The URL can be used to link to this page

Home My WebLink About206-104Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:206-104 6.50-029-20127-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 12100 12066 9010 8613 12064 7454 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 24 - 104 24 - 104 1530 520 Surface 2666 13-3/8" 23 - 2689 23 - 2689 4930 2670 Intermediate 9179 9-5/8" 21 - 9200 21 - 7940 6870 4760 Production 1053 7" 8677 - 9730 7507 - 8407 8160 7020 Perforation Depth: Measured depth: 11070 - 12050 feet True vertical depth:9014 - 9010 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 19 - 9730 19 - 8407 8613 7454Packers and SSSV (type, measured and true vertical depth) 4-1/2" Otis RH Packer Liner 2812 9288 - 12100 8014 - 9012 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 96010937044627 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Wyatt Rivard wrivard@hilcorp.com Authorized Name: Authorized Title: Authorized Signature with Date:Contact Phone:(907)777-8547 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9012 Sundry Number or N/A if C.O. Exempt: Junk Packer Printed and Electronic Fracture Stimulation Data 5 Install Polar Choke Operations shutdown Change Approved Program 5 n/a Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028305 & 028310 PBU C-06B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 3-1/2" x 3-3/16" x 2-7/8" N/A 368 948 208 700800 670 Bo York By Samantha Carlisle at 1:36 pm, Nov 30, 2020 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.11.30 12:56:30 -09'00' Bo York SFD 12/1/2020DSR-11/30/2020MGR11JAN2021 RBDMS HEW 11/30/2020 ACTIVITY DATE SUMMARY 11/22/2020 CTU #9 1.75" coil 0.156WT Objective: set polar choke Perform weekly bop test. MIRU. Set up equipment for next day (daylight unit). ***In progress*** 11/23/2020 CTU #9 1.75" coil 0.156WT Objective: set polar choke MU/RIH with SLB memory GR/CCL with 2.30" DJSN. Tree had a little bit of ice in it that prevented SSV from stroking fully open. Applied heat and pumped 60/40 to mitigate fairly quickly. Drift to 12,000' CTM, paint flag at 11500' in prep for polar choke setting. Log up to 9086'. POOH. RU Northern Solution 2-7/8" Polar choke and hang in lubricator for am. Lay down for the night. ***In progress*** 11/24/2020 CTU #9 1.75" coil 0.156WT Objective: Set polar choke RIH with Northern Solutions 2-7/8" Polar choke with 8/32 bean choke (0.25"). Set ME at 11524', confirm plug with 3k tag. POOH. RDMO ***Complete*** Daily Report of Well Operations PBU C-06B nr-V.wFZ5V CLP STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Am 3 1 2 w+rD 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown _, ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Mill CBP & CIBP 0 2. Operator Name: BP Exploration (Alaska), Inc 14. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number. 206-104 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-20127-02.00 7. Property Designation (Lease Number): ADL 028305 & 028310 = 8. Well Name and Number: PBU C -06B 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: Total Depth: measured 12100 feet Plugs measured None feet true vertical 9012 feet Junk measured 12064 feet Effective Depth: measured 12066 feet Packer measured 8613 feet true vertical 9010 feet Packer true vertical 7454 feet Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Conductor 80 20" 24-104 24-104 1530 520 Surface 2666 13-3/8' 23-2689 23-2689 4930/3450 2670/1950 Intermediate 9179 9-5/8" 21 -9200 21 -7940 6870 4760 Liner 1053 7" 8867-9730 7507-8407 8160 7020 Liner 2812 3-1/2" x 3-3/16" x 2-7/8" 9288-12100 8014-9012 10160 110570 10530/11170 Perforation Depth: Measured depth: 11070 -12050 feet True vertical depth: 9014-9010 feel Tubing (size, grade, measured and true vertical depth) 4-1/2' 12.6# L-80 19-9730 19-8407 Packers and SSSV (type, measured and 4-1/2" Otis RH Packer 8613 7454 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Md Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 153 8788 38 0 700 Subsequent to operation: 401 44193 82 0 652 14. Attachments: (required per 20 MC 2507025,071, & 2s 2MI 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and conect to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Glasheen, Brian P Contact Name: Glasheen, Brian P Authorized Title: Production Enqineer Contact Email: Brian.GlasheenQbp.com Authorized Signature: / Date: I ; (/ I Contact Phone: +1 907 564 5905 Form 10.404 Revised 04/2017 M`0-r4'FVBDMS3�-FEB 0 12019 Submit Original Only Daily Report of Well Operations PBU C -06B ACT1viTvnATF ¢I innneeav CTU#8 1.75" CT Job Scope: Mill CBP & CIBP, Cont N2 Lift. MIRU CTU. RIH w/ Baker 2-1/8" Milling BHA w/ 2.30" Junk Mill. Dry Tag at 9304'. Appear to be just below the LTP. Mill with no motorwork down to 9400'. Kick off pump & dry drift to a Tag in the 2 7/8" liner at 11225'. Pooh to pick up 1.69" Milling Equipment. 1/3/2019 "'Continue Job on 1/4/19 WSR*" CTU#8 1.75" CT. Job Scope: Mill CBP & CIBP, Cont N2 Lift. MIRU CTU. Drift new Coil w/ 1-3/16" ball. RIH with Baker 1.69" Milling BHA w/ 2.30" Junk Mill. 1/6/2019 ***Continue Job on 1!1/19 WSR**' CTU#8 1.75" CT. Job Scope: Mill CBP & CIBP, Cont N2 Lift. Continue RIH with Baker 1.69" Milling BHA w/ 2.30" Junk Mill. Begin pushing CBP debris at 11230'. Mill/push down to CIBP at 11485'. Get weight back & flag pipe. Attempt to mill plugs. Unable to see motor work. Work tools with same results. Pooh to inspect/change bha. MU & RIH wl Venturi burnshoe BHA wl 2.30" Shoe. Mill CIBP & push to 12064'. Pooh. Jet tubing w/ diesel. Recover CIBP core in burnshoe. Rig up N2 Pump. Unable to route through GC -3 Test Bank to LP Header. GC -3 lined up to HP Header. RIH w/ 2.0" JSN pumping N2 to tanks. Flowed back- 110 bbls. 1/7/2019 **'In Progress*** CTU#8 1.75" CT. Job Scope: Mill CBP & CIBP, Cont N2 Lift. Continue N2 Lift. Lift down to 3500' flowing to tanks. Well kicked off. Divert to GC -3 HP Header. RDMO. 2093 gallons of N2 pumped. 1/8/2019 'Complete" TREE= 4" FMC V1ELLIFAD- MCEVOY AC'n1ATOR= KB. ELEV = BE ELE1/ _ BAKER - 55.4' 35.54' KOP= Max Angle = 3100' 93'@ 11723' Datum MD= 10269' Datum TVD= 88W SS 20' COPD 13-3f8" CSG, 68#, N-80, D = 12.415" C_0 6 B FsAFETY NOTES: WELL ANGLE> 700 @ 10397'. O 2016'4 r-AMCOBAL-OSSSVN,D=3.813" 2097' 13-3/8'X 9-5/8' BOT PBR F�f—{ 2061' 2113' 13-3/B" X 9-5/8' BOT PKR w / LNR FRG, D = Fac 2126' 2686' 9-58" FOC H 4198' Minimum ID = 2.387" @ 10993' 33/16" X 2-7/8" XO 7- BOT PBR(40'),D=? 8 9-5/8" X 7' BOT LTP, HGR & TEBACK, D =7 =8.681' LNR D = 2.992' PPTAG bpf, D=6.184" PERFORATION SUMMARY REF LOG. MCNJCCL/GR OF 0827/06 TIE-IN LOG GEOLOGY PDC LOG ANGLEATTOPP97F: 91° @ 11070' Note: Refer to Production DB for historical pert data SIZE I SPF I INTERVAL I Opn/Sgz I LATE SEE PAGE2 FOR PERFOPATON INFORMATION 1 8066' 1 X 7' XO PN, D=3.90' 19-5/8' X 4-1/2' OTIS RH PKR D = 3.92' 1 13.70' BKR KB LNR TOP P KR D = 2.560- 3.45- LOCATOR SEAL ASSY XO TO 2-7/8' JOINT, D = 2.39' 13.70' FIOVYCO X NP. D = 2.813' 1 MLLOUT WINDOW (C -06B) 9730' - 9738" 3-3/16" LW 6.2#, L-80 TCJ, .0076 bpf, D = 2.80' DATE REV BY COKWENTS DATE REV BY I ODWAENTS 06701!73 ? DRILLED 12/18/17 MSS/JI6UCMIT SQZ, SE7CBP& MLLEDDH 05/09!75 ? ORIGINAL COMPLETION 11/14/18 SK/JM7 ADDED TOP OF LNR DEPTH 07130MB N1E3 RWO 01/09/19 M?/JMO MLLCBP&CIBP(01/07/19) 09/07/98 NORDIC 1 CTD SIDETRACK (C -06A) 08118106 NORDIC 1 CTD SIDETRACK (C-068) 12/13/08 RI"SV SETOBP(11/26/08) 70993'�� ) = 2.X2 1� D = 2.387' PRIDFOE BAY LINT WELL GO6B P97Mf No: 12061040 An No: 5D-029-20127-02 T11N, R14E 1866' FNL & 879' FEL BP Exploration )Alaska) PERFORATION SMAWRY REF LOG: WNJCCL/GR OF 08/27/06 TIE-IN LOG: GEOLOGY PDC LOG ANGLE AT TOP FERE: 91" @ 1107(Y Note: Refer to Production DB for historical cert data 2- 6 I 11890-12 050 I O C -06B RATE REV BY COMr34TS DATE REV BY OCAMENTS 06101173 ? DRILLED 12118117 MiS/JMDCMr SQZ,SEFCBP&MLLEDDFI 05/09175 ? ORIGINAL COMPLETION 11114/18 SK/JN1D ADDED TOP OF LNR DEPTH 07/30188 N1 ES RWO 01/09/19 MUMU MLLCBP&CBP(01107/19) 09107198 NORDIC 1 CTD SIDETRACK JC -06A) 08/28/06 NORDIC 1 CTD SIDETRACK(G-068) 12/13108 RDBISV SETOBP(1126108) TR DHOE BAY UNIT WELL GO6B PEFMT No. `2061040 AH No 50-029-20127-02 SEC 19, TI IR R14E, 1866' FTL & 879' FED 8P Exploration (Alaska) STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well I! Re-enter Susp Well 0 Other: Packer Squeeze 10 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-104 3. Address: P.O.Box 196612 Anchorage, Development 10 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20127-02-00 7. Property Designation(Lease Number): ADL 0028310 Si Well Name and Number: PBU C-06B 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 12100 feet Plugs measured 10480 feet true vertical 9012 feet Junkmeasured 9288 feet Effective Depth: measured 10480 feet Packer measured 8607 feet JAN 1 0 2018 true vertical 8931 feet Packer true vertical 7450 feet r AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" 24-103 24-103 1530 520 Surface 2669 13-3/8" 23-2692 23-2692 4930/3450/4930 2670/1950/2670 Intermediate 8803 9-5/8" 21-8817 21-7623 6870 4760 Production Liner 2812 2-7/8"x3-1/2"x3-3/16"x2-7/8" 9288-12100 8014-9012 10566/10160/1056 11165/10530/1116 Liner 1051 7" 8679-9730 7509-8407 8160 7020 Perforation Depth: Measured depth: 11070-12050 feet True vertical depth: 9014-9010 feet feet Tubing(size,grade,measured and true vertical depth) 4-1/2",L-80 19-9730 19-8407 Packers and SSSV(type,measured and 4-1/2"Otis RH Packer 8607 7450 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED •'C'i'',1 2 3 2 i"17>i Treatment descriptions including volumes used and final pressure: 6� ES 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 153 8788 36 500 700 Subsequent to operation: Shut-In 280 60 14.Attachments:(required per 20 AAC 25.07025.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I3 Exploratory 0 Development I3 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Il Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-401 Authorized Name: Glasheen,Brian P Contact Name: Glasheen,Brian P Authorized Title: Production gi eer Contact Email: Brian.Glasheenfibp.com Authorized Signature: 1 M/C— — Date: r / l /2ot 4 Contact Phone: +1 907 564 5905 Form 10-404 Revised 04/2017 r(i(4 V rt i l/4'`l f RBDMS ti-,1",',4 1 1 218 Submit Original Only • S Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary January 9, 2018 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Repairing the Well with a Packer Squeeze covered under Sundry Approval # 317-401 for Well C-06B, PTD # 206- 104. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • - ai 5 c a) It' oO me a) -) a) L a) o)co ' cm_D T m _j E o cYi M �� Q co a U o a) CO -0 'Q Y O «f i a) 3 c o Q E op Y o CD- U O E `_ .O O N .a c .V T O o@ oo o U Q O N C O -O 'O 1— L W O (o o c a) ` a) a) . Q O) L C Y U ( If c E c b 2 r, a) ,_ vi _ CO J co + •ct m = N o 0- Z ?� U)• u) o ca a m y /0�0� (U + O O O o a) + H. O Y v Q O Qom N coo * Z ~ m W O L i L -,-, N dm E O O N Q co O E L ImoCD- o � � 0 wa a� Q °o _ N Q O a Y Y Z O m J CDa a) 0 E LNC) -O Cl) (vi _ • 2 _ rn S/ CI) CO CO OL 0 LL O • N ❑_ -J co U 0 - L W j W > O — — to Osco — coH 01-2 _2O a) c = U CA 0 a) 00 L o � � L o � c�ia) .0„, 2 -a oho aa)) .0 N O N N N fo co Q) a) N L (o E (.,) O N Q) _ U 0 L- (n _ r. lL E > Cn Q O Cn U Q L7 a) Lam. C ~ i a)•- U . a)N co O O O Q. O E Z 0- a m 0ay 0 1- sZ c N (n ❑ o a on O a) W d W a)"45 CO a LU N (o m � N Z o O m m -) �CO 0. m- (n a) co — 19-.c o co- M j p ao) (� CO � U VaoL�co 00 0 � U cVY Eo c- CSO O m W Q a) a— T rncp Z co 0_w E co a), a O o r- . D O O mo 0 W o a o c U M-. U u) m a J J (N O ? L (� -� N 7 0 C J E O fA O a) N rn 0 = Z u) UJ 0 L op O CO11 in CO Q.N L- 0 a. 0- Nc cm L c ay a) p m 0I * cn � QQ 0 = 0 -0 -0 QQm "a� E cco10� i 0 ai n- * F, -. a) 3 rn o U Q. WJ « IL m 3 0_ co a8i x (� = o a) a) • a) C U)) Q «Q Q ai >, ai a O ai 1- L U 0 U) > ai = -o IX " > (� � � W ° mac * n = � >, o Q 3 •� UQ c W (n Q•- c >I Qg � � 0 � o a°)i � o � � @ U � o - = co v°)) .,..: >,O pp_ -r.,_ o E o > Li] - - 00� I" oi (o ci Eb o 0) com Q� u) -oo 0 co Fi >co scnNo_ O o Es0CV o , am a) � o o cE co fl--' QQ OONa. * Q > N ,— — O Co ,_ _a , N f— I M 0065 - .0 N W' -• O OOZ HU oo amirn a) n 0 (� o 0 a0W ro ° °o o- com vo) s U) V- - W - H a-. O c >,O O - co -- C2LL . J � � T c m ° a)ca) in coQo c 3 coo -a � 3L a) (n v D W 3 a) a ti -a Q(n a_•- 0 3 o a) = W J O H H ❑ J , I— c c- O O ,_ 2 E 7 c ,- a) co m to -a c 2 _ 15 2 J LL Z z W J 00 U .0 00 m -a O dE U 2 `J E O L C W C a) W O O J W 4t O c o U co Q) co i* o c ° aci ID aci c co c 4* 3 50000 � 5 ❑ ctUD • da- �- QU ❑ 't '5L E 'n E c>n o ❑ * I— * * D H i, H C C7 (o m O . a) N a) r: a) 2 O U E- c c) x U) : 1 W + U 2 x 0 LL O 'a 0 'a : U a. i W U N U W 2 : U 2 N r W I- QN- N- r` r- N- ❑ r- O O 0 O O O N N N N N N N N N N 17.= r U r- Q • • O m O N Q C a) L N 0 2 rn H (- J c- M a) N co -C co N O Cci 1, QO CM (I CO -0 C 1- C 0 n C E a) a) E _ U H CO CU O a) (fl 0- E 03 m w E E a) CD N cu U CL Q d rn a) a) 1:1-_ H CO on = U c0 m e 5 CD U °2S E Q ui U EC -1 E CO N CD J E L a a) (6 C 2 O 0 o c).)_C 06 O a Q O 0. C O U G) a) = o __ a) a) c�i) o C C a. O O 0 U) eo * a co c� v E L QON '- 45 (7) 0 0 - O U' F-- Y ° ? a) I- ca a) 5 U co c 3 C B U D j o c a) C J a) CD 0 E LO- F- g E To 30 a) - N- -' E - Y Q) a F- a) co 0 Q) •'C J CO 3 U U Q O _ Q O O : U V °- HDU U H m* Q) O •o CO N U2 � 2 : UtY : Om .- N r- o 0 N N U 1- v- ,Q CO V t0 ("N ( O) CO N N N N TREE= 4"FN1C • WELLHEAD= MCEVOY C-06 B SAFETY NOTES: WELL ANGLE>70°@ 10397°. ACTUATOR= BAKER KB.ELEV= 554' [20"COND — 73' [ BE ELEV= 35-54' 13-3/8"CSG, H 1108' 2016I-14-1/2"CAMCO BAL-O SSSVN,0=3.813" KOP= 3100' 6&#,N-80, tum TVD= 8800' [ 2016' —4-1/2"DREAIVCATCFER 5/16"PORTS(12/26/17) Max Angle= 93°@ 11723' ID=12.415" Datum NU= 10269' 2097' I—13-3/8"X 9-5/8"BOT PBR DaSS 1 9-5/8"FOCI— 2061' 1 2113' J—I13-3/8"X 9-5/8"BOT PKR w/LNR HRG,0=? 0 ; I [925/8"FOC _--1._ 2126' 9-5/8"FOC — 2686' [13-3/8"CSG,72#,N-80,0=12.347' —I 2889' 8066' 1—EST TOC(12107/17) [9-5/8"FOC -L 4188' _i V•1 OA _ _ ._. •• 8623' —14-1/2"OTIS XA SU)SLV,D=3.813" [ :+44 I I 0 8682' —[4-1/2'X 7"X0 PIN,0=3.90" •• .•.• Minimum ID = .3125" @2016' ••4 •• 141 47.4 *it ov. 8683' Hr X 5-1/2'SBR,ID=3.813" 1 •,t 4-1/2" DREAMCATCHER 5/16" PORTS /0 0 /., 4•• .14 ve•E, , ...... -- L 8613' 1-19-5/8"X 4-1/2"OTtS RH PKR 0=3.92" [ eN M 1:7"BOT PBR(40),0=?_[—' 8677' 9288' —FISH:MILLED CBP FROM 8640'&PUSHED TO 9-5/8"X 7'BOT LTP,HGR&TIEBACK,D=? 1— 8717' 4 11 TOP OF LTP-Lb-I IN HOLE CAPS CORE, -6 SLIPS,ELEMENT REMNANTS(12/09/17) 1 9-5/8"CSG,47#,N-80 BUTT,0=8.681" —1 9200' 4 9288' _1-13.70"BKR KB LNR TOP PKR 0=2.560" t.... i: 9293' 1-3.45"LOCATOR SEAL ASSY !TUBING PUNCI-1(08/15/06) [-- 9300'-9306'1 XO TO 2-7/8'JOINT,ID=2.39" i9434' i--[3.70"BOT LNR DEPLOY SLV, )=3.00" 0, • 8 :II' 9464' —3.70"I-40WCO X NP,0=2.813* 2-7/8'LNR 6.4#,L-80 STL,.0058 bpf.,ID=2.441 H semer A . A t 9466' _1—3.70"X 3-1/2"X0,0=2.992' • IA • • li 1 4 • 13-1/2"LNR,9.3#,L-80 STL,.0087 bpf,r)=2.992" —I 9483' 1 • • 1 4 •. 9483' +t3-1'2'X 3-3/16"XO,D=2_786" 4-1/2"MECHANICAL NAWSTOCK(08/16/06) — 9729' V. .• 1,4 • 14-1/2"TBG, 12.6#,L-80, .0152 bpf,ID=3.958"J— 9730' i I 4 s IN&LOUT WNDOW(C-088) 9730'-9738" IRA PIP TAG — 9739' „1 I .• • 11 -SVP SOUBEZE PKR(08/15/06) ---L ' ' J k7/8"LNR STUB(MLLE)08/14/06) — 3760' j 0 iii i A : i• TUBING PUNCH(08/15/06) H 9761'-9766' o • • 10993' —3-3/16"X 2-7/8"XO, ../II'....WA 0 0=2_387' oil- A r LNR,29#,N-80 BUTT -11 10406' oar2smoirmmA 0 'II,IIINAIIIMIIA,• .0371 bpf,0=6.184' f /II .1.,4 •1 [ 11480' 1-1SET C1BP(11/26/08) iripw I PERFORATION SUMARY •pAr REF LOG: MCIAJOCUGR OF 08/27/06 II \ 1 PBTD J— 12068' TE-14 LOG:GEOLOGY PDC LOG 1 3-3/16"LNR,6.2#, —I 10993' i A, ANGLE AT TOP PERE: 91*@ 11070' ....., L-80 TOL .0076 bpf, 4.4 Note:Refer to Production DB for historical perf data ••• ID=2.80" 4.4 \ SIZE SF F INTERVAL Opn/Sgz DATE , •.•-•. SEE PAGE 2 FOR PERFORATION INFORMATION I 12-7/8"LNR,6.4#,L-80 STL,.0058 bpf,ID=2.441" 1 —_, 12100' ih. .o. •., DATE REV BY COM44311TS DATE FV BY COMMENTS PRUDHOE BAY LAW 06/01/73 ? DRILLED 12/13/08 RDB/SV SET CEP(11/26/08) MIL: C-06B 05109/75 ? ORIGINAL COMPLETION 12/18/17 ISS/JM)CMI SQZ,SET CBP&MILLED DH PERNIT No:r2061040 07130/88 N1 RWO 12/28/17 CiNisiNt) SET DREAMCATCHER(12/26/17) API No: 50-029-20127-02 09/07/98 NORDIC 1 CTD SIDETRACK(C-06A) SEC 19,T11N,R14E, 1866'FM_&879'FEL 1 08/28/06 NORDIC 1 CTD SIDETRACK(C-066) 1 06/04/08 *ADM DRAW/NG COWECTTONS BP Bcploration(Alaska) C-06B I I X 1.7 ® ► ♦♦ I I .•• ••• •�• ♦♦ • ♦♦ • i I Z r 1 :1 ►: PERFORATION SUMMARY •i ► • REF LOG: MCP1JCCL/GR OF 08/27/06 N ,1 ► TELOG:GEOLOGY RDC LOG �� ► I1 ► ANGLE AT TOP PERP 91" ! 11070 ♦ Nate:Refertonfor ••' • Not Roducdo COD8 o historical perf data ••♦ • SIZE SW INTERVAL Opn/Sqz SHOT SOZ •. • 2' 6 11070-11370 0 08/27/06 ♦• • ♦. ► 2" 6 11580-11830 C 08/27/06 •4• � 2" 6 11890-12050 C 08/27/06 •♦� i 111 ♦♦♦♦•4 • /♦ ♦ ► ',i/MA ♦ ,# l�!//iIiA 1111111/, 'WA/i ' 1\ IA 0•i' C:. DATE REV BY COtsitilENTS DATE REV BY CON9.434TS PRUDHOE BAY INT 06/01/73 ? DRILLED 412/13/08 RDB/SV SET COP(11,26/08) WELL: C-06B 05109175 ? ORIGINAL COMPLETION • 12/18/17 MSS/14)CMT SQZ,SET C8P&MILLED CH PERMIT No:"2061040 07730/88 NIES RNO 12/28/17 CJNrJMD SET DREAMCATCHER(12/26/17) AR No: 50-029-20127-02 09/07198 NORDIC I CTD SIDETRACK(C-06A) \, SEC 19,T11 N,R14E, 1866'FT!&879'Fa NORDIC 1 CTD SIDETRACK(C-0613) 06/04/08 JAD/PJC DRAINING OORRECTIONS 8P Exploration(Alaska) V OF to. • w 1.* %%y's THE STATE Alaska Oil and Gas • E7.g�"� „ALASKA Conservation Commission 333 West Seventh Avenue gym, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 04t;ALASY' Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Travis Montgomery ��7� Interventions and Integrity Engineer ONt BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-06B Permit to Drill Number: 206-104 Sundry Number: 317-401 Dear Mr. Montgomery: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French �L Chair DATED this day of October, 2017. RBD .MS L 11E.f i 21137 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well EI • Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Pull Tubing 0 Chan a Approv Program 0 Plugfor RedrillPerforate New Pool � �� 0 0 Re-enter Susp Well 0 Alter Casing 0 Other Packer Squeeze 0 • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 206-104 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0• 99519-66126.6. API Number 50-029-20127-02-00 • Stratigraphic ❑ Service ❑ 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU C-06B • C E IV E D Pro erty Field/Pools: 0028310 9 ADLDesignationn (Lease Number): 10. PRUDHOE BAY,PRUDHOE OIL • AUG 2 2 017 11. PRESENT WELL CONDITION SUMMARY Dv S p�lc 17 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Ji, ). 12100 • 9012 ' 9254 7985 9254/10480 Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20"94#H-40 24-103 24-102 1530 520 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 19-9730 Packers and SSSV Type: 4-1/2"Baker KB LT Packer Packers and SSSV MD(ft)and ND(ft): 9288, 8013.39 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development lI- Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil RI • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Montgomery,Travis J • be deviated from without prior written approval. Contact Email: Travis.Montgomery@bp.com Authorized Name: Montgomery,Travis J Contact Phone: +1 907 564 4127 Authorized Title: Interventions&Integrity Engineer Authorized Signature: /1.4,11_, 111074Date:9/2247 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number 3l-T-'4 0l Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other. Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes 0 No il Subsequent Form Required: 1 0 'FO 4— Approved by: APPROVED BYTHE COMMISSIONER COMMISSION Date: .lb (2JI I1 /� VTL 10/20/17 /` \oRIGINAL RE3Daiswoci- 252017 ote 1/2/ zs , r7 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Alaska Oil and Gas Conservation Commission 3333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Application for Sundry Approval (10-403) August 22, 2017 To Whom it May Concern: Attached please find the Sundry Application for a Packer Squeeze for Well C-06B, PTD # 206-104. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 • Wellwork Procedure Request To: Well Intervention Superintendents Date: 07/03/17 VER1 AFE: APBWELIR From: Travis Montgomery -Well Intervention Engineer Brian Glasheen — Base PE IOR: Est. Cost: Subject: C-06B Packer Squeeze Please perform the following steps: 1. S Pull WRP. 2. E Set CBP. 3. D CMIT-TxIA. 4. C Packer Squeeze. Mill CBP. 5. D MIT-IA. 6. S Contingent set dreamcatcher Program Contacts Contact Phone-Work Phone -Mobile/Home Interventions Engineer Travis Montgomery 907-564-4127 918-281-9663 Pad Engineer Brian Glasheen 907-564-5905 907-545-1144 Notes Background DHD recorded a LLR of 0.28 gpm during a CMIT-TxIA at 2500 psi on 12/7/13. DHD then recorded a LLR of 0.43 gpm with IAP at 3000 psi and TP at 1900 psi on 12/20/13. However, no leak was detected by the acoustic LDL at those pressures. A tubing leak was suspected when the IAP tracked with the TP during the MIT-T that was rolled into a CMIT-TxIA on 7/22/14. Although the acoustic LDLs that were performed on 2/1/15 and 4/2/15 indicated a PC leak when the IAP was 3500 psi, a CMIT-TxIA passed to 2419 psi on 10/17/16. The LDL on 4/2/15 also recorded a packer leak signature at IAP and tubing pressures of 3500 psi and when the tubing pressure was bled. None of the three acoustic LDLs were performed with the IA bled down. A possible indication of a wellhead leak during the LDL on 2/1/15 was not repeated during the LDL on 4/2/15. PPPOT-T/IC both passed on 3/6/15. On 11/12/16, DHD recorded LLRs of 0.23 gpm and 0.46 gpm at tubing pressures of 1000 psi and 2000 psi, respectively. However, DHD couldn't reach a tubing pressure of 3000 psi after tubing pressure fell from 2960 psi to 400 psi at 10 gpm. DHD recorded a LLR of 7.27 gpm while pumping down the tubing @ 330 psi and taking returns up the IA on 11/18/16. DHD then found LLRs of 0.43 gpm and 0.5 gpm with IA pressures of 1000 psi and 2000 psi, respectively. The IA was maintaining pressure after it was pressurized to 3000 psi. A leak by the SBR @ 8580' MD and a leak at the packer @ 8613' S • were detected by a spinner LDL that was performed while pumping 1 BPM down the tubing @ 1700 psi and taking returns up the IA on 1/3/1. Objective The objective of this procedure is to fix the TxIA communication with a packer squeeze. Following the set of the CBP and a successful CMIT, a packer squeeze will be performed. Slickline Pull WRP. 1. Pull WRP from 9254' MD. Electric Line Set CBP. 2. Set 4-1/2" composite bridge plug at 8625' MD (top of plug at this depth). This corresponds to —3' below the top collar of the first full joint below the packer. DHD CMIT-TxIA. 3. At surface, perform a CMIT-TxIA to 2380 psi (target pressure). Max applied pressure of 2618 psi. Maximum Anticipated Surface Pressure is 2380 psi from 8/26/16 T/I/O. 4. If test is a failure, contact town for further guidance. Coiled Tubing Packer Squeeze. Mill CBP. 5. See detailed procedure in [Appendix AJ. DHD MIT-IA. 6. Perform a MIT-IA to 2380 psi (target pressure). Max applied pressure of 2618 psi. Slickline Contingent set dreamcatcher. 