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Development Exploratory Service 5 Permit to Drill Number:208-121 6.50-029-20737-03-00 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 10861 10774 9023 8516 Unknown None 8293 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 31 - 111 31 - 111 1490 470 Surface 2646 13-3/8" 30 - 2676 30 - 2676 4930 2670 Intermediate 4184 9-5/8" 27 - 4211 27 - 4210 6870 4760 Production 5048 7" 3691 - 8739 3691 - 8505 7240 5410 Perforation Depth: Measured depth: 8746 - 10760 feet True vertical depth:8512 - 9023 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 25 - 8593 25 - 8366 8516 8293Packers and SSSV (type, measured and true vertical depth) Liner 2277 4-1/2" 8583 - 10860 8356 - 9025 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 4296501161 72015959 550 10500 368 471 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: Noel Nocas Noel.Nocas@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5278 Treatment descriptions including volumes used and final pressure: 13. Sr. Area 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 measured9025 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Mill CIBP 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 0028285 PBU D-22C 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 4-1/2" Baker S3 Packer By Samantha Carlisle at 9:55 am, Jun 09, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.08 16:38:17 -08'00' Stan Golis (880) MGR28JUL2021 RBDMS HEW 6/9/2021 SFD 6/18/2021DSR-6/9/21 ACTIVITY DATE SUMMARY 5/26/2021 CTU6 1.75" CT Job Scope: Mill CIBP MIRU CTU6. Completed weekly BOP testing. Make up TBird Milling BHA. Bullhead 3 bbls MEOH followed by 140 bbls of 2% slick SKI w/Safelube down 13CR tubing. ***Job in Progress*** 5/27/2021 CTU6 1.75" CT Job Scope: Mill CIBP RIH w/TBird MHA & Milling BHA = 3.70" 5 - bladed junk mill. Dry tag 4.5" WFD CIBP @ 9,258' ctm. Mill WFD CIBP, push debris to restriction at 9,326' ctm. Stalled mill on restriction multiple times. Pooh w/BHA, Pump 100bbls of diesel down well to underbalance for pop. RDMO CTU6. ***Job Complete*** 6/1/2021 ***WELL S/I UPON ARRIVAL*** (mill / underream) SET 4-1/2" WHIDDON CATCHER SUB ON XN-NIPPLE @ 8581' MD. PULLED BK-DGLV FROM ST#1 @ 6435' MD. PULLED RK-DGLV FROM ST#2 @ 3595' MD. SET RK-LGLV(16/64",1500#) IN ST#2 @ 3595' MD. SET BK-OGLV(20/64") IN ST#1 @ 6435' MD. PULLED 4-1/2" WHIDDON CATCHER SUB FROM XN-NIPPLE @ 8581' MD.(empty) SET 4 1/2" DREAM CATCHER IN X-NIPPLE @ 8,443' MD (verified w/ check set) ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** Daily Report of Well Operations PBU D-22C RECEIVED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION CO ION REPORT OF SUNDRY WELL OPERATIONS APR 1 6 2018 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operation :* ".. Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set CIBP,Perf OI, 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 208-121 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20737-03-00 7. Property Designation(Lease Number): ADL 028285 8. Well Name and Number: PBU D-22C 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 10861 feet Plugs measured 9260 feet true vertical 9025 feet Junk measured None feet Effective Depth: measured 9260 feet Packer measured 8516 feet true vertical 8905 feet Packer true vertical 8292 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 31-111 31-111 1490 470 Surface 2646 13-3/8" 30-2676 30-2676 5380 2670 Intermediate 2061 9-5/8" 28-2089 28-2089 6870 4760 Liner 5048 7" 3691 -8739 3691-8505 7240 5410 Liner 2277 4-1/2" 8586-10860 8356-9025 8430 7500 Perforation Depth: Measured depth: 8746-10760 feet True vertical depth: 8512-9023 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 25-8593 25-8366 — Packers and SSSV(type,measured and 4-1/2"BKR S-3 Packer 8516 8292 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED F i -:_ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 554 43093 504 640 1206 Subsequent to operation: 111 1606 4 340 717 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Travis Alatalo Contact Name: Travis Alatalo Authorized Title: ^Production Engineer Contact Email: Travis.Alatalot bp.com Authorized Signature: '/rzi !�f-t -� 1 Date: -'t /t.t `L2 Contact Phone: +1 907 564 5351 Form 10-404 Revised 04/2017 </rL -1127--PS' R,BDMSK 8il 7018 �, el �{i'j� 1 U Submit Original Only • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary April 12, 2018 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for the setting of a Cast Iron Bridge Plug (CIBP) and the addition of perforations for well D-22C, PTD #208-121. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (AIaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 0 • L N N r7 -a N ±- c II 0 o Q a co O N Ta 0 J co d N 0 II 0 cu II W < H E O U) 0 H tu d Q _, ui �. N a, Q LL Y -t 0- z N osa < M O cc M CO w 3 c w0 O V 4c cc a m cea mli c=nz w E ` Qa co Lb N u") 0o Qo z Q d 2 * m pm � m Q. U n zv I- D co OOL aOVH * _ a) _ O _IW * Q H M N o 0 11 LT- CD GD W _ia � o CJ0 UH coo 14- 7-1 co O n wmO = c • a) cew °ro — Q U) H u CO m w 0 _ c < 2 N a H —' < ° O. a c cc � ww col— a Ou) 0i1 < d "� 0 o O re * � ml's ca 255 Hu.ir A > - mZp ii 0 cc - 7, N. � 0z '- 0 - CO_ Q O N Z 0 Q' O > uWjF_ mCOW O J (DO W Fit Qw aM � = O CcDzNLLIf� 0 Ww O II mZo 0 � X00 OZa OHZo 0o xu)W U 0 -JHQOpaMON < o C9 7-7. U) _1 -1> co WQOJOmcII v °—Ca U_ 0 _i � 0 0 a) ~ ce ? O - > ? = m W = " J W> ? p ? t TREE= CIW WELLHEAD= M3=VOY NOTES: '•°4-112"CHROME TBG& ACTUATOR= MKB C D_2 2 D NIPPLES"'WELL ANGLE>70°@ 9348"""ORIG OKB t3EV 785' WELL,D-22A,D-22B&D-22C NOT SHOWN BEI. BF R.EV / I 4 I i I WHIPSTOCK""* Max Angle_ _ 92" t, 1013T 1 1 •'4 421T 4 �'� tum MD- 9196 40 207T 9-5/8'HES ESC ENTER Datum TVD= 8800'SS 41 14� I I 2188' -14-112'HES X NP,D=3.813" 9-5/8"CSG,47#,L-80 BTC,D=8.681' H 2089' GAS LFT MANDRELS 13-3/8"CSG,72#,L-80, D=12.347' - 2684' ST MD TVD DEV TYPE VLV LATCH FORT DATE • 2 3595 3595 0 MMG1 DOME RK ' 16 09/02/08 1 6435 6338 19 KBG2-1, SO BK r 20 09/02/08 Minimum ID =—2.9" @ 9314' 4-1/2" ID RESTRICTION 3691* H9-5/8"x 7"ZxP LW w inE13ACK SIV,0=6. 