TOP LOG INTERVAL (FT): 9082.0 BOTTOM LOG INTERVAL (FT): 9451.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 20.2 MAXIMUM ANGLE: 29.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 CTN COMP THERMAL NEUTRON 10508998 EWR4 Electromag Resis. 4 156404 ALD Azimuthal Litho -Dens 10859715 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9082.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 8.50 Page 10 • • 7- 08b.tapx MUD VISCOSITY (S): 49.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 2800 FLUID LOSS (C3): 9.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .600 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .410 104.0 MUD FILTRATE AT MT: .800 58.0 MUD CAKE AT MT: .700 58.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD030 CP30 4 1 68 4 2 NCNT MWD030 CP30 4 1 68 8 3 RHOB MWD030 G /CC 4 1 68 12 4 DRHO MWD030 G /CC 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 B/E 4 1 68 44 12 ROP MWD030 FPH 4 1 68 48 13 NPHI MWD030 PU -S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9027 9451 9239 849 9027 9451 FCNT MWD030 CP30 104.4 1323.53 699.007 571 9075 9360 NCNT MWD030 CP30 13255.1 32916.8 25555.7 571 9075 9360 RHOB MWD030 G /CC 2.027 2.869 2.28759 601 9075 9375 DRHO MWD030 G /CC -0.727 0.371 0.0340782 601 9075 9375 RPD MWD030 OHMM 1.24 2000 266.494 737 9027 9395 RPM MWD030 OHMM 1.25 2000 122.943 737 9027 9395 RPS MWD030 OHMM 0.46 238.49 53.4783 737 9027 9395 RPX MWD030 OHMM 0.84 723.62 40.5859 737 9027 9395 FET MWD030 HR 0.37 67.62 11.1691 737 9027 9395 Page 11 I • 7- 08b.tapx GR MWD030 API 14.04 504.07 75.4162 708 9034.5 9388 PEF MWD030 B/E 1.19 12.67 2.68101 601 9075 9375 ROP MWD030 FPH 12.33 287.31 133.458 738 9082.5 9451 NPHI MWD030 PU -S 10.44 65.1 21.0672 571 9075 9360 First Reading For Entire File 9027 Last Reading For Entire File 9451 File Trailer Service name STSLIB.004 Service Sub Level Name version Number 1 0 0 Date of Generation 09/05/05 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.005 Physical EOF File Header Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/05/05 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CTFA 9360.5 9888.0 TNPS 9360.5 9888.0 CTNA 9360.5 9888.0 SNP2 9375.5 9903.0 SCO2 9375.5 9903.0 SBD2 9375.5 9903.0 SGRC 9388.5 9916.0 SESP 9395.5 9923.0 SEMP 9395.5 9923.0 SEXP 9395.5 9923.0 SEDP 9395.5 9923.0 SFXE 9395.5 9923.0 SROP 9451.5 9979.0 LOG HEADER DATA DATE LOGGED: 31- JAN -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory Page 12 • 7- 08b.tapx TD DRILLER (FT): 9979.0 TOP LOG INTERVAL (FT): 9451.0 BOTTOM LOG INTERVAL (FT): 9979.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.1 MAXIMUM ANGLE: 78.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 CTN COMP THERMAL NEUTRON 10508998 EWR4 Electromag Resis. 4 156404 ALD Azimuthal Litho -Dens 10859715 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9082.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 8.45 MUD VISCOSITY (5): 51.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 5200 FLUID LOSS (C3): 8.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.960 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.275 111.2 MUD FILTRATE AT MT: 1.940 70.0 MUD CAKE AT MT: 1.930 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .AIN Max frames per record Undefined Absent value -999 Depth Units Datum specification Block sub- type...0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD040 CP30 4 1 68 4 2 NCNT MWD040 CP30 4 1 68 8 3 RHOB MWD040 G /CC 4 1 68 12 4 DRHO MWD040 G /CC 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 Page 13 . • • 7- 08b.tapx RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 B/E 4 1 68 44 12 ROP MWD040 FPH 4 1 68 48 13 NPHI MWD040 PU -S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9360.5 9979 9669.75 1238 9360.5 9979 FCNT MWD040 CP30 409.04 1573.06 677.809 1056 9360.5 9888 NCNT MWD040 CP30 21408.3 36185.8 26686.1 1056 9360.5 9888 RHOB MWD040 G /CC 2.058 2.868 2.33974 1056 