7. If MIT-IA passes and CBP didn't pass below the perfs, set a dreamcatcher in the safety valve profile at 2016' MD. • • APPENDIX A: CT Packer Squeeze Operation for C-06B From: Travis Montgomery- Intervention Engineer Contact: 918-281-9663 Objective The objective of this procedure is place a cement packer in C-06B to fix the TxIA communication. Cement Design: BHST-207 deg F. SBHP - -3574 psi. BHCT- 195 deg F Cement: Class G Unislurry cement. Batch mixed. Density: 15.8 ppg Thickening time: 4 to 6 hrs. (1 hr surface time + 1 hr pump time + 1 hr clean out + 1 hr contingency) API Fluid Loss: 50-80 (25-40 cc/30 min) Free Water: 0 Compressive Strength: Minimum of 2000 psi Requested Volume: 35.5 bbls pumpable. (27.5 to be placed in the IA) Planned Procedure 1. MIRU 1.75" CT. 2. Ensure an IA line to a reverse out skid is rigged up. Taking returns from the IA will be necessary for this job. IA has been previously loaded with dead crude and will require no additional conditioning. Packer Squeeze 3. MU and RIH with a BDN cementing assembly. 4. Well is now a closed system and it will be necessary to take returns while RIH. 5. Tag composite bridge plug. 6. PUH until weight indicator breaks over plus 1-2' and prep for pumping cement. 7. Verify TxIA communication by pumping down the CT taking returns up the IA. 5 bbls should be sufficient to verify a flow path. 8. Pump the following down the CT taking returns up the CTxTBG annulus to tanks. • 5 bbl freshwater spacer. • 35.5 bbls of 15.8 ppg cement. • CT volume of freshwater to displace cement to nozzle. 9. As cement reaches nozzle, ensure nozzle is -1-2' from the CBP. Allow 1-2 bbls of cement to get above the nozzle and lay in cement 1:1 to -6290' MD. 10. Position nozzle at cement top just as last barrel of cement reaches nozzle. Pull up hole to safety -300' above WCTOC. 11. While at safety, circulate 27.5 bbls of cement into the IA. 12. After placing the 27.5 bbls, shut in IA and take returns from the CTxTBG annulus for the remainder of the job. • • 13. Swap to powervis (1.25 ppb mixed in fresh water) to contaminate cement. Pump 5 bbls, drop ball, and continue pumping powervis. Cleanout cement down to the CBP and lay in powervis from the CBP up to 8095' MD (8.0 bbls). This will help contaminate any cement that leaks back into the tubing. • Maintain -200 psi on the choke for the entire clean out. 14. Chase OOH at 80% with slick 1% KCI, washing the SSSVN. Wash BOP stack. Mill Composite Bridge Plug 15. At surface, make up a motor/mill assembly with a 3.70 junk mill suitable for cement and a CBP. 16. Wait on cement to build at least 500 psi compressive strength based on field blend testing results. Do not RIH until 500 psi compressive strength is reached. 17. Mill composite bridge plug and push to LTP. 18. POOH. 19. Make up a motor/mill assembly with a 2-1/8"junk mill. 20. RIH and mill composite bridge plug and push to 11,420' to ensure that we are past the bottom of perfs at 11,370' MD but won't mill the CIBP at 11,480' MD. If plug didn't pass below the perfs, SL will set a dream catcher. 21. POOH. Ensure that tubing is freeze protected to 2000' with 60/40. TREE= 4"FMC WELLHEAD= MCEVOY • C_0 6 B Airy NOTES: WELL ANGLE>70'@ 10397'. ACTUATOR= BAKER KB.ELEV= 55.4' 20"COND —1 73' N BF.ELEV= 35.54' KOP= 3100' 13-3/8"CSG, H 1108' --X Max Angle= 93*(4;11723' 68#,µ8D, 1 o 1 2016' -14-1/2"CAMCO BAL-O SSSV N,D=3.813" Datum MD= 10269' D=12.415" 2097' H13-3/8"X 9-5/8"BOT PBR Datum ND= 8800'SS 9-5/8"FOC H 2051' 174, .22113' H13-3/8"X 9.5/8"BOT PKR w/LNR HRG,D=? 9-5/8"FOC H 2125' �.+ 45� 9-5/8"FOC H 2686' Imo— k To, of Packer Squeeze-Target TOC in IA-8066' 13-3/8"CSG,72#,N-80,13=12.347" —1 2689' . "ti" 8523' H4-1/2"OTIS XA SLD SLV,D=3.813" 9-5/8"FOC --I 4198' ▪ I I . r �,ti. 5-.7.rti" 8582' —I4 1/2"X 7"XO PIN,D=3.90" ;rti; ;ti" 8583' -17"X 5-1/2"SBR,ID=3.813" Minimum ID =2.387" @ 10992' '., rti 3-3/16" X 2-7/8" XO SUB °' ?" ' �▪ ' r' 8613' H9-5/8"x4-112'oTIS R-I PKR,D=3.92" ►�� 7"BOT PBR(40'),D=? —1 8677' I----ry 9-5/8"X 7"BOT LTP,HGR&TRACK,D=? H 8717' 1 l Z 9264' H4-1/2"WRP(07/22/14) 9-5/8"CSG,47#,N-80 BUTT,ID=8.681" —1 9200' Ha 9288' H 3.70"BKR KB LNR TOP PKR,D=2.560" I 9293' 3.45"LOCATOR SEAL ASSY TUBING PUNCH(08/15/06) —I 9300'-9305' XO TO 2-7/8"JOINT,D=2.39" 9434' —13.70'BOT LNR DEPLOY SLV,ID=3.00" ►� �1 9454' H 3.70"HOVVCO X NP,D=2.813" 2-7/8"LNR,6.4#,L-80 STL,.0058 bpf.,D=2.441 —I 9434' R, ,.: • ✓ 8 9455' —13.70"X 3-1/2"XO,D=2.992" ►♦4 •4 3-1/2"LNR 9.3#,L-80 STL,.0087 bpf,D=2.992" H I 94$$' 14 ►� 9483' H3-1/2"X 3-3/16"XO,D=2.786" 4-1/2"MECHANICAL WHPSTOCK(08/16/06) H 972W •• •i,, 4-1/2"TBG,12.6#,L-80, .0152 bpf,ID=3.958" — 9730' • ♦♦�s� MLLOUT WINDOW(C-060) 9730'-9738" RA PIP TAG —i 9739' i *♦*i ♦4 EZ-SVP SQUEEZE FKR(08/15/06) 9746' 2-7/8"LNR STUB(MILLED 08/14/06) 9760' • N TUBNG PUNCH(08/15/06) 9751'-9756' 'i 'i �� 10993' -1 3-3/16"X 2-7/8"XO, iiia , • ►� D=2.387" 7"LNR,29#,N-80 BUTT —I 10406' ►a _0371 bpf,D=6.184" f///////�i�� 1 11480' —I SET CBP(11/26/08) PERFORATION StARY ' •P , .IAtM REF LOG: MCNJCCL/GR OF 08/27/06 , ` PBTD 120 " TE IN LOG:GEOLOGY PDC LOG I3-3/16"LNR,6.2#, —I 10993' ANGLE AT TOP PERE: 91"@ 11070' •y•, L-80 TCI, .0076 bpf, Note:Refer to Production DB for historical pert data •••, D=2.80" ` SIZE SPF INTERVAL Opn/Sqz DATE 4.4/•.• SEE PAGE 2 FOR PERFORATION NFORMATIDN I I I I 2-7/8"LNR,6.4#,L-80 STL,_0058 bpf,ID=2.441" --I 12100' Srs DATE REV BY CONSENTS DATE REV BY COMMENTS PRUDHOE BAY tNT 06/01/73 ? DRILLED 06/04/08 JAD/PJC DRAWING CORRECTIONS WELL: C-06B 05/09/75 ? ORIGINAL COMPLETION 12/13/08 RCB/SV SET CBP(11/26/08) PERMTNO: 2061040 07/30/88 N1 ES RWO 07/25/14 DJS/JMD SET VVRP(07/22/14) AR No: 50-029-20127-02 09/07/98 NORDIC 1 CTD SIDETRACK(C-06A) SEC 19,T11N,R14E,1866'FNL&879'Fa 08/28/06 NORDIC 1 CTD SIDETRACK(C-06B) 05/06/08 BOO/PJC DRAWING CORRECTIONS BP Exploration(Alaska) • • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Friday, October 20,2017 8:49 AM To: 'Montgomery,Travis J' Subject: RE: PBU C-06B(PTD 206-104,Sundry 317-401)Cement Packer Squeeze Travis, This appears to be more than a packer squeeze with 2300' MD cement above packer. Are there other leaks you are targeting? Victoria From:Montgomery,Travis J [mailto:Travis.Montgomery@bp.com] Sent:Thursday,October 19,2017 5:00 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: FW: PBU C-06B(PTD 206-104,Sundry 317-401)Cement Packer Squeeze Victoria, Just checking on the sundry status for the C-06B packer squeeze. Thanks, Travis From: Montgomery,Travis J Sent:Wednesday,September 13,2017 3:00 PM To:'Loepp,Victoria T(DOA)'<victoria.loepp@alaska.gov> Subject: RE: PBU C-06B(PTD 206-104,Sundry 317-401)Cement Packer Squeeze Victoria, Attached is a post work wellbore schematic for C-06B. Thanks, Travis From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday,September 12,2017 1:02 PM To: Montgomery,Travis J<Travis.Montgomerv@bp.com> Subject: PBU C-06B(PTD 206-104,Sundry 317-401)Cement Packer Squeeze Travis, Please provide a post work wellbore schematic showing the cement and TOC in the IA. Thanx, Victoria 1 • • Loepp, Victoria T (DOA) From: Montgomery,Travis J <Travis.Montgomery@bp.com> Sent: Friday, October 20,2017 9:47 AM To: Loepp,Victoria T(DOA) Subject: RE: PBU C-06B(PTD 206-104, Sundry 317-401)Cement Packer Squeeze Attachments: C-06B post schematic TOC.PDF Victoria, Attached is a post work wellbore schematic for C-06B with the corrected TOC in the IA. I apologize for the error in the previous schematic. Thanks, Travis From: Loepp,Victoria T(DOA) [mailto:victoria.Ioepp@alaska.gov] Sent:Tuesday,September 12,2017 1:02 PM To: Montgomery,Travis J<Travis.Montgomery@bp.com> Subject: PBU C-06B(PTD 206-104,Sundry 317-401)Cement Packer Squeeze Travis, Please provide a post work wellbore schematic showing the cement and TOC in the IA. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov 1 TREE= 4"FMC WE..LF EAD= MCEVOY IP C_0 6 B ilkTy NOTES: WELL ANGLE>70°@ 10397'. ACTUATOR= BAKER KB.REV= 55.4' 20"COND —I 73' 1 BF.BEV= 35.54' KOP= 3100' 13-3/8"CSG, — 1108' '"— Max Angle= 930 @ 11723' 68#,N-80, I O I 2016' 4-1/2"CAMCO BAL-O SSSYN,D=3.813" Datum 1V = 10269' D=12.415" /� 2097' H 13-3/8"X 9-5/8"BOT RBR Datum ND= 8800'SS 9-5/8"FOC --I 2051' I,// 2113' H 13-3/8"X 9-5/8"BOT PKR w/LNR HRG,D=? ►,1 95/8"FOC H 2125' 6 3 M 9-5/8"FOC 2686 " Top acker eze-Target TOC in IA-6290' 13-3/8"CSG,72#,N-80,D=12.347" H 2689' .ti 23' 4-1/2"OTIS XA SLD SLV,D=3.813" 9-5/8"FOC4198' '::' ti" H .1;,' I rti� 8582' H4-1/2"X 7"XO RN,D=3.90" ?;'ti; '?ti. 8583' 7"X 5-1/2"SBR,ID=3.813" Minimum ID =2.387" @ 10992' • ti :;▪ i rti 3-3/16" X 2-7/8" XO SUB •!..:•▪.:\\:.!,:i r -•t 8613' H9-5/8"X 4-1/2"OTIS WIPKR,ID=3.92" 7"BOT PBR(40'),D=? --I 867T 9-5/8"X 7"BOT LTP,HGR&TE3ACK,D=? H 8717' Z 9264' H4-1/2"WRP(07/22/14) 9-5/8"CSG,47#,N-80 BUTT,ID=8.681" — 9200' 9288' H 3.70"BKR KB LNR TOP PKR,D=2.560" 76 9293' 3.45"LOCATOR SEAL ASSY TUBING PUNCH(08/15/06) 9300'-9305' 1PF XO TO 2-7/8"JOINT,D=2.39" � '� 9434' H3.7°"BOT LNR DEPLOY SLV,ID=3.00" r• ,0 9454' H 3.70"HOWCO X NP,D=2.813" 2-7/8"LNR,6.4#,L-80 STL,.0058 bpf.,D=2.441 � 9434' ► !: ---1 • 14 .• � 9455' H 3.70"X 3-1/2"XO,D=2.992" •►♦4 •4 3-1/T LNR,9.3#,L-80 STL,.0087 bpf,D=2.992" H 9483' ►♦4 �� ♦ V94$3' --I 3-1/2"X 33116"XO,D=2.786" 4-1/2"MECHANICAL WHPSTOCK(08/16/06) H 729' ►♦4 ••► 4-1/2"TBG,12.6#,L-80, .0152 bpf,D=3.958" 9730' VsML.LOUT WNDOW(C-06B) 9730'-9738" RA RP TAG 9739' I ♦♦♦♦•4 •4 EZ-SVP SQUEEZE PKR(08115/06/ — 9746' 2-7/8"LNR STUB(ML.L®08/14/06) H 9760' IrTUBNG PUNCH(08/15/06) 9751'-9756' P -- //„ �� 10993' —3-3/16"X 2-7/8"XO, .ro.7il�e ►4 ', 13=2.387" 7"LNR,29#,N-80 BUTT 10406' ,iisiiiiii4 4 ► , .0371 bpf,D=6.184" "I "do I 11480' H SET CEP(11/26/08) )Ir f, RAR FG FORA SUMMARY p 111RIEF LOG: GR OF 08/27/06 , ` PBTD 12066' TE-IN LOG:GEOLOGY PDC LOG , 3-3/16"LNR,6.2#, —) 10993' ANGLE AT TOP PBRF: 91°@ 11070' ••#•4•. L-80 TCI, .0076 bpf, ` (Note:Refer to Rod uction DB for historical pert data •�•�•. D=2.80" J SIZE SPF INT R'VAL Opn/Sqz DATE SCC.. �(�` ` SEE PAGE 2 FOR PERFORATION INFORMATION V I I I I 2-7/8"LNR,6.4#,L-80 STL,.0058 bpf,D=2.441" —I 12100' ilk DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY MT 06/01/73 ? DRILLED 06/04/08 JAD/PJC DRAWING CORRECTIONS WEPL: C-06B 05/09/75 ? ORIGINAL COMPLETION 12/13/08 RDB/SV SET CEP(11/26/08) PBRMTNo: 2061040 07/30/88 N18S MO 07/25/14 DJS/JMD SET WRP(07/22/14) AR I b: 50-029-20127-02 09/07/98 NORDIC 1 CTD SIDETRACK(C-06A) SEC 19,T11 N,R14E,1866'FNL&879'FEL 08/28/06 NORDIC 1 CTD SIDETRACK(C-06B) 05/06/08 BOO/PJC DRAWING CORRECTIONS BP Exploration(Alaska) III • TREE- 4'FMC 0 6 WELLHEAD MCEVOY — SAFETY NOTES:WELL ANGLE>70°@ 10397'. ACTUATOR= BAKER KB.ELEV= 55 4' 20"ODND - 73' F---I i BF aEV= 35.54' X KOP= 3100' i 13-3/8"CSG, - 1108' Max Angle= 93"@ 11723' 6840,N'843: I _ j 2016' 4-12'CAMCO SAL-O SSSVN,D. 3.813' I Datum MD= 10269' D=12.415' r""— 2097' H13-3/8"X 9-5/8-BOT FBR I Datum TVD= 8900'SS 19-5/8'FOCI k 2051' • 0 I 2113' I-113-3/8"X 9-5/8"BOT PK'w/LNR HRG,D=?I ' 9-518'FOC- '25' Ill ' 19-5/8 FOCI 2686' , 1 13-318'CSG,72#,N-80,D=12.347' I- 2689' I 8523' I 4-1/2"OT6 A SLD SLV,D=3.813" I9-5/8'FOC-1 4198' III I 8582' __.1-I4-112"X t XO FiN D=3.90" II - 8583' I-7"X 5 /2'SBR ID=3.813'I Minimum ID=2"387"@ 10992' 3-3/16"X 2-7/8"XO SUB •_' 8613' '9_5/8"X 4-t/2"OTIS RH PKR D=3.92' I 17"BOT POR(40'),D=? H 8677' •Sc D r S 2 19-5/8"X 7"SOT LTP,NCR 8 TEBACK,D=? I--1 8717' • I T '•"54' -4.02"WRP(0722/14) 9-518'CSG,47#,N-80 BUTT,ID=8.681" H 9200' _ � ---I 3.7O'BKR KB LNR TOP R(R D=2.560' 0 � 3.45'LOCATOR SEAL ASSY Tt�NG PUNCH(08/15/06) 93j XO TO 2-718'DONT,ID=2.39" pair 9434'j-3.70"SOT LNR DEPLOY SLV,D=3.00' N ` I 9454' -i 3.70"HOWCO X NP,D=2.813" 2-7/8'LNR,6 4#,L-80 STL, 0058. bpf.,D=2.441 - 9434' p • • ►♦j 9455' —I3.70"X 3-12"XO,D=2.992' 10 011, 13-1/2'LNR,9.3#,L-80 STL,.0087 bpf,D=2.992' --1 9483' 4IA �� 9483' —3.1/2'X 3-3/16"XO,D=2.786' I4-1/2"MECHANICAL WHIPSTOCK(08/16/06) 1 9729' ' : ►1 4-1/2"TBG,12.6#,L-80, .0152 bpf,D=3.958" 9730' /-NIA:. MLLOUT VIMDOW(C 068) 9730' 9738" IRA PPTAG 1 9739' ;:- ♦♦♦t♦ [F-SVP SOUFF7E PKR(08/15/06) 1111=A1111111111111 �♦ 2-7/8"LNR STUB(MLLED 08/14/06) r ii Ni � ITUBG PUNCH(08/15/06) mama0j �� i♦ I 10993' -3-3/16'X 2-7/8'XO, iii. ♦ ♦ j D=2.387" j 7"LNR 29#,N-80 BUTT H 10406' A j4 .0371 bpf,D=6.184" I 1, "►At4 I 11480' -iSET GBP(it/261o8)I i PERFORATION SIJIMAARY I •�� REF LOG: MCW CCUGR OF 0: :7/06 1 STD 12066' i TEN LOG.GEOLOGY PDC L• I I3-3/16"LNR,6 2#, j 10993' ., ANGLE A T TOP FIBRE- 91'r)11070' ''vv. L-80 ICI, 0076 bpf, Note Refer to Productbn DB for tonal perf data 111.1•: D=2.80' SIZE 1 SFF I NTBRVAL Opn/Sqz DATE 1.1.1. SEE PAGE 2 FOR PERFO•, •N NFORIN\TUN I I I 2-7/8'LNR 6.4#,L-80 STL, 0058 bpf,D -J=2.441' I t 12100' oh. DATE REV BY COM.6YTS I DATE REV BY COMrUNTS PRU01-CE BAY UNIT 06101/73 ? DRILL® 06/04/08 JADPJC DRAWING CORRECTIONS WELL. C-068 05109/75 ? ORIGINAL COMPLETION 12/13/08 Roe/SV I SET CEP(11/26/08) PERN1'T No: 2061040 07/30/88 IVES RWO 0725/14 DJS/JMD SET WRP(07/22/14) AR No 50-029-20127-02 09/07/98 NORDIC 1 CTD SIDETRACK(C-06A) SEC 19,T11N,R14E,1866'FNL&879'FEL 08/28106 NORDIC 1 CTD SIDETRACK(C-06B) 05/06/08 BOO/PJC DRAWING COIRECT1DNS BP Exploration� (Alaska) o , J • I a) LO CD N• O O O COO CD 0 0 O O C O CO 6)N O r O rLO - r N V d- f` - - U co O co coO C) 0 ( 0 0 co 0 0 O O • lo V 'Cr O O c0 O O O co • N CO M O N N I� D O N M O N O M C0 c- - O CO CO CO r CO *Cr r 0 0 d' • N N I� co co co o) CA co I 1 1 1 1 1 1 1 1 1 1 1- ✓ 6) OsZr 6) N i,- • co O N 6) O CO CO r- CA N N (.0 CO N O O - N N- CO CO CO 6) Q) M N O O d' cocr) Q O O O N O O M co c0 cp co • O co co N 00 6C ) 6) O O " O) � r r C.) p I I I I I MM Q• C 6) 6) co V co M 0 V' M CD N = 6) I- 00 M C70 6) CJ) N N CO CO N CD CO N a7 - NCO0) 6) 6) O_ • Ca a ,0 0 0 0 O O . 0 0 0 co O o Lo co 0 O co co , co co C _ N co N *k Z N CO V M V .N _ - _ V V O a) O co co 00 -- co c N 00 N CO 00 - o CO M tC) Lc? N N M M A M CO .- c- CA O NC`') N COar r r L() CO .- 6) f"-- 01 �01 0) N CO N 00 .- CO 6) O O C N- M CC) O O N O a) r r N C6r r 6) J W W Ct C:1)0 _Q Q _ H W W W " " ca � QQQ � � U 0 Li_ u_ Ct Cr Z ZWWWWLUWUJ O J j J H H Z Z Z Z Z D Z C/) C(/) (n Z J J J J J H • 410 N co 03 co co co t co co Ln y Co O CI O O O O O O > I- 0_ 0 I- O 6) in L N- 0) ‘— .+ a cYi ai r--: o d v— oo W 0 O O O > O 0 6) 0) 0 > 2 I— WcC 0 0 W Z W W 0 W 0 I- i— J °- W °' 5 5 Y 0 0 > m 0 O W Y Y I- c cn cn J U 0 W W r o 0 o J J J a s z_ fr .�.ra co co C O N U U U W III O J O O 0 a -1 0 E m CD Q Q ¢ = 0 0 a W o 0 0 0 W ..d- ae Z oz W W W d 1- I- Q J Q C) m O cn Cl) v) cn cn arc CO a � Q U C - sono Q c co o) O = d O in co m s—ca d as L N ,.O - = -I = IU— I a J 0a i 2 2 2 0 cn cn cn U cn a) n. y v 0 0 C O (n w cn gl a. a. a. N CO CO m a 0 0 0 CL 0 W -J 0 LLJ CD d cn 1-- o avvv O 1— r A-- CI j D O C 0 0 0 W J J Z LL O N N N Z a. d < W W co N N N 0 W W W J W W L N N N Z d U U U W W W W Q Q 0 0 0 J J D D ct d O CO 0 CC CC J J 0 0 W W Q Q m m LL L. cn cn a. d' N E L6 Z m m m co c.o co 0 0 0 u_ d V) 0 U- N CC LL N 0 0 0 Q Q m Cl- U- ii--Li U) cn d cC a`� • a) ra r l r11-111H: o N o v —0>a Q W11 ° h C7 0 oA .' ca >- 0NZ p _ Q W ' H _. ° a) N cum J�Q7 -J G. T- O r U N 4-+ > F- U U . Q c C C T yO S ns +J a' 'C +-' -0 W a-.* C Q - 7 F t ❑:. U 0U T 7 d • d L.7 co n v) L a1 u i N Q 0 0 C w c E a- -p O C 2 d r M N N OU -0 M 0O 4-' U d• iz = •c O c 0 aC +� u *' co O 1- co N 'o N u ❑ ❑ ❑ ❑ C v p L la- J J J J bO C 4- U O W_ _W W W_ v N c k-r LL LL LL LL ++ a) a) a -O 0 Q _0 > a) d J J J J F 0O pQ Z z z z N L v ° 41 1 {L LL LL LL aC — -0 C > E Ov sO _0 E a Cai a u > 2 O = CO9 c (U `" g 0 ! ` C 1_ > u N .c C co Q O o U U W j a d a) Q v, C Q Z Z.; >S .04 u, � W G, 7.. F, O ❑ 2 ❑ LLco tj co O U J O w A E_ o a _ a 0 co U r >v cc co a � V -J j — C) > Caa 44,o 41 1 1 Ce le . a 17 0 8 o O 1 cu o w a a a a U 5 g m m m m d W W W W VS CI ,41--'pliar ,..-4,1P cn a) U.11 IP z 0 0 0 0 0 -I0000 Av w > LL SY m ccx Y t1 0 CL a a a U � as (o X v) LUr 0 N a (U 0 o00o E O 0 0 0 al �' U U cc co co 0 N O N M C z Y o Y tY m LU o 0 w • ❑ ❑ ❑ (1) UJ QM v,W fa u W Q 00000.0 a CO N v, N `O 71 g I0 yt CO O, N U O O N CN a N N N N L '[ 01 O O O O 4 C N in N N a am cz Lel a)▪ F a) U- co '� a yL Q oti = Z oN z4 . -.. • a▪ ia 1`4 v E m "SLa N U rZ v m o , N co 0 O▪ CA M. 0 E 1`- a` a Q 2.,0rc.-104 2-510 co WELL LOG TRANSMITTAL ¢ PROACTIVE DIAgNosTic SERViCES, INC. APR 2 2 2015 AOGCC To: AOGCC DATA LOGGED Makana Bender SiIS12015 333 W. 7th Ave M.K.BENDER Suite 100 Anchorage,Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MU) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2 - 1 900 Benson Blvd. - Anchorage,AK 99508 gancpdc@bp.comSCANNEL 0 8 2101'3 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 02-Apr-15 C-06B BL/ CD 50-029-20127-02 2) Signed : ,/'i"""""0v(/) .- Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEOMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Archrves\MasterTemplateFlles\Templates\Distribution\TransmrttalSheets\BP_Transmit docx 20G- t0 2.5C01. 0 ELL ►+L� DATA LOGGED TRANSMITTAL s n izoi K BENDER wl „, PROACTIVE DIAGNOSTIC SERVICES, INC. RECEIVED APR 0 9 2015 To: AOGCC AOGCC Makana Bender 333 W. 7th Ave Suite 100 Anchorage,Alaska 99501 SCANNED MAY 0 7 2[15 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MU) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 gancpdc@bp.com and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1] LeakPointTM Survey 31-Jan-15 C-06B BL/ CD 50-029-20127-02 2) Signed : 11),A.L2.4za..,(/) Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-8952 E-MAIL: PDSANCHORAGE(I MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Archrves\MasterTemplateFiles\Templates\Dlstributon\TransmmalSheets\BP_Transmlt docx 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. Q ~ - ~ Q ~- Well History File Identifier Organizing (done) RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ~.wo,,dea uumiiuiiuui DIGITAL DATA ~iskettes, No. ^ Other, No/Type: a„~a~~~cea uiimiiuiuiiiii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~ ~ ~ /s/ (r 1 Project Proofing III II~III IIIII II III BY: Maria Date: ~ ~ /s/ Scanning Preparation ~~ x 30 = _~ + _____~ =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: ' /s/ Production Scanning I II I I'l ll lll ll I I II I Stage 1 Page Count from Scanned File: _ ~~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation : ~ES NO BY: Maria Date: l ~ r1 ~ ~ /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. I I I I I II II I I I II I I II I ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II'll1 III II'I III P P 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 //yy August 22, 2011 RECEIVED Mr. Tom Maunder AUG 31 21M Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Alaska Off & Gas Cam• Go • nissj Anchorage, Alaska 99501 Anchorage Subject: Corrosion Inhibitor Treatments of GPB C -Pad c a p 6 - / 0 q Dear Mr. Maunder, '' 0 b B Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C -01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 K .> C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -19B 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C -20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C -21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -27B 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -28B 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C-31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -358 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C -378 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C -41A 2041880 500292238501 Sealed NA NA NA NA NA C -42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 • } ~ ~` "~.~ ' '- wr. ~` ~~4 ~C ~' ~~~' MICROFILMED 6/30/2010 DO NOT PLACE ANY N EW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • WELL LOG TRANSMITTAL To: State of Alaska August 18, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: C-06B AK-MW-4558964 C-06B: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20127-02 2" x ~" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20127-02 Digital Log Images: ~ ~ - _. 1 CD Rom 50-029-20127-02 ~" PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date:-_ _ - - Signed: aaCo -r UU ~ (o b ts3 ~~ DATA SUBMITTAL COMPLIANCE REPORT 8/4/2008 Permit to Drill 2061040 Well Name/No. PRUDHOE BAY UNIT C-O6B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20127-02-00 MD 12100 TVD 9012 Completion Date 8/28/2006 Complet ion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional S y Yes DATA INFORMATION Types Electric or Other Logs Run: MWD / EWR / SGRD / SGRC / SROP, MGR / CGL / CNL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type~MediFrmt Number Name Scale Media No Start Stop CH Received Comments o~C g Cement Evaluation 5 Col 1 9300 9746 Case 9/12/2006 USCE, 4 1/2 Baker Whipstock w/WPP Tool 16- Aug-2006 D Asc Directional Surrey 9700 12100 Open 10/19/2006 1 ~og Production 5 Blu 9195 11705 '3/22/2007 Mem PPL, GR, CCL, ~~ Temp, Pres, Spin 25-Feb- ~ 2007 /Log Neutron 2 Blu 1 9232 11981 4/30/2007 MCNL, GR, CCL, TNN, 1 TNF 27-Aug-2006 og Neutron 2 Blu 1 9410 12055 4/30/2007 CONeR MCNL & Borax Log, GR, ~ CCL, CNL 25-Feb-2007 C Lis 15132 I ' ' y (~ ~ 9229 11986 ~ ~ 5/16/2007 LIS Veri, GR, CNT, CCL D C Lis 15133 I Cs ~ 9403 12046 5/16/2007 LIS Veri, GR, CNT, CCL D C Lis 15243 InductionlResistivity 9712 12100 Open 6/25/2007 LIS Veri, GR, ROP, Fet w/ Graphics txt PDF F~(it 15243 LIS Verification 9712 12100 Open 6/25/2007 LIS Veri, GR, ROP, Fet Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 8/4/2008 Permit to Drill 2061040 Well Name/No. PRUDHOE BAY UNIT C-06B Operator BP EXPLORATION (ALASKA) INC MD 12100 TVD 9012 Completion Date 8/28/2006 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMATION Well Cored? Y /~ Daily History Received? ~ / N Chips Received? ~T't'N~- Formation Tops `„~" Analysis Received? Comments: API No. 50-029-20127-02-00 UIC N ti Compliance Reviewed By: _ _______ Date: N1 ~~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: C-06B June 21, 2007 AK-MW-4558964 1 LDWG formatted CD rom with verification listing. API#: 50-029-20127-02 __ __ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ~.,. F ~,~~ Date: Signed: ~~(JN =~' ~~ l0(1C w~~ ~J61 ~ ~3~i l~i.~ i.. F..