90" Ft ga t 3709' -I9-5/8"X 7"BKR FLEXLOCK UR HGR,D=6.320' 9-5/8'VYFPSTOCK(08/10/08) H 4211' (*CLOUT WINDOW(D-22C) 4211'-4227' 9-5/8"CSG,47#,L-80,13=8.681" --I 8745' 8¢43' 41/2'HES X NP D=3.813' PEFFORATgN SUMMARY 8516' H 7"X 41/2"BM S-3 PKR,D=3.870' REF LOG: 777 \i ANGLE AT TCW PERF: 17'fp 8746' irk111 Note:Refer to Production DB for historical perf data 8550` -4-1/2"HES XIV,D=3.813" SIZE SPF NTB?fAL Opn/Sgz SHOT SOZ 2-1/2- 6 8746-8771 0 03/17/18 8581' H4-1/2"HES XN NP,D=3.725' 2-7/8" 6 9820-9920 C 08/21/08 2-7/8" 6 9940-10030 C 08/21/088583' E---r X 5' fit ZXP LIP w/ 2-7/8" 6 10060-10310 C 08/21/08TRK SLV,D=4.460' 2-7/8" 6 10340-10760 C 08/21/08 ;- \ 8593' H4-1/2 VVLEG,D=3.958 8600' 17"X 5" BKR HMC LNR • y HGR,D=4450" 41/2'TBG,12.6#,13-CR YAM TOP,.0152 bpf,13=3.958' H 8593' 8610' —15'X 4-1/2"XO,13=3.930' I T LNR,26#,L-80 BTC-M,.0383 bpf,D=6.276" - 8739' , 9314' -D RESTRICTION-2.9'D X 2' LONG.SL TAGGED 1 13. —7/4 LIABLE TO BASS w .5"OD, 4-1/2"WFD CEBP(03/17/18)H 9280' ♦ 2.7"WAS ABLE TO F LL ♦• 11-RU.Vow ♦ SLB FPROF/GHOST/ MD 10774' +444ik ON 12/07/13 4444 14:4,' 4-1/2"LNR,12.6#,L-80.0152 bpf,D=3.958" H 10860' - _ t DATE REV BY COMMENTS DATE REV BY CONSENTS PRUDHOE BAY UGIT 01/11/83 ORIGINAL COMPLETION 05/17/10 EV/JM) DRLG DRAFT CORRECTIONS VNI3L: D-220 12/03/97 PARKER SIDETRACK(D.22A) 12/11/13 JCT/JM) D RESTRICTION(12/07/13) F IT No:' 81210 06/14102 JOMIKAK I6G SIDETRACK(D.22B) 03/19/18 MS/JM) ADPERFS&SET CBP AR No: 50-029-20737-03-00 08/23/08 N7ES RIG SIDETRACK(D-22C) SEC 23,T11N,R13E 1550'FNL&1692'FE. 10/13/08 TLWPJC VS PSTOCK DB'TH CORRECTION 10/13/08 KJB/PJC GLV C/O(09102/08) BP Exploration(Alaska) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q~ - ~~, ~ Well History File Identifier Or anizin (done} ^ Two-sided III IIIIIIIIIII VIII ^ Rescan Needed III II~IIIIIII (VIII 9- 9 R SCAN DIG AL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. I ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: /s/ Pro'ectProofing III IIIIIIIIIII VIII J BY: Maria Date: 3 /s/ Scannin Pre aration ~ x 30 = ~ + ~ =TOTAL PAGES ~~ (Count does not include cover sheet),, n g YI/I BY: Maria Date: 3 /~, /~~ /s! Production Scanning Stage 1 BY: Stage 1 BY: Page Count from Scanned File: ~~ (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO Maria Date: 3 /D /s/ r~~ /' If NO in stage 1, page(s) discrepancies were found: YES NO Maria Date: /s/............ Scanning is complete at this point unless rescanning is required. ReScanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II~III III II') III 10/6/2005 Well History File Cover Page doc 03/24/11 Schkraberp NO. 5709 Alaska Data & Consulting Services Company: State of Alaska 2525 GambaN Street, Sege 400 Alaska Oil & Gas Cons Comm Anchorage, AK 55803 - 2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job N Log Description Date BL Color CD 01 -20 BBSK -00054 PRODUCTION PROFILE / P St 03104111 1 nsraa 1 ' 09-46 BMSA -00006 PRODUCTION PROFILE J ^ a J 3 03/01/11 ' 1 ,; 33 1 _ 14-05A BBKA -00090 PRODUC • PROFILE r. 03/12111 1 1 12-30 BBSK -00055 LDL k-YT ®L'M 1a Sr3:c..' 1 D-22C ;, .. , . T . T� rtm �` it / /p!7 0 _7�:ST 1 1 09-02 BBSK -00052 PRODUCTION PROFILE acrd nil 77... "kit 1 09 -41 BBSK-00053 PRODUCTION PROFILE_ "(i lift ` • _ r 1 15 -05A BCRD -00094 SCMT . I' 02/13/11 , -f 1 1 Ia H -1S BCRD-00063 USIT , — •7 ~ 02/11111 IaSr .ir 1 1 F -35 BG4H -00037 PRODUCTION • - • ILE ~ r 02/22/11 1 1 1 Z -31 BJOII -00009 INJECTION PROFILE $1 ,, J -• I a 02/12/11 1 _ 1 e' 4 � 1 06-16 BCRD -00090 PRODUCTION PROFILE j '� 1 3 03107/11 1 1 X -17 BJOH -00006 RST /if i...411 02/11/11 1 H -20 BBSK -00051 RST .* -* 02/13/11 1 : I . : , 1 06-20A BNWP -00003 RST }(DS •-• 02/17/11 1 • 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: - BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 2525 Gambalt Street, Suite 400 900 5. Benson Blvd. Anchorage, AK 99503 -2838 r • ?, rt._. • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 March 06, 2011 g f � C� A� MAR I �(�i'�� ee Mr. Tom Maunder EIV Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 1 Anchorage, Alaska 99501 0i� : G one �'3�SiiD/1 Subject: Corrosion Inhibitor Treatments of GPB D Pad ilrichortativ Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D 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, Jerry 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) Date: 03/04/11 Corrosion • Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement pumped cement date inhibitor sealant date ft bbls ft na gal D -01A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 D -05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 D -07B 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 D -08A 2021230 50029203720100 NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 0-10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 0-11 B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 0-12 1800150 50029204430000 NA 1.3 NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 D -14A 1961530 50029204500100 NA 0.2 NA 0.85 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 • D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 D -17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -198 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 D -20 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 0-21 1820520 50029207880000 NA 0.2 NA 3.40 2/10/2011 D -22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 D -24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 D -27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 0-29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 D -30B 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D -31A 1960950 50029226720100 NA 3.3 NA 27.20 1/19/2011 D -33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 DATA SUBMITTAL COMPLIANCE REPORT 2/2212010 Permit to Drill 2081210 Well Name/No. PRUDHOE BAY UNIT. D-22C Operator BP EXPLORATION (ALASF(~ INC API No. 50-029-20737-03-00 MD 10861 TVD 9025 Completion Date 8/22/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION .. Mud Log No Samples No Directional Survey Yes DATA INFORMATIDN Types Electric or Other Logs Run: MWD DIR / GR / PWD, MWD DIR / GR /RES, MWD DIR / GR /RES / (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type mearrrm[ rvumcer Name ~caie meaia No Start Stop CH Received Comments og Ce ment Evaluation 5 Col 3702 8526 Case 9/26/2008 USIT, CEL, GR, CCL 20- / ~eq 4'i ,/ Aug-2008 ED , C Pds 3696- Cement Evaluation 3702 8526 Case 9/26/2008 USIT, CEL, GR, CCL 20- Aug-2008 ED D Asc Directional Survey 0 10861 Open 8/27/2008 pt, Directional Survey 0 10861 Open 8/27/2008 i ~'b/ C Lis / 17178~Induction/Resistivity 4150 10863 Open 11/17/2008 LIS Veri, GR, FET, ROP, ~ RPX, RPS, RPM, RPD, DRHO og 17178 Induction/Resistivity 5 Blu 0 10861 Open 11/17/2008 TVD Vision Service 19- Aug-2008 Log 17178 Induction/Resistivity 2 Blu 0 10861 Open 11/17/2008 MD Vision