9375.5 9903 DRHO MWD040 G /CC -0.067 0.467 0.100043 1056 9375.5 9903 RPD MWD040 OHMM 5.77 286.63 58.9387 1056 9395.5 9923 RPM MWD040 OHMM 4.76 223.47 46.837 1056 9395.5 9923 RPS MWD040 OHMM 4.34 109.29 31.8463 1056 9395.5 9923 RPX MWD040 OHMM 3.9 72.28 21.9087 1056 9395.5 9923 FET MWD040 HR 1.16 24.36 4.43575 1056 9395.5 9923 GR MWD040 API 12.17 118.24 30.982 1056 9388.5 9916 PEF MWD040 B/E 0.97 9.16 1.9989 1056 9375.5 9903 ROP MWD040 FPH 0.44 320.97 75.2637 1056 9451.5 9979 NPHI MWD040 PU -S 10.24 29.33 20.4624 1056 9360.5 9888 First Reading For Entire File 9360.5 Last Reading For Entire File 9979 File Trailer Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/05/05 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.006 Physical EOF File Header Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/05/05 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # Page 14 • 7- 08b.tapx FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CTFA 9888.5 11229.0 CTNA 9888.5 11229.0 TNPS 9888.5 11229.0 SCO2 9903.5 11244.0 SNP2 9903.5 11244.0 SBD2 9903.5 11244.0 SGRC 9916.5 11257.0 SEMP 9923.5 11264.0 SEXP 9923.5 11264.0 SESP 9923.5 11264.0 SEDP 9923.5 11264.0 SFXE 9923.5 11264.0 SROP 9979.5 11321.0 LOG HEADER DATA DATE LOGGED: 02- FEB -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 11321.0 TOP LOG INTERVAL (FT): 9979.0 BOTTOM LOG INTERVAL (FT): 11321.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.7 MAXIMUM ANGLE: 90.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 CTN COMP THERMAL NEUTRON 10508998 EWR4 Electromag Resis. 4 156404 ALD Azimuthal Litho -Dens 10859715 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9082.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 8.50 MUD VISCOSITY (S): 50.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 29000 FLUID LOSS (C3): 7.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .500 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .252 125.6 MUD FILTRATE AT MT: .750 60.0 MUD CAKE AT MT: .540 60.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Page 15 . 410 III 7- 08b.tapx # REMARKS: $ # Data Format Specification Record Data Record Type 0 Data specification Block Type 0 Logging Direction Down optical log depth units Feet Data Reference Point undefined Frame spacing 60 .11N Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD050 CP30 4 1 68 4 2 NCNT MWD050 CP30 4 1 68 8 3 RHOB MWD050 G /CC 4 1 68 12 4 DRHO MWD050 G /CC 4 1 68 16 5 RPD MWD050 OHMM 4 1 68 20 6 RPM MWD050 OHMM 4 1 68 24 7 RPS MWD050 OHMM 4 1 68 28 8 RPX MWD050 OHMM 4 1 68 32 9 FET MWD050 HR 4 1 68 36 10 GR MWD050 API 4 1 68 40 11 PEF MWD050 B/E 4 1 68 44 12 ROP MWD050 FPH 4 1 68 48 13 NPHI MWD050 PU -S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9888.5 11321 10604.8 2866 9888.5 11321 FCNT MWD050 CP30 330.6 804.41 545.379 2682 9888.5 11229 NCNT MWD050 CP30 20381.9 31444.2 26493.6 2682 9888.5 11229 RHOB MWD050 G /CC 2.113 2.823 2.37624 2682 9903.5 11244 DRHO MWD050 G /CC -0.14 0.522 0.109823 2682 9903.5 11244 RPD MWD050 OHMM 5.67 26.42 11.4658 2682 9923.5 11264 RPM MWD050 OHMM 4.99 23.43 10.7512 2682 9923.5 11264 RPS MWD050 OHMM 4.99 19.8 10.1278 2682 9923.5 11264 RPX MWD050 OHMM 5.24 20.9 9.68607 2682 9923.5 11264 FET MWD050 HR 0.27 39.21 2.75346 2682 9923.5 11264 GR MWD050 API 18.26 110.59 37.6128 2682 9916.5 11257 PEF MWD050 B/E 1.08 6.46 2.31443 2682 9903.5 11244 ROP MWD050 FPH 0.28 376.35 134.143 2684 9979.5 11321 NPHI MWD050 PU - 17.76 35.47 24.8232 2682 9888.5 11229 First Reading For Entire File 9888.5 Last Reading For Entire File 11321 File Trailer Service name STSLIB.006 service sub Level Name Version Number 1 0 0 Date of Generation 09/05/05 Maximum Physical Record 65535 File Type LO Page 16 7- 08b.tapx Next File Name STSLIB.007 Physical EOF Tape Trailer Service name LISTPE Date 09/05/05 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 09/05/05 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End of LIS File Page 17