~,~~f~t fi:~i'l.ati Q ,'~IK;~'1('N'iyi~k ~:~ ~' pCo -/0~/ ~ 1 ~-"a1~13 04/25/07 • • Schlu~mberer NO.4229 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 ) ,~ j Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~: "` l t.. ( Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Lo Descri tion Date BL Color C-066 11285939 MCNL ~ ~ «- / 08/27/06 1 1 C-066 11649947 MCNL - 02!25/07 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 ATTN: Beth f Received by ~ ~ ,,~~_ ;APR ~ ~ 2JQ~ ~~ ~ ~S C~nS. L~J~ ~~~w1v10 ~134'~',ft"'yat'B 03/15/2007 ~~~~~~W~~~~i~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well _Inh it ~~-ion/ 1 nn rlncrrin4inn NO. 4184 Company: State of Alaska Alaska Oil & Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n..a.. of n_I_- Z-20 11686722 PRESSITEMP SURVEY 02/26/07 P2-35 11657107 PRODUCTION PROFILE 02/19/07 1 L5-28A 11661127 MEMORY STP 01/30107 1 NK-43 11686716 PRODUCTION PROFILE 02117/07 1 C-066 N/A MEM PROD PROFILE 02125/07 1 05-31A 11686719 SCMT 02/19107 1 03-02 11626072 USIT CORROSION EVALUATION 02122107 1 03-02 11626072 USIT CEMENT EVALUATION 02/22/07 1 2-54/Q-12 11626376 USIT 02/22107 1 4-18/S-30 11638613 USIT 02/12/07 1 DS 03-08 11630455 USIT 02/07/07 1 DS 16-20 11666863 PRODUCTION PROFILE 01/26/07 1 14-24 _ 11549359 RST 12/26/06 1 1 U-066PB1 40011873 OH EDIT MWD/LWD 05/01/05 2 1 U-06B 40011873 OH EDIT MWDILWD 05/08/05 2 1 .-~.-.v.- .-. v,+,.v~~~~vv~ ~~~v~,r 1 ul .~IVI~II~V Iil~v rtC 1 Vnly nvV VIYC I,VrT CN~.1'1 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 , r- -- i - n. 900 E. Benson Blvd. ~ #""-' ~1 i A '#~.,-,, t.-, ~~1 ~1 Anchorage, Alaska 99508 Date Delivered: ~ ~ ~ ~ ~!; ~ oil ~ ?b'' i.~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~~ ~ ~ ~~ • r 14-Sep-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well C-06B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,700.00' MD Window /Kickoff Survey 9,730.00' MD (if applicable) Projected Survey: 12,100.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICHC~3HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Si ned ~ (~~-~4 g Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~i~~I 1 2 2006 WELL COMPLETION OR RECOMPLETION REPORT AND L~I~a~;a Cat ~x Gas Cons. Com~r:~~.~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 10/11 /06 Revised action 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 08/28/2006 12. Permit to Drill Number 206-104 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 08/18/2006 13. API Number 50-029-20127-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 8/25/2006 14. Well Name and Number: PBU C-066 1866 FNL, 879 FEL, SEC. 19, T11 N, R14E, UM Top of Productive Horizon: 757' FNL, 77' FEL, SEC. 30, T11 N, R14E, UM g. KB Elevation (ft): 55.40 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 509' FNL, 1322' FWL, SEC. 29, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 12066 + 9010 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 664514 y- 5959356 Zone- ASP4 10. Total Depth (MD+TVD) 12100 + 9012 Ft 16. Property Designation: ADL 028310 TPI: x- 665421 y- 5955204 Zone- ASP4 Total Depth: x- 666814 y- 5955483 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ~ Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD / EWR / SGRD / SGRC / SROP, MGR / CCL / CNL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 73' Surface 73' 26" 175 sx Arcticset 13-3/8" 68# / 72# N-80 Surface 2689' Surface 2689' 18-1/2" 250 sx Arcticset 3435 sx Arcticset 9-5/8" 47# N-80 Surface 92 0' Surface 7940' 12-1/4" 1070 sx Howco Li ht 20 sx'G' 7" 29# N-80 730' 9962' 8407' 8621' 8-1/2" 450 sx Class 'G' 100 sx Class'G' a-, ir~ x 33/16" x z-~ia° s.~n, s.za ~ s.au L-80 9288' 12100' 8014' 9012 4-1 /8" 137 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24: TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9962' 8613' MD TVD MD TVD 11070' - 11370' 9014' - 9015' 11580' - 11830' 9010' - 9007' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11890' - 12050' 9007' - 9010' DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED 2500' Freeze Protected with 60/40 McOH 26. PRODUCTION TEST Date First Production: October 1, 2006 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 10/1/2006 Hours Tested $ PRODUCTION FOR TEST PERIOD OIL-BBL 1,116 GAS-MCF 8,501 WATER-BBL 6 CHOKE SIZE 96 GAS-OIL RATIO 7,619 FIOW TUbing Press. 1,100 CaSing PreSSUre 620 CALCULATED 24-HOURRATE• OIL-BBL 3,347 GAS-McF 25,502 WATER-BBL 18 OIL GRAVITY-API (CORK) 27. GORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None BFI. oc~ ~ ~ Zoos Form 10-407 Revised 12/2003 ~ ~ ~ I\ ~ TINUED ON REVERSE SIDE r 28. GEOLOGIC MARK 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, Name MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Shublik 9752' 8427' None Sadlerochit 9836' 8508' Top CGL 10028' 8683' Base CGL 10131' 8769' 23S6 /Zone 26 10232' 8836' 22TS 10387' 8905' 21 TS 1 Zone 2A 10569' 8954' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. / `O ~ / Si ned / ~ i D /o~ ~ stant Title Technical Ass ate 9 Terrie Hubble PBU C-06B 206-104 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Robert Laughlin, 564-4080 Permit No. / A royal No. INSTRUCTIONS GeNeRn~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: True vertical thickness. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COM ISSION l~E~EIVED SEP 2 7 2006 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Commission 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 2oAAC2s.~os 2oAAC2s.»o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Clas ora9e ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 08/28/2006 12. Permit to Drill Number 206-104 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 08/18/2006 13. API Number 50-029-20127-02-00 4a. Location of Wel! (Governmental Section): Surface: ' ' 7. Date T.D. Reached 8/25/2006 14. Well Name and Number: PBU C-06B 1866 FNL, 879 FEL, SEC. 19, T11 N, R14E, UM Top of Productive Horizon: 757' FNL, 77' FEL, SEC. 30, T11 N, R14E, UM 8. KB Elevation (ft): 55.40 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 509' FNL, 1322' FWL, SEC. 29, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 12066 + 9010 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 664514 y- 5959356 Zone- ASP4 10. Total Depth (MD+TVD) 12100 + 9012 Ft 16. Property Designation: ADL 028310 TPI: x- 665421 y_ 5955204 Zone- ASP4 Total Depth: x- 666814 y- 5955483 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD / EWR / SGRD / SGRC / SROP, MGR / CCL / CNL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING D EPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 73' Surface 73' 26" 175 sx Arcticset 13-3/8" 68# ! 72# N-80 Surface 2689' Surface 2689' 18-1/2" 250 sx Arcticset 3435 sx Arcticset 9-5/ " 47# N-80 rfa 92 0' Surface 7940' 12-1/4" 1 7 sx How o Li h 200 sx'G' 7" 29# N-80 9962' 8407' 8621' 8-1 /2" 450 sx Class 'G' 100 sx Class 'G' s-v2" x s-~„ s° x 2-7/8" 9.3# / s.2# / 6.4# L-80 9288' 12100' 8014' 9012 4-1l8" 137 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and `24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9962' 8613' MD TVD MD TVD 11070' - 11370' 9014' - 9015' 11580' - 11830' 9010' - 9007' 25. Acio, FRACTURE, CEMENT SQUEEZE, ETC. 11890' - 12050' 9007' - 9010' DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED 2500' Freeze Protected with 60/40 McOH 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc,): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). S A , _e ships; if none, state "none". 7L Non ~; o~GU~M~me.~ (/.~d .M/ g~67 F9Ep '-~-~- 7 Form 1 - 12/2003 ~~''~ C NTiNUED ON REVERSE SIDE - ` ~ ~ ` ~ ~oo~ ~,,, 4 ~. 28. ~ GEOLOGIC MARK 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NaMe MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Shublik 9752' 8427' None Sadlerochit 9836' 8508' Top CGL 10028' 8683' Base CGL 10131' 8769' 23S6 /Zone 2B 10232' 8836' 22TS 10387' 8905' 21 TS /Zone 2A 10569' 8954' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. / n Signed Terrie Hubble ~ Title Technical Assistant Date ~` Z7~v~p PBU C-06B 206-104 Prepared By NameMumber• Terrie Hubble, 564-4628 Well Number Drilling Engineer: Robert Laughlin, 564-4080 Permit No. / A royal No. INSTRUCTIONS GeNewu: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. frets 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page 1 of 17 Operations Summary Report Legal Well Name: C-06 Common Well Name: C-06 Spud Date: 6/27/1973 Event Name: REENTER+COMPLETE Start: 8/3/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 8/28/2006 Rig Name: NORDIC 1 Rig Number: N1 ~ Date From - To . Hours ~ Task Code NPT Phase Description of Operations 8/9/2006 12:00 - 16:30 4.50 MOB N WAIT PRE Rig released from 15-366 ~ 12:00 Hrs on 5/12/2006. W.O. Security to move rig to C-06. Meanwhile prep to move rig off well. PJSM. Jack-up rig & pull • rig off 15-366 well. N/U & P/test 15-36 tree cap. 16:30 - 00:00 7.50 MOB N WAIT PRE W.O. Security & tool services to move rig. Tool services getting rig mats from Rig 2ES move and laying plywood. 8/10/2006 00:00 - 04:00 4.00 MOB N WAIT PRE Wait on Tool services to lay plywood on road and get rig mats for move. 04:00 - 04:30 0.50 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigaiton for rig move to C pad with all personnel. 04:30 - 13:30 9.00 MOB P PRE Move rig to C pad via Oxbow road and West Dock road. 13:30 - 21:00 7.50 MOB N WAIT PRE Rig sank into rut on K-pad road approx. 1 mile to K-pad access road. Attempt to jack rig up to back-up but rig slid further towards edge of road approx. 3' from 36" oil transit line from PM2 to GC1. S/D rig move & inform all parties - IMT, GC1 production center, ADW Management, ACS, EOA production operations. Conduct risk assessment & mobilize 2 CAT D8 pullers and a contingency Vac truck. Meanwhile shut-in FL ~ STP & depressurize FL. 21:00 - 23:00 2.00 MOB N WAIT PRE Position second D8 Cat at 90 deg to rig for side pull away from flowline. Place rig mat and wood blocks infront of rig front tires with fork lift, to prevent rig backing up. Rig mat placed behind back tires to support rig weight as quickly as possible, once rig is pulled/drived back onto rig mat. Flowline was depressured at 2300 hrs. 23:00 - 23:30 0.50 MOB N WAIT PRE SAFETY MEETING. Review procedure, hazards and mitigation for backing rig out of hole in road. 23:30 - 00:00 0.50 MOB N WAIT PRE Back rig out of hole using D8 Cats for side pull. Pull out clean. Clean up timbers used in hole. File hole with gravel. Rig ready to move to C pad. 8/11/2006 00:00 - 05:00 5.00 MOB P PRE Move rig to C pad & align rig in front of C-06 well. 05:00 - 05:15 0.25 MOB P PRE SAFETY MEETING. Review rig back over well procedure, hazards and mitigation. 05:15 - 05:30 0.25 MOB P PRE Back rig over well. ACCEPT RIG ~ 05:30 HRS, 8/11/2006 on C-066. 05:30 - 06:00 0.50 RIGU P PRE PJSM for N/U BOPE. 06:00 - 08:30 2.50 RIGU N WAIT PRE Fetch 1-1/4" x 8-1/2" studs from valve shop for installing additional riser spool on the short C-06 tree. Meanwhile spot outside trailers & tanks. R/U hardline to tiger tank & PT to 4k. 08:30 - 10:30 2.00 RIGU P PRE N/U BOPE & grease tree valves. 10:30 - 10:45 0.25 BOPSU P PRE R/U to P/Test BOPE. 10:45 - 11:00 0.25 BOPSU P PRE PJSM for P/Testing BOPE. 11:00 - 18:30 7.50 BOPSU P PRE Perform initial BOPE pressure /function test witnessed by AOGCC Rep, John Crisp. Meanwhile fill rig pits with 2% KCL bio-water. Held safety stand-down with ANC & discussed the safe way forward amidst all the current Slope distractions. 18:30 - 21:00 2.50 PULL P DECOMP Fill coil with Biozan /KCL water. Pump dart. Dart landed at 55.6 bbls. Cut off CTC. M/U new BOT CTC. Pull /Press test Printed: 9/5/2006 11:09:02 AM BP EXPLORATION Page 2 of 17 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: ell Name: e: Name: From - To ~ C-06 C-06 REENTE NORDIC NORDIC Hours R+COM CALIST 1 Task PLET A Code' E NPT 8/11/2006 18:30 - 21:00 2.50 PULL P 21:00 - 23:00 2.00 PULL P 23:00 - 23:40 0.67 PULL P 23:40 - 00:00 0.33 PULL P 8/12/2006 00:00 - 01:15 1.25 PULL P 01:15 - 03:30 2.25 PULL P 03:30 - 05:00 1.50 PULL P 05:00 - 05:15 0.25 PULL P 05:15 - 07:00 1.75 PULL P 07:00 - 07:15 0.25 PULL P 07:15 - 07:30 0.25 PULL P 07:30 - 08:00 0.50 PULL P 08:00 - 08:40 0.67 CLEAN P 08:40 - 10:45 2.08 CLEAN P 10:45 - 12:15 1.50 CLEAN P 12:15 - 13:00 0.75 CLEAN P 13:00 - 14:40 1.67 CLEAN P 14:40 - 16:00 1.33 CLEAN P 16:00 - 16:45 0.75 CLEAN P 16:45 - 20:30 3.75 CLEAN P 20:30 - 00:00 3.50 CLEAN P 8/13/2006 00:00 - 02:30 2.50 CLEAN P Spud Date: 6/27/1973 Start: 8/3/2006 End: Rig Release: 8/28/2006 Rig Number: N1 Phase Description of Operations DECOMP CTC. DECOMP Held PJSM. R/U BP valve pulling equip. RIH. M/U to BPV. Not able to equalize press. Try twice. Pump thru BPV thru kill line. Pull BPV with 1000 psi lubricator press. Pulled OK. Closed master valve and bleed off press. Recover BPV and rig down. DECOMP M/U BOT 4" GS Spear fishing BHA. 4" GS, Circ sub, Hyd Disc, Bowen Jars, Check valves, and CTC. OAL = 14.24'. DECOMP RIH with BOT liner fishing BHA #1. SIWHP = 630 psi, Bled down quickly to 30 PSI. RIH Circ at 0.3 bpm. DECOMP RIH with BOT GS fishing BHA #1 to 9500'. Circ at 0.3 bpm while RIH. DECOMP Kill well by pumping Biozan/KCL water at 2.8 bpm, Circ. 150 bbls thru choke to Tiger tank. Up wt at 9500' = 34K. Still getting gasy returns after circulating 300 bbls at 2.6 bpm. DECOMP Shut in well and had 50 psi. Open choke and continue to Circ. Getting clean Biozan back with some gas. Continue circ. until we got clean retums. DECOMP RIH to 9600'. Up wt at 9600' = 39K. Sat down on liner deployment sleeve at 9676'. Sat down with 4K, 6K, and 8K down wt. Pick up with no pump with 39.5K up wt. DECOMP POH with fishing BHA, Pump down backside with choke closed, hold 300 psi WHP, bullhead down backside at 0.5bpm while POH at 110 fpm. DECOMP OOH. Flowcheck well for 15mins -stable. DECOMP PJSM. Review procedure for UD liner, well control procedures & requirement for Norm testing. DECOMP S/B injector. R/U & UD BHA #1 & recovered 100% of cut liner assembly consisting of BKR deploy sub & 2.5 jts of 2-7/8" STL tbg without cementralizers (OAL - 70.76'). Test all retrieved pipe for Norm -normal background radioactivity of 3uRem/hr. DECOMP PJSM. Lock-fife & M/U liner milling BHA #2 with a 3.00" Baker pilot mill, Xtreme motor, MHA & 2 jts of PH6 tbg (OAL 85.04'). M/U injector. DECOMP RIH liner milling BHA #2. Tag TOF & stall ~ 9748'. Correct CTD to 9711'. Up wt check - 36k & Run-in wt = 15k. DECOMP Ease-into milling from 9710'. Mill to 9713' with 2.6/2.6bpm 1600/1750psi, Ok WOB & 1.3fph ave ROP. DECOMP Mill to 9714' with 2.6/2.6bpm 1600/2000psi, Ok WOB & 1.3fph ave ROP. Getting metal shavings over the shakers. DECOMP Mill to 9715' with 2.6/2.6bpm 1700/2150psi, Ok WOB & 0.6fph ave ROP. P/U clean & ease back into milling. DECOMP Mill to 9716' with 2.6/2.6bpm 1700/2250psi, Ok WOB & 0.75fph ave ROP. DECOMP Mill to 9717' with 2.6/2.6bpm 1700/2450psi, Ok WOB & 0.75fph ave ROP. Stall 2x C~ 9717'. P/U & ease back into milling. DECOMP Milled to 9719 ft with 2.8 / 2.8 bpm, 1750-2400 psi, 4K WOB, 0.5 fph, Stalled 1 time. DECOMP Milled to 9721 ft with 2.8 / 2.8 bpm, 1750-2400 psi, 6K WOB, 0.6 fph, Stalled 1 time. DECOMP Milled 2-7/8" Liner to 9722.2'. 2.9 / 2.9 bpm, 1800-2400 psi, 4 K WOB, 0.5 FPH, 2 stalls. Printed: 9/5/2006 11:09:02 AM BP EXPLORATION Page 3 of 1'7 Operations Summary Report Legal Well Name: C-06 Common Well Name: C-06 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours i Task Cade ( NPT 8/13/2006 02:30 - 04:30 2.00 ~ CLEAN P 04:30 - 05:30 I 1.00 CLEAN P 05:30 - 07:00 I 1.501 CLEAN I P 07:00 - 07:30 0.50 CLEAN P 07:30 - 07:45 I 0.251 CLEAN I P 07:45 - 09:20 I 1.581 CLEAN I P 09:20 - 09:45 I 0.421 CLEAN I P 09:45 - 10:05 0.33 ~ CLEAN P 10:05 - 11:05 1.00 CLEAN P 11:05 - 11:50 I 0.751 CLEAN I P 11:50 - 13:00 I 1.171 CLEAN I P 13:00 - 13:45 I 0.751 CLEAN I P 13:45 - 15:30 1.75 CLEAN P 15:30 - 16:15 0.75 CLEAN P 16:15 - 16:45 I 0.50 I CLEAN I P 16:45 - 17:45 I 1.001 CLEAN I P 17:45 - 19:40 1.921 CLEAN I P 19:40 - 21:30 1.831 CLEAN P 21:30 - 23:00 1.50 CLEAN P 23:00 - 00:00 1.00 CLEAN P 8/14/2006 00:00 - 02:00 2.00 CLEAN P 02:00 - 04:00 I 2.00 I CLEAN I P Spud Date: 6/27/1973 Start: 8/3/2006 End: Rig Release: 8/28/2006 Rig Number: N1 Phase ~ Description of Operations DECOMP Milled 2-7/8" Liner to 9723.7'. 2.9 / 2.9 bpm, 1800-2400 psi, 4 K WOB, 0.5 FPH, 2 stalls. DECOMP Milled 2-7/8" Liner to 9724'. 2.9 / 2.9 bpm, 1800-2400 psi, 6 K WOB, 0.3 FPH, 2 stalls. Circ. second very high vis pill around, 15 bbls. We had steady fine steel cuttings to surface all night. Seem to be lifting cuttings OK. DECOMP POH to check mill and motor. Pump full rate until BHA at surface to lift out any cuttings. 2.8 bpm, 1700 psi. Got back 3 buckets of metal shavings to surafce. DECOMP OOH. S/B injector. R/U & UO Pilot mill -was 50% worn. Check motor - OK. Take back worn pilot mill to BOT for redressing. DECOMP PJSM. Lock-tite & M/U liner milling BHA #3 with a 3.79" Baker Piranha mill, Xtreme motor, MHA & 2 jts of PH6 tbg (OAL 84.61'). M/U injector. DECOMP RIH liner milling BHA #3. Tag TOF & stall ~ 9761'. Correct CTD to 9724'. Up wt check - 39k & Run-in wt = 17k. DECOMP Ease-into milling from 9723'. Mill to 9725' with 2.55/2.55bpm 1500/1650psi, 1k WOB & 2.3fph ave ROP. DECOMP Mill to 9726' with 2.55/2.55bpm 1500/1750psi, 2k WOB & 3fph ave ROP. DECOMP Mill to 9727' with 2.55/2.55bpm 1500/1750psi, 3k WOB & lfph ave ROP. DECOMP Mill to 9729' with 2.70/2.70bpm 1700/2050psi, 3k WOB & 2.5fph ave ROP. DECOMP Mill to 9730' with 2.65/2.65bpm 1700/2050psi, 6k WOB & 0.85fph ave ROP. Stacking wt. DECOMP Attempt to mill ahead but making no progress. Pump 30bbls of hivis sweep. DECOMP POOH milling BHA#3 chasing hivis sweep OOH. DECOMP OOH. S/B injector. R/U & UO Piranha mill - has a 2-7/8" half-moon groove on its face. DECOMP W. O. redress pilot mill to arrive from BOT. Ask BOT to make another pilot mill for us. DECOMP PJSM. C/O Xtrememotor, hyd disconnect & circ sub. M/U liner milling BHA #4 with a 3.0" Baker Pilot mill, Xtreme motor, MHA & 2 jts of PH6 tbg (OAL - 84.92'). M/U injector. DECOMP RIH liner milling BHA #4. Tag bottom at 9767' and correct depth to 9730'. DECOMP Milled 2-7/8" Liner to 9734', 2.8 bpm, 1980-2200 psi, 1-4K WOB, 0.75 FPH. DECOMP Milled 2-7/8" Liner to 9736', 2.8 bpm, 1980-2200 psi, 2-4K WOB, 1.0 FPH. Circ. 15 bbl high vis pill around with no additional metal recovery. DECOMP Milled 2-7/8" Liner to 9738', 2.8 bpm, 2000-2400 psi, 2-4K WOB, 1.0 FPH. DECOMP Milled 2-7/8" Liner from 9738-9740, 2.9 bpm, 2000-2400 psi, 3-4K WOB, 1 FPH. DECOMP Milled 2-7/8" Liner to 9741, 2.9 bpm, 2000-2600 psi, 3-4K WOB, 0.5 FPH. Printed: 9/5/2006 11:09:02 AM BP EXPLORATION Page 4 of 17 Operations Summary Report Legal Well Name: C-06 Common Well Name: C-06 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Start: 8/3/2006 Rig Release: 8/28/2006 Rig Number: N1 Spud Date: 6/27/1973 End: Date From - To Hours ' Task Code I 8/14/2006 04:00 - 06:15 2.251 CLEAN P 06:15 - 07:30 1.25 CLEAN P 07:30 - 08:00 0.50 CLEAN P 08:00 - 08:30 I 0.501 CLEAN I P 08:30 - 10:15 I 1.751 CLEAN I P 10:15 - 10:40 I 0.42 I CLEAN I P 10:40 - 10:55 0.25 CLEAN P 10:55 - 11:25 0.50 CLEAN P 11:25 - 11:55 I 0.501 CLEAN I P 11:55 - 12:20 I 0.42 I CLEAN I P 12:20 - 12:40 I 0.33 I CLEAN I P 12:40 - 13:05 I 0.421 CLEAN I P 13:05 - 13:45 0.67 CLEAN P 13:45 - 15:05 1.33 CLEAN P 15:05 - 15:25 I 0.331 CLEAN I P 15:25 - 16:00 0.58 CLEAN P 16:00 - 18:00 2.00 CLEAN N 18:00 - 18:30 I 0.50 I CLEAN I N 18:30 - 19:15 I 0.75 I CLEAN I N NPT j Phase ~ Description of Operations DECOMP Milled 2-7/8" Liner to 9742, 2.9 bpm, 2000-2600 psi, 3-4K WOB, 0.5 FPH. Back ream up to 9710' and RIH. Up wt = 32K. DECOMP POOH milling BHA#4 chasing metal cuttings OOH. DECOMP OOH. S/B injector. R/U & UO Pilot mill -- was 80%worn. Observed metal slivers stuck on the CTC -probably slivers from the last Piranha mill run. Check motor - OK. Take back worn pilot mill to BOT for redressing. Conduct valve drill while handling BHA -satisfactory response. DECOMP PJSM. Cut off CTC & rehead & M/U new Baker CTC. Lock-tite & M/U liner milling BHA #5 with a 3.0" Baker Pilot mill, Xtreme motor, MHA & 2 jts of PH6 tbg (OAL - 84.92'). M/U injector. DECOMP RIH liner milling BHA #5. Tag TOF @ 9781'. Correct CTD to 9742'. Up wt check - 39k & Run-in wt = 17k. DECOMP Ease-into milling from 9741'. Mill to 9744' with 2.65/2.65bpm 1780/2000psi, 1k WOB & 4.8fph ave ROP. DECOMP Mill to 9745' with 2.65/2.65bpm 1780/2100psi, 1k WOB & 4fph ave ROP. DECOMP Mill to 9746' with 2.65/2.65bpm 1780/2300psi, 2k WOB & 2fph ave ROP. DECOMP Mill to 9747' with 2.65/2.65bpm 1780/2400psi, 2k WOB & 2fph ave ROP. DECOMP Mill to 9748' with 2.65/2.65bpm 1780/2350psi, 3k WOB & 2.3fph ave ROP. DECOMP Mill to 9750' with 2.65/2.65bpm 1780/2350psi, 3k WOB & 6fph ave ROP. Must have gotten into some cemented and / or rotten pipe. DECOMP Mill to 9753' with 2.55/2.55bpm 1700/2020psi, 3k WOB & 7fph ave ROP. Faster milling break is most likely top of good liner cement. Well cemented liner mills faster. DECOMP Mill to 9754' with 2.80/2.80bpm 1700/2380psi, 3k WOB & 1.5fph ave ROP. DECOMP Mill to 9760' with 2.80/2.80bpm 1700/2380psi, 3k WOB & 4.5fph ave ROP. DECOMP Pump down 30bbls of hivis pill. Stall ~ 9760'. PUH &RBIH with lots of drag. Also circ pressure is spiking up to 4000psi ~ 1.5bpm. Circ hivis pill around mill. CTP lock up ~ 4000psi. Suspect we have some junk around the bit box that is torquing us up. DECOMP POOH milling BHA#5 with 30k ~ drag. Attempt several times to RBIH & shake off junk without success. STUC DECOMP Get mechanically stuck ~ 8760'. Work CT free with 90k pull. Stuck again @ 8653'. Work free. Stuck ~ 8623'. Work CT. Meanwhile callout Cmt pump truck in case we have to open the burst disk to drop disconnect ball. STUC DECOMP Isolate the MM & attempt to pump open the Baker burst disc with Nordic pump -blew pop-off ~ 5100psi. STUC DECOMP Press backside up to 2000 psi and work pipe free going in hole. RIH to 8695 ft, 0.4 bpm, 1800 psi, full returns. Pick up, 25K up wt. Pick up to 8657'. 48K up wt, RIH to 8800'. Printed: 9/5/2006 11:09:02 AM BP EXPLORATION Page 5 of 17 Operations Summary Report Legal Well Name: C-06 Common Well Name: C-06 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To ~ Hours Task Code ~ NPT 8/14/2006 18:30 - 19:15 0.75 CLEAN N STUC 19:15 - 22:15 ~ 3.00 CLEAN ~ N ~ STUC 22:15 - 22:30 0.25 CLEAN N STUC 22:30 - 00:00 1.50 CLEAN P 8/15/2006 00:00 - 01:10 1.17 CLEAN P 01:10 - 02:30 1.33 CLEAN P 02:30 - 02:45 0.25 BOPSU P 02:45 - 04:00 1.25 CLEAN P 04:00 - 04:50 0.83 CLEAN P 04:50 - 06:30 1.67 CLEAN P 06:30 - 07:15 0.75 CLEAN P 07:15 - 08:50 1.58 CLEAN P 08:50 - 11:00 2.17 CLEAN P 11:00 - 11:30 0.50 CLEAN P 11:30 - 11:45 0.25 REMCM P 11:45 - 13:00 1.25 REMCM P Spud Date: 6/27/1973 Start: 8/3/2006 End: Rig Release: 8/28/2006 Rig Number: N1 Phase Description of Operations DECOMP Try to circ. Pump 1.5 bpm, 3300 psi, full returns. Packed off again. RIH to 9050', 10K, Pull up slow, circ max rate at 1.2 bpm, 4300 psi, with mill at 8870'. Press dropped off. Finally able to pump at full rate at normal press. DECOMP Circ. bottoms up [90 bbl] at max rate. 3.0 bpm, 3900 psi. Pumped 70 bbls and press started increasing. Slow rate to 2 bpm at 4000 psi. Pump 100 bbls, pulled up to 8640' and had overpull again, BHA is in X nipple at 8587'. RIH to 8740' and circ at full rate again. 