Service 19-Aug- 2008 JVell Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments !I DATA SUBMITTAL COMPLIANCE REPORT 2/22/2010 Permit to Drill 2081210 Well Name/No. PRUDHOE BAY UNIT D-22C MD 10861 TVD 9025 ADDITIONAL INFORMATION Well Cored? Y~` Chips Received? ~-~-' Analysis ~F-FIB Received? Completion Date 8/22/2008 Operator BP EXPLORATION (ALASKEy INC Completion Status 1-OIL Current Status 1-OIL Daily History Received? ~ N Formation Tops ~ N API No. 50-029-20737-03-00 UIC N Comments: Compliance Reviewed By: ___. ~"'~ Date: ~~ r~~ o~ L (j Page 1 of 1 Saltmarsh, Arthur C (DOA) ~j From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Thursday, October 23, 2008 2:16 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU D-22C, PTD # 208-121 - Hi Art, Please reference the following well: Well Name: PBU D-22C Permit #: 208-121 API #: 50-029-20737-03-00 Top Perf MD: 9820' Bottom PerF D: 10760' This well began Production on October 13, 2008 Method of Operations is: Flowing Date of Test: 10/14/08 Hours Tested: 6 24-Hour Rate /Oil-Bbl: 3,213 24-Hour Rate /Gas-Mcf: 25,619 24-Hour Rate /Water-Bbl: 340 Test Rate 1 Oil-Bbl: 803 Test Rate 1 Gas-Mcf: 6,405 Test Rate !Water-Bbl: 85 Choke Size: 94 Gas-Oil Ration: 7,974 Flow Tubing Pressure: 800 Casing Pressure: 650 Oil Gravity-API: Unavailable 10/23/2008 ~~ 4~' ~{i~1~111I~G1~~~~ N0.4903 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth .333 West 7th Ave, Suite 100 Anchorage, AK 99501 t~ lU Well _Inh ~ 1 n.. 09/23/08 L-216 10687773 MDT - _ 05/09/04 _ 1~ 1 L-204 11212880 MDT 07/24/06 1 1 14-22A 11999036 PPROF W/FLOW SCAN IMAGER - / '~(p 08/17/08 1 1 H-11 12017507 USIT - 08!09/08 1 1 D-22C 11963190 USIT '~ ~ ~ (~ '7 08/20/08 1 1 NK-10 12066549 MEM I JECTION PROFILE C) - / J g'~ 09/11/08 1 1 09-28A 12031499 RST - 9 08/01/08 1 1 N-10A 12005225 MCNL 08/20/08 1 1 05-23B 40016995 OH MWD/LWD EDIT , 05/27/08 2 1 ~~.-..+~ .+v.".v..ccrr mac ncvor ~ o. a~w~n~aa raw nG I lJnrvnYl7 VIYC ~.VF'T CNl. r7 1 V: 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 99503-283 ATTN: Beth Received by: ~ ~" . Page 1 of 2 Regg, James B (DOA) From: DeRuyter, Thomas R (DEC) ~~~ ( ~ Sent: Friday, September 26, 2008 8:26 AM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; Daniel, Ryan; Engel, Harry R; GPB, Environ Advisor (Services); GPB, Environ Advisor West; Klein, Carol A (ATS); Fletcher, Bill D; Nleggert, Edward E (DEC); DeRuyter, Thomas R (DEC) Subject: RE: PBU D-pad well with hole in 13-3/8" csg? All, The lab analysis of samples taken at the bottom of the hole show significant levels of remaining contamination (DRO). I am waiting on a site characterization work plan from 8P. As previously discussed this need not be elaborate and can be similar to the plans used on other spill sites. I haue worked with l3P and CPA on the cleanup of contaminated gravel in and around many different well cellars. Each one seems to pose its own challenges due to the variety of construction methods and materials used. The questian that is very likely to come up is haw can the well cellar be safely removed to allow further cleanup? We can cross that bridge when we get there. Thanks Tom DeRuyter 451-2145 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Thursday, September 25, 2008 8:31 PM To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; DeRuyter, Thomas R (DEC); Daniel, Ryan; Engel, Harry R; NSU, ADW Well Integrity Engineer; GPB, Environ Advisor (Services); GPB, Environ Advisor West; Klein, Carol A (ATS); Fletcher, Bill D Subject: RE: PBU D-pad well with hole in 13-3/8" csg? Jim, The D-pad spill report you mention below is, indeed, regarding the recent sidetrack on D-22. The surface casing leak, with an estimated depth of 48', was a known integrity issue and cementing of the OA to surface was a planned repair. Subsidence crew personnel inspected the cellar and determined that there were no major concerns of structural failure, but the decision was still made to discontinue manned cleanup operations to mitigate risk to personnel. Consequently the cellar, as of yet, has not been filled in. The cleanup effort is being managed by the GPB West Environmental Advisor position currently staffed by Carol Klein with Bill Fletcher due to relieve her in the next couple of days. Currently they are awaiting a response from Mr. Tom DeRuyter, ADEC, for further discussion and guidance regarding test analysis of soil samples from within the cellar before proceeding with the cleanup. A response and plan forward are anticipated by the end of the week. Please feel free to contact me if you have any questions. Thanks. 9/26/2008 ae~-tai Page 2 of 2 On behalf of Anna Dube, ,~f1.S01`l ~. ~(1Ft~E7tt alternate -Taylor Wellman by Alaska -Well Integrity Engineer office: 907-659-5098 cell: 713-299-2651 pager: 659-5100 x1446 harmony: 758-2418 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, September 23, 2008 4:26 PM To: NSU, ADW Well Integrity Engineer Cc: DOA AOGCC Prudhoe Bay Subject: PBU D-pad well with hole in 13-3/8" csg? Received spill reports for D-pad well; cause listed as hole in well's 13-3/8" casing. Spill report indicates approx 55 bbls diesel released from casing into the well cellar. Appears from interim report received 9/12/08 that the casing was cemented to surface to "plug the hole". Also, spill report indicates vac ops removal of fluids and gravel has undermined the well cellar structure. Which we-1 (D-22C?) Any idea of the depth of the hole? Was this a known integrity issue prior to rig moving onto well? What is being done to remedy undermined well cellar? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 9/26/2008 North Slope Spill Report ~~ BP Exploration(Afasfca),INC. 90U fast Benson R[vcl. Anchorage, AK 99519-6612 BPX Spiii Rpt#: 08-195 Datt•; of Spill (DD/MM/YYYY) 06/08/2008 Time (HH:MM): 10:00:00 PM Report Status: Interim 1 Location1: West Location2: Watt Pad D NaC I~pt#: Company: Nabors Drilling Total in Containment{Gallons): Total Outside Contalnment(Gal): RecycledlReused (Gal): Disposed (Gal): Surface Area Impacted {Sq.Ft): Ail Secondary Containment? Tundra Affected? Water Affected? Material Nama Diesel Amount (Ga!): 2310 Cause: Hole In 13 318" casing Clean-Up' Sucked up with vacuum truck. 9!4/08 Utlized SuperSueker truck to recova approx. 