2.8 bpm, 1920 psi. Pump 140 bbls. Pump 30 bbl very high vis sweep around at 3.0 bpm, 2200 psi, work pipe while circ high vis pill around. Chase pill to surface while work pipe from 9000-8700'. DECOMP Circ. high vis pill to surface, saw more metal to surface. Pulled up to 8620' with no overpull. Then 10 K overpull, Pulled up at 10 fpm with 2.9 bpm, Pull up thru X nipple and Slidding sleeve at 8583'. We are free and back in business. DECOMP POH while circ at 2.9 bpm, 2000 psi. POH at 80 fpm. Saw good amount of steel cuttings while POH from 2700' to surface. No overpull at SSSV at 2016'. Bump up and RIH again to 1000' and POH with pump at 2.9 bpm to clean up tubing. DECOMP POH to surface with 2.9 bpm, RIH to 1000'. POH to surface pumping 2.9 bpm.. DECOMP UO BHA, recovered 100%, close swab, jet stack with swizzlestick at 4 bpm, saw more steel on shaker, Pump across kill to flowline. DECOMP Performed weekly BOPE function test. All rams OK. Jet stack after function test to clear any metal shavings. DECOMP C/O packoff, C/O CTC. M/U new Baker 3-1/8" CTC. Pull / Press test - OK. DECOMP PJSM. Lock-tite & M/U cleanout BHA #6 with a 3.79" HC D331 parabolic diamond mill, X/Over, Xtreme motor, MHA & 2 jts of PH6 tbg (OAL - 84.64'). M/U injector. DECOMP RIH cleanout BHA #6 to 9638'. Correct CTD to 9600' -ave correction from last runs = -38'. Up wt check - 39k & Run-in wt = 16k. Meanwhile swap wellbore to clean 2% bio-KCL water. DECOMP Ream in hole from 9600' with 2.7/2.7bpm & 60fph ave ROP. Tag TOL ~ 9761'. DECOMP Backream up hole from 9761' to 9700' with 2.7/2.7bpm & 7fpm. Ream back in hole to 9761'. Make 2 more backreaming & reaming passes. Meanwhile pump down 30bbls of hivis pill & circ up hole past the X-nipple. DECOMP POOH cleanout BHA#6 C~3 20fpm chasing hivis pill OOH. Pull thru X-Nipple without problems. POH at 130 fpm. Circ. at 2.6 bpm. DECOMP UO Milling BHA. Recover 100%. Mill gauged at 3.79" No-Go. WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for R/U SWS to perforate liner. WEXIT Rig up SWS tubing punch equipment with 5' at 4 SPF with Printed: 9/5/2006 11:09:02 AM BP EXPLORATION Page 6 of 17 Operations Summary Report Legal Well Name: C-06 Common Well Name: C-06 Spud Date: 6/27/1973 Event Name: REENTER+COMPLETE Start: 8/3/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 8/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date ~ From - To i Hours Task ~ Code NPT I Phase ~ Description of Operations 8/15/2006 11:45 - 13:00 1.25 REMCM P WEXIT GR/CCL. 13:00 - 14:45 1.75 REMCM P WEXIT RIH and log GR tie-in. Tag PBTD at 9760'. Fired 5', 4 SPF. of Tubing punch from 9751-9756'. one foot off bottom with tools. 14:45 - 16:00 1.25 REMCM P WEXIT POH with tubing punch tools. C/O fired tubing punch 16:00 - 17:00 1.00 REMCM P WEXIT RIH and log GR tie-in. Tag PBTD at 9760'. Fired 5', 4 SPF. of Tubing punch from 9300-9305'. 17:00 - 17:45 0.75 REMCM P WEXIT POH with Tubing punch #2 tools. 17:45 - 18:00 0.25 REMCM P WEXIT M/U Halco 4-1/2" EZDRILL Cement Retainer and setting tool onto SWS GR/CCL logging tools. EZDRILL OD = 3.66". 18:00 - 19:40 1.67 REMCM P WEXIT RIH with retainer. Tie in to GR at 9270. SET retainer with top at 9746'. Observe 300# weight loss. 19:40 - 20:45 1.08 REMCM P WEXIT POH 20:45 - 21:00 0.25 REMCM P WEXIT PU Howco Starguide running tool 21:00 - 23:00 2.00 REMCM P WEXIT RIH to retainer. 1.0 bpm @ 400 psi. RIH to 9700. 1 bpm 430 psi, 2 bpm 750 psi. Up wt 38K, DN wt 18.5K, Tag at 9790. set Down 15K OK. 23:00 - 23:45 0,75 REMCM N DPRB WEXIT Attempt to inject thru retainer. Pressure to 4600 psi no returns. Unsting and resting and repressure. No communications. Pressure to 1500 psi down backside. No communications notify anchorage. 23:45 - 00:00 0.25 REMCM P WEXIT POH 8/16/2006 00:00 - 01:00 1.00 REMCM N DPRB WEXIT POH LD BHA 01:00 - 05:00 4,00 REMCM X WAIT WEXIT Wait on SLB to run Cement bond log. Crews were timed out. 05:00 - 06:45 1.75 REMCM C WEXIT Position SBL E line unit. Rehead E line. 06:45 - 07:00 0.25 REMCM C WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for R/U SWS E Line equipment for running cement bond log. 07:00 - 08:00 1.00 REMCM C WEXIT R/U SWS E Line equipment. 08:00 - 09:30 1.50 REMCM C WEXIT RIH with CML tools. 09:30 - 10:30 1.00 REMCM C WEXIT Log up from 9746' to 9000'. Make repeat from 9746-9500'. 10:30 - 12:00 1.50 REMCM C WEXIT POH with logging tools. 12:00 - 12:15 0.25 WHIP P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for M/U BOT Whipstock onto SWS E Line tools. 12:15 - 13:15 1.00 WHIP P WEXIT M/U BOT Whipstock to SWS tools. Orient Scribe line. Zero depth. 13:15 - 14:30 1.25 WHIP P WEXIT RIH with BOT 4-1/2" Monobore whipstock on SWS E Line. Logged GR/CCL tie-in. Set top of whipstock at 9729'. Orient Whipstock TF to 166 deg LOHS. Set 500# down wt on whipstock. Pick up +400# to shear off. 14:30 - 16:15 1.75 WHIP P WEXIT POH with setting tools. UO setting tools and SWS logging tools. R/D SWS. 16:15 - 16:30 0.25 STWHIP P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for M/U BOT Window Milling BHA. 16:30 - 19:00 2.50 STWHIP P WEXIT RIH with window milling BHA #8 with 3.80" Diamond window mill and string reamer. Circ at 0.2 bpm while RIH. Tag at 9763 Correct 34'. Paint flag. 19:00 - 00:00 5.00 STWHIP P WEXIT Mill window.2.74/2.74 bpm ~ 1650 psi, Time mill per window milling procedure. PT 303 bbl. 8/17/2006 00:00 - 06:00 6.00 STWHIP P WEXIT Continue milling dual exit window2.98 / 2.98 bpm ~ 2220 psi., FS 1700psi, 35k Up Wt, 17K Dn Wt, WOB 6K, 06:00 - 08:00 2.00 STWHIP P WEXIT Mill window thru 4-1/2 x 7" liners, 2.9 bpm, 1830 - 2250 psi, 6K wob, slow milling, Printed: 9/5/2006 11:09:02 AM BP EXPLORATION Page 7 of 17 Operations Summary Report Legal Well Name: C-06 Common Well Name: C-06 Spud Date: 6/27/1973 Event Name: REENTER+COMPLETE Start: 8/3/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 8/28/2006 Rig Name: NORDIC 1 Rig Number: N1 NPT ~ Phase Description of Operations Date From - To i Hours Task Code 8/17/2006 06:00 - 08:00 2.00 STWHIP P WEXIT - Back ream up to 9710'. Ream down stow. 08:00 - 10:00 2.00 STWHIP P WEXIT Mill window thru 4-1/2 x 7" liners, 2.9 bpm, 1650 - 2250 psi, 4-5K wob, slow milling, Milled to 9736'. Very slow, steady progress. 10:00 - 13:00 3.00 STWHIP P WEXIT Mill window thru 4-1/2 x 7" liners, 2.9 bpm, 1650 - 2350 psi, 5K wob, slow milling, Exit 7" Liner at 9737'. 13:00 - 14:00 1.00 STWHIP P WEXIT Time mill 1 ft to allow string reamer to ream exit point. 2.9 bpm, 2000 psi, 1K WOB. 14:00 - 15:45 1.75 STWHIP P WEXIT Mill 10 ft of formation at 7 FPH, 2.9 bpm, 2100 psi. Swap to reconditioned FloPro. 15:45 - 19:30 3.75 STWHIP P WEXIT Ream window up/down 3 times. 2.9 bpm, 2430 psi, Full returns. 34K up wt, 100 psi motor work on first pass up. Ream down, had 90 psi motor work. Two additional pass with slight MW. Dry tag OK. 19:30 - 21:15 1.75 STWHIP P WEXIT POH.Over pull at 9120. RIH and pull back no problem. Continue to POH. 21:15 - 22:30 1.25 STWHIP P WEXIT LD milling BHA mills gauged 3.8 Go, 3.79 NO GO 22:30 - 23:00 0.50 DRILL P PROD1 PJSM Rehhead coil and PU drilling BHA. 23:00 - 23:15 0.25 DRILL P PROD1 Rehead coil. Pull test 40K OK. Fluid pack coil. Pressure test to 3200 psi. 23:15 - 00:00 0.75 DRILL P PROD1 MU drilling build assembly. 8/18/2006 00:00 - 00:30 0.50 DRILL P PROD1 MU building BHA. 00:30 - 02:45 2.25 DRILL P PROD1 RIH tag at 9790 correct to 9748.. 02:45 - 05:40 2.92 DRILL P PROD1 Driectionally drill 2.5/2.6 bpm at 3050 psi, FS = 2550 psi, PT =300 bbl. WOB 2-3K, ROP 29. 05:40 - 05;45 0.08 DRILL P PROD1 Orient to 80 L 05:45 - 07:00 1.25 DRILL P PROD1 Drill build section, 2.7 bpm, 2950 - 3300 psi, 55L, 20 fph, Drilled to 9798'. 07:00 - 07:30 0.50 DRILL P PROD1 Log GR tie-in to log RA depth reference original open hole log. RA tag at 9738.5'. RA = 8.6' from top of whipstock. Whipstock top at 8730'. Top of window at 9730'. Bottom of window at 9738'. 07:30 - 08:00 0.50 DRILL P PROD1 Orient TF. 08:00 - 11:00 3.00 DRILL P PROD1 Drill build section, 2.7 bpm, 2950 - 3300 psi, 55L, 15 fph, Drilled to 9830'. 11:00 - 13:00 2.00 DRILL P PROD1 Drill build section in Shublik, 2.8 bpm, 3000 - 3300 psi, 55L, 10 fph, Drilled to 9844'. 13:00 - 17:00 4.00 DRILL P PROD1 Drill build section in Zone4, 2.8 bpm, 3000 - 3400 psi, 60L, 22 deg incl, 50 fph, Drilled to 9920'. 17:00 - 17:30 0.50 DRILL P PROD1 Orient TF. 17:30 - 18:30 1.00 DRILL P PRODi Drill build section in Zone4, 2.8 bpm, 3000 - 3400 psi, 70L, 25 deg incl, 60 fph, Drilled to 9950'. 18:30 - 19:00 0.50 DRILL P PROD1 Wiper trip to window. 19:00 - 00:00 5.00 DRILL P PROD1 Drilling turn in zone 4. 2.6 / 2.6 bpm @ 2950 psi, FS = 2800 psi. WOB 2K, ROP 25FPH . 8/19/2006 00:00 - 01:45 1.75 DRILL P PROD1 POH Printed: 9/5/2006 11:09:02 AM BP EXPLORATION Page 8 of t ~ Operations Summary Report Legal Well Name: C-06 Common Well Name: C-06 Spud Date: 6/27/1973 Event Name: REENTER+COMPLETE Start: 8/3/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 8/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date i From - To Hours Task Code; NPT Phase Description of Operations 8/19/2006 01:45 - 03:15 1.50 DRILL P PRODi Swap out Bit Motor and Orienter. 03:15 - 05:15 2.00 DRILL P PROD1 RIH. Tag at 10086. Correct to 10048. 05:15 - 05:45 0.50 DRILL P PROD1 POH. to 9780'. Tie - in. Correction-1'. 05:45 - 06:00 0.25 DRILL P PROD1 RIH tag 06:00 - 06:30 0.50 DRILL P PROD1 Orient TF. 06:30 - 08:30 2.00 DRILL P PROD1 Drill Zone 3, 2.7 / 2.7 bpm, 2900 -3400 psi, 36L, 29 deg incl, 08:30 - 11:30 I 3.001 DRILL I P I I PROD1 11:30 - 13:15 I 1.751 DRILL I P I I PROD1 13:15 - 15:00 1.75 DRILL P PROD1 15:00 - 15:15 0.25 DRILL P PROD1 15:15 - 15:30 0.25 DRILL P PROD1 15:30 - 16:30 1.00 DRILL P PROD1 16:30 - 18:30 2.00 DRILL P PROD1 18:30 - 20:45 I 2.251 DRILL I P I I PROD1 20:45 - 21:00 0.25 DRILL P PROD1 21:00 - 21:15 0.25 DRILL P PROD1 21:15 - 00:00 2.75 DRILL P PROD1 8/20/2006 00:00 - 03:30 3.50 DRILL P PROD1 03:30 - 05:30 2.00 DRILL P PROD1 05:30 - 06:45 1.25 DRILL P PROD1 06:45 - 08:30 1.75 DRILL P PROD1 08:30 - 09:00 0.50 DRILL P PROD1 09:00 - 09:45 0.75 DRILL P PROD1 09:45 - 11:45 2.00 DRILL P PROD1 11:45 - 12:45 I 1.001 DRILL A P I I PROD1 12:45 - 14:15 ~ 1.501 DRILL P PROD1 14:15 - 15:10 I 0.921 DRILL I P I I PROD1 15:10 - 15:30 0.33 DRILL P PROD1 15:30 - 17:30 2.00 DRILL P PROD1 17:30 - 19:30 I 2.001 DRILL I P I I PROD1 10 fph, Drilled to 10068'. Drill Zone 3, 2.7 / 2.7 bpm, 2900 - 3400 psi, 36L, 29 deg incl, 6 fph, Very slow drilling in Z3. Drilled to 10089'. Drill Zone 3, 2.7 / 2.7 bpm, 2900 - 3400 psi, 36L, 29 deg incl, 2 fph, Very slow drilling, Drilled to 10093'. POH for bit. UO Drilling BHA. Bit graded at [ 8, 6, I ]. SAFETY MEETING. Review procedure, hazards and mitigation for cutting off coil with hyd cutter. Cut off 600' of coil for coil life maintenance. This will move fatigue point above window. M/U CTC, pull/press test, M/U Used Hycalog BC bit, 1.4 deg Xtreme motor and Sperry MW D. OAL =64.65'. RIH orient low side thru window. RIH tag TD correct to 10093'. PU to 9780. Tie - in. Correction No correction. RIH. Orient to 20L Drilling 2.52 / 2.55 bpm C~? 3325 psi. FS 2850 psi, Directionally drill 2.54 /2.58 bpm C~ 2870 psi FS = 2650, 2-3L wob, ROP 12. Drill to 10135'. POH for slow ROP. POH. Flag pipe at 9500' UO Bit and motor. M/U new HCC BC Bit #10 and new 1.5 deg Xtreme motor. M/U Sperry MWD. RIH with Build /Turn BHA #12. Circ at min rate while RIH. Log GR tie-in at RA tag. -3.5' CTD. RIH clean to TD. Tag at 10,138'. Drill in Zone 2, 2.7 / 2.7 bpm, 2800-3200 psi, 20R, 42 deg incl, Drilled to 10165'. Drill in Zone 2, 2.7 / 2.7 bpm, 2800-3200 psi, 70L, 46 deg incl, Drilled to 10184'. Drill in Zone 2, 2.7 / 2.7 bpm, 2800-3200 psi, 70L, 52 deg incl, Drilled to 10220'. Drill in Zone 2, 2.7 / 2.7 bpm, 2900-3400 psi, 50L, 55 deg incl, Drilled to 10243'. Orient TF to 70L. Drill in Zone 2, 2.7 / 2.7 bpm, 3000-3500 psi, 80L, 58 deg incl, Drilled to 10270'. Drill in Zone 2, 2.7 / 2.7 bpm, 3000-3500 psi, 80L, 60 deg Printed: 9/5/2006 11:09:02 AM BP EXPLORATION Page 9 of 17 Operations Summary Report Legal Well Name: C-06 Common Well Name: C-06 Spud Date: 6/27/1973 Event Name: REENTER+COMPLETE Start: 8/3/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 8/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date ~ From - To Hours Task ~ Code ~ NPT Phase i Description of Operations 8/20/2006 17:30 - 19:30 2.00 DRILL P PROD1 incl, Drill to 10298. 19:30 - 20:30 1.00 DRILL P PROD1 Wiper to window 20:30 - 22:15 1.75 DRILL P PROD1 Drill in Zone 2, 2.7 / 2.7 bpm, 3000-3500 psi, 2950 FS, 67L, 63 deg incl, Drill to 10340. ROP increase to 30-50 fph. 22:15 - 00:00 1.75 DRILL P PROD1 Drill in Zone 2, 2.7 / 2.7 bpm, 3100 psi, 2800psi FS, 50L, 69 deg incl, Drill to 10397'. 8/21/2006 00:00 - 03:00 3.00 DRILL P PROD1 Drill in Zone 2, 2.7 / 2.7 bpm, 3100 psi, 2800psi FS,78L, 70 deg incl, Drill to 10441 03:00 - 04:30 1.50 DRILL P PROD1 Wiper to window. 04:30 - 04:45 0.25 DRILL P PROD1 Drill in Zone 2, 2.7 / 2.7 bpm, 3100 psi, 2800psi FS,78L, 70 deg incl, Drill to 10447. 04:45 - 06:30 1.75 DRILL P PROD1 POH 06:30 - 09:30 3.00 DRILL P PROD1 C/O bit and motor, M/U HCC BC Bit#11, New Xtreme 1.3 deg motor, Sperry RES too and MWD. Upload RES tool. OAL = 89.29'. 09:30 - 11:15 1.75 DRILL P PROD1 RIH with RES /MWD BHA #13, Circ at min rate. SHT tools. RIH. 11:15 - 11:30 0.25 DRILL P PROD1 Orient TF to lowside above window. 11:30 - 11:50 0.33 DRILL P PROD1 RIH clean thru window. Subtract -38' before logging to save time. Log GR tie-in at RA tag. -5' CTD correction, -43' total. 11:50 - 12:00 0.17 DRILL P PROD1 RIH clean to bottom. 12:00 - 12:20 0.33 DRILL P PROD1 Orient TF to 100L. 12:20 - 16:00 3.67 DRILL P PROD1 Drill turn section in Zone 2 with RES tool. 2.7/2.7 bpm, 3100-3600 psi, 90L, 75 deg incl, 30 fph, Drilled to 10535', GEO samples show about 60%chert still. 16:00 - 19:00 3.00 DRILL P PROD1 Drill turn section in Zone 2 with RES tool. 2.7/2.7 bpm, 3100-3600 psi, 90L, 75 deg incl, 40 fph, Drilled to 10,580'. GEO sample at 10,550' had 20% chert. 19:00 - 20:15 1.25 DRILL P PROD1 Wiper 20:15 - 23:30 3.25 DRILL P PROD1 Drill tum section in Zone 2 with RES tool. 2.65!2.62 bpm, 2800 psi, 99L, 75 deg incl, 26 fph, drilled to 10645. Stacking slow drilling .Sample show 80% chert. Starting to see rubber over the shaker. Stalling continuously. Coil life 50% becoming a concern. 23:30 - 00:00 0.50 DRILL P PROD1 POH 8/22/2006 00:00 - 01:30 1.50 DRILL P PROD1 POH 01:30 - 03:15 1.75 DRILL P PROD1 Change out Bit, motor,& MHA. Bit 03:15 - 05:40 2.42 DRILL P PROD1 RIH orient to low side the enter window. RIH to 9800. 05:40 - 06:05 0.42 DRILL P PROD1 Log tie -in. Correction -44 06:05 - 06:30 0.42 DRILL P PROD1 RIH, clean hole, tag bottom at 10,645'. 06:30 - 06:45 0.25 DRILL P PROD1 Orient TF to 100L. 06:45 - 09:00 2.25 DRILL P PROD1 Drill Zone 2A, 2.7 / 2.7 bpm, 2800-3400 psi, 110L, 77 deg incl, 30 fph, Drilled to 10715'. 09:00 - 11:00 2.00 DRILL P PROD1 Drill Zone 2A, 2.7 / 2.7 bpm, 2800-3400 psi, 110R, 79 deg incl, 30 fph, Drilled to 10,748'. 11:00 - 12:30 1.50 DRILL P PROD1 Drill Zone 2A, 2.7 / 2.7 bpm, 2800-3400 psi, 120R, 79 deg incl, 20 fph, Drilled to 10,765'. 12:30 - 14:15 1.75 DRILL P PROD1 Drill Zone 2A, 2.7 / 2.7 bpm, 2800-3400 psi, 120R, 79 deg Printed: 9/5/2006 11:09:02 AM r~ BP EXPLORATION Page 10 of 17 Operations Summary Report Legal Well Name: C-06 Common Well Name: C-06 Spud Date: 6/27/1973 Event Name: REENTER+COMPLETE Start: 8/3/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 8/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task ~ Code NPT Phase i Description of Operations 8/22/2006 12:30 - 14:15 1.75 DRILL P PROD1 incl, 20 fph, 14:15 - 14:35 0.33 DRILL P PROD1 Orient TF around to 15R 14:35 - 16:00 1.42 DRILL P PROD1 Drill Zone 2A, 2.7 / 2.7 bpm, 3150-3500 psi, 9R, 769 deg incl, 20 - 25 fph 16:00 - 17:00 1.00 DRILL P PROD1 Wiper trip, no hole problems 17:00 - 19:30 2.50 DRILL P PRODi Drill Zone 2A, 2.7 / 2.7 bpm, 3200-3650 psi, 10-25R, periodically stalling bit and stacking weight. Drilled to 10808'. 19:30 - 21:20 1.83 DRILL P PROD1 Grind on to 10825' with 15R TF, 2.7/2.7bpm, 3100/3500psi, 7k WOB & 5fph ave ROP. Observe freespin pressure fluctuating from 3000psi to 3400psi. Decide to POOH to inspect BHA. 21:20 - 23:10 1.83 DRILL P PROD1 POOH drilling BHA #14. 23:10 - 00:00 0.83 DRILL P PROD1 OOH. PJSM. S/B injector. L/D drilling BHA #14. Observed clay balling on CTC & bit. Also, bit has 2 rubber pieces in it plugging one internal jet on the guage & 1 jet on the nose was plugged with shale. Found additional rubber piece over the shakers. C/O 1.3degs X-treme motor & bit. Scribe tools. 8/23/2006 00:00 - 00:30 0.50 DRILL P PROD1 Download RES data & initialize EWR. 00:30 - 00:45 0.25 DRILL P PROD1 PJSM for cutting CT. 00:45 - 01:00 0.25 DRILL P PROD1 R/U hydraulic cutter & cut 200' of CT for fatigue management. Have 13143' of CT left on reel. 01:00 - 01:15 0.25 DRILL P PROD1 Rehead & install SLB CTC. Pull test to 35k & P/test to 3500psi - OK. 01:15 - 01:45 0.50 DRILL P PROD1 M/U drilling BHA #15 with 1.3degs X-treme motor, MWD/GR/RES, orienter & rerun Hughes 3-3/4" x 4-1/8" RWD2ST bicenter bit #13. M/U injector. 01:45 - 03:40 1.92 DRILL P PROD1 RIH drilling BHA #15. SHT tool ~ 3000' - OK. Continue RIH to 9040'. Correct CTD to 9000'. RIH clean thru window. 03:40 - 03:50 0.17 DRILL P PROD1 Log up GR & tie into RA Pip tag -Subtract 7' from CTD. 03:50 - 04:10 0.33 DRILL P PRODi RIH & tag btm C~? 10822'. 04:10 - 05:45 1.58 DRILL P PRODi Drill to 10857' with 15-40R TF, 2.7/2.7bpm, 2800/3150psi, 4k WOB & 30fph ave ROP. 05:45 - 06:15 0.50 DRILL P PROD1 Orient 2 clicks & drill with 85R TF, 2.7/2.7bpm, 2800/3250psi, 3k WOB & 80fph ave ROP. 06:15 - 06:25 0.17 DRILL P PROD1 Orient TF around to 25R 06:25 - 06:50 0.42 DRILL P PROD1 Drill with 20-41 R TF, 2.6/2.6bpm, 3100/3475psi, 4k WOB, ROP 100-140fph 06:50 - 07:10 0.33 DRILL P PROD1 Orient 2 clicks & drill with 84-102R TF, 2.7/2.7bpm, FS 3050psi, 3300/3700psi, 3k WOB, ROP 80-120fph, TF rolling to right 07:10 - 07:30 0.33 DRILL P PROD1 Orient TF around to 60R 07:30 - 07:50 0.33 DRILL P PROD1 Drill with 45-75R TF, 2.68/2.68bpm, 3100/3475psi, 4k WOB, ROP 100-140fph 07:50 - 08:00 0.17 DRILL P PROD1 Orient TF around to HS 08:00 - 08:20 0.33 DRILL P PROD1 Drill with 15R TF, 2.68/2.68bpm, 3127/3505psi, 2-4k WOB, ROP 129fph 08:20 - 09:35 1.25 DRILL P PROD1 Wiper Trip 09:35 - 09:50 0.25 DRILL P PROD1 Drill with 17-35R TF, 2.7/2.7bpm, 3347/3700psi, 4k WOB, ROP 150fph 09:50 - 10:40 0.83 DRILL P PROD1 Orient 2 clicks & drill with 82-90R TF, 2.7/2.7bpm, FS 3050psi, 3300/3700psi, 3k WOB, ROP 80-120fph, 20 deg doglegs to right 10:40 - 10:45 0.08 DRILL P PROD1 Orient, Drill with 82-90R TF, 2.7/2.7bpm, FS 2900psi, 3300/3700psi, 3k WOB, ROP 80-120fph, 20 deg doglegs to Printed: 9/5/2006 11:09:02 AM BP EXPLORATION Page 11 of 17 Operations Summary Report Legal Well Name: C-06 Common Well Name: C-06 Spud Date: 6/27/1973 Event Name: REENTER+COMPLETE Start: 8/3/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 8/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To ~ Hours Task Code' NPT Phase Description of Operations 8/23/2006 10:40 - 10:45 0.08 DRILL P PROD1 right 10:45 - 12:15 1.50 DRILL P PROD1 Wiper trip while discussing w/ Anch office about polygon width 12:15 - 14:00 1.75 DRILL P PROD1 14:00 - 16:00 2.00 DRILL P PROD1 16:00 - 16:10 0.17 DRILL P PRODi 16:10 - 17:50 1.67 DRILL P PROD1 17:50 - 19:45 1.92 DRILL N DFAL PROD1 19:45 - 20:30 0.75 DRILL N DFAL PROD1 20:30 - 21:15 0.75 DRILL P PROD1 21:15 - 22:45 1.50 DRILL N DFAL PROD1 22:45 - 23:25 0.67 DRILL N DFAL PROD1 23:25 - 00:00 0.58 DRILL N DFAL PROD1 8/24/2006 00:00 - 00:10 0.17 DRILL N DFAL PROD1 00:10 - 00:45 0.58 DRILL N DFAL PRODf 00:45 - 02:25 1.67 DRILL N DFAL PROD1 02:25 - 03:10 0.751 DRILL I N DFAL PRODi 03:10 - 03:40 0.50 DRILL N DFAL PROD1 03:40 - 05:40 2.00 DRILL N DFAL PROD1 05:40 - 09:00 I 3.331 DRILL I N I DFAL I PROD1 09:00 - 09:35 I 0.581 DRILL I P I I PROD1 09:35 - 09:40 I 0.081 DRILL P PROD1 09:40 - 10:40 I t.001 DRILL I P I PRODi 10:40 - 11:00 0.331 DRILL P PROD1 11:00 - 11:10 0.17 DRILL P PROD1 11:10 - 11:25 0.25 DRILL P PROD1 11:25 - 12:00 0.58 DRILL P PROD1 12:00 - 13:20 i.33 DRILL P PROD1 13:20 - 13:35 0.25 DRILL P PROD1 13:35 - 14:10 0.58 DRILL P PROD1 extension, drilling and geology approve drilling outside the south side of polygon Orient, Drill with 95-53L TF, 2.53/2.53bpm, FS 2900 psi, 3380/3710psi, 3-5k WOB, ROP 125fph Wiper trip, tie-in pass w/ +4' correction Orient TF around to 85L Drill with 95-62L TF, 2.71/2.71bpm, FS 3050 psi, 3560/3904psi, 3-5k WOB, ROP 43-75fph, Note: TF rolled left to 165R at 11247', PU off btm, set down on btm TF rol-ed to right to 65L, stacking wt, mtr stalling several times, ROP dropped off to 15' POH to BHA #15 OOH. PJSM. S/B injector. L/D drilling BHA #15. Observed clay balling around bit gauge cutters and jets. Also, bit has 2 rubber pieces in it plugging one internal jet on the on the nose. Download RES data & initialize EWR. Fetch new motor from BHI. M/U drilling BHA #16 with new 1.3degs X-treme motor, MWD/GR/RES, orienter & rerun Hycalog 3-3/4" DS49 PDC bit #14. Scribe tools. M/U injector. RIH drilling BHA #16. RIH drilling BHA #16. SHT tool @ 3000' -MWD not decoding data. POOH to C/O tools. OOH. S/B injector. C/O MWD probe &orienter. Re-initialize EWR. M/U injector. RIH drilling BHA #16. SHT tool ~ 3000' -MWD still not decoding data. Pulse test MWD ~ surface - OK. POOH to C/O tools. OOH. S/B injector. C/O EWR & D&I package. Re-scribe tools. Re-initialize EWR. M/U injector. Pulse test MWD ~ surface OK. RIH drilling BHA #16, SHT MW D tools, RIH, orient thru window with TF at 143L, Tie-in pass, -6' correction, RIH to 11249', tagged btm, corrected depth, no openhole problems Attempt to orient TF around to 95L, clicks not responding, TF at 131 L Drill w/ TF at 148-166L, 2.46 bpm, FS at 2950 psi, 3140/3523psi, 0-1k WOB, ROP 72fph POH to 9775', no response, POH above window to 9690', no response POH to BHA, noticing additional drag f/ 29k to 45k while POH f/ 9690' to 9375', up wt resumed to normal, orient f/ 148E to 107E w/ two clicks RIH to 9780 below window Orient around to 99L RIH to btm, IA 650psi, OA 21 psi Drill w/ TF at 96-62L, 2.63 bpm, FS at 3250 psi, 3420/3820psi, 0-1k WOB, ROP 30-95fph Orient around to 140E off btm Drill w/ TF at 99-75L, 2.55 bpm, FS at 3150 psi, 3355/3765psi, 0-1k WOB, ROP 51-80fph Printed: 9/5/2006 11:09:02 AM BP EXPLORATfON Page 12 of 17 Operations Summary Report Legal Well Name: C-06 Common Well Name: C-06 Spud Date: 6/27h 973 Event Name: REENTER+COMPLETE Start: 8/3/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 8/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date ;From - To ~ Hours Task Code ~ NPT Phase Description of Operations 8/24/2006 ~ 14:10 - 14:30 ~ 0.33 DRILL P ~ ~ PROD1 Orient, drill w/ TF at 69L, 2.65 bpm, 3512/3933psi, 2k WOB, 14:30 - 15:10 0.67 DRILL P 15:10 - 15:30 0.33 DRILL P 15:30 - 15:40 0.17 DRILL P 15:40 - 16:50 1.17 DRILL P 8/25/2006 16:50 - 18:15 ( 1.421 DRILL I P 18:15 - 18:20 18:20 - 19:00 19:00 - 20:30 20:30 - 22:15 22:15 - 22:50 22:50 - 23:15 23:15 - 23:40 23:40 - 23:45 23:45 - 00:00 00:00 - 00:05 00:05 - 00:20 00:20 - 00:25 00:25 - 00:35 00:35 - 01:00 01:00 - 02:00 02:00 - 02:30 02:30 - 04:30 0.08 DRILL P 0.67 DRILL P 1.50 DRILL P 1.75 DRILL P 0.58 DRILL P 0.42 DRILL P 0.42 DRILL P 0.08 DRILL P 0.25 DRILL P 0.08 DRILL P 0.25 DRILL P 0.08 DRILL P 0.17 DRILL P 0.42 DRILL P 1.00 DRILL P 0.50 DRILL P 2.00 DRILL P 04:30 - 04:40 04:40 - 05:45 05:45 - 06:00 06:00 - 07:15 07:15 - 08:50 0.17 DRILL P 1.08 DRILL P 0.25 DRILL P 1.25 DRILL P 1.581 DRILL I P ROP 51-80fph, TF rolled right to 133R, Displaced well to new Flo-Pro Mud PRODi PU to 11287', Orient around to 110L, RIH to btm, TF rolling hard to right at 130R, work pipe, TF rolled back to 64L PROD1 Drill to 11347', started losing 1/4bpm of mud to formation at 13325' w/ TF at 58L, 2.55/2.15 bpm, 3420/3820psi, 3-4k WOB, ROP 20-30fph TF continuing to roll hard to 135R while drill at 60L, work pipe, TF goes back and forth to 60L, 130R, hole healing up, no loses PROD1 Orient TF around to 75L PROD1 Orient and Drill w/ new mud, TF at 49-69L, 2.5/2.5bpm, FS at 2600psi, 2.6/2.6bpm, 2760/3182psi, 2-3k WOB, ROP 67fph, IA 400psi, OA 32psi PROD1 Wiper Trip, several overpulls 15 to 20k at 10903', 10879', 10868', 10812', RIH to btm, additional down drag of 3 - 4K thru shale interval f/ 10797' to 10862'. Increase Kla-Gard conc to 12ppb. PROD1 Orient TF to 50L. Up wt = 37k. Down wt = 16k. IAP = 300psi. OAP = 30psi. Freespin = 2.6bpm/2600psi. PVT = 292bb1s. PROD1 Drill to 11428' with 45L TF, 2.6/2.6bpm, 2600/3000psi, 2k WOB & 90fph ave ROP. PROD1 Orient & drill to 11540' with 50-70L TF, 2.6/2.6bpm, 2600/3000psi, 6-8k WOB & 90fph ave ROP. PROD1 Wiper trip to window. RBIH to btm. Saw wt bobbles across shale areas. PRODi Orient TF around to 100L. PROD1 Drill to 11558' with 85L TF, 2.7/2.7bpm, 2700/3000psi, 2k WOB & 60fph ave ROP. PROD1 Orient & drill to 11600' with 80L TF, 2.7/2.7bpm, 2700/3000psi, 3k WOB & 130fph ave ROP. PROD1 Short BHA wiper. RBIH to btm. PROD1 Drill to 11637' with 60L TF, 2.7/2.7bpm, 2700/3000psi, 2k WOB & 130fph ave ROP. PRODi Short BHA wiper. RBIH to btm. PROD1 Drill to 11668' with 60L TF, 2.7/2.7bpm, 2750/3150psi, 2k WOB & 130fph ave ROP. PRODt Short BHA wiper. RBIH to btm. PROD1 Orient TF to 80R. PVT = 276bb1s. PROD1 Drill to 11700' with 75R TF, 2.65/2.65bpm, 2750/3150psi, 4k WOB & 130fph ave ROP. PROD1 Wiper trip to window. Saw wt bobbles across shale areas. PROD1 Log up & tie-into RA pip tag. Add 3.5' to CTD. PROD1 RBIH. Set down & O/pull in shales from 10760' to 10830'. Orient to as-drilled TF & reamed thru shales. Backreamed clean thru shales. Continue RIH to btm. PROD1 Orient TF to 90R. PROD1 Orient & drill to 11763' with 110-160R TF, 2.7/2.7bpm, 2800/3200psi, 3k WOB & 90fph ave ROP. PROD1 Orient TF to 70R. PVT = 256bb1s. PROD1 Orient & drill to 11850' with 1.00-56R TF, 2.62/2.62bpm, 3036/3446psi, 2-12k WOB, ROP 50-75fph PROD1 Wiper trip to window, no overpulls thru out open hole, RIH, Printed: 9/5/2006 11:09:02 AM BP EXPLORATION Page 13 of 17 Operations Summary Report Legal Well Name: C-06 Common Well Name: C-06 Spud Date: 6/27/1973 Event Name: REENTER+COMPLETE Start: 8/3/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 8/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 8/25/2006 07:15 - 08:50 1.58 DRILL P PROD1 down drag of 1 K across shale area f/ 10800' to 10900', openhole looked good 08:50 - 09:15 0.42 DRILL P PROD1 Orient TF to 45R. 09:15 - 10:00 0.75 DRILL P PROD1 Drill to 11852' with 90-15R TF, 2.72/2.72bpm, 3175/3600psi, 4 -6k WOB, ROP 15-26fph 10:00 - 11:30 1.50 DRILL P PROD1 Orient, Drill to 11900' with 115-36R TF, 2.53/2.72bpm, 3075/3470psi, 4 -6k WOB, ROP 20-75fph 11:30 - 12:20 0.83 DRILL P PROD1 Orient, Drill to 11955' with 124-36R TF, 2.75/2.72bpm, 3200/3600psi, 2-4k WOB, ROP 75-150fph 12:20 - 12:45 0.42 DRILL P PROD1 Orient TF around to HS 12:45 - 13:05 0.33 DRILL P PROD1 Drill to 11977' with 18R TF, 2.72/2.72bpm, 3385/3805psi, 4k WOB, ROP 117-156fph 13:05 - 13:15 0.17 DRILL P PROD1 Attempt 2x Survey on Btm, no good 13:15 - 13:20 0.08 DRILL P PROD1 Drill to 11984' with 18R TF, 2.72/2.72bpm, 3325/3750psi, 3k WOB, ROP 75fph 13:20 - 13:25 0.08 DRILL P PROD1 Good Surrey on Btm 13:25 - 13:35 0.17 DRILL P PROD1 Drill to 12000' with 18-13R TF, 2.66/2.66bpm, FS 3032psi, 3150/3570psi, 3k WOB, ROP 102fph 13:35 - 16:05 2.50 DRILL P PROD1 Wiper trip to window, overpulls of 1-2k at 10919' and 10901', and 10k at 10803' thru open hole, RIH, down drag of 2-3K 10820', 10870', 10885', no other hole problems 16:05 - 16:15 0.17 DRILL P PROD1 Orient TF around to 100R 16:15 - 17:15 1.00 DRILL P PROD1 Drill to 12100' with 119-103R TF, 2.72/2.72bpm, FS 3075psi, 3285/3725psi, 2-5k WOB, ROP 95-153fph, Swap mud system to 9.1+ppg Flo-Pro mud w/ 12 ppg KlaGard as per Anch office do to swelling shales 17:15 - 19:00 1.75 DRILL P PROD1 POH to BHA #16, overpulls of 5-10k at 10880', 10863' and 10812' 19:00 - 19:25 0.42 DRILL P PROD1 Log up & tie-into RA pip tag. Add 1' to CTD. 19:25 - 21:00 1.58 DRILL P PROD1 Paint EOP flag ~ 9600' & POOH lateral BHA#16. Meanwhile rebuild MP#1 valve seats. 21:00 - 22:00 1.00 DRILL P PRODf OOH. PJSM. S/B injector. Download RES data & initialize EWR. L/D drilling BHA #16. Bit gauge - 2/1/I. 22:00 - 00:00 2.00 BOPSU P PROD1 Perform bi-weekly ROPE pressure/function test. AOGCC test witness waived by Chuck Scheve. Meanwhile rebuild MP#2 valve seats. 8/26/2006 00:00 - 04:00 4.00 BOPSU P PROD1 Continue with bi-weekly BOPE pressure/function test. Test inner reel valve -observe leak from CTC. Replace O-rings in CTC & retest inner reel valve OK. 04:00 - 04:30 0.50 BOPSU P PROD1 C/O pack-off. 04:30 - 05:10 0.67 DRILL P PROD1 M/U cleanout BHA #17 with 1.3degs X-treme motor, MWD/GR/RES, orienter & rerun Hycalog 3-3/4" DS49 PDC bit #15. M/U injector. 05:10 - 06:40 1.50 DRILL P PROD1 RIH cleanout BHA #17. SHT tool ~ 3000' - OK. Continue RIH to 9250' 06:40 - 06:45 0.08 DRILL P PRODi Brk circ, pressure test MP #1 and MP #2 to 3000psi 06:45 - 06:55 0.17 DRILL P PROD1 RIH to 9800', TF 90L, passed thru window, no problems, corrected pipe to EOP at 9600', -49.6' correction 06:55 - 07:20 0.42 DRILL P PROD1 Tie-in pass, +1.5' correction 07:20 - 08:30 1.17 DRILL P PROD1 RIH at 58.3fpm, slight bobble at 10870', set down at 11550', TF 80 R, drilled at 110L, PU, no overpull, S/O, no problems going thru 11550', RIH to 11921', TF at 146L, drilled at 110R, do drag of Sk, work thru hole, RIH to btm, tagged at 12099.2', Up Wt Printed: 9/5/2006 11:09:02 AM • • BP EXPLORATION Page 14 of 17 Operations Summary Report Legal Well Name: C-06 Common Well Name: C-06 Spud Date: 6/27/1973 Event Name: REENTER+COMPLETE Start: 8/3/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 8/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase ~ Description of Operations 8/26/2006 07:20 - 08:30 1.17 DRILL P PROD1 39.7k, S/O Wt 13.4k 08:30 - 10:00 1.50 DRILL P PROD1 Madd Pass f/ 12100' to 10725' at 900fph, no overpulls 10:00 - 12:00 2.00 DRILL P PROD1 POH to BHA #17, painted EOP at 9337' & 6967', set back injector 12:00 - 12:45 0.75 DRILL P PROD1 POH w/ BHA #17, dnload MWD tools, change out CTC to Baker CTC, LD BHA, pull and pressure test CTC 12:45 - 13:50 1.08 CASE P RUNPRD Install dart catcher. Load wiper dart. Launch & chase with 9.2 ppg mud, Dart hit ~ 52.6bbls, retr dart, rd ball catcher 13:50 - 14:15 0.42 CASE P RUNPRD Held PJSM on RU handling equipment and running liner 14:15 - 18:00 3.75 CASE P RUNPRD M/U 2-7/8" STL rotating guide shoe, 2 float collars, 1 shoe jt & landing collar. M/U 35jts of 2-7/8" 6.4# L-80 STL , 2-7/8" STL pup & LSL TC11 sub. M/U 49jts of 3-3/16" 6.2# L-80 TCII, XO, 1 jt of 3-1/2" 9.3# L80 STL, X nipple, 3-1/2" STL pup. M/U Baker Deployment sleeve w/ 3 1/2 "STL pup, OAL - 2663.67', and CTLRT w/ MHA 18:00 - 20:30 2.50 CASE P RUNPRD RIH with liner circ ~ min rate. Correct CTD -42.3' ~ 1st flag. Wt check: Up = 40k. Run-in wt = 18k. Continue RIH smoothly 50fpm thru window into OH. Observe wt bobbles across shales from 10711' to 10861'. Set down ~ 11794', 11860' to 11925' & 11998'. P/U, wash & work liner thru tight spots. Saw 2nd flag on depth. Tag btm ~ 12106'. P/U ~ 54k & retag TD hard several times ~ same depth. Call it good! Correct CTD to 12100'. 20:30 - 21:00 0.50 CASE P RUNPRD Establish circ. Load 5/8" steel ball &circ with mud ~ 2.54/2.54bpm & 2530psi. Set down 10k down on CTLRT. Continue circ ball to seat. Slow down @ 40bbls away. Ball on seat ~ 42.9bbls. Pressure up to 3740psi & release CTLRT. P/U ~ 31 k & confirm release. 21:00 - 23:00 2.00 CASE P RUNPRD Line up to pump via the cementing high-pressure filters. Circ well to 9.2ppg NaCUKCL fps 2.5/2.5bpm & 2280psi. Send used FloPro to MI for reconditioning. Meanwhile R/U SLB cementers. 23:00 - 00:00 1.00 CASE P RUNPRD Load balance 9.2ppg NaCUKCL into pits & mix 2ppb bio displacement pill. Meanwhile continue circulating 9.2ppg NaCUKCL around @ 2.45/2.41 bpm & 1930psi. 8/27/2006 00:00 - 00:30 0.50 CEMT P RUNPRD PJSM with all personnel concerning cementing operations. Meanwhile continue circulating 9.2ppg NaCUKCL brine @ 2.43/2.39bpm & 1660psi. 00:30 - 01:45 1.25 CEMT P RUNPRD Batch mix 29bbls 15.8ppg 'G' latex cmt with additives. Cmt to wt ~ 00:30hrs. Flush/PT lines to 4k. Pump 28.3bbls cmt slurry ~ 2.05/1.96bpm & 1560psi. Close inner reel valve & clean lines. Load/launch CTWP with 500psi. Chase with 30bbls bio-KCL C~ 2.85/2.75bpm & 1870psi. Slow down pumps to 2.17bpm/1300psi C~ 48bbls. CTW P engage LW P (~ 53bbls away. Shear plug with 2750psi. Continue displacing LWP ~ 2.12/1.94bpm, 2300psi & bump ~ 70.4bbls away with 1000psi over. Bleed off & check floats -held. Pressure up to 500psi & sting out of liner. 25.9bbls cmt pumped around shoe. CIP ~ 01:45hrs. 01:45 - 04:00 2.25 CEMT P RUNPRD Circ 1 bbl of bio-KCL at 0.5bpm on TOL. POOH to BHA at 100fpm pumping at 0.55bpm to replace CT voidage only. 04:00 - 04:30 0.50 CEMT P RUNPRD OOH. PJSM. S/B injector. UD CTLRT. 04:30 - 05:00 0.50 EVAL P LOW ER1 R/U floor for running looging/cleanout BHA. Initialize & test Printed: 9/5/2006 11:09:02 AM BP EXPLORATION Page 15 of 17 Operations Summary Report Legal Well Name: C-06 Common Well Name: C-06 Spud Date: 6/27/1973 Event Name: REENTER+COMPLETE Start: 8/3/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 8/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Mours Task Code j NPT Phase ~ Description of Operations 8/27/2006 04:30 - 05:00 0.50 EVAL P LOW ER1 logging tools. P/U tools to rig floor. 05:00 - 05:15 0.25 EVAL P LOWERI PJSM on P/U &RIH MCNL tools & 1-1/4" CHS tbg. 05:15 - 07:15 2.00 EVAL P LOWERI P/U logging/cleanout BHA #19 with 2.30" D331 mill, 2-1/8" straight motor, XO, 2jts of 1-1/4" CSH tbg, MCNUCCUGR logging tool carrier, XO, lower MHA, 88jts of 1-1/4" CSH tbg, XO & upper MHA. M/U Injector. 07:15 - 08:00 0.75 EVAL P LOW ER1 RIH w/ logging/cleanout BHA #19 to 7827' 08:00 - 08:30 0.50 EVAL N CEMT LOWERI Wait on UCA cement test for 500 psi compressive strength. Confirmed 08:30 - 08:50 0.33 EVAL P LOWERI RIH w/ logging/cleanout BHA #19 to 9200' 08:50 - 10:35 1.75 EVAL P LOWERI Cleanout wellbore C~ 1.3bpm & log down MCNUCCUGR ~ 30fpm from 9300'. Reciprocate 2x across LSL sub @ 1.5bpm. Log down to PBTD tagged 2x ~ 12065'. 10:35 - 11:25 0.83 EVAL P LOW ER1 Log up ~ 60fpm from PBTD to 9300' while laying-in 150kcps pert pill in liner 11:25 - 12:35 1.17 EVAL P LOWERI POH to BHA, flag EOP at 9240', 141' from PBTD. 12:35 - 14:35 2.00 EVAL P LOWERI PJSM on handling MCNL BHA, open circ sub, POH, std back 1 14" CSH, LD logging tools 14:35 - 14:55 0.33 EVAL P LOW ERi MU Nozzle, RIH, flush out tree and stack 14:55 - 15:35 0.67 EVAL P LOW ER1 PJSM, IA 62 psi, OA 15 psi, RU, Testing Liner lap using 9.2 ppg brine pressured up to 1380 psi at .83 bpm, pressure stabilizing, shut down pumps, pressure fell off to 700 psi within seconds and continued falling, bled off remaining pressure to Opsi, closed the master valve, tested surface lines and equipment to 1100 psi, good test, made second attempt to pressure up on liner lap with same results as the first attempt. Liner lap failed. 15:35 - 16:00 0.42 PERFO P LOWERI PJSM on handling and running pert gun assy, RU handling tools, processing MCNL log 16:00 - 18:45 2.75 PERFO P LOW ER1 PU, MU 47 2" 6SPF 2006PJ Perf Guns and blanks, 27 stds of 1 1/4" CSH, MHA and CTC, stab inj, BHA length of 2685.15'. Meanwhile fax CNL log to ANC Geo. ANC Geo OKs preliminary pert picks. From log data, PBTD = 12067' & TOL = 9432'. 18:45 - 21:00 2.25 PERFO P LOWERI RIH with perforating BHA#20 circ 15bbls of pert pill ahead ~ min rate. Correct -38' ~ the flag. Wt check ~ 11925' - Up wt = 44k & Run-in wt = 20k. Tag PBTD 2x ~ 12068'. Pull to P/U wt & CTD was right on depth ~ 12067' (PBTD as per MCNL). PUH to ball drop postion ~ 12038'. Meanwhile R/U sonogram detector to choke manifold for shot detection. 21:00 - 21:45 0.75 PERFO P LOWERI Load & launch 5/8" AL ball. RBIH to 12050.7'. Pump 15bbls of pert pill behind & chase ball ~ 2.15bpm/3350psi. Slow to 0.78bpm/260psi ~ 40bbls. Ball on seat after 48.6bbls away. S/D pumps & RBIH to 12055'. PUH very slowly, ramp up to 4500psi & observe no firing, no pressure drop indication & no sonogram detection. Repeat process & trip pumps C~3 4800psi. Reset pump trips to 4900psi. Repeat process again & trip pumps ~ 4900psi with no sonogram shot detection. However observe returns indicating guns did fire. Also check circ pressure C~ 0.78bpm & had 100psi (previously had 260psi) indicating guns must have fired. Continue POOH with pert gun BHA. Perforated interval = 11070' - 11370', 11580' - 11830' & 11890' - 12050'. Printed: 9/5/2006 11:09:02 AM ~~ ~~ BP EXPLORATION Page 16 of 17 Operations Summary Report Legal Well Name: C-06 Common Well Name: C-06 Spud Date: 6/27/1973 Event Name: REENTER+COMPLETE Start: 8/3/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 8/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code i NPT Phase ~ Description of Operations 8/27/2006 21:45 - 22:35 0.83 PERFO P LOWERI POOH with pert gun BHA @ 60fpm pumping down the CT ~ 1.127bpm & 700psi. Lost a total of 2bbls while POOH to TOL. 22:35 - 22:50 0.25 PERFO P LOW ER1 S/D pump &flowcheck well for 15 mins -well stable. 22:50 - 00:00 1.17 PERFO P LOW ER1 POOH with pert gun BHA ~ 60fpm pumping down the CT @ 1.46bpm & 1020psi. Lost an additional 2bbls while POOH to surface. 8/28/2006 00:00 - 00:30 0.50 PERFO P LOW ER1 S/D pump &flowcheck well for 30 mins -well stable. Meanwhile held PJSM for R/8 1-1/4" CSH. 00:30 - 01:30 1.00 PERFO P LOWERI S/B injector. UD MHAs & R/B 27 stands of 1-1/4" CSH. 01:30 - 01:45 0.25 PERFO P LOW ER1 R/U to UD perf guns. Observe 3 pieces of cement rocks & scale/rust debris on firing head ball seat which probably caused the poor firing indication. Opened up & inspected inner reel valve -found no cement debris. 01:45 - 02:00 0.25 PERFO P LOW ER1 PJSM for LD perf guns. 02:00 - 04:30 2.50 PERFO P LOWERI UD 47jts of perf guns & blanks. ASF! 04:30 - 04:45 0.25 PERFO P LOW ER1 Load out spent perf guns & blanks. 04:45 - 05:00 0.25 PERFO P LOW ER1 R/U to run LTP. P/U tools into rig floor. 05:00 - 05:15 0.25 PERFO P LOW ER1 Held PJSM for M/U &RIH LTP. 05:15 - 06:30 1.25 CASE P RUNPRD M/U BHA #21 with Bkr seal assy, 4jts & 2 pup jts of 2-7/8" STL Lnr, KB Packer, GH R/Tool, 2 jts of PH6 tbg & MHA. M/U injector. 06:30 - 08:30 2.00 CASE P RUNPRD RIH w/ LTP Assy 08:30 - 08:45 0.25 CASE P RUNPRD Stung seals in at 9478', corrected depth to 9434' and Set down at 9441.9' with 10K wt. Pull out to circ. 08:45 - 09:30 0.75 CASE P RUNPRD Insert 5/8" Steel ball, Up Wt 34.7k, Dn Wt 17.5k, Displace ball with 9.2 ppg brine, slowed pumps to .3 bpm, after pumping 25 bbls, stung in to deployment sleeve at 9434', shut down pumps, continued to slacked off to 9442' w/ S/O Wt of 10k , PU to Up Wt to 9435', allowed ball to free fall, Ball on seat, Press up to 2000 psi and set packer slips. Pressured up to 3300 psi, shear out ball. Stack wt back to 10K at 9439'. Top of Liner Top Packer at 9287' 09:30 - 10:15 0.75 CASE P RUNPRD Pressure test Packer seals with 9.2ppg brine, 2058 psi on backside of coil. IA 81 psi, OA 12 psi, Chart 30 min test, lost 73 psi in first 15 min, lost 18 psi in last 15 min, Lost 91 psi over 30 minutes, Passed, released pressure, RD test equipment. ISIP = 2058 psi 05 min = 2007 psi 10 min = 1996 psi 15 min = 1985 psi 20 min = 1978 psi 25 min = 1974 psi 30 min = 1967 psi 10:15 - 11:30 1.25 CASE P RUNPRD Pickup with no overpull, POH to 2500', circ 1 bpm while POH. 11:30 - 11:45 0.25 CASE P RUNPRD Freeze protect 4-1/2" tubing from 2500 - 300 W/ 60/40 McOH, f/ 300-0 ft with 100 percent McOH. 11:45 - 12:30 0.75 CASE P RUNPRD Lay out BOT liner running tools. Close Master and Swab valves. 12:30 - 13:15 0.75 RIGD P POST PJSM. PR Lines to 2500 psi, Pump 5 bbl McOH in coil. Displace with N2 to tiger tank, 1500 CFM for 18 min. Bleed down coil press. Clean cuttings tank with supersucker. Clean rig pits. Printed: 9/5/2006 11:09:02 AM • • BP EXPLORATION Page 17 of 17 Operations Summary Report Legal Well Name: C-06 Common Well Name: C-06 Spud Date: 6/27/1973 Event Name: REENTER+COMPLETE Start: 8/3/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 8/28/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task ~ Code NPT ~ Phase Description of Operations 8/28/2006 12:30 - 13:15 0.75 RIGD P POST M/U internal CTC. Pull test. Pull coil stub to reel. Secure coil on reel with chains and crossbar. Nipple down BOPE. UP tree cap and test. Release rig at 20:00 hrs. 13:15 - 15:30 2.25 RIGD P POST Clean cuttings tank with supersucker. Clean rig pits. Nipple down BOPE. N/U tree cap and pressure test - OK. Release rig at 15:30 hrs on 8/28/06. Printed: 9/5/2006 11:09:02 AM Halliburton Company • Survey Report Cumpanc: BP Amoco 1)atc: 9/8/2006 l imc: 15.42:00 Na~c: 1 Field: Prudhoe Sey Co -ordinate(~'F) Reference: Well: C-06. True North Site: PB C Pad Ve rtical (~fVll) Re ference: 7: 06 6/27/1973 00:00 55.4 11e11: C-06 Sec tiuu (~'S) Refer ence: Well (0-OON.O.O OE95.OOAzi) N`ellperh: C-06B Su ne~ Calculation ~1Mhud: Minimum Curva ture Ub: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Cla rke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: C-06 Slot Name: 06 C-06 Well Position: +N/-S 2094.47 ft Northing: 5959356.00 ft Latitude: 70 17 42.964 N +E/-W 2009.86 ft Easti ng : 664514.00 ft Longitude: 148 40 4.217 W Position Uncertainty: 0.00 ft Wellpath: C-06B Drilled From: C-06 500292012702 Tie-on Depth: 9700.00 ft Current Datum: 7:06 6/27/1973 00:00 Height 55.40 ft Above System Datum: Mean Sea Level Magnetic Data: 7/11/2006 Declination: 24.47 deg Field Strength: 57606 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 22.40 0.00 0.00 95.00 Survey Program for DeTinitive Wellpath Date: 7/11/2006 Validated: Yes Version: 6 Actual From To Survey Toolcode Tool Name ft ft 100.00 9700.00 1 : Camera based gyro multisho CB-GYRO-MS Camera based gyro multishot 9730.00 12100.00 MWD (9730.00-12100.00) MWD MWD -Standard Survey MD Licl Azim TVD Sys TVD N/S E/1t ~~lapN ~~tapE Tool ft deg deg ft ft ft ft ft ft 22.40 0.00 0.00 22.40 -33.00 0.00 0.00 5959356.00 664514.00 TIE LINE 100.00 0.50 228.40 100.00 44.60 -0.22 -0.25 5959355.77 664513.75 CB-GYRO-MS 200.00 0.40 209.50 200.00 144.60 -0.82 -0.75 5959355.17 664513.27 CB-GYRO-MS 300.00 0.58 238.20 299.99 244.59 -1.39 -1.35 5959354.58 664512.68 CB-GYRO-MS 400.00 0.62 256.80 399.99 344.59 -1.78 -2.31 5959354.17 664511.73 CB-GYRO-MS 500.00 0.75 251.40 499.98 444.58 -2.11 -3.46 5959353.81 664510.59 CB-GYRO-MS 600.00 0.38 253.40 599.97 544.57 -2.41 -4.40 5959353.49 664509.66 CB-GYRO-MS 700.00 0.25 219.40 699.97 644.57 -2.68 -4.85 5959353.22 664509.21 CB-GYRO-MS 800.00 0.07 329.20 799.97 744.57 -2.79 -5.02 5959353.10 664509.04 CB-GYRO-MS 900.00 0.33 158.30 899.97 844.57 -3.01 -4.95 5959352.88 664509.12 CB-GYRO-MS 1000.00 0.25 41.50 999.97 944.57 -3.11 -4.70 5959352.79 664509.37 CB-GYRO-MS 1100.00 0.42 27.50 1099.97 1044.57 -2.63 -4.38 5959353.28 664509.68 CB-GYRO-MS 1200.00 0.42 349.00 1199.97 1144.57 -1.94 -4.28 5959353.97 664509.76 CB-GYRO-MS 1300.00 0.67 322.40 1299.96 1244.56 -1.12 -4.71 5959354.78 664509.32 CB-GYRO-MS 1400.00 0.75 290.00 1399.96 1344.56 -0.43 -5.68 5959355.45 664508.33 CB-GYRO-MS 1500.00 0.58 286.00 1499.95 1444.55 -0.07 -6.78 5959355.79 664507.22 CB-GYRO-MS 1600.00 0.33 263.90 1599.95 1544.55 0.04 -7.55 5959355.88 664506.45 CB-GYRO-MS 1700.00 0.17 280.60 1699.95 1644.55 0.04 -7.99 5959355.86 664506.01 CB-GYRO-MS 1800.00 0.25 309.10 1799.94 1744.54 0.20 -8.30 5959356.02 664505.70 CB-GYRO-MS 1900.00 0.57 191.90 1899.94 1844.54 -0.15 -8.57 5959355.67 664505.43 CB-GYRO-MS 2000.00 0.50 238.30 1999.94 1944.54 -0.86 -9.05 5959354.94 664504.97 CB-GYRO-MS 2100.00 0.60 238.10 2099.93 2044.53 -1.37 -9.86 5959354.42 664504.17 CB-GYRO-MS 2200.00 1.03 224.20 2199.92 2144.52 -2.29 -10.93 5959353.47 664503.12 CB-GYRO-MS 2300.00 1.13 227.50 2299.91 2244.51 -3.60 -12.29 5959352.13 664501.79 CB-GYRO-MS 2400.00 1.23 232.00 2399.89 2344.49 -4.93 -13.86 5959350.77 664500.25 CB-GYRO-MS 2500.00 1.00 236.70 2499.87 2444.47 -6.07 -15.44 5959349.60 664498.70 CB-GYRO-MS 2600.00 0.75 235.50 2599.85 2544.45 -6.92 -16.71 5959348.72 664497.45 CB-GYRO-MS 2700.00 0.92 247.30 2699.84 2644.44 -7.60 -17.99 5959348.01 664496.19 CB-GYRO-MS 2800.00 1.22 203.50 2799.83 2744.43 -8.88 -19.15 5959346.70 664495.05 CB-GYRO-MS Halliburton Company Survey Report Company: BP Amoco Field: Prudhoe Say Sitr. PB C Pad 1Vcll: C-U6 1Vdlpath: C-06B Sur~c~ ~~~ 11ll Incl Azim TVD ft deg deg ft - - 2900.00 4.75 174.80 2899.68 3000.00 6.62 159.00 2999.19 3100.00 9.07 159.30 3098.25 3200.00 10.70 156.10 3196.76 3300.00 11.75 157.50 3294.84 3400.00 12.83 158.90 3392.55 3500.00 15.23 162.80 3489.56 3600.00 17.23 164.10 3585.57 3700.00 19.58 164.10 3680.45 3800.00 22.00 164.50 3773.93 3900.00 24.65 165.30 3865.75 4000.00 27.17 166.10 3955.69 4100.00 30.65 165.80 4043.22 4200.00 33.50 166.70 4127.95 4300.00 36.58 166.80 4209.81 4400.00 39.67 166.90 4288.47 4500.00 42.88 167.60 4363.61 4600.00 44.23 167.80 4436.08 4700.00 44.00 168.30 4507.88 4800.00 44.12 168.50 4579.74 4900.00 43.88 168.90 4651.67 5000.00 43.83 168.80 4723.78 5100.00 43.92 169.30 4795.87 5200.00 43.75 169.30 4868.00 5300.00 43.62 169.30 4940.32 5400.00 43.50 169.40 5012.78 5500.00 43.08 169.70 5085.57 5600.00 42.92 169.40 5158.71 5700.00 42.75 169.30 5232.04 5800.00 42.78 170.10 5305.45 5900.00 43.25 170.10 5378.57 6000.00 42.03 170.50 5452.13 6100.00 43.17 170.70 5525.74 6200.00 43.05 170.70 5598.75 6300.00 42.80 170.70 5671.97 6400.00 42.65 170.60 5745.43 6500.00 42.48 170.60 5819.08 6600.00 42.78 170.40 5892.66 6700.00 42.83 170.70 5966.02 6800.00 42.50 169.90 6039.56 6900.00 42.62 170.60 6113.21 7000.00 42.15 170.50 6187.08 7100.00 41.62 170.10 6261.53 7200.00 41.33 170.20 6336.45 7300.00 41.17 170.70 6411.63 7400.00 40.67 170.90 6487.20 7500.00 39.95 170.70 6563.45 7600.00 39.33 171.40 6640.46 7700.00 38.50 171.00 6718.27 7800.00 37.83 172.10 6796.89 7900.00 37.45 172.00 6876.08 8000.00 36.87 172.30 6955.77 Date 9/8/2006 7~ime: 15:4200 Page: 2 Co-ordinafe(_AF:j Ftc(erence: Well: C-06, True North Vertical (Il'D) F2eference: 7:06 6/27/1973 00:00 55.4 Section (VSI F:cierence: Well (O.OON,O.OOE.95.OOAzi) Survey Calculutioo M1lethod: Minimum Curvature Db: Orade Svs'h~ D \'S t%W ft ft it 2844. 