16 cubic yards of gravel. Currently we an: at the point that wa are undettnining the oeflar atn~pture. SE were taken for DRO and BETX,_ -____.. ---- --•-- •• -• • -- Disposal: Class II disposal weEl Environmental Impact: None Preventative Action: A herculite liner was pieced around the well in the cellar to preven! further spillage. The 13 318 casing was ceMented tp surfaco which plugs the hole. Additional Informaticn: The drilling rig Is moving off of the wall on 8123 and then a sitckline unit is scheduled to complete same work oh the well. 1n approximately 2 weeks the well ba ava{lablo for Environmental to complete the Gean up operation. This report sadsfles tho noHficatlon requirements of 18 AAC 075.300 ~~ ~ ~. `~D7'~,S~~i`' ~ 37,5 5ubrnitted ey telephone ~rrof ~ ~ > ~Y'~L'v1 Rage 1 Of 1 Gitnerated on: 12/092008 _-~ _~ 0 2310 ,y I ~ 0 r `` ~- ~ ?~ ~ _ ~~~. v %. ` 2310 ± ~ <, '~ `- ~, 180 ~ ~ -~--~ ~:` ~ N . ~ ~ ~ ~ ~ ~ ~ ~ N N ~• ~a~ YY13-d l00/l00•d ti51-1 b11g6591013 laSVOM Xd9-woad we~~:Ot 8002-Z1-60 y~ STATE OF ALASKA `' ., ~~. ; ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT'~I~fils@~( 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zaAACZe.~oB zoAaczs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Com letions One 1b. Well Class: ®Development ^ Exploratory ^ Service ^ Strati ra hic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 8/22/2008 12. Permit to Drill Number 208-121- 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8!11/2008 ' 13. API Number 50-029-20737-03-00 - 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 8/18/2008 14. Well Name and Number: PBU D-22C - 1550 FNL, 1692 FEL, SEC. 23, T11 N, R13E, UM Top of Productive Horizon: 438' FNL, 3017' FEL, SEC. 23, T11 N, R13E, UM g KB (ft above MSL): 70.55' Ground (ft MSL): 41.48' 15. Field /Pool(s): - Prudhoe Bay Field / Prudhoe Bay Total Depth: 146' FNL, 4415' FEL, SEC. 23, T11 N, R13E, UM 9. Plug Back Depth (MD+TVD) 10774' 9023' P°ol 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 653460 y- 5959438 Zone- ASP4 10. Total Depth (MD+TVD) 10861' 9025' 16. Property Designation: ADL 028285 TPI: x- 652111 y_ 5960523 Zone- ASP4 Total De th: x- 650707 - 5960787 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: y p 18. Directional Survey ®Yes ^ No r 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and MWD DIR / GR / PWD, MWD DIR / GR /RES, MWD DI printed information per 20 AAC 25.071):~„GG~/DD/f-aL ?~~~M~ R / GR /RES / ABI /DEN / NEU, USIT ~ao9.8'rl-d 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT Wi. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENnNG RECORD PULLED u X I r n - / " 7# 7' _ /4" 1170 cu ft'G, 130 cu ft PF'C', 7235 cu ft'G 7" 2 -1 /2" 793 cu ft LiteCrete 195 cu ft Class'G' 23. Open to production or inject ion? ®Yes ^ No 24. TuelNC RECORD If Yes, list each i & Bottom (MD+TVD of To Pe nterval open rforation Slze and Number): SIZE DEPTH SET Mo PACKER SET MD ; p 2-7/8" Gun Diameter 6 spf 4-1/2", 12.6#, 13Cr80 8593' 8516' , MD TVD MD TVD 9820' - 9920' 9028' -9027' 9026' -9027' 9940' -10030' 9027' - 9027' 9027' - 902T 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC.. 10060' - 10310' 9027' -9024' 9027' - X24' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 10340' - 10760' 9024' - 9023' 9024' -9023' Freeze Protected with 151 Bbls Diesel 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: CALCULATED 2a-HouR RATE.., OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): Z7. CORE DATA Conventional Core(s) A wired? ^Yes ® No Sidewal l Core s A wired? ^Yes ~ No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. COt~FyLE i 10~{ None ~~~,~~ Form 1o-av~ Revised ozizw~ ORIGINAL CONTINUED UN KEVERSE SIDE s ~~~ ~~P ~ ~ coos ~~z~ 28. GEOLOGIC MARKERS LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. ORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefty summarizing test results. Attach separate sheets to this form, ff needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 8740' 8506' None Shublik 8772' 8537' Sadlerochit 8863' 8621' Top CGL /Zone 3 9087' 8800' Base CGL /Zone 2C 9180' 8861' 25N /Zone 26 9415' 8965' 22N /Zone 2A 9919' 9027' Formation at Total Depth (Name): 22N /Zone 2A 9919' 902T 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoi g is true and correct to the best of my knowledge. ~ ~~~~ Signed Terris Hubble Title Drilling Technologist Date PBU D-22C 208-121 Prepared ey Namenvumber. Terris Hubble, 564-4628 Well Number Dn11"'gE"9'"~~ Eleazar'Eli' VSzquez, 564-5918 INSTRUCnoNs GENERAL:. This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Satt 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 cempletely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level, Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing. of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test artd analytical laboratory information required by 20 AAC 25.07E Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: D-22 Common Name: D-22 Test Date - ~ Test Type Test Depth (TMD) Test Depth (TVD) ~ AMW f Surface Pressure Leak Off Pressure (BHP) _ EMW 6/1/2002 FIT 8,278.0 (ft) 8,040.0 (ft) 10.60 (ppg) 600 (psi) 5,027 (psi) 12.04 (ppg) 6/6/2002 FIT 8,804.0 (ft) 8,505.0 (ft) 8.40 (ppg) 930 (psi) 4,641 (psi) 10.50 (ppg) 8/11/2008 FIT 4,219.0 (ft) 4,218.0 (ft) 9.20 (ppg) 550 (psi) 2,566 (psi) 11.71 (ppg) 8/16/2008 FIT 8,739.0 (ft) 8,506.0 (ft) 8.40 (ppg) 975 (psi) 4,687 (psi) 10.61 (ppg) Printed: 9/2/2008 17:50:27 AM 1~i BP EXPLORATION Page 1 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABORS 7ES Rig Number: 7ES Date ~~ From - To Hours Task :Code NPT Phase Description of Operations 8/3/2008 00:00 - 13:00 13.00 MOB N WAIT PRE Release rig from DS 06-21 B at 00:00 hrs Bridle up and prepare derrick & lay down Perform Preventive Maintenace 13:00 - 17:00 4.00 MOB P PRE 17:00 - 00:00 7.00 MOB P PRE 8/4/2008 00:00 - 03:30 3.50 MOB P PRE 03:30 - 05:00 1.50 MOB P PRE 05:00 - 06:00 1.00 MOB P 06:00 - 08:30 I 2.501 KILL I P 08:30 - 09:00 0.50 KILL P 09:00 - 10:00 1.00 KILL P 10:00 - 11:30 1.50 DHB P 11:30 - 12:00 0.50 KILL P 12:00 - 14:00 2.00 KILL P 14:00 - 16:00 2.00 KILL P 16:00 - 21:00 5.00 KILL P 21:00 - 22:00 1.00 DHB P 22:00 - 23:00 1.00 WHSUR P 23:00 - 00:00 1.00 BOPSU P 8/5/2008 00:00 - 01:00 1.00 BOPSU P 01:00 - 04:30 I 3.501 BOPSUq P PRE Wait on rig mats to be laid on road Move Satellite camp, Pit Module and Rig Shop to D Pad Lay mats, spread herculite, Move Rig from DS 06 to D Pad Continue moving Rig from DS 06 to D Pad Spot Sub-structure over well Spot pit module, -Prepare and inspect derrick to raise. -Spot open top contingency tank along side of pits PJSM -Raise Derrick, Cattle chute and Hang Bridle Lines DECOMP