28 -13. 98 -19. 20 2943. 79 -23. 49 -16. 76 3042. 85 -36. 25 -11. 91 3141. 36 -52. 11 -5. 36 3239. 44 -70. 00 2. 30 3337. 15 -89. 77 10. 19 3434. 16 -112. 68 18. 08 3530. 17 -139. 47 26. 02 3625. 05 -169. 84 34. 67 3718. 53 -204. 01 44. 26 3810. 35 -242. 23 54. 56 3900. 29 -284. 57 65. 34 3987. 82 -331. 46 77. 08 4072. 55 -383. 04 89. 69 4154. 41 -438. 92 102. 84 4233. 07 -499. 03 116. 89 4308. 21 -563. 37 131. 43 4380. 68 -630. 69 146. 11 4452. 48 -698. 79 160. 52 4524. 34 -766. 91 174. 50 4596. 27 -835. 03 188. 12 4668. 38 -903. 00 201. 51 4740. 47 -971. 05 214. 68 4812. 60 -1039. 11 227. 54 4884. 92 -1106. 97 240. 36 4957. 38 -1174. 70 253. 10 5030. 17 -1242. 13 265. 53 5103. 31 -1309. 20 277. 90 5176. 64 -1376. 02 290. 47 5250. 05 -1442. 82 302. 61 5323. 17 -1510. 02 314. 34 5396. 73 -1576. 79 325. 75 5470. 34 -1643. 57 336. 81 5543. 35 -1711. 01 347. 85 5616. 57 -1778. 22 358. 86 5690. 03 -1845. 17 369. 88 5763. 68 -1911. 90 380. 93 5837. 26 -1978. 70 392. 11 5910. 62 -2045. 73 403. 26 5984. 16 -2112. 53 414. 68 6057. 81 -2179. 19 426. 13 6131. 68 -2245. 68 437. 20 6206. 13 -2311. 49 448. 45 6281. 05 -2376. 74 459. 78 6356. 23 -2441. 76 470. 72 6431. 80 -2506. 42 481. 19 6508. 05 -2570. 28 491. 53 6585. 06 -2633. 30 501. 46 6662. 87 -2695. 38 511. 07 6741. 49 -2756. 49 520. 15 6820. 68 -2816. 98 528. 60 6900. 37 -2876. 81 536. 85 ~1ap~ MapE Fool ~~~~~~ ft ft 5959341.60 664495.11 CB-GYRO-MS 5959332.15 664497,76 CB-GYRO-MS 5959319.50 664502.89 CB-GYRO-MS 5959303.79 664509.78 CB-GYRO-MS 5959286.07 664517.83 CB-GYRO-MS 5959266.48 664526.15 CB-GYRO-MS 5959243.75 664534.54 CB-GYRO-MS 5959217.14 664543.06 CB-GYRO-MS 5959186.98 664552.37 CB-GYRO-MS 5959153.03 664562.72 CB-GYRO-MS 5959115.04 664573.85 CB-GYRO-MS 5959072.95 664585.55 CB-GYRO-MS 5959026.33 664598.31 CB-GYRO-MS 5958975.04 664612.04 CB-GYRO-MS 5958919.47 664626.42 CB-GYRO-MS 5958859.68 664641.77 CB-GYRO-MS 5958795.68 664657.72 CB-GYRO-MS 5958728.70 664673.86 CB-GYRO-MS 5958660.94 664689.76 CB-GYRO-MS 5958593.15 664705.23 CB-GYRO-MS 5958525.35 664720.33 CB-GYRO-MS 5958457.69 664735.21 CB-GYRO-MS 5958389.95 664749.86 CB-GYRO-MS 5958322.20 664764.21 CB-GYRO-MS 5958254.63 664778.51 CB-GYRO-MS 5958187.20 664792.73 CB-GYRO-MS 5958120.07 664806.64 CB-GYRO-MS 5958053.29 664820.47 CB-GYRO-MS 5957986.77 664834.50 CB-GYRO-MS 5957920.25 664848.09 CB-GYRO-MS 5957853.32 664861.29 CB-GYRO-MS 5957786.83 664874.16 CB-GYRO-MS 5957720.31 664886.68 CB-GYRO-MS 5957653.13 664899.19 CB-GYRO-MS 5957586.18 664911.67 CB-GYRO-MS 5957519.50 664924.15 CB-GYRO-MS 5957453.03 664936.65 CB-GYRO-MS 5957386.50 664949.29 CB-GYRO-MS 5957319.73 664961.91 CB-GYRO-MS 5957253.20 664974.79 CB-GYRO-MS 5957186.81 664987.70 CB-GYRO-MS 5957120.58 665000.22 CB-GYRO-MS 5957055.04 665012.90 CB-GYRO-MS 5956990.05 665025.66 CB-GYRO-MS 5956925.29 665038.01 CB-GYRO-MS 5956860.89 665049.90 CB-GYRO-MS 5956797.27 665061.64 CB-GYRO-MS 5956734.49 665072.94 CB-GYRO-MS 5956672.64 665083.90 CB-GYRO-MS 5956611.74 665094.32 CB-GYRO-MS 5956551.46 665104.09 CB-GYRO-MS 5956491.82 665113.65 CB-GYRO-MS Halliburton Company Survey Report Gimpan~: BP Amoco llatc: 9/8/2006 I~imr. 15.42-00 Pale: 3 Field: Prudhoe Bay Cu-~rdinate(VF) Rc('crcncc: Well: C-06, True North Site PB C Pad ~~ertical ('I ~U) Keferencc 7:06 6/27/1973 00:00 55.4 ~~~cll: C-06 Section (~'ti) ReCereuce: Well (O.OON.O.OOE,95.OOP.zi) ~~'ellpath: C-06B Sur~e~ Calculation 6lerhod: Minimum Curvature Ub: Oracle Su n cc MD lncl Azim "CVD Sys'1~~'D \IS h./~ti ~tapn MapE Tool ft deg deg ft ft ft ft ft ft 8100.00 36.15 172.20 7036.15 6980.75 -2935.77 544.87 5956433.07 665122.96 CB-GYRO-MS 8200.00 36.08 172.80 7116.93 7061.53 -2994.20 552.57 5956374.82 665131.93 CB-GYRO-MS 8300.00 35.67 173.60 7197.96 7142.56 -3052.39 559.51 5956316.80 665140.14 CB-GYRO-MS 8400.00 35.08 174.40 7279.50 7224.10 -3109.97 565.56 5956259.37 665147.45 CB-GYRO-MS 8500.00 35.08 175.10 7361.33 7305.93 -3167.20 570.82 5956202.28 665153.96 CB-GYRO-MS 8600.00 34.35 175.90 7443.53 7388.13 -3223.97 575.29 5956145.62 665159.67 CB-GYRO-MS 8700.00 34.22 177.10 7526.16 7470.76 -3280.19 578.73 5956089.49 665164.34 CB-GYRO-MS 8800.00 33.58 178.30 7609.16 7553.76 -3335.92 580.97 5956033.83 665167.81 CB-GYRO-MS 8900.00 33.98 179.90 7692.28 7636.88 -3391.51 581.84 5955978.28 665169.89 CB-GYRO-MS 9000.00 34.25 181.20 7775.07 7719.67 -3447.59 581.30 5955922.20 665170.58 CB-GYRO-MS 9100.00 34.73 182.80 7857.50 7802.10 -3504.17 579.32 5955865.59 665169.84 CB-GYRO-MS 9200.00 33.67 184.10 7940.20 7884.80 -3560.28 575.95 5955809.43 665167.69 CB-GYRO-MS 9300.00 32.92 191.80 8023.83 7968.43 -3614.55 568.41 5955755.01 665161.34 CB-GYRO-MS 9400.00 31.00 205.30 8108.77 8053.37 -3664.50 551.82 5955704.71 665145.85 CB-GYRO-MS 9500.00 24.75 206.90 8197.13 8141.73 -3706.49 531.32 5955662.28 665126.28 CB-GYRO-MS 9600.00 24.30 210.70 8288.11 8232.71 -3742.86 511.35 5955625.49 665107.11 CB-GYRO-MS 9700.00 24.17 215.60 8379.31 8323.91 -3777.20 488.92 5955590.67 665085.44 CB-GYRO-MS 9730.00 23.89 215.54 8406.71 8351.31 -3787.13 481.82 5955580.58 665078.55 MWD 9758.38 19.16 207.57 8433.11 8377.71 -3795.95 476.32 5955571.65 665073.25 MWD 9787.91 14.50 197.61 8461.37 8405.97 -3803.77 472.95 5955563.76 665070.06 MWD 9817.20 14.68 186.11 8489.72 8434.32 -3810.96 471.45 5955556.54 665068.71 MWD 9855.42 18.07 169.69 8526.41 8471.01 -3821.61 471.99 5955545.90 665069.49 MWD 9888.65 21.80 168.25 8557.64 8502.24 -3832.73 474.17 5955534.83 665071.91 MWD 9924.42 25.31 154.71 8590.45 8535.05 -3846.16 478.80 5955521.51 665076.83 MWD 9959.87 27.86 160.34 8622.15 8566.75 -3860.82 484.82 5955506.99 665083.17 MWD 9991.86 25.58 163.50 8650.73 8595.33 -3874.48 489.30 5955493.43 665087.95 MWD 10024.07 27.33 155.59 8679.57 8624.17 -3887.88 494.33 5955480.14 665093.27 MWD 10060.98 30.23 148.56 8711.93 8656.53 -3903.54 502.69 5955464.67 665101.96 MWD 10096.46 35.07 147.33 8741.79 8686.39 -3919.75 512.85 5955448.69 665112.48 MWD 10128.01 39.29 149.09 8766.92 8711.52 -3935.95 522.88 5955432.71 665122.86 MWD 10159.48 45.44 149.79 8790.17 8734.77 -3954.21 533.65 5955414.69 665134.03 MWD 10190.50 50.19 152.60 8810.99 8755.59 -3974.35 544.70 5955394.80 665145.52 MWD 10220.88 54.84 150.67 8829.48 8774.08 -3995.55 556.16 5955373.86 665157.44 MWD 10250.55 58.62 143.81 8845.76 8790.36 -4016.37 569.60 5955353.34 665171.33 MWD 10284.66 60.91 137.13 8862.95 8807.55 -4039.07 588.35 5955331.06 665190.57 MWD 10316.67 63.54 134.85 8877.87 8822.47 -4059.43 608.03 5955311.13 665210.69 MWD 10347.67 66.53 131.51 8890.96 8835.56 -4078.65 628.53 5955292.37 665231.60 MWD 10380.23 69.78 127.46 8903.07 8847.67 -4097.85 651.85 5955273.69 665255.34 MWD 10413.44 73.48 124.30 8913.54 8858.14 -4116.31 677.38 5955255.79 665281.27 MWD 10445.61 74.63 118.38 8922.39 8866.99 -4132.38 703.79 5955240.30 665308.02 MWD 10479.99 75.07 113.09 8931.38 8875.98 -4146.78 733.67 5955226.56 665338.21 MWD 10509.34 75.07 108.69 8938.94 8883.54 -4156.89 760.16 5955217.03 665364.91 MWD 10543.54 75.33 103.75 8947.68 8892.28 -4166.12 791.90 5955208.49 665396.84 MWD 10576.23 75.15 100.23 8956.01 8900.61 -4172.69 822.82 5955202.61 665427.89 MWD 10606.49 76.65 97.41 8963.39 8907.99 -4177.19 851.81 5955198.75 665456.97 MWD 10636.85 77.27 91.95 8970.24 8914.84 -4179.60 881.28 5955196.98 665486.48 MWD 10666.47 76.12 85.60 8977.07 8921.67 -4178.99 910.08 5955198.22 665515.26 MWD 10700.53 77.27 82.61 8984.91 8929.51 -4175.58 943.05 5955202.35 665548.14 MWD 10732.80 78.85 78.20 8991.58 8936.18 -4170.32 974.17 5955208.29 665579.14 MWD 10767.98 77.00 84.72 8998.95 8943.55 -4165.20 1008.16 5955214.15 665613.01 MWD 10804.64 80.18 84.54 9006.20 8950.80 -4161.84 1043.94 5955218.29 665648.70 MWD 10833.92 84.67 86.48 9010.06 8954.66 -4159.57 1072.86 5955221.19 665677.57 MWD 10871.15 86.61 88.42 9012.89 8957.49 -4157.92 1109.95 5955223.66 665714.61 MWD Halliburton Company Survey Report Compan}: BP Amoco Date 9/8/2006 Lime 15'42-00 Page: 4 Field: Prudhoe Bay Co-ordinatc~l~F) Keference Well: C-06. True North Site PB C Pad ~~erfical ~'1~~'U) Keference: 7:06 6/27119!3 00:00 55.4 Well: C-06 Section (~~S) Keference Well (O OON.O.OOE95-OOAzi) Wdlpath: C-06B Survey Calculation 1llethod: M'mirnum Curvature Db: Orade $U rcct ~MD Ind ~zim TVD SysTVU iA/S E/W Mapti 1fapF: Toole ~~ ft deg deg ft ft ft ft ft ft 10902.52 87.84 95.12 9014.41 8959.01 -4158.89 1141.25 5955223.37 665745.92 MWD 10932.68 87.58 97.41 9015.62 8960.22 -4162.18 1171.20 5955220.74 665775.93 MWD 10969.03 88.72 101.81 9016.79 8961.39 -4168.24 1207.01 5955215.46 665811.87 MWD 11004.05 92.51 104.99 9016.42 8961.02 -4176.35 1241.07 5955208.10 665846.09 MWD 11037.06 92.78 111.33 9014.89 8959.49 -4186.63 1272.38 5955198.52 665877.62 MWD 11072.19 90.93 115.91 9013.75 8958.35 -4200.69 1304.54 5955185.16 665910.08 MWD 11101.41 89.34 112.91 9013.68 8958.28 -4212.76 1331.15 5955173.67 665936.94 MWD 11134.85 88.72 109.39 9014.25 8958.85 -4224.83 1362.32 5955162.30 665968.37 MWD 11162.73 88.55 104.81 9014.92 8959.52 -4233.02 1388.96 5955154.69 665995.17 MWD 11198.35 90.40 102.17 9015.24 8959.84 -4241.33 1423.59 5955147.14 666029.98 MWD 11232.59 92.16 101.28 9014.48 8959.08 -4248.28 1457.10 5955140.92 666063.63 MWD 11261.80 90.48 96.53 9013.80 8958.40 -4252.80 1485.94 5955137.03 666092.56 MWD 11289.90 89.96 94.77 9013.70 8958.30 -4255.57 1513.91 5955134.88 666120.58 MWD 11322.84 88.37 91.24 9014.18 8958.78 -4257.29 1546.79 5955133.87 666153.49 MWD 11354.84 89.16 87.72 9014.87 8959.47 -4257.00 1578.78 5955134.87 666185.46 MWD 11384.50 90.75 82.61 9014.89 8959.49 -4254.51 1608.32 5955138.01 666214.94 MWD 11418.08 92.51 78.91 9013.93 8958.53 -4249.12 1641.44 5955144.12 666247.94 MWD 11457.12 91.72 71.86 9012.49 8957.09 -4239.28 1679.17 5955154.78 666285.44 MWD 11489.51 90.48 65.34 9011.87 8956.47 -4227.47 1709.31 5955167.25 666315.30 MWD 11525.83 91.98 60.58 9011.09 8955.69 -4210.97 1741.64 5955184.45 666347.26 MWD 11562.05 90.84 54.24 9010.20 8954.80 -4191.47 1772.13 5955204.61 666377.32 MWD 11603.54 90.04 45.43 9009.88 8954.48 -4164.74 1803.80 5955232.03 666408.40 MWD 11643.67 90.93 38.23 9009.54 8954.14 -4134.86 1830.55 5955262.48 666434.48 MWD 11674.00 92.33 36.62 9008.67 8953.27 -4110.78 1848.97 5955286.95 666452.37 MWD 11723.25 92.95 43.66 9006.40 8951.00 -4073.20 1880.67 5955325.22 666483.23 MWD 11756.13 88.90 44.37 9005.87 8950.47 -4049.56 1903.51 5955349.35 666505.55 MWD 11786.83 89.25 48.95 9006.37 8950.97 -4028.50 1925.82 5955370.90 666527.40 MWD 11815.18 88.19 52.65 9007.00 8951.60 -4010.59 1947.78 5955389.28 666548.96 MWD 11843.21 89.43 57.23 9007.58 8952.18 -3994.49 1970.72 5955405.87 666571.53 MWD 11874.88 91.28 59.52 9007.39 8951.99 -3977.89 1997.68 5955423.06 666598.13 MWD 11909.39 89.43 65.34 9007.17 8951.77 -3961.93 2028.26 5955439.69 666628.34 MWD 11950.98 86.52 75.38 9008.65 8953.25 -3947.97 2067.35 5955454.50 666667.12 MWD 11985.52 90.31 77.32 9009.60 8954.20 -3939.83 2100.89 5955463.37 666700.47 MWD 12021.77 90.66 78.73 9009.30 8953.90 -3932.31 2136.35 5955471.67 666735.76 MWD 12054.36 87.75 79.08 9009.75 8954.35 -3926.04 2168.32 5955478.64 666767.58 MWD 12079.40 86.26 88.60 9011.06 8955.66 -3923.35 2193.16 5955481.86 666792.35 MWD 12100.00 86.26 88.60 9012.40 8957.00 -3922.85 2213.71 5955482.81 666812.88 MWD TREE F 4" FMC WELLHEAD = ACTUATOR = MCEVOY BAKER KB. ELEV = 55.39' BF. ELEV = KOP = 35.54' 9730' Max Angle = 92.95° ~ 11723' Datum MD = 10248' Datum TVD = 8800' SS l TOP OF 9-518" BOT PBR ~ 2097' 13-3/8" X 9-5/8" BOT PKR /LNR HGR 2112' 13-3/8" CSG, 72#, N-80, ID = 12.347" ~ 2889' Minimum ID = 2.37" @ 10992' 2-7/8" STL LNR \j ~0 6 B S NaTES: WELL IXC®S 70° ~ 10430' 8. FROM CTD/DRLG DRAFT ~~ HORIZONTALS 10825'. 1618' t 3-3/8"CSG, 68# X 72# XO • 2016' 4112" CAMCO BAL-O SSSVN, ID = 3.813" 2!151' 9-5/8" FOC 7" BOT PSR (40') I-I 8677' 9-5/8" X 7" BOT PKR /LNR HGR W/ TEBACK ' 8717' 9-5/8" CSG, 47if, N-80, ID = 8,881" 9200' TUBING PUNCH 9300' - 9305' TOP OF 3-1/2" X 3-3/16" X 2-7%8" LNR 9434' MECHANICAL WHIPSTOCK ~ 9730' 7" & 4-1/2" DUAL WINDOW 9730' - 9738' RA PIP TAG 9738.5' EZ-SV6 SQUEEZE PACKER I ^J = TUBING PUNCH 9751' - 9756' 2-7/8" CEMENTED LNR MILLED TO 9760' 9760' PERFORATION SUMMARY REF LOG: MCNL/CCL/GR OF 8/27/2006 TIE-IN LOG: GEOLOGY PDC LOG A NGLE AT TOP PERF: 91.05° @ 11070' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11070' - 11370' Opn O8/27I06 2" 6 11580' - 11830' Opn 08/27%06 2" 6 11890' - 12050' Opn 08127%06 41/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9962' 7" LNR. 29#. N-80..0371 bof. ID = 6.184" 10406' 2125' --j s-s/8" Foc ~ 2686' 9-5/8" FOC 4198' s-s/a" Foc 8523' 4112" OTIS XA SLIDING SLV, ID = 3.813" 8583' 41/2" OTIS SBR TBG SEAL ASSY 8587' 41 /2' OTIS X NIP, ID = 3.813" 8613' 9-5/8" X 41/2" OTIS RH PKR, ~ = 3.92" 92$7' - j BOT'KB' LINER TOP PACKER 9434' BOT DEPLOY SLEEVE, 6' LONG, 3" ID 9434' EST TOP OF LINER CEMENT 9453' 3-1(2" X NIP, ID = 2.813" 9483' 3-1/2" X 3-3/16" X-OVER 10992' LSL SUB, 3-3/16 x 2-7/8 X-OVER 12065' PBTD 3-1/2" X 3-3/16" X 2-7/8" CMTED & PERFED ~~ 12100' 10455' CI-j B? J t 8 A-Y2" M ILLUUT WINDOW 9962' - 99 /(]' TOP OF WHPSTOCK ~ 9962' (RA TAG ~ 9970' ) PBTD H 11850' 2-7/8" LNR, 6.16#, STL, .0058 bpf, ID = 2.372" )-( 11917' DATE REV BY COMMENTS DATE REV BY COMMENTS 01118!78 ORIGINAL COMPLETION 09/14/03 CMO/TLP DATUM MD CORRECTION 07/30/88 RWO 08i28/O6 JUE NORDIC 1 CTD SIDETRACK 09/07198 CTD SIDETRACK (C-06A) 07/27101 CWKAK CORRECTIONS 06/16/03 CMOlTLP MAX ANGLE CORRECTION 07/13/03 TMWKK ADPERFS PRUDHOE BAY UNfT WELL: GO68 PERMff No: 206-104 A F1 No: 50-029-20127-02 SEC 19, T11 N, R14E, 1866' SNL 8 879' WEL BP Exploration (Alaska) =~ ~~~,~ ,.w _ os/2s/os ~~~~~ ~ J. 'd bide Schlumberger N0.394, . ~~ ~ Gas c~l'~, c~lr~n Ani~cr~ce Alaska Data 8< Consulting Services f Company: State of Alaska 2525 Gambell Street, Suite 400 ~ ~~' ~ ~~ ~ Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~~ Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Weil Joh # 1 nn r)occrinfinn r1~fn m r.. ~... rn C-11A 11225983 LDL 07/02/06 1 B-25 11217247 LDL 05/11/06 1 F-06A 11258688 PROD PROFILE W/DEFT 03/20/06 1 G-18A 11209612 MEM INJECTION PROFILE 07/19/06 1 P-24 11216206 MEM INJECTION PROFILE 07/06/06 1 B-28 11221590 LDL 07/04/06 1 B-01 11211508 PROD LOG W/DEFT 06/23/06 1 W-39A 11216197 MEM PROD PROFILE 05/29/06 1 Z-02A 11212856 INJECTION PROFILE 05/02/06 1 G-03A 11211493 LDL 05124/06 1 C-26A 11225979 LDL 06/07/06 1 F-266 NIA MEM PROD & INJECTION 06/06/06 1 F-26B N/A MEM BORAX LOG 06/06/06 1 W-39A 11216197 MEM BORAX LOG 05/29!06 1 F-04A 11221602 SCMT 08/18/06 1 Y-08A 11221604 SCMT 08/20106 1 C-06B 11212883 USIT 08/15/06 1 X-27 11217274 USIT 08126/06 1 K-07D 10942217 MEMORY SCMT 06/15/05 1 Y-10A 11209611 MEM INJECTION PROFILE 07/18/06 1 F-12 11225984 LDL 07/02/06 1 K-07D 11058256 SBHP SURVEY 11/28/05 1 X-04 10919925 PROD PROFILE W/DEFT 12/15104 1 A-30A 11054295 CH EDIT OF PDC LOG W/GR 04/06/05 1 17-046 40010183 OH EDIT OF MWD/LWD (REDO OF TVD DATA) 03/09/04 1 1 Z-30A 40010092 OH EDIT OF MWD/LWD (REDO OF TVD DATA) 01/27/04 1 1 17-04B PB1 40010183 OH EDIT OF MWD/LWD 03/08/04 2 1 Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite aoo 900 E. Benson Blvd. Anchorage, AK 99503-2838 Anchorage,. Alaska 99508 ATTN: Beth • _ _ °'° Ailr~a78A OIL COI~TSERQA'TI011T COMI~'IISSIOIQ Robert Caughlin CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-06B BP Exploration (Alaska) Inc. Permit No: 206-104 Surface Location: 1866' FNL, 879' FEL, SEC. 19, T11N, R14E, UM Bottomhole Location: 572' FNL, 1290' FWL, SEC. 29, T11N, R14E, UM Dear Mr. Caughlin: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED thisLl day of July, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~J~o[o STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS J ~J l_ 1 9 2006 PERMIT TO DRILL 20 AAC 25.005 faska Cif ~ Gas Cons. Commission 1 a. Type of work 1 b. Current Well Class ^ Exploratory ^ Development Gas 1 c. Specify if well is propos r: ^ 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 C-06B 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 12000 TVD 8955ss Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028310 1866' FNL, 879' FEL, SEC. 19, T11 N, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spu e: 549' FNL, 443' FEL, SEC. 30, T11N, R14E, UM Augus 10, 06 Total Depth: 9. Acres in Property: 14. Distance to N st Property: 572' FNL, 1290' FWL, SEC. 29, T11 N, R14E, UM 2560 18,500' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool: Surface: x-664514 y-5959356 Zone-ASP4 (Height above GL): 55.39 feet 850' 16. Deviated Wells: Kickoff Depth: 8725 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole An le: 90 de rees Downhole: 3250 Surface: 2370 18;` Casin Pro 'ram: S cifications To - Settin 'De th -Bottom uantit of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4_1 /g~~ 3-3/16" X zaie" 6.2# / 6.16# L-80 TCII / STL 2575' 9425' 8075' 12000' 8955' 136 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): 11917 9011 None 11850 9005 None asing Length -Size Cement Volume MD TVD Conductor /Structural 73' 20" 175 sx Arcticset 73' 73' Surface 2689' 13-3/8" 250 sx Arcticset 3435 sx Arcticset 2689' 2689' Intermediate 9200' 9-5/8" 1070 sx Howco Li ht 200 sx Class 'G' 9200' 7940' Production Liner 1285' 7" 450 sx Class'G~ 100 sx Class'G' 8677' - 9962' 7507' - 8621' Liner 2279' 2-7/8" 86 sx Class 'G' 9638' - 11917' 8323' - 9011' Perforation Depth MD (ft): 10730' - 11840' Perforation Depth TVD (ft): 8981' - 9005' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Robert Laughlin, 564-4080 Printed Name Robert C ghlin Title CT Drilling Engineer 1, 7 Prepared By Name/Number: Si nature ~~ ~ lyjr Phone 564-4080 Date ~ / i7 ` ~)~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill API Number: Permit A pr I See cover letter for Number: D 50-029-20127-02-00 Date: ' ~ other re uirements Conditions of Approva-: ~,( If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or as contained shales: 1C4. Samples Req'd: ^ Yes~No Mu Log Req'd: ^ Yes ~No HZS Measures: Yes ^ No I urvey Req'd: ~ Yes ^ No Other: l ~,S t` ~ CI f l`" f~ 3 ~0 ~ ~ ~~ ' APPROVED BY THE COMMISSION Date '2~ ,COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate (1R1(;InlLll • Bp Prudhoe Bay C-06B CTD Sidetrack CTD Sidetrack Summary Pre-Rig Work: 1. Passed tubing caliper 13-May-OS 2. Passed MIT-IA/OA 23-Mar-06 3. O AC-PPPOT-IC, T 4. E or S Set CIBP in 2 7/8" @ 10000' MD (+/- 50') 5. E Chemical cut 2 7/8" liner @ 9711' 6. S Pull test to determine if tubing (73' section of 2 7/8") is free. If the section of tubing pulls free, the prep work is done. If not, go to step 6. 7. C Pull test to determine if tubing (73' section of 2 7/8") is free. If the section of tubing pulls free, the prep work is done. If not, consult with Drilling Eng. Rig Work: (scheduled to begin on August 10, 2006) 1. MIRU and test BOPS to 250 psi low and 3500 psi high. 2. Pu1173' section of 2 7/8" liner 3. Mill-up 2 7/8" liner from 9711' to 9760'. 4. Cleanout/underream cement from 9760' up to 9700'. 5. Punch tubing 9759'-9755'(tag bottom - p/u 1') and 9300' - 9304'. 6. Set cement retainer 9750'(recommend Halliburton 4.5" EZ-SVB Squeeze Packer) 7. Pump 10 bbls of 15.8 ppg unislurry cement through the 4.5" x 7" annulus using tubing punch holes. 8. Run 3.80" mill and motor for cleanout run to 9745'. 9. Set Baker 4.5" monobore WS with KB packer at 9725' with LS orientation. 10. Mi113.8" window at 9725' and 10' of rathole. Swap the well to Flo-Pro. 11. Drill Build and Lateral: 4.125" OH, 2275' (12 deg/100 planned) with resistivity(res in lateral, not in build) 12. MAD pass OH with resistivity tools in memory mode 13. Run 3-3/16" x 2-7/8" solid liner leaving TOL 9425' 14. Pump primary cement leaving TOC at 9425 , 2 bbls of 15.8 ppg liner cmt planned 15. cleanout liner and MCNL/GR/CCL log , 16. Test liner lap to 2000 psi. 17. Perforate liner per asset instructions 0600') 18. Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Test separator 0600' of prefs) Mud Program: • Well kill: 8.6 ppg brine / • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4-1/8" Casing Program: fully cemented liner • 3-3/16", L-80 6.2# TCII 9425' and - 11000' and • 2-7/8", L-80 6.16# STL 11000'md - 12000'md • A minimum of 28 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 9425' Existing casing/tubin~ Information 13-3/8", L-80 72#, Burst 5380, collapse 2670 psi ~ 9 5/8", L-80 47#, Burst 6870, collapse 4750 psi 4-1/2", L-80 12.6#, Burst 8430, collapse 7500 psi • Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 90 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property -18,500 ft. (North) • Distance to nearest well within pool - 850 ft. (C-10) 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 C Pad i 20 pm. • Lost circulation risk is average. Reservoir Pressure • The max res. press. is estimated to be 3250 psi at 8800'ss (7.1 ppg EMW). • Max. surface pressure with gas (0.10 psi/ft) to surface is 2370 psi. i = 4.. FMC LHEAD= MCEVOY CTUATOR= BAKER . ELEV = 55.39' F. ELEV = 35.54' OP= 3100' Ang~ _ ~2 @ 11317' tum MD = 10248' tum TVD = 8800' SS C -O ~~ I ~AFETI(~10T ~W~ ~ ,°` 2EEDS 70° ~ 10430' 1618' -1 13-3/8"CSG, 68# X 721E XO 2016' 4-1l2" CAMCO BAL-O SSSVN, D = 3.813" 2051' 9-5/8" FOCI TOP OF 9-5/8" BOT PBR ~--i 2097' 13-3/8" X 9-5/8" BOT PKR /LNR HGR 2112' I 13-3/8" CSG, 72#, N-80, D =12.347" I Minimum ID = 2.372" @ 9638' TOP OF 2-7/8" LINER 7" BOT PBR (40') H 8877' 9-5/8" X 7" BOT PKR /LNR HGR W/.TIEBACK 8717' 9-5/8" CSG, 47#, N-80, ID = 8.681" ~ 9200' TOP OF 2-718" LNR, ID = 2.372" 9638' - 62' PERFORATION SUMMARY REF LOG: SPERRY MW~VGR on 9!7/98 ANGLE AT TOP PERF: 89 (c~ 10730' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpNSgz OWTE 2" 6 10730 - 10755 O 07/13/03 2" 6 10815 - 10840 07/13/03 2" 4 10940 - 11000 O 03/12/00 2-1/8" 4 11150 - 11220 O 09/07/98 2-1/8" 4 11270 - 11360 O 09/07/98 2-1/8" 4 11550- 11630 O 09/07/98 2-1/8" 4 11720 - 11840 O 09/07!98 7" LNR, 29~, N-80, .0371 bpf, ID = 6.184" I'""I 10406' ~ 2125' ~ -{ s-5/s" FOC I ~ 2686' 9-5/8" FOG 4198' 9-5/8" FOC 8523' 4-1/2" OTIS XA SLDING SLV, D = 3.813" 8583' 4-1/2" OTIS SBR TBG SEAL ASSY 8587' 4-1/2" OTIS X Nom, ID= 3.813" 8613' 9-5/8" X 4-1 /2" OTIS RH PKR, ID = 3.92" 7" & 4-1/2" MILLOUT WINDOW 9962' - 9970' TOP OF WHIPSTOCK ~ 9962' (RA TAG @ 9970' ) u- 2-7/8" LNR, 6.16#, STL, .0058 bpf, D = 2.372" DATE REV BY COMUBVTS DATE REV BY COMVBJTS 01/18A8 ORIgNAL COMPLETION 09/14/03 CMD/TLP DATUM MD CORRECTION 07/30/88 RWO 09/07/98 CTD SIDETRACK (C-06A) 07/27/01 CHIKAK CORRECTIONS 06/16/03 CMOfTLP MAX ANGLE OORRFCTION 07/13/03 TMN/KK ADPERFS I 11917' I PRUDFIpE BAY UNff WELL: GO6A PERMIT No: 1981570 API No: 50-029-20127-01 SEC 19, T11 N, R14E, 1866' SNL & 879' WEL BP 6cploration (Alaska) = 4.. FMIC LHEAD= MCEVOY CTLIATOR= BAKR2 B. E1EV = 55.39' F. El_EV = 35.54' OP = 3100' Angle = f2 ~ 11317' tum MD = 10248' tum ND = 8800' SS TOP OF 9-5/8" BOT PBR H 2097' 13-3/8" X 9-5/8" BOT PKR /LNR HGR 2112' 13-3/8" CSG, 72#, N-80, ID = 12.347" - Minimum ID = 2.372" @ 9638' TOP OF 2-7/8" LINER O ~-'--}--~- 2016' 4-1/2" CAMCO BAL-O SSSVN, ID= 4198' 9-5/8" FOC 8523' 4-1/2" OTIS XA SLDING SLV, D = 3.813" 8587' H 4-1/2" OTIS X NIP, ID = 3.813" 9-5/8" X 7" BOT PKR /LNR HGR W/ TIEBACK H 8717' 9-5/8" CSG, 47#, N-80, ID= 8.681" 9200' tubing punch 9300' PERFORATION SUMMARY REF LOG: SPS2RY MWLYGR on 9/7198 ANGLE AT TOP PERF: 89 ~ 10730' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL OpNSgz DATE 2" 6 10730 - 10755 !soated propo, 2" 6 10815 - 10840 solated propo~ 2" 4 10940- 11000 isolated propo: 2-1/8" 4 11150-11220 isolated propo~, 2-1/8" 4 11270 - 11360 isolated propos 2-1/8" 4 11550-11630 isolated orooo 2-1/8" 4 11720 - 11840 !solated Cement retainer 9750' Mill 2-7/8" cemented liner to 9760 H 9760' CIBP 10000' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9962' 7" LNR, 29#, N-80, .0371 bpf, D = 6.184" 10406' 9425' ~--jTop of Cement 9425' TOP OF 3-3/16" LNR 9435' 3 5" X Nip 2.813" ID 11000' H3-3/16 x 2-7/8 X-over 3-3/16" X 2-718" cmt'ed and perfed~--~ 12000' Mechanical Whi sto k 7" 8 4-1/2" MILLOUT WINDOW 9962' - 9970' TOP OF WHIPSTOCK Q 9982' (RA TAG @ 9970' ) ~ PBTD H 11850' 2-7/8" LNR, 6.16#, STL, .0058 bpf, ID = 2.372" -{ DATE REV BY COfvNBVTS DATE REV BY OOMvBVTS 01N8/78 ORIGINAL COMPLETION 09/14/03 CMO/TLP DATUM MD CORRECTION 07/30/88 RWO 09/07/98 CTD SIDETRACK (C-08A) 07/27/01 CWKAK CORRECTIONS 06/16/03 CMCVTLP MAX ANGLE CORRECTION 07/13/03 TMN/KK ADPERFS V ~ V V ~ I SAFETY NOTES: WELL IXCEEDS 70° ~ 10430' & Proposed CTD Sidetrack ~~ HORIZONTAL @ 10825'. 1618' 13-3/8"CSG. 68# X 72# XO PRlAFIOE BAY UNIT WELL: G06A PERMfr No: 1981570 AR No: 50-029-20127-01 SEC 19, T11 N, R14E, 1866' SNL & 879' WEL BP 6rploration (Alaska) • • a ~ ~;. _ dada t'=_ t~ ~;~~ 9 _ ~c .~s$~ .:1. ~~ ~~~8 ~- ~ a~^i I ~F i $~ a a s ~~; eee3f I__ 5^^~.. .L r r - ~~~~ +1~~~ii~ L~ +}~~} i*L ~!trl~i [Itril i:i~i. i.il ~L!Ii~ «j ~~{ I~j, t ~k ,_ , ~. ~' ~._~., .. __. ~.._ ~. r. r . __ ...... , .... ~ ~ ~ ~ ., ~ ._. r~ i ~ $€~~£~~FFF ddq :~:Sa.'39~~ • : 83"6.°C8F9: 8nF F '3 •~• ~y6F: 8 3 8 " w! ~ ~ y ~ $ ~~'g ~ °i69~~6:~~ 8088888888 :8aF 9 d R 988~8~8~88 ~a^~~ N ff s ~ ~ ~~~85 ~m~ • ::a °9a:c q ~SiiiiiC'~~ ~ 6 ~ ~9 g ~ ~' ~ §~ 9 ~ €~g~~ ~ ~ s~$$i a ~ a~ ;.:: ~ #ac#E3::o„ = , 9a:o9^9969 3~aaaaaa€a ~ ~ mze~~ ~ 8 a58 5 ii1~ • A W 8i ~~ ~~ ~ ~s m4 ~ZyBro ~ :°:~ttt$Sa ~~%~~~.~ ~~ ~ ~ ~~~~ ~ 7 8.....x%.8 p ~$7 o f cs::98ae: ` sdd?7~YYSi '~ 8888:9ata8 ' ° ~ i eettytagggt:~gag 566598" t $ ~:7 ~"~" .e~~~t' .. . . ... S•:a 88689$ Z dl9wtlferti A 8 `-' e 0 ~o C: A A uu S i S 8 ----~~ ~ ~ t~~ ,~k~ ' by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P B~R~ s INTEQ Company: BP Amoco Date: 7/11/2006 Time: 13138:34 Page: t Field: Prudhoe Bay Co-ordinate(NE)12eferenee: We1L• C-06, True North Site: PB C Pad Vertical ('1'VD) Reference: 7: 06 6/27/1973 00:00 55.4 Well: C-06 Section (VS) Reference: Wetl (O.OON,O.OOE,95.OOAzi) Wellpath: Ptan 3, C-066 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: bggm2005 Site: PB C Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5957218. 72 ft Latitude: 70 17 22.367 N From: Map Easting: 662550. 03 ft Longitude: 148 41 2.797 W Position Uucertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.24 deg Well: C-06 Slot Name: O6 C-O6 Well Position: +N/-S 2094.47 ft Northing: 5959356. 00 ft Latitude: 70 17 42.964 N +E/-W 2009.86 ft Easting : 664514. 00 ft Longitude: 148 40 4.217 W Position Uncertainty:- 0.00 ft Wellpath: Plan 3, C-O66 Drilled From: C-06 500292012702 Tie-on Depth: 9700.00 ft Current Daturo: 7:06 6/27/1973 00:00 H eight 55. 40 ft Above System Datum: Mean Sea Level Magnetic Data: 7/11/2006 Declination: 24.47 deg Field Strength: 57606 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 22.40 0.00 0.00 95.00 Plan: Plan #3 Date Composed: 7/11/2006 Version: 3 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <-_- Latitude --> <--- Longitude; -->' Name Description TVD +N/-S ,+E/-W Northing Fasting Deg Min .Sec Deg`1Nin Seca Dip. Dir... ft ft ft ft ft C-06B Polygon 55.40 -4086.49 1106.90 5955295.00 665710.00 70 17 2.772 N 148 39 31.973 W -Polygon 1 55.40 -4086.49 1106.90 5955295.00 665710.00 70 17 2.772 N 148 39 31.973 W -Polygon 2 55.40 -3799.89 2408.58 5955610.00 667005.00 70 17 5.588 N 148 38 54.052 W -Polygon 3 55.40 -4051.05 2458.09 5955360.00 667060.00 70 17 3.118 N 148 38 52.612 W -Polygon 4 55.40 -4307.55 1152.08 5955075.00 665760.00 70 17 0.598 N 148 39 30.658 W C-06B Fault 1 55.40 -3491.89 219.64 5955870.00 664810.00 70 17 8.621 N 148 39 57.819 W -Polygon 1 55.40 -3491.89 219.64 5955870.00 664810.00 70 17 8.621 N 148 39 57.819 W -Polygon 2 55.40 -4021.76 663.18 5955350.00 665265.00 70 17 3.409 N 148 39 44.898 W C-06B Fault 2 55.40 -4710.48 823.16 5954665.00 665440.00 70 16 56.636 N 148 39 40.240 W -Polygon 1 55.40 -4710.48 823.16 5954665.00 665440.00 70 16 56.636 N 148 39 40.240 W -Polygon 2 55.40 -4072.52 1382.29 5955315.00 665985.00 70 17 2.909 N 148 39 23.950 W C-068 Fault 3 55.40 -4036.21 1323.07 5955350.00 665925.00 70 17 3.267 N 148 39 25.676 W -Polygon 1 55.40 -4036.21 1323.07 5955350.00 665925.00 70 17 3.267 N 148 39 25.676 W -Polygon 2 55.40 -4093.83 1441.85 5955295.00 666045.00 70 17 2.700 N 148 39 22.216 W -Polygon 3 55.40 -4278.43 1877.94 5955120.00 666485.00 70 17 0.883 N 148 39 9.514 W -Polygon 4 55.40 -4093.83 1441.85 5955295.00 666045.00 70 17 2.700 N 148 39 22.216 W C-06B Fault 4 55.40 -3857.99 721.78 5955515.00 665320.00 70 17 5.020 N 148 39 43.191 W -Polygon 1 55.40 -3857.99 721.78 5955515.00 665320.00 70 17 5.020 N 148 39 43.191 W -Polygon 2 55.40 -3801.65 1118.14 .5955580.00 665715.00 70 17 5.574 N 148 39 31.644 W -Polygon 3 55.40 -3654.55 2166.68 5955750.00 666760.00 70 17 7.018 N 148 39 1.097 W -Polygon 4 55.40 -3571.17 2698.67 5955845.00 667290.00 70 17 7.837 N 148 38 45.599 W -Polygon 5 55.40 -3654.55 2166.68 5955750.00 666760.00 70 17 7.018 N 148 39 1.097 W -Polygon 6 55.40 -3801.65 1118.14 5955580.00 665715.00 70 17 5.574 N 148 39 31.644 W by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P s~R~ Nur,.~s INTEQ .Company: BP Amoco Date: . 7/11!2006 Time: 13:38:34 Page: Z Field: Prudhoe $ay Co-ordin$te(NE) Reference: Well:. C-06, True North Site: PB C Pad Vertical (1'VD) Reference: 7:06 til27/1973 00:00 55.4 Welly C-06 Section (VS) Reference: Well'(O.OON,O:OOE, 95.OOAzi) Wellpath: Plarr 3, C-0ti6 Survey Calculation Method: Minimum Curvature Db: OraGe Targets Map Map <--- Latitude - ---> <-- ..Longitude -> Name -. Description TVD +N/-S +E/-W Northing Fasting .Deg Mine Sec Deg Min Seca Dip. ` Dir. ft ft ft ft ft C-066 Faults 55.40 -4066.97 2042.62 5955335.00 666645.00 70 17 2.962 N 148 39 4. 715 W -Polygon 1 55.40 -4066.97 2042.62 5955335.00 666645.00 70 17 2.962 N 148 39 4. 715 W -Polygon 2 55.40 -4296.67 2482.73 5955115.00 667090.00 70 17 0.702 N 148 38 51. 896 W C-06B Fault 6 55.40 -3822.85 1857.90 5955575.00 666455.00 70 17 5.364 N 148 39 10. 094 W -Polygon 1 55.40 -3822.85 1857.90 5955575.00 666455.00 70 17 5.364 N 148 39 10. 094 W -Polygon 2 55.40 -3698.09 1870.64 5955700.00 666465.00 70 17 6.591 N 148 39 9. 722 W C-06B Target 1 8965.40 -4066.54 698.21 5955306.00 665301.00 70 17 2.969 N 148 39 43. 878 W C-06B Target 3 9010.40 -3985.20 2191.45 5955420.00 666792.00 70 17 3.766 N 148 39 0. 378 W C-06B Target 2 9013.40 -4182.46 1149.81 5955200.00 665755.00 70 17 1.828 N 148 39 30.723 W Annotation MD TVD ft _ ft 9700.00 8379.31 TIP 9725.00 8402.14 KOP 9745.00 8420.54 End of 9 Deg/100' DLS 9795.00 8467.76 4 10149.98 8778.19 5 10367.83 8894.49 6 10967.66 9013.09 7 11317.66 9012.45 8 11697.66 9011.25 9 12000.00 0.00 TD Plan Section Information MD Inc! Azim TVD +N/-S +E/-W DLS Build Turn TFO ' Target.. ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 9700.00 24.17 215.60 8379.31 -3777.20 488.92 0.00 0.00 0.00 0.00 9725.00 23.94 215.55 8402.14 -3785.49 482.99 0.92 -0.92 -0.20 185.04 9745.00 22.14 215.55 8420.54 -3791.85 478.44 9.00 -9.00 0.00 180.00 9795.00 16.14 215.55 8467.76 -3805.19 468.92 12.00 -12.00 0.00 180.00 10149.98 45.00 142.37 8778.19 -3951.53 519.19 12.00 8.13 -20.61 270.00 10367.83 70.00 133.14 8894.49 -4084.85 643.05 12.00 11.48 -4.24 340.00 10967.66 90.00 62.36 9013.09 -4146.83 1188.02 12.00 3.33 -11.80 276.80 11317.66 90.20 104.36 9012.45 -4107.28 1527.94 12.00 0.06 12.00 89.70 11697.66 90.14 58.76 9011.25 -4052.99 1893.99 12.00 -0.02 -12.00 270.00 12000.00 90.11 95.04 9010.56 -3985.63 2183.57 12.00 -0.01 12.00 90.00 Survey MD Inc! Azim Sys TVD N!S E/R' MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 9700.00 24.17 215.60 8323.91 -3777.20 488.92 5955590.67 665085.44 0.00 816.27 0.00 MWD 9725.00 23.94 215.55 8346.74 -3785.49 482.99 5955582.25 665079.70 0.92 811.08 185.04 MWD 9745.00 22.14 215.55 8365.14 -3791.85 478.44 5955575.79 665075.29 9.00 807.10 180.00 MWD 9750.00 21.54 215.55 8369.78 -3793.37 477.36 5955574.25 665074.24 12.00 806.16 180.00 MWD 9775.00 18.54 215.55 8393.27 -3800.34 472.38 5955567.18 665069.41 12.00 801.81 180.00 MWD 9795.00 16.14 215.55 8412.36 -3805.19 468.92 5955562.25 665066.05 12.00 798.78 180.00 MWD 9800.00 16.15 213.39 8417.16 -3806.33 468.13 5955561.09 665065.29 12.00 798.09 270.00 MWD 9825.00 16.53 202.80 8441.15 -3812.51 464.84 5955554.84 665062.14 12.00 795.35 272.07 MWD 9850.00 17.40 192.95 8465.07 -3819.44 462.62 5955547.87 665060.07 12.00 793.75 282.24 MWD 9875.00 18.71 184.23 8488,84 -3827.08 461.49 5955540.20 665059.11 12.00 793.28 291.66 MWD 9900.00 20.37 176.75 8512.41 -3835.43 461.44 5955531.86 665059.24 12.00 793.96 299.95 MWD 9925.00 22.30 170.42 8535.69 -3844.45 462.47 5955522.86 665060.47 12.00 795.78 307.01 MWD by BP Alaska nth sN"ucias Baker Hughes INTEQ Planning Report INTEQ Company; BP Amoco Date: 7/11/2006 Time: 13;38:34 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: C-O6, True North Site:' PB C Pad Vertical (TVD)Reference: 7:06 6/27/1973 00:00 55.4 WeIL• C-06 Section (VS) Reference: Well (O.OON,O.OOE,95.OOAzi) Wellpath:' Plan 3, C-066 Survey Calculation Method: Minimum Curvature Dbc Oracle Survey MD Incl Azim Sys 1'VD N/S E/W MapN MapE DLS VS TFO TooC ft deg deg ft ft ft ft ft deg/100ft ft deg 9950.00 24.44 165.11 8558.64 -3854.13 464.59 5955513.23 665062.80 12.00 798.73 312.90 MWD 9975.00 26.73 160.62 8581.19 -3864.43 467.79 5955503.00 665066.22 12.00 802.82 317.78 MWD 10000.00 29.14 156.81 8603.28 -3875.34 472.05 5955492.19 665070.72 12.00 808.01 321.83 MWD 10025.00 31.65 153.55 8624.84 -3886.81 477.37 5955480.84 665076.29 12.00 814.31 325.19 MWD 10050.00 34.23 150.73 8645.83 -3898.82 483.73 5955468.98 665082.91 12.00 821.69 328.01 MWD 10075.00 36.86 148.25 8666.17 -3911.33 491.12 5955456.63 665090.57 12.00 830.14 330.38 MWD 10100.00 39.54 146.07 8685.81 -3924.31 499.51 5955443.83 665099.24 12.00 839.63 332.39 MWD 10125.00 42.26 144.12 8704.71 -3937.73 508.87 5955430.63 665108.90 12.00 .850.13 334.11 MWD 10149.98 45.00 142.37 8722.79 -3951.53 519.19 5955417.05 665119.52 12.00 861.62 335.58 MWD 10175.00 47.83 140.99 8740.04 -3965.74 530.43 5955403.09 665131.06 12.00 874.05 340.00 MWD 10200.00 50.67 139.72 8756.35 -3980.32 542.52 5955388.78 665143.47 12.00 887.36 340.96 MWD 10225.00 53.53 138.56 8771.71 -3995.24 555.42 5955374.15 665156.69 12.00 901.52 341.78 MWD 10250.00 56.39 137.47 8786.06 -4010.45 569.12 5955359.25 665170.72 12.00 916.49 342.50 MWD 10275.00 59.27 136.46 8799.37 -4025.91 583.56 5955344.10 665185.49 12.00 932.22 343.12 MWD 10300.00 62.15 135.51 8811.60 -4041.59 598.71 5955328.76 665200.98 12.00 948.68 343.66 MWD 10325.00 65.04 134.60 8822.72 -4057.43 614.53 5955313.27 665217.14 12.00 965.82 344.13 MWD 10350.00 67.93 133.74 8832.69 -4073.40 630.97 5955297.66 665233.93 12.00 983.59 344.53 MWD 10367.83 70.00 133.14 8839.09 -4084.85 643.05 5955286.49 665246.26 12.00 996.63 344.87 MWD 10375.00 70.10 132.23 8841.54 -4089.42 648.01 5955282.03 665251.31 12.00 1001.96 276.80 MWD 10400.00 70.50 129.08 8849.96 -4104.75 665.86 5955267.09 665269.50 12.00 1021.08 277.11 MWD 10425.00 70.96 125.94 8858.22 -4119.11 684.58 5955253.14 665288.52 12.00 1040.98 278.17 MWD 10450.00 71.46 122.81 8866.27 -4132.47 704.11 5955240.22 665308.34 12.00 1061.60 279.21 MWD 10475.00 72.02 119.71 8874.10 -4144.79 724.41 5955228.35 665328.90 12.00 1082.89 280.22 MWD 10500.00 72.63 116.62 8881.70 -4156.03 745.40 5955217.57 665350.13 12.00 1104.79 281.19 MWD 10525.00 73.28 113.56 8889.03 -4166.16 767.05 5955207.91 665371.99 12.00 1127.23 282.13 MWD 10550.00 73.98 110.52 8896.07 -4175.16 789.28 5955199.40 665394.41 12.00 1150.16 283.03 MWD 10575.00 74.72 107.50 8902.82 -4183.00 812.03 5955192.06 665417.33 12.00 1173.52 283.88 MWD 10600.00 75.50 104.50 8909.25 -4189.66 835.26 5955185.91 665440.69 12.00 1197.23 284.70 MWD 10603.02 75.60 104.14 8910.00 -4190.39 838.09 5955185.25 665443.55 12.00 1200.12 285.47 C-06B 10625.00 76.32 101.53 8915.33 -4195.12 858.88 5955180.97 665464.43 12.00 1221.24 285.56 MWD 10650.00 77.17 98.57 8921.07 -4199.37 882.83 5955177.25 665488.47 12.00 1245.47 286.19 MWD 10675.00 78.06 95.64 8926.43 -4202.38 907.06 5955174.77 665512.76 12.00 1269.87 286.87 MWD 10700.00 78.98 92.72 8931.41 -4204.17 931.49 5955173.52 665537.22 12.00 1294.37 287.50 MWD 10725.00 79.92 89.83 8935.99 -4204.72 956.06 5955173.51 665561.79 12.00 1318.89 288.08 MWD 10750.00 80.89 86.95 8940.15 -4204.02 980.70 5955174.74 665586.41 12.00 1343.37 288.61 MWD 10775.00 81.88 84.08 8943.90 -4202.09 1005.34 5955177.21 665611.00 12.00 1367.75 289.09 MWD 10800.00 82.89 81.24 8947.21 -4198.92 1029.91 5955180.92 665635.49 12.00 1391.95 289.52 MWD 10825.00 83.92 78.40 8950.08 -4194.53 1054.35 5955185.84 665659.83 12.00 1415.92 289.90 MWD 10850.00 84.97 75.57 8952.50 -4188.93 1078.59 5955191.97 665683.94 12.00 1439.58 290.22 MV1ID 10875.00 86.02 72.76 8954.47 -4182.13 1102.57 5955199.29 665707.76 12.00 1462.87 290.50 MWD 10900.00 87.09 69.95 8955.97 -4174.15 1126.21 5955207.79 665731.22 12.00 1485.72 290.72 MWD 10925.00 88.16 67.14 8957.01 -4165.01 1149.45 5955217.43 665754.26 12.00 1508.08 290.89 MWD 10950.00 89.24 64.34 8957.57 -4154.75 1172.24 5955228.19 665776.81 12.00 1529.89 291.00 MWD 10967.66 90.00 62.36 8957.69 -4146.83 1188.02 5955236.46 665792.41 12.00 1544.92 291.07 MWD 10975.00 90.00 63.25 8957.69 -4143.47 1194.55 5955239.95 665798.87 12.00 1551.13 89.70 MWD 11000.00 90.02 66.25 8957.68 -4132.81 1217.16 5955251.11 665821.23 12.00 1572.72 89.70 MWD 11025.00 90.04 69.25 8957.67 -4123.34 1240.29 5955261.08 665844.16 12.00 1594.95 89.70 MWD 11050.00 90.05 72.25 8957.65 -4115.10 1263.89 5955269.84 665867.57 12.00 1617.74 89.70 MWD 11075.00 90.07 75.25 8957.63 -4108.10 1287.89 5955277.36 665891.40 12.00 1641.03 89.70 MWD 11100.00 90.08 78.24 8957.60 -4102.37 1312.22 5955283.62 665915.60 12.00 1664.77 89.71 MWD 11125.00 90.10 81.24 8957.56 -4097.92 1336.82 5955288.61 665940.09 12.00 1688.89 89.71 MWD 11150.00 90.11 84.24 8957.51 -4094.76 1361.62 5955292.30 665964.81 12.00 1713.32 89.72 MWD 11175.00 90.13 87.24 8957.46 -4092.91 1386.54 5955294.70 665989.69 12.00 1737.99 89.72 MWD " by ~ BP Alaska Baker Hu hes INTE Plann>tn Re ort g Q g P s~ ~r Nuc;r~s 11NTEQ Company:. BP Amoco Date: 7/11/2006 Time:.. 13:38:34 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Welf: C-06; True North Site: PB C Pad Vertical (TVD) Reference: 7:06 6/27/1973 00:00 55.4 We1L• C-06 Section (VS) Reference: Well (O.OON,O.OOE,95.OOAzi) Wellpath:< .Plan 3, G066 Survey Calculation Method: Minimum Curvature Db: Oracle - Survey MD Incl Azm Sys TVD N/S E/VV MapN MapE DLS VS TFQ Tool. ft deg deg ft ft ft ft ft deg/1-0Oft ft' deg 11200.00 90.14 90.24 8957.40 -4092.36 1411.53 5955295.80 666014.67 12.00 1762.84 89.73 MWD 11225.00 90.15 93.24 8957.34 -4093.12 1436.52 5955295.58 666039.66 12.00 1787.79 89.73 MWD 11250.00 90.17 96.24 8957.27 -4095.19 1461.43 5955294.06 666064.61 12.00 1812.79 89.74 MWD 11275.00 90.18 99.24 8957.19 -4098.56 1486.20 5955291.24 666089.44 12.00 1837.76 89.75 MWD 11300.00 90.19 102.24 8957.11 -4103.22 1510.76 5955287.12 666114.10 12.00 1862.63 89.76 MWD 11317.66 90.20 104.36 8957.05 -4107.28 1527.94 5955283.43 666131.37 12.00 1880.10 89.77 MWD 11325.00 90.20 103.48 8957.02 -4109.05 1535.07 5955281.82 666138.53 12.00 1887.35 270.00 MWD 11350.00 90.20 100.48 8956.94 -4114.24 1559.52 5955277.17 666163.09 12.00 1912.17 270.00 MWD 11375.00 90.20 97.48 8956.85 -4118.14 1584.21 5955273.80 666187.85 12.00 1937.10 269.99 MWD 11400.00 90.20 94.48 8956.76 -4120.75 1609.07 5955271.74 666212.76 12.00 1962.10 269.98 MWD 11425.00 90.20 91.48 8956.68 -4122.05 1634.03 5955270.99 666237.75 12.00 1987.08 269.97 MWD 11450.00 90.19 88.48 8956.59 -4122.04 1659.03 5955271.54 666262.74 12.00 2011.98 269.96 MWD 11475.00 90.19 85.48 8956.51 -4120.72 1683.99 5955273.41 666287.66 12.00 2036.73 269.95 MWD 11500.00 90.19 82.48 8956.43 -4118.10 1708.85 5955276.57 666312.46 12.00 2061.27 269.94 MWD 11525.00 90.18 79.48 8956.34 -4114.19 1733.54 5955281.03 666337.05 12.00 2085.52 269.93 MWD 11550.00 90.18 76.48 8956.27 -4108.98 1757.99 5955286.76 666361.38 12.00 2109.42 269.92 MVUD 11575.00 90.17 73.48 8956.19 -4102.50 1782.13 5955293.77 666385.37 12.00 2132.91 269.91 MWD 11600.00 90.17 70.48 8956.12 -4094.77 1805.91 5955302.02 666408.97 12.00 2155.92 269.90 MWD 11625.00 90.16 67.48 8956.04 -4085.81 1829.24 5955311.49 666432.10 12.00 2178.38 269.89 MWD 11650.00 90.15 64.48 8955.98 -4075.63 1852.07 5955322.16 666454.70 12.00 2200.24 269.88 MWD 11675.00 90.15 61.48 8955.91 -4064.28 1874.34 5955334.00 666476.72 12.00 2221.43 269.87 MWD 11697.66 90.14 58.76 8955.85 -4052.99 1893.99 5955345.71 666496.11 12.00 2240.02 269.86 MWD 11700.00 90.14 59.04 8955.85 -4051.78 1895.99 5955346.96 666498.09 12.00 2241.91 90.00 MWD 11725.00 90.14 62.04 8955.79 -4039.49 1917.76 5955359.73 666519.58 12.00 2262.53 90.00 MWD 11750.00 90.14 65.04 8955.73 -4028.36 1940.14 5955371.35 666541.70 12.00 2283.85 90.01 MWD 11775.00 90.14 68.04 8955.66 -4018.41 1963.07 5955381.80 666564.41 12.00 2305.83 90.02 MWD 11800.00 90.14 71.04 8955.60 -4009.67 1986.49 5955391.05 666587.63 12.00 2328.40 90.02 MVUD 11825.00 90.14 74.04 8955.54 -4002.17 2010.34 5955399.06 666611.31 12.00 2351.50 90.03 MWD 11850.00 90.13 .77.04 8955.49 -3995.93 2034.54 5955405.83 666635.37 12.00 2375.07 90.04 MWD 11875.00 90.13 80.04 8955.43 -3990.97 2059.04 5955411.33 666659.75 12.00 2399.04 90.04 MWD 11900.00 90.13 83.04 8955.37 -3987.29 2083.77 5955415.55 666684.39 12.00 2423.35 90.05 MWD 11925.00 90.12 86.04 8955.32 -3984.92 2108.65 5955418.47 666709.21 12.00 2447.93 90.06 MWD 11950.00 90.12 89.04 8955.26 -3983.84 2133.62 5955420.08 666734.16 12.00 2472.72 90.06 MWD 11975.00 90.12 92.04 8955.21 -3984.08 2158.62 5955420.39 666759.15 12.00 2497.64 90.07 MWD 12000.00 90.11 95.04 8955.16 -3985.63 2183.57 5955419.39 666784.13 12.00 2522.63 90.08 2-7/8"" are s.. ~_ of bag Dowel I bag of slips Blind/Shears 2 3/8" combi ram/slips C, BAG TOTs ~ ~ ~ Mud Cross I I Mud Cross of flow cross variable bore pipe 3 1/2"-2 7/8" 2 3/8" combi ram/slips Flow Tee TOTs l • Terri. Hubble BP Exploration AK Inc. PO Box 196612 M$ 7-5 Anchorage, AK 9.9519 PAY TO THE ORDER OF "Mastercard Check'° First. National. Bank. Alaska ~ Anchorage, AK 99501 MEM• C • 89-6/125.2 290 DATE ~ ~, " 1~~ .~' ~: L 25 200060:99 L46 2 27 L 556~~' 0 290 • • TRANSMITTAL LETTER CHECKLIST WELL NAME _ ~~/~ -~~~ PTD# Z~- /~j L,1 Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-Olv'S TEXT FOR APPROVAL LETTER I WHAT (OPTIONS) ~ 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. i 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 (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 I from where samples are first caught and 10' sample intervals through target zones. Ptease 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 (Com~an. NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCompany Name) must contact the Commission to obtain advance approval of such water well testing pro ram. Rev: U25i06 C:\jody\transmittal checklist -~ ',`-; N , m a ; w N a~ ~ : $ ~ a ° i ~ c : 1 , : ~ 1 o` o I I ~ I ' , ~ : ~ E O ~ : : m i , o I I ~, a ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~~ ~ ~~ ~~ j of i ~ , ~ I I ~ l I ~ c ~ I ~ ~ , ~ ~ o U~ , , ~ F.. ; Z ~ ~ ~ ~ ~ ~ ~ m ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ; ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 0 ~ ~ ~ ~ ~ w ~ O ~ N o i ° N, ~ ~~ ~~ ~ a'~ ° N, a .~ ~, I ~ ~ ~ ~ ~ ~~ Z II ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ j. ~, ~ ~ ~ ~~ ~ ~, G N, N. N~ y~ N~ y~ y, y~ N~ N~ N~ N, N~ ¢¢~ ~ ~ ~ Z z Z ~ ~ N Z Z Z z } y tlN y. } } } y, y, y, y. y. y, Z Z Z } ~ } } } } Q ¢ ¢ Z Z a } } } } } }, ~ } } , } } }~ } Z; ; ~ ; : ~ ~ ~ ~ ~ ~ ; Z; ; Z Z; T ~ ~ ~ , . O. o: , C L• p• N' i N M N' Q' ~ N ~ Q N ~p O W. X W C : y. N, ~ . ~ W ~ : . . O ~ I ~ ..+ C~ Q ~ ~ , ~ ~ ~ ~ C. ~ ~ ~ ~. • 3 ~ ~ y , ~ , v ~ ~, t : w ~ ~ , m, N, T y, 4 ~- ~ ~ ~ ~ ~~ N, ~ ~ ".' 3 C• ~~ •~. N. C~ a, ~ N p ~ M y~ O. 7. ~, ~'j~ N~ N: ~, 'O~ y, C. 6, C. >~ ~ C, N~ ~ ~ f ~ O. _ Qi ~ 3, d•~ N• N. ~ ~~ -O, N, tA~ ~ ~ , ~ ~ ~ c: ~ 7• ~ . , , C• ~ • '~ ~ ~ ~~ °~ ~ M' ~ ~~ ~~ ' p, m i U ~ ~- rn ~, ~ j , N ~~ U 2' m a fn' o c L' ~, ~ ~ c' 7, o, o' °' c ~?' L Q' 7 tl1 tl) w' ~ ~' m m Z a. °, . ° ~- m, >, w, o, > m a 4 ~ ~ , ^' n ~ O ¢ ~ I ' o ~' c, c ' ~' ~' ~ `~' ~' ~ 3' c ~' ~' ~ .. ~' , c d, ~ c ~ ~, - o _ ~ Y o ~ '~ o c o~ f0~ a '~ ~ o o ~ U. ~ m 4 a~, N ° Q . ~ • ~ o rn a I ~ ~ g ~ c; ~ d; o ~ 4 ~ ~ ~ ~ , , ° o. C ~ ~~ ° ° ~ ' ~? o x ~, . 4 ° ~~ Z , . ~ m m o E . ;~ c °~ y ° ` ~ ~ a d z co ~ 3 o ~ a ' m. , , rn; ~ a c i, a i o m a ° , , . Z m. c ~ y y ~ °` °` 3 3 aai a oi m; ~ €~ ~ ~: N' u a~ 3 °' ~, oM; a y N' ~ 4 d' ' u; o', 3', a: `° m °o O v, 'v, >, m. c w., , , ~ $: a a a m o c ~o, , o o c, ~ a N m, o: rn c a m a, y: d, a ~ F '' y' a - m m' ~' ' ' : c' ~' ~' ~ ~ ~ rn ~ `° v °, c: o: o, ~ q a o ai _ m, N O ~ N ~ O ~ ° ° ° v; N ~ ~ C 4 °: ° °: - y °' ° ~ f0 O ~ , E; 2 C 3 ~ T C ~ ff : ~: O. fl ~ N 'p GL~ Oi U. Y fd, ~ , , , l6 C N: ~' p p ' N~ ~~ f0~ ~ , , N y, y. 3~ C. ' ~ ' ~~ ~~ , ~ `, C O' 8' y. p, N~ f C. Y. ~, p, , . , ~ O a, ' -, 7 ~: m, p, 7 w, , , a . I y, ~: >~ y, N J! , , . . T N' C' tp U a to ~ ~ L L ~ -°~ L ~ , N. d. >~ y, • C ~ L, ~ U N, D; a !~ U O U N, U, ~ ~ L, p fp: C~ ~: ~ ~.! ~: o. L: -, a~ a~ a~ , C• ~~ y. ~~ a;~ a>~ m, ~~ o~ , _ f6• ~ . +• ~ ~~ c~ c~ c, ~ a;, ~3~ ~ y ~ ° ~~ ~. ~~ ~ . ~~ -, N ~ >+, °, ~ ~, ~, o, ~ ~ c~, ~ w' m ~' c w ' ~ ' ° $ 0 0 0, : N o c, ~ ~ ~, ~, ~3 ° ~ a, ~, r: o vi °- ; N ~ Q ~ ~ 2'r ~ a~ E' ~0 '°~ a~ ~ ° -° > ~' o ~ •E; •E, o. -, ~ °: °o a' m' N ~; F- •~' ~ ~'' ~ d; Y' '~ ~' v °' ?