Take On water in Pits and start mixing 8.5 NaCI brine -Prep Rig Floor for Workover operations -Prep Cellar For pumping kill fluid and testing IA x Tubing -Finish R/U of Rig DECOMP Hold Pre-Spud Safety meeting DECOMP R/U and Test IA x 4 1/2" Tubina to 2230 osi for 30 min_ O.I -Chart Recorded Test DECOMP Ri U Lubricator on to of Tree n DECOMP Reverse Circ. out 15 bbls of Diesel from Tubing DECOMP Circ. down tubing with 50 bbl soap sweep, followed by 130 degree seawater -210 gpm / 400 psi -Sweep Back at 213 bbls Stop Circ and Monitor well, 170 psi on tubing / 0 on IA 'Hold Pre-Spud Safety meeting with crew coming' DECOMP R/U and U-Tube IA x T -After 1 hr 234 psi on Tubing and / 0 IA DECOMP Reverse Circulate and balance fluid in well -Mud Weight reading from 9.5 ppg to 8.5 ppg pump until 8.5 ppg In /Out -Monitor well , Tubing 70 psi /zero on IA -Bleed of tubing to zero, bled back 4 bbls still "dribbling" -Pump 40 bbl down tubing of 8.7 ppg brine -Monitor well, zero on annulus and zero on IA -Monitor well for 10 min, well is dead DECOMP Set TWC and test from below to 1000 osi for 10 min. - aoo st DECOMP Nipple down tree -screw in hanger crossover, 7" NSCC Threads - 8 turns DECOMP N/U BOP's DECOMP Finish nippling up BOP's -Set Bell Nipple and Riser Connect Kill and Choke Lines DECOMP PJSM with Rig Crew on testing BOP's Nnrnea: ai~euua 11:SU::14 HM r BP EXPLORATION Page 2 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES .Date From - To Hours Task Code NPT Phase ~, Description of Operations 8/5/2008 01:00 - 04:30 3.50 BOPSU P DECOMP -Witness of Test by waived by AOGCC rep Jeff Jones, test witnessed by BP WSL Dave Newlon, NAD Toolpusher Lenward Toussant Test to 250 psi low and 3500 psi high, each test held for 5 minutes and charted #1 Test -Top Pipe 3 1/2" x 6" Var.Rams, Choke Valves 1,2,3,16, HCR Kill valve, Upper IBOP #2 Test -Choke Valves 4,5,6, Manual Kill valve, TIW, Manual IBOP #3 Test -Choke Valves 7,8 & 9 #4 Test -Test Super Choke and Manual Choke to 250 psi low, 3000 high - #5 Test -Choke Valves 10, 11 and 15 #6 Test -Choke Valve #14 #7 Test -Manual Valve on BOP stack #8 Test -Annular, Choke Line HCR Valve on Stack -Accumulator Test #10 Test -Blind Pipe Rams, Choke Valves 12 &13 No Failures, Good Test 04:30 - 06:30 2.00 DHB P DECOMP PJSM with NAD Drill Crew and DSM on pulling TWC - Lubricator test to 10 0 si K , -P -R/D Lubricator 06:30 - 08:00 1.50 PULL P DECOMP Make up a landing joint to the Top Drive and cross over to the tubing hanger threads. -Engage the tubing hanger. -Back out lock down screws. f 1 ~ nnn l f ll H _ ar raP o an9~r pL - -Free PUW 120,000 SOW - 115,000 08:00 - 09:00 1.00 PULL P DECOMP Circulate Hole volume -500 gpm / 600 psi Monitor well for 10 minutes, Static 8.5 ppg In /Out 09:00 - 15:30 6.50 PULL P DECOMP Laydown tubing -200 joints of Vam Ace, 2 GLM, 1 "x" Nipple -Cut off joint 4.28' 15:30 - 18:30 3.00 BOPSU P DECOMP PJSM with Rig Crew on testing BOP's Test BOP's to 250 Low and 3500 si Hi h -Witness of Test by waived by AOGCC rep Jeff Jones, test witnessed by BP WSL Mike Dinger, NAD Toolpusher Larry Wurdemann -Recorded each test on chart -Test with 4" test joint -Test bottom set of Pipe Rams with 2 7/8" x 5" Var -Test top set og pipe rams with 3 1/2" x 6" Var.Rams Test Annular with 4" test joint -No Failures, Good Test 18:30 - 23:00 4.50 CLEAN P DECOMP Make u 9 5/8" casin scra er and Cross over -Pick up 18 jts of 4" HWDP -Pick up 144 jts of 4" Drill Pipe to 5155' No Problems RIH 23:00 - 00:00 1.00 CLEAN P DECOMP CBU -555 gpm / 1930 psi -PUW 110 k /SOW 110k Printed: 9/2/2008 1 LSU:34 Ana ~ ~ BP EXPLORATION Page 3 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABORS 7ES Rig Number: 7ES Date !~ From - To Hours Task Code NPT Phase Description of Operations 8/5/2008 23:00 - 00:00 1.00 CLEAN P 00:00 - 0.00 CLEAN P 8/6/2008 00:00 - 02:00 2.00 CLEAN P 02:00 - 03:30 1.50 BOPSU P 03:30 - 12:30 I 9.00 I DHB I P 12:30 - 16:00 I 3.50 I CLEAN I P 16:00 - 17:00 1.00 CLEAN P 17:00 - 19:30 2.50 CLEAN P 19:30 - 22:00 2.50 FISH P DECOMP Monitor well for 10 minutes, Static 8.5 ppg In /Out DECOMP POOH DECOMP POH standing back Drill Pipe and HWDP DECOMP Chan a To set of i e rams to 9 5/8" PJSM with Rig Crew on testing BOP's and Changing Rams Test BOP's to 250 Low and 3500 psi High -Witness of Test by BP WSL Dave Newlon, NAD Toolpusher Lenward Toussant -Recorded test on chart -Test with 9.625" test joint Good Test DECOMP Rig UP and Run E-Line Run 8.52 gauge ring and junk basket, unable to get by 48' Run 8.25" Gauge Ring and Junk Basket to 4500', no problems CCL and GR log to surface -Run in with CCU GR / 9 5/8 EZSV set EZSV at 4235' -RIH and shoot 5 strand String Shot ~ collar located at 2088' -R/D Wireline unit DECOMP RIH with Bit Sub and 8 1/2" bit to displace well to 9.8 ppg brine -Picking up DP 1 x 1 DECOMP Displace to 9.8 Brine DECOMP POH DECOMP P/U String Cutter and RIH -RIH to 2088' - RIH into hole slow as per Baker Service Rep. - P/U stand, M/U Top Drive, Establish Circulation - Locate Collar ~ 2088 - P/U 16' C~1 2072' - Up wt 73K and DN wt 73k -Stop pumping and let well balance out -IA fell aox 60' -No Flow out to the Open Top Tank via the OA -Total of 25 bbls of Arctic Pack taken into 22:00 - 00:00 2.001 FISH ~ P 18/7/2008 100:00 - 01:30 I 1.501 FISH I P DECOMP Monitor Well and consu t wit nchorage Rig Team -Well is in balance with the fluid level in IA apx 60' down and no flow though 13 3/8 mandrel into cellar DECOMP Dis~larP Arr•.1ir•, Pack from the 13 3/8 X 9 5/8 annulus -Returns going in cellar and being suck out with vac truck -Circulating across top hole with charge pump with 9.8 brine 01:30 - 03:30 2.001 FISH ~ P Pump a total of 20 bbls and the returns in the cellar stop and started to get returns through the 13 3/8 x 9 5/8 annulus to the open top tank DECOMP PJSM with Little Red Pumping services and NAD rig crew -Pressure test line to Rig floor to 3000psi, O.K. -Pump 60 bbls of diesel heated to 130 degrees down the DP -With 20 bbls in DP and 40 bbls in annulus, shut the bag and pump another 60 bbls down the DP through 9 5/8" cut and Printed: 9/2/2008 11:50:34 AM ~ ~ BP EXPLORATION Page 4 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To ~ Hours Task ~ Code NPT Phase Description of Operations 2.00 FISH I P DECOMP taking returns up 13 3/8 x 9 5/8 annulus, 8/7/2008 01:30 - 03:30 _ - -- 03:30 - 05:00 1.501 FISH ~ P 05:00 - 06:30 1.50 FISH P 06:30 - 07:30 1.00 FISH P 07:30 - 09:00 1.50 CASE P 09:00 - 10:00 1.00 CASE P 10:00 - 11:00 1.00 CASE P 11:00 - 12:00 1.00 CASE P 12:00 - 14:00 2.00 CASE P 14:00 - 22:00 8.00 CASE P 22:00 - 23:30 I 1.50 I CLEAN I P 23:30 - 00:00 0.50 CLEAN P 8/8/2008 00:00 - 01:00 1.00 FISH P 01:00 - 03:00 2.00 FISH P 03:00 - 06:00 3.001 FISH P 06:00 - 08:00 I 2.001 FISH I P -LRS pump pressure = 500 psi ~ 1 bpm -Pump a total of 120 bbls DECOMP Reverse Circ., Pumping Down to IA ~ 2 bpm / 50 psi -Pump 50 bbls of Safe Surf O, 9.8 ppg brine pill -Pump another 100 bbls of 9.8 brine down IA 90% of returns going to Open Top Tank via OA DECOMP Pump down DP A 3 bpm with IA Shut in DECOMP POH with Casing Cutter -L/D Casing cutter BHA DECOMP Ri and Pull 9 5/8" casin h -Prepare Rig Floor for Laying down casing -Pull Wear Bushing -P/U Spear/ Pack off assembly -Engage Casing and Back out Lock Down Screws -Pull to 200 k and Hanger Pull free -Free P/U Wt 110k DECOMP Rig Rig floor with Power Tongs, Elevators and False Bowl / Slips DECOMP Pull 2 jts of 9 5/8 casing -Breakout 42 - 52 kfUlbs DECOMP Read Cellar for takin returns via 13 3/8 x 20" Annul -La H r lit n Berm DECOMP CBU -3 bpm / 105 psi DECOMP La Down 9 5/8" Casing -50 'ts and 22.88' cut off 't -No Centralizers recovered -26 - 62k fUlbs to breakout casing -Clear floor of casing handling equipment -Clean Arctic Pack off rig floor and drip pan DECOMP M/U 12 1/8" bit , 13 3/8" casing scraper, jars, bumper sub, 6 1/4" DC, -RIH and Tag at 53 feet in, attempted several times to work down unsuccessful) -POH and L/D 12 1/8" Bit -RIH and Tag at 53 feet in, Body of casing scraper 11.00 inches -Scrape Marks on body of csg scraper apx 10 3/4" DECOMP Lay Down Casing scraper BHA DECOMP Remove IBOP from Top Drive and Ready rig for Swaging Operations DECOMP Pick Up Swaging BHA with 10 13/16 Swage -Tight at 53' but was able to work down with 15k -10 13/16" Swa a worked throw h 52 - 55' DECOMP POH and change to 11 1/2" Swage -RIH to 53' ,Begin Swaging operations -Unable to make anv oroaress -POH DECOMP Pick up HWDP on top of 7 DC's below 11 1/2" Swage.. Printed: 9/2/2008 11:50:34 AM ~ r BP EXPLORATION Page 5 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To ', Hours Task Code NPT Phase Description of Qperations ,_ ___ __ 8/8/2008 06:00 - 08:00 2.00 FISH P DECOMP -Swa a Between 53-55' 08:00 - 10:00 2.00 FISH i P 10:00 - 12:30 2.50 FISH P 12:30 - 15:30 3.00 FISH P 15:30 - 17:30 2.00 FISH P 17:30 - 19:30 2.00 FISH P 19:30 - 21:00 1.50 FISH P 21:00 - 22:30 1.50 FISH P 22:30 - 00:00 1.50 FISH P 8/9/2008 00:00 - 00:30 0.50 FISH P 00:30 - 01:30 1.00 FISH P 01:30 - 02:30 1.00 FISH P 02:30 - 03:30 1.00 FISH P 03:30 - 05:00 1.501 FISH P 05:00 - 06:30 1.50 CASE P 06:30 - 10:00 3.50 CASE P 10:00 - 11:00 1.001 CASE P 11:00 - 11:30 I 0.501 CASE I P -1V-LVI~UIQU 1111VU411 JV-VV DECOMP Slip and cut drilling line -Service Top Drive, Crown and Draw Works -Perform Derrick Inspection -Replace Sheared bolt on the "J" Box on the Top Drive DECOMP Make u 12 3/16" Swage BHA and RIH tagging at 53' -Attem t to Swa a out to 12 3/16" unsuccess ull DECOMP POH standing Back DC's and HWDP -L/D Swaging BHA DECOMP Make up Baker Back off tool and BHA DECOMP RIH filling DP with fresh water DECOMP Position Baker Back off tool across casing collar at 2088' -PJSM with all Personnel -Test Lines to 5000 psi -Pressure up to 1500 and shear pins ,set bottom slips at 2095 -Slack off 20k and confirm slips set -Pressure up to 4600 psi and set top set of slips -Perform 8 cycles of pressuring up to 2500 psi and bleeding to zero for a total of 5 rounds -Release slips and Rig Down circulating equipment DECOMP POH with Back off BHA DECOMP L/D Back Off BHA DECOMP Clean Arctic Pack off Rig Floor and Fishing Tools -Lay Down Fishing Tools off Rig Floor DECOMP Install IBOP back on Top Drive -Detail Derrick Inspection DECOMP Make Up Spear BHA and RIH to 2072' -Engage spear in 9 5/8 cut off stub and back out 5 turns -Pull out of box 2" DECOMP Circulate Safe Surf O pill around -400 gpm / 345 psi -Residual Arctic Pack Returns initially but turn to clean brine after CBU -Less then 1 b m comin out of the 20 x 13 3/8 annulus whit circulatin DECOMP POH with cut off joint -14.76' cut off joint, -Back off at in, will screw into a box on to of 9 5/8" in the holy DECOMP Rig up to run 9 5/8 casing DECOMP Run 50 'oints of 9 5/8" 40# H dril 563 casin -BOT screw sub, Baffle Collar, ES Cementer -1 Pup Joint used to space out for spaceout -No centralizers due to collasped 13 3/8 casing -Jet Lube Seal Guard thread compound -Baker-Locked connections on Cementer and below -M/U Torque on Hydril 563 to 15800k ft/Ibs DECOMP Tag Casing top ~ 2089' -Free PUW 100 K /SOW 98k -Screw in with 7 Turns and Work 10k Tor ue down -Pull Test to 250k O.K DECOMP Pressure Test Casing to 2000 psi for 30 minutes, Good Test Printed: 9/2/2008 11:50:34 AM • ~ Page 6 of 16 ~ Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES Date ~ From - To Hours ~' Task Code NPT Phase Description of Operations 8/9/2008 11:30 - 12:30 1.00 CASE P DECOMP M/U Cement Head, hoses and Valves -Shear out cementer at 3100 psi -CBU ~ 6 bpm / 270 psi BP EXPLORATION 12:30 - 14:30 I 2.00 I CASE I P DECOMP 'Arctic Pack still coming out intermittently -Pump 5 bbl fresh water and pressure test to 4000 psi -Batch Mix and pump 220 bbl Class "G" cement (100 bbls excess) at 15.8 ppg with GasBlok Drop ES-Cementer closing plug. -Drop Plug -Pump 10 bbl fresh water behind plug to clear lines. -Switch to rig pump and displace with 147 bbl (2534 strokes) fresh water at 5-6 bpm. -At 2000 strokes, reduce rate to 2 bpm, close bag and sgueeze_ -Bump plug to 1700 psi, then continued to pressure up to 3000 psi to shear pins and close ES-Cementer. -Hold for 5 minutes then bleed off and check for flow back, -Rig Down Cementing equipment 01:30 - 02:30 ~ 1.001 BOPSUq P CIP ~ 14:00 Hrs DECOMP Split Stack to set emergency slips -Drain cement and flush lines DECOMP Land 9 5/8 casing and Install New casing Wellhead -Set Emergency slips on 9 5/8" casing -Set with 100k -Cut off casing with Wachs Cutter -UD Cut Off Joint -NU new McEvoy SB-3 SSH Tubing Spool with YBT Packoff -Fill Void with Plastic sealant -Test to 2500 psi for 30 minutes DECOMP Nipple up BOP's -Install Riser, secondary valves and tighten turnbuckles DECOMP Change Top Set of Pipe Rams from 9 5/8 to 3 1/2" x 6" VBR -Open all of the Ram doors and flush out Cement and Inspect cavities DECOMP Finish Cleaning and Inspecting Ram Bodies -Open all of the Ram doors and Hush out Cement and Inspect -Close Bag and Flush out cement behind bag DECOMP Function Test All Rams PJSM with Rig Crew on testing BOP's Test BOP's to 250 Low and 3500 psi High -Witness of Test BP WSL Dave Newlon, NAD Toolpusher Biff Perry -Each test held for 5 minutes and charted -Test Top Set of Pipe Rams with 4" Test Joint, This test also tested flange breaks on New Spool -Good Test 14:30 - 15:30 I 1.001 BOPSUR P 15:30 - 20:30 5.00 WHSUR P 20:30 - 22:30 2.00 BOPSU~P 22:30 - 00:00 1.50 BOPSU P 8/10/2008 100:00 - 01:30 1.50 BOPSUF~ P Printed: 9/2/2008 11:50:34 AM ~ r BP EXPLORATION Page 7 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To Hours ~ Task .Code NPT Phase ~ Description of Operations 8/10/2008 02:30 - 03:30 1.00 CLEAN P DECOMP Make up an 8 1/2" bit, 2 junk baskets, Jars, 3 stands of 6 1/4" drill collars 03:30 - 04:30 1.00 CLEAN P DECOMP RIH to ES cementer at 2061'. 04:30 - 06:30 2.00 CLEAN P DECOMP Cleanout ES cementer and Plug catcher -Tag Cement Stringers at 2049 -Wash Down to plugs ~ 2077' -400 gpm / 600 psi -80 rpm 1-2k ft/Ibs of Torque -PUW - 75k SOW - 73k 06:30 - 07:00 0.50 CLEAN P DECOMP RI and Ta EZSV ~ 4235` 07:00 - 08:00 1.00 CLEAN P DECOMP Pump High Vis Sweep around -550 gpm / 1170 psi -Monitor Well, static 8.4 ppg INOut 08:00 - 11:30 3.50 CLEAN P DECOMP POH and UD Junk Baskets - no debris in baskets 11:30 - 14:00 2.50 CLEAN P DECOMP Make 9 5/8" casing Scraper - RIH Picking up the remaining drill pipe 1 xi 14:00 - 16:30 2.50 CLEAN P DECOMP POH Rack Back DC's and UD Scrapper -No Issues running scraper 16:30 - 19:30 3.00 STWHIP P WEXIT Make u Whi stock and Mills 19:30 - 22:00 2.50 STWHIP P WEXIT RIH to 4189' -Shallow hole test MWD, O.K. 22:00 - 22:30 0.50 STWHIP P WEXIT Displace to 9.2 ppg LSND Milling Fluid -500 gpm / 1000 psi 22:30 - 23:30 1.00 CASE P DECOMP Test Casing to 3500 psi for 30 min -Lost 50 psi for the first 15 mionutes -Lost 20 psi for the second 15 minutes -Total pressure loss for test of 70 psi 23:30 - 00:00 0.50 STWHIP P WEXIT Set Whi stock -Orient Whip stock to 60 degees left of high side -set anchor with 20k down weight -Confirm anchor is set pulling 15k -Sheared off with 40k slack off weight D•'1'~c -Whi stock set at 57 derees left of hi h side 8/11/2008 00:00 - 04:00 4.00 STWHIP P WEXIT ,Mill window from 4211 - 4239' -370 gpm / 650 psi -90 rpm 1-3 off btm torque / 3 -7 on bottom torque TOW ~ 4211 BOW ~ 4227' Middle of window is 4219' 04:00 - 04:30 0.50 STWHIP P WEXIT CBU 04:30 - 05:00 0.50 STWHIP P WEXIT -Chart test, Good test Fit Test Data - 4219' MD / 4217' TVD 9.2 ppg / 550 psi 05:00 - 06:30 1.50 STWHIP P WEXIT Finish Milling window to 4248' -370 gpm / 650 psi -90 rpm 1-3 off btm torque / 3 -7 on bottom torque -Work Mills through window to clean up, Good Window -CBU -Monitor Well, Static 9.2 ppg In /Out 06:30 - 08:00 1.50 STWHIP P WEXIT POH standing back Drill Pipe and HWDP 08:00 - 09:00 1.00 STWHIP P WEXIT Lay Down Drill Collars and Window Milling BHA 09:00 - 10:00 1.00 STWHIP P WEXIT Flush Stack with Jetting Tool -Clear Floor of Milling Equipment and tools Nrinted: aivzuuts 11:~U::14 HM BP EXPLORATION Page 8 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To ,Hours Task Code NPT Phase Description of Operations 8/11/2008 10:00 - 12:00 2.001 DRILL I P INT1 Pick up 8 1/2" Drilling BHA 12:00 - 13:30 1.501 DRILL P 13:30 - 14:00 0.50 DRILL P 14:00 - 14:30 0.50 DRILL P 14:30 - 00:00 9.501 DRILL ~ P 8/12/2008 100:00 - 06:00 6.00 ~ DRILL P 06:00 - 13:30 I 7.501 DRILL P 13:30 - 00:00 10.501 DRILL P 18/13/2008 100:00 - 11:00 I 11.001 DRILL I P 11:00 - 12:30 1.50 DRILL P 12:30 - 13:00 0.50 DRILL P -PDC, PDM set ~ 1.5 degree, LWD/MWD, NM Stab, 2 x NMDC, NM Stab, NMDC, Float Sub, Jars, XO, 20 x 4" HWDP, 4" DP, Shallow Test MWD O.K. INT1 RIH to 4100 - 4" DP, Ghost Reamer ~ 977' behind bit, 4" DP, Ghost Reamer ~ 2904' behind Bit INT1 Mad Pass Log to Tle-In Geology -440 gpm / 1150 psi / 30 rpm / 1-2k ft/Ibs Torque INT1 Orient and Run through window -Perform ECD Baseline -Take SPR's INT1 Directionally Drill from 4248-5126'md (5104 tvd) -550 gpm / 2000 psi on - 1790 psi off -80 rpm / 3k ft/Ibs torque off / 5kl ff/Ibs torque on bottom -5-10k WOB -EMW = 9.85 ppg Cal. ECD = 9.46 ppg -AST = 3.90 hrs ART = 1.68 hrs ADT= 5.58 hrs Total hrs on bit = 5.58 hrs -Total Jar hrs = 5.58 hrs -PUW = 127k SOW = 112k RtWt = 117k INTi Directionally Drill from 5126- 5900'md -540 gpm / 2100 psi on - 1800 psi off -80 rpm / 3k fUlbs torque off / 5k ft/Ibs torque on bottom -5-10k WOB INT1 Directionally drill ahead from 5,900' to 7,040' md. PU - 165k, SO - 130k, RTW - 140k, 20k WOB 550 gpm, 2805 psi on, 2300 psi off 80 rpm, 10k TO on, 5.Ok TO off MW - 9.2 ppg, CECD - 9.46 ppg, AECD - 10.14 ppg INTi .Directional) drill ahead from 7 040 to 7 898' md. Start spike fluid around to weight uo mud to 10 2 oaa at 7 040' md. After 10.2 around surface to surface wel t takin fluid and breathin back on connections. Lost 8 bbl i the first 1.5 hours and losses to erin off from there to less th 10 b h. Total losses for day at 180 bbls. PU - 175k, SO - 139k, RTW - 150k, 12k WOB 500 gpm, 2860 psi on, 2580 psi off 80 rpm, 7.Ok TO on, 5.5k TO off MW - 10.2 ppg, CECD - 10.39 ppg, AECD - 11.01 ppg ART - 11.44 hrs, AST - 5.43 hrs, ADT - 16.87 hrs for the day. INT1 Directionally drill ahead from 7,898' to TD ~ 8,740' md. Still breathin on connections but not takin an fluid. PU - 200k, SO - 145k, RTW - 160k, 10-15k WOB 500 gpm, 3140 psi on, 2970 psi off 80 rpm, 8.Ok TO on, 7.Ok TO off MW - 10.2 ppg, CECD - 10.38 ppg, AECD - 10.89 ppg AST - 1.20 hrs, ART - 7.25 hrs, ADT - 8.45 hrs. INT1 CBU x 1.5. 500 gpm, 2900 psi, 80 rpm, 7k TO. RTW - 160k. Sample from bottoms up shows sand w/ glauconite. INT1 Pull 5 stands dry from TD to 8,270' md. Hole started taking Printed: 9/2/2008 17:50::34 AM ~ ~ BP EXPLORATION Page 9 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT .Phase Description of Operations ~ -- 8/13/2008 12:30 - 13:00 0.50 DRILL P INT1 overpulls to 30k and some swabbing. RU to backream. 13:00 - 15:30 2.50 DRILL P INTi Backream out from 8,270' and to 7,030' md. Pumped out last 2 stands without rotation to avoid rotating reamer across window. Well still breathing back on connections. Losses resumed at up to 20 bph during backreaming. 15:30 - 17:00 1.50 DRILL P INT1 RIH from 7,030 to 8,730' and and tag up on 10' of fill. Fill pipe and wash to TD ~ 8,740' md. 17:00 - 18:00 1.00 DRILL P INT1 Circulate 25 bbl hi-vis sweep surface to surface. Rotate and reciprocate while circulating. 