~ ~ d ~ ~ ~ c :° J m ~ m N - - `°' 'c o' °~' m ~' a Q: 4 a~ m ~; y: 3. o, o o; ~' ~; ~, ~' m' v. ~ . . a, ~, '- O O. z; °' ~ ° ' . , . ~ m. m. a~ a~, o. T c , a ° w ~; cn _ O J ~: s' ~' , z a; a; U ~; ¢; a O U <n U U U, v a, - a -, o, m; m, c.~, ~ -, ~ a, o, ~, ~, v, U W ~ V ~ , ~ , , , , , N M a to (O f~ a0 01 , , , , O ~ N M V' ~ O n ~ , , . , ( GO W O N ~ N N N . M I YY N N N (O t~ 00 O O N M er N N N N M M M M M ~ f0 ~ OD W M M M M M U ~ _ _ co ° ~ co ° 0 o o m ~ ~ a~ o a; rn ~ °~ c G rn ~ p o N p W,; ° R ~ c • ~ n J 0. N y I T W 0 C ~ L C ~ Q O ~ a a Q~ 1L Q ?' ~ Q~ ,.N. U .Q 3 a rn° c c 0 ~ '~ c N c E WV ~: ~ m O a`> U = O O y C7 E U U • • Well History File APPENDIX Information of detailed nature that is not pariiculariy 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 io chronologically organize this category of information. C06BO08262006ssN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jun 08 11:49:10 2007 Reel Header Service name .............LISTPE Date . ...................07/06/08 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................07/06/08 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing scientific Technical services Library. Scientific Technical services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: C-06B API NUMBER: 500292012702 OPERATOR: B. P. Explorati on (Alaska) Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 08-JUN-07 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: w-0004558964 w-0004558964 w-0004558964 LOGGING ENGINEER: B. JAHN B. JAHN B. JAHN OPERATOR WITNESS: B. LAULE / R B. LAULE / R B. LAULE / R MWD RUN 4 MWD RUN 5 MWD RUN 6 JOB NUMBER: W-0004558964 W-0004558964 W-0004558964 LOGGING ENGINEER: B. JAHN B. JAHN B. JAHN OPERATOR WITNESS: B. LAULE / R B. LAULE / R B. LAULE / R MWD RUN 7 MWD RUN 9 MAD RUN 10 JOB NUMBER: w-0004558964 w-0004558964 w-0004558964 LOGGING ENGINEER: S. LATZ S. LATZ S. LATZ OPERATOR WITNESS: R. BORDES / R. BORDES / R. BORDES / SURFACE LOCATION SECTION: 19 Page 1 ~CSCo -`lb~ ~ r ~ay3 • TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD C066o08262006SSN.txt 11 14 1866 879 55.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 4.125 4.500 9730.0 2ND STRING 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 - SUBSEA (TVDSS). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK IN THE C-06 WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 9730'MD/8351'TVDSS.THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT-HOLE WAS DRILLED PRIOR TO MWD RUN 1. 4. MWD RUNS 1-4 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG), UTILIZING SCINTILLATION DETECTORS. UPHOLE SGRD TIE-IN DATA WERE MERGED WITH MWD DATA FROM RUN 1. 5. MWD RUNS 5-10 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). A FINAL MAD PASS (MWD RUN 10) WAS ACQUIRED OVER THE INTERVAL 12100'MD - 10720'MD (BIT DEPTHS) AFTER REACHING TD. A SEPARATE MAD PASS PRESENTATION IS INCLUDED. NO PROGRESS WAS MADE ON MWD RUN 8 DUE TO A TOOL FAILURE. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN C-06B ON 27 AUGUST 2006. THESE DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 19 APRIL 2007. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 7. MWD RUNS 1-7,9,10 REPRESENT WELL C-06B WITH API#: 50-029-20127-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12100'MD/8957'TVDSS. Page 2 c066o08262006ssN.txt SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED TOOL RUNNING SPEED WHEN NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED NATURAL GAMMA RAY. 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. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP RPM FET RPD RPS RPX 1 clipped curves; all bit runs merged. .5000 START DEPTH 9712.0 9748.5 10416.0 10416.0 10416.0 10416.0 10416.0 STOP DEPTH 12055.5 12100.5 12070.0 12070.0 12070.0 12070.0 12070.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 9712.0 9714.5 9713.0 9715.5 9719.5 9722.0 9721.0 9723.5 9736.5 9738.5 9750.5 9752.5 9753.5 9755.5 9763.0 9765.0 9764.5 9766.5 9773.0 9774.5 9777.0 9778.0 9780.0 9781.5 9786.0 9787.5 9789.0 9790.5 9797.0 9799.0 Page 3 9803.0 9808.5 9819.5 9827.0 9830.0 9833.0 9836.0 9866.5 9872.5 9875.0 9877.5 9882.0 9886.0 9903.0 9913.0 9932.0 9936.5 9944.0 9968.5 9970.0 9983.5 10000.0 10003.5 10016.0 10019.0 10022.5 10023.5 10025.5 10044.5 10055.0 10064.5 10130.0 10168.0 10178.5 10193.0 10202.0 10214.0 10222.0 10231.5 10251.5 10264.5 10273.0 10276.0 10281.0 10285.0 10316.5 10338.0 10497.5 10559.5 10562.5 10565.0 10571.5 10660.5 10673.0 10751.5 10758.0 10794.0 10795.5 10801.0 10818.0 10825.5 10835.0 10840.0 9805.0 9809.5 9820.5 9828.5 9831.0 9834.0 9837.0 9867.5 9874.0 9876.0 9878.5 9883.0 9887.0 9904.0 9913.5 9932.0 9937.0 9945.5 9970.0 9971.5 9984.5 10001.0 10004.5 10016.5 10020.0 10023.0 10024.5 10026.5 10045.0 10056.0 10066.0 10130.0 10168.0 10179.0 10193.5 10202.0 10215.0 10223.5 10232.0 10252.5 10265.0 10274.0 10277.0 10282.0 10286.0 10317.5 10340.0 10499.5 10561.0 10564.0 10567.0 10572.0 10661.5 10674.5 10752.0 10761.5 10799.0 10800.5 10806.0 10821.5 10828.5 10838.5 10843.5 C066o0826200655N.txt Page 4 • 10847.5 10876.0 10886.5 10894.5 10903.0 10912.5 10993.5 11016.5 11023.5 11069.5 11165.5 11226.5 11281.0 11469.0 11492.5 11497.0 11533.0 11536.5 11551.5 11566.5 11573.5 11577.0 11597.0 11601.5 11634.0 11661.5 11802.0 11805.5 11834.5 11847.0 11890.5 11895.5 11919.0 11926.5 11939.5 11953.5 11966.0 11970.5 11973.5 $2100.5 10851.0 10878.5 10889.0 10895.5 10904.5 10914.0 10993.5 11017.0 11024.0 11070.0 11165.5 11227.5 11282.0 11472.5 11496.0 11500.0 11534.5 11540.0 11555.0 11570.0 11578.5 11583.0 11604.5 11608.5 11639.0 11666.5 11807.0 11811.5 11840.0 11852.5 11894.0 11897.5 11921.0 11928.5 11942.0 11954.5 11967.5 11971.0 11973.0 12100.0 C0660082620065SN.txt MERGED PBU MWD MWD MWD MWD MWD MWD MWD MWD REMARKS DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP MERGE BASE 1 9714.5 10047.0 2 10047.0 10092.5 3 10092.5 10135.0 4 10135.0 10447.0 5 10447.0 10647.0 6 10647.0 10825.0 7 10825.0 11255.0 9 11255.0 12100.5 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 Page 5 ~ ~ C06BO0826200655N.txt Frame Spacing.. ..... .... ........60 .lIN Max fr ames per record ..... .. ......undefined Absent value ... ........... .. ......-999 Depth Units. .. . . ..... Datum specifica tion Block sub-type...0 Name serv ice order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Serv ice Unit Min Max Mean Nsam Reading Reading DEPT FT 9712 12100.5 10906.3 4778 9712 12100.5 RPD MWD OHMM 6.71 57.68 16.5554 3309 10416 12070 RPM MWD OHMM 3.96 43 14.4189 3309 10416 12070 RPS MWD OHMM 3.82 57.83 13.8441 3309 10416 12070 RPX MWD OHMM 3.05 905.94 16.8986 3309 10416 12070 FET MWD HOUR 0.2 22.26 2.05792 3309 10416 12070 GR MWD API 13.75 881.44 42.1929 4688 9712 12055.5 ROP MWD FT/H 0.06 1233.56 66.407 4705 9748.5 12100.5 First Reading For Entire File..........9712 Last Reading For Entire File...........12100.5 File Trailer Service name... .......STSLIB.OOi Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type ................L0 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.......07/06/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 Page 6 ~I FILE SUMMARY PBU TOOL CODE GR RPS RPX FET RPM RPD RAT MERGED DATA PBU TOOL MWD REMARKS: C06BO08262006SSN.txt A START DEPTH STOP DEPTH 10680.0 12062.5 10687.5 12077.0 10687.5 12077.0 10687.5 12077.0 10687.5 12077.0 10687.5 12077.0 10721.0 12100.5 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 10 1 10681.5 12100.0 SOURCE CODE MERGED MAD 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 .lIN 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 MAD OHMM 4 1 68 4 2 RPM MAD OHMM 4 1 68 8 3 RPS MAD OHMM 4 1 68 12 4 RPX MAD OHMM 4 1 68 16 5 FET MAD HOUR 4 1 68 20 6 GR MAD API 4 1 68 24 7 RAT MAD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10680 12100.5 11390.3 2842 10680 12100.5 RPD MAD OHMM 4.03 1342.18 17.3569 2780 10687.5 12077 RPM MAD OHMM 2.03 2000 16.7812 2780 10687.5 12077 RPS MAD OHMM 1.62 499.76 13.495 2780 10687.5 12077 RPX MAD OHMM 1.36 2000 21.7107 2780 10687.5 12077 FET MAD HOUR 15.48 97.81 49.3078 2780 10687.5 12077 GR MAD API 11.27 196.85 38.3374 2766 10680 12062.5. RAT MAD FT/H 609 2416 877.916 2760 10721 12100.5 First Reading For Entire File..........10680 Last Reading For Entire File...........12100.5 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number...........1.0.0 Page 7 C066o0826200655N.txt Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type. .LO Next File Name.........,.5T5LIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9714.5 ROP 9750.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10017.0 10047.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) Page 8 header data for each bit run in separate files. 1 .5000 3 19-AUG-06 Incite 7.75 Memory 10047.0 9748.0 10047.0 14.5 27.9 TOOL NUMBER TL0002 4.125 9730.0 Polymer 8.60 60.0 9.1 27000 5.8 C066008262006SSN.txt MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 141.7 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 Loging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN 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 MWDO10 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9714.5 10047 9880.75 666 9714.5 10047 GR MWDO10 API 20.79 881.44 89.3254 606 9714.5 10017 ROP MWDO10 FT/H 0.06 118.2 30.496 594 9750.5 10047 First Reading For Entire File..........9714.5 Last Reading For Entire File...........10047 File Trailer service name... .......sTSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/08 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 Page 9 • C066o0826200655N.txt Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10017.5 10063.0 ROP 10047.5 10092.5 LOG HEADER DATA DATE LOGGED: 19-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10092.0 TOP LOG INTERVAL (FT): 10047.0 BOTTOM LOG INTERVAL (FT): 10092.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 27,3 MAXIMUM ANGLE: 30.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER $CG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 9730.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 60.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 27000 FLUID LO55 (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATU RE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMP ERATURE: .000 141.7 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Page 10 ~ ~ C06BO08262006S5N.txt REMARKS: Data Format specification Record Data Record Type... ........,.0 Data Specification Block Type.....0 Loging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN 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 MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10017.5 10092.5 10055 151 10017.5 10092.5 GR MWD020 API 21.57 109.77 38.0481 92 10017.5 10063 ROP MWD020 FT/H 0.2 51.13 9.98 91 10047.5 10092.5 First Reading For Entire File..........10017.5 Last Reading For Entire File...........10092.5 File Trailer Service name... .......STSLIB.004 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......07/06/08 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.......07/06/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6,004 comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 Page 11 C06B008262006SSN.txt FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10063.5 10106.0 RoP 10093.0 10135.0 LOG HEADER DATA DATE LOGGED: 20-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10135.0 TOP LOG INTERVAL (FT): 10092.0 BOTTOM LOG INTERVAL (FT): 10135.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 35.1 MAXIMUM ANGLE: 35.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 9730.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): $,70 MUD VISCOSITY (S): 60.0 MUD PH: $,6 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3): 5.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 141.7 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ....................... Page 12 ~ ~ C06B0082620065SN.txt Datum specification Block sub-type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 10063.5 10135 10099.3 144 10063.5 10135 GR MWD030 API 19.97 33.04 22.5521 86 10063.5 10106 ROP MWD030 FT/H 0.15 42.16 10.7532 85 10093 10135 First Reading For Entire File..........10063.5 Last Reading For Entire File...........10135 File Trailer Service name... .......STStI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLI6.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5L26,005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10106.5 10419.0 ROP 10135.5 10447.0 LOG HEADER DATA DATE LOGGED: 21-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10447.0 Page 13 C066o08262006SSN.txt TOP LOG INTERVAL (FT): 10135.0 BOTTOM LOG INTERVAL (FT): 10447.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 45.4 MAXIMUM ANGLE: 73.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 9730.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): $,$0 MUD VISCOSITY (S): 60.0 MUD PH: $,5 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 150.1 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 .lIN 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 MWD040 API 4 1 68 4 2 ROP MWD040 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10106.5 10447 10276.8 682 10106.5 10447 GR MWD040 API 19.33 69.41 28.8537 626 10106.5 10419 Page 14 ~ r C06BO08262006SSN.txt ROP MWD040 FT/H 1.34 54.77 27.6907 624 10135.5 First Reading For Entire File..........10106.5 Last Reading For Entire File...........10447 File Trailer Service name... .......STSLIB.006 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/08 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.007 Physical EOF File Header Service name... .......STSLI6.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 Comment Record FILE HEADER FILE NUMBER: 7 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 RPX 10418.0 10616.0 FET 10418.0 10616.0 RPM 10418.0 10616.0 RPD 10418.0 10616.0 RPS 10418.0 10616.0 GR 10419.5 10602.0 ROP 10447.5 10647.0 LOG HEADER DATA DATE LOGGED: 21-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10647.0 TOP LOG INTERVAL (FT): 10447.0 BOTTOM LOG INTERVAL (FT): 10647.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 74.6 MAXIMUM ANGLE: 76.7 TOOL STRING (TOP TO BOTTOM) Page 15 10447 C066o0826200655N.txt VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR $275$ EWR4 ELECTROMAG. RESIS. 4 218615 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 9730.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 60.0 MUD PH: 9,7 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3): $,4 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .160 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .080 149.0 MUD FILTRATE AT MT: .160 69.0 MUD CAKE AT MT: .130 69.0 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 Loging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN 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 MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MwD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MwD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10418 10647 10532.5 459 10418 10647 RPD MwD050 OHMM 13.72 40.58 20.7692 397 10418 10616 RPM MWD050 OHMM 7.68 36.24 16.6769 397 10418 10616 RPS MWD050 OHMM 5.53 31.21 13.8714 397 10418 10616 Page 16 C066o0826200655N.txt RPX MWDO50 OHMM 3.77 22.89 9.84662 397 10418 10616 FET MWD050 HOUR 1.05 11.04 2.95232 397 10418 10616 GR MWD050 API 18.38 54.25 23.8353 366 10419.5 10602 ROP MWD050 FT/H 1.42 107.91 26.6095 400 10447.5 10647 First Reading For Entire File..........10418 Last Reading For Entire File...........10647 File Trailer service name... .......sTSLI6.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.008 Physical EOF File Header Service name... .......STSLIB.008 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10602.5 10780.5 RPx 10616.5 10795.0 RPD 10616.5 10795.0 FET 10616.5 10795.0 RPS 10616.5 10795.0 RPM 10616.5 10795.0 OP 10647.5 10825.0 $ LOG HEADER DATA DATE LOGGED: 22-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10825.0 TOP LOG INTERVAL (FT): 10647.0 BOTTOM LOG INTERVAL (FT): 10825.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.1 Page 17 • C066o08262006SSN.txt MAXIMUM ANGLE: 79.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 EWR4 ELECTROMAG. RESIS. 4 218615 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 9730.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 60.0 MUD PH: $.$ MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3): 6.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .160 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .080 149.0 MUD FILTRATE AT MT: .160 69.0 MUD CAKE AT MT: .130 69.0 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 Loggin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN 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 MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MwD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MwD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10602.5 10825 10713.8 446 10602.5 10825 Page 18 i C066008262006SSN.txt RPD MWD060 OHMM 7.26 20.26 11.0196 358 10616.5 10795 RPM MWD060 OHMM 4.63 21.47 9.3619 358 10616.5 10795 RPS MWD060 OHMM 3.82 19.82 8.36712 358 10616.5 10795 RPX MWD060 OHMM 3.05 17.17 7.-01534 358 10616.5 10795 FET MWD060 HOUR 0.71 10.17 3.70441 358 10616.5 10795 GR MWD060 API 17.54 255.94 40.8135 357 10602.5 10780.5 ROP MWD060 FT/H 0.19 117.2 25.8733 356 10647.5 10825 First Reading For Entire File..........10602.5 Last Reading For Entire File...........10825 File Trailer service name... .......sTSLIB.008 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.009 Physical EOF File Header service name... .......sTSLI6.009 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLIB.008 comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY .5000 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10781.0 11210.5 FET 10795.5 11225.0 RPx 10795.5 11225.0 RPS 10795.5 11225.0 RPD 10795.5 11225.0 RPM 10795.5 11225.0 ROP 10825.5 11255.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): header data for each bit run in separate files. 7 23-AUG-06 Incite 4.3 Memory 11255.0 10825.0 11255.0 Page 19 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 r~ LJ C06600826200655N.txt BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 84.7 92.8 TOOL NUMBER 82758 218615 4.125 9730.0 Polymer 8.70 60.0 8.6 27000 5.4 .100 69.0 .050 156.0 .140 69.0 .120 69.0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MwD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 Page 20 • • C06B008262006SSN.txt First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10781 11255 11018 949 10781 11255 RPD MWD070 OHMM 9.26 28.51 13.516 860 10795.5 11225 RPM MWD070 OHMM 6.97 31.58 12.6052 860 10795.5 11225 RPS MWD070 OHMM 6.59 39.04 11.9795 860 10795.5 11225 RPX MWD070 OHMM 6.3 29.73 11.6053 860 10795.5 11225 FET MwD070 HOUR 0.23 12.48 1.5226 860 10795.5 11225 GR MWD070 API 17.64 159.26 42.2945 860 10781 11210.5 ROP MWD070 FT/H 0.58 972.02 106.673 860 10825.5 11255 First Reading For Entire File..........10781 Last Reading For Entire File...........11255 File Trailer Service name... .......STSLI6.009 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.010 Physical EOF File Header Service name... .......STSLIB.O10 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.009 comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11211.0 12055.0 RPS 11225.5 12069.5 FET 11225.5 12069.5 RPD 11225.5 12069.5 RPx 11225.5 12069.5 RPM 11225.5 12069.5 OP 11255.5 12100.5 $ LOG HEADER DATA DATE LOGGED: 25-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory Page 21 • • C06BO08262006SSN.txt TD DRILLER (FT): 12100.0 TOP LOG INTERVAL (FT): 11255.0 BOTTOM LOG INTERVAL (FT): 12100.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.5 MAXIMUM ANGLE: 93.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 72829 EWR4 ELECTROMAG. RESIS. 4 218615 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 3.750 9730.0 Polymer 8.60 60.0 8.5 28000 8.2 .100 69.0 .040 164.8 .140 69.0 .150 69.0 Name Service order units Size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD090 OHMM 4 1 68 4 2 RPM MWD090 OHMM 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MwD090 OHMM 4 1 68 16 5 FET MWD090 HOUR 4 1 68 20 6 GR MwD090 API 4 1 68 24 7 ROP MWD090 FT/H 4 1 68 28 8 Page 22 C06BO0826200655N.txt First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 11211 12100.5 11655.8 1780 11211 12100.5 RPD MWD090 OHMM 6.71 57.68 18.2703 1689 11225.5 12069.5 RPM MWD090 OHMM 3.96 43 15.8881 1689 11225.5 12069.5 RPS MWD090 OHMM 3.95 57.83 15.9609 1689 11225.5 12069.5 RPX MWD090 OHMM 3.38 905.94 23.487 1689 11225.5 12069.5 FET MWD090 HOUR 0.2 22.26 1.77163 1689 11225.5 12069.5 GR MWD090 API 13.75 110.5 35.7931 1689 11211 12055 ROP MWD090 FT/H 0.45 1233.56 96.4564 1691 11255.5 12100.5 First Reading For Entire File..........11211 Last Reading For Entire File...........12100.5 File Trailer Service name... .......STSLIB.O10 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.011 Physical EOF File Header Service name... .......STSLIB.O11 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MAD Curves and log header data DEPTH INCREMENT: .5000 MAD RUN NUMBER: 10 MAD PASS NUMBER: 1 FILE SUMMARY for each pass of each run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10681.5 12062.0 RPD 10689.0 12076.5 RPM 10689.0 12076.5 RPx 10689.0 12076.5 RPS 10689.0 12076.5 FET 10689.0 12076.5 RAT 10722.0 12100.0 LOG HEADER DATA DATE LOGGED: Page 23 26-AUG-06 • C066o0826200655N.txt SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Insite 4.3 Memory 12100.0 10720.0 12100.0 77.3 92.8 TOOL NUMBER 72829 218615 3.750 9730.0 Polymer 9.20 60.0 9.0 79000 8.8 .060 65.0 .030 165.0 .080 65.0 .070 65.0 Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MAD101 OHMM 4 1 68 4 2 RPM MAD101 OHMM 4 1 68 8 3 RPS MAD101 OHMM 4 1 68 12 4 Page 24 • C066o08262006S5N.txt RPX MAD101 OHMM 4 1 68 16 5 FET MAD101 HOUR 4 1 68 20 6 GR MAD101 API 4 1 68 24 7 RAT MAD101 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10681.5 12100 11390.8 2838 10681.5 12100 RPD MAD101 OHMM 4.03 1342.18 17.3617 2776 10689 12076.5 RPM MAD101 OHMM 2.03 2000 16.8 2776 10689 12076.5 RPS MAD101 OHMM 1.62 499.76 13.5193 2776 10689 12076.5 RPX MAD101 OHMM 1.36 2000 21.7402 2776 10689 12076.5 FET MAD101 HOUR 15.48 97.81 49.4054 2776 10689 12076.5 GR MAD101 API 11.27 196.85 38.4439 2762 10681.5 12062 RAT MAD101 FT/H 609 2416 878.178 2757 10722 12100 First Reading For Entire File..........10681.5 Last Reading For Entire File...........12100 File Trailer Service name... .......STSLIB.O11 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/08 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.012 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/06/08 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................07/06/08 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services writing Library. scientific Technical services Physical EOF Physical EOF Page 25 • C066008262006SSN.txt End Of LIS File Page 26