500 gpm, 2900 psi, 110 rpm, RTW - 160k °° increase in cuttin s seen across shakers when swee beck to surface. Some splinters up to 1" in length seen. Loss rate back to less than 10 b h while um in . 18:00 - 19:30 1.50 DRILL P INT1 Shut down monitor well, static. MW in 10.2, MW out 10.2. POH from TD ~ 8,740' to 7,023' md. No overpulls over 10k. 19:30 - 23:00 3.50 DRILL P INT1 Pulling 35k over ~ 6,950' and swabbing fluid. MU topdrive and backream 3 stands to 6,643' md. Pull 5 more stands without more than 10k overpulls before pulling tight 35k again and swabbing at 6,200' md. Backream remaining stands to 5,203' bit depth and pump out to 5,109' bit depth without rotation to pull 2nd reamer into window. Still losing -5 bph while pumping. Well breathing back slightly on connections. 23:00 - 00:00 1.00 DRILL P INTi POH without pumping from 5,109' to 4,169' md. (Top of window at 4,211' md) Less than 10k overpulls. Shut down monitor well at window -static. 8/14/2008 00:00 - 02:00 2.00 DRILL P INT1 Pump dry job. Drop 2.5" rabbit. Remove blower hose. POH to top of BHA. 02:00 - 03:00 1.00 DRILL P INT1 Lay down HWDP to shed 1x1. Lay down BHA #13. Bit Grade 1 - 2 - BU - S - X - I - CT - TD. One nozzle plugged and 2 junk slots balled up. 03:00 - 04:30 1.50 BOPSU P LNRi PJSM. Install test lu CO to rams f/3.5" x 6" to 7". RU test equipment and test to 250/3500 psi low/high pressure. Record on chart. Test good. 04:30 - 06:00 1.50 CASE P LNR1 RU casing running equipment. 06:00 - 12:30 6.50 CASE P LNR1 MU shoe track w/Bakerlok. RIH and check floats both ways. Function as required both ways. MU tq on BTC-M 9,000 ff lbs. RIH w/7" 105 ioints of 26# L-80 BTC-M liner string at 1 jt. per minute to 4,181' and (Top of window at 4,211') filling each jt w/ 2" line, topping off every 10 joints. 12:30 - 14:00 1.50 CASE P LNR1 RU crossover, TIW valve, and head pin. Circulate above 9-5/8" window. Stage pump rates up and pump 1 liner volume 160 bbls ~ 168 gpm, 360 psi. PU - 120k, SO - 118k. Lost 29 bbls during circulation. 14:00 - 15:00 1.00 CASE P LNR1 RIH w/7" joints 106-126 of 26# L-80 BTC-M liner string at 1 jt. per minute o i mg eac ~t w ine, topping o f every 10 joints. PU - 151 k, SO - 129k. 15:00 - 16:00 1.00 CASE P LNR1 MU 7" x 9-5/8" Flexlock liner hanger/ZXP liner top packer/Hydraulic setting tool w/ rotating dog sub to 7" liner. Lay down singles as necessary for spaceout and RIH to 5,188' md. 16:00 - 17:00 1.00 CASE P LNR1 Circulate 1 liner volume - 194 bbls, 168 gpm, 305 psi. PU - 155k, SO - 130k. Lost 105 bbls during circulation. 17:00 - 20:30 3.50 CASE P LNR1 RIH from 5,188' to 8,739' w/drillpipe from derrick. Work pipe Printed: 9/2/2008 11:50:34 AM BP EXPLORATION Page 10 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES Date .From - To Hours Task Code NPT Phase ~ Description of-0perations 8/14/2008 17:00 - 20:30 3.50 CASE P LNR1 through ti ht hole reci rocatin as necessa between 8,250' and and 8 550' md. Tag and wash 3' of fill out at 1 bpm to TD at 8,740' md. PU 1' and leave shoe at 8,739' md. Pushing awa dis lacement volume while runnin . 20:30 - 00:00 3.50 CASE P LNR1 Stage up pumps slowly from 0.5 bpm to 6 bpm. Losing fluid, in -50 boh• 8/15/2008 00:00 - 02:00 2.00 CEMT P LNR1 Pump 5 bbls H2O w/Schlumberger pumps to floor and out to flow line. Shut in. Test lines to 4500 psi and walk lines. Pump mud push to rig floor w/Schlumberger pumps and overboard all H2O in lines via wash up line at floor. Pump a total of 22.1 bbls 10.5 ppg mud push down hole. At 00:13 start to mix and pump 141.2 bbls of 11.0 ppg LiteCrete slurry at 6.0 bpm. ICP - 1044 psi, FCP - 162.5 psi. Shut down. At 00:40 start to mix and pump 34.7 bbls class G tail slurry plus additives at 3.9 bpm. ICP - 403 psi, FCP - 224 psi. Shut down. Drop drill pipe wiper dart and note plug drop indicator trip. Chase wiper dart w/ 5 bbls H2O from Dowell to flush lines. Total displacement = 227 bbls. Switch to rig and pump 140 bbls 10.2 ppg LSND mud ~ 5 bpm ICP - 892 psi, FCP - 1143 psi. (Slow to 3 bpm at 32 bbls away & see drill pipe wiper dart catch liner wiper plug ~ 37 bbls away, and shear off as expected before returning to 5 bpm). At 140 bbls away, reduce pump rate to 3 bpm for next 50 bbls ICP - 738 psi, FCP - 1045 psi. At 190 bbls away, reduce pump rate to 2 bpm for next 32 bbls ICP - 937 psi, FCP - 1010 psi. See plugs bump landing collar as expected. Saw lifting pressure throughout displacement until last 15 bbls. Lost 130 bbls Burin dis lacement. Cement in place at 01:51. Bring pressure up to 3000 psi and hold f/3 mins to set liner hanger slips. 02:00 - 03:00 1.00 CASE P LNR1 Setting hanger and packer after bumping plug. Slack off entire string weight - 55k to check liner hanger. Hanger holding. Pressure to 4,300 psi no noticable indication on weight indicator of pusher tool stroke. Bleed off pressure to zero and check floats for bleedoff back to surface. Floats holding. Rotate 15 turns right to release C-2 running tool, pressure up to 1000 psi. PU until PBR packoff cleared liner top extension sleeve and pressure bled off to 200 psi PU - 75k, SO - 72k. Circulate cement 50 bbls above liner top. PU rotating dog sub clear of liner top and slack off 50k. Rotate at 15 rpm. SO rotatin w/ 50k entire strip wei ht to confirm ZXP acker set. PU 20' to clear liner top w/stinger and put NOGG mark on drill pipe. Circulate 1.3 bottoms up at 490 gpm, 960 psi. No cement or mud ush returns to surface. 03:00 - 03:30 0.50 CASE P LNR1 Shut down and lay down cementing head and 1 single. 03:30 - 04:30 1.00 CASE P LNR1 POH on DP to top of running tools. 04:30 - 05:00 0.50 CASE P LNR1 Lay down running tools and inspect. Tattle tales on both pusher tool and dog sub sheared as expected. 05:00 - 06:00 1.00 BOPSU P LNR1 PJSM. Install test plug. CO top rams U3.5" x 6" from 7". RU test equipment. 06:00 - 12:30 6.50 BOPSU P PROD1 Test BOPE stack all valves and manual & hydraulic chokes to 250 psi low and 3500 psi high pressure. Upper rams tested with 4" & 4-1/2" test joints. Lower rams and annular preventer tested with 4-1/2" & 2-7/8" Record on chart. Witness of test rnmea: muzuun iiavawr+m i • BP EXPLORATION Page 11 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES I .Date From - To Hours Task Code NPT Phase ~ Description of Operations 8/15/2008 06:00 - 12:30 6.50 BOPSU P PROD1 waived by AOGCC Rep. Chuck Scheve. Tests witnessed by BP WSL Mike Dinger & NAD TP Chris Weaver. 12:30 - 13:00 0.50 BOPSU P PROD1 RD test equipment. Install wear bushing. 13:00 - 14:00 1.00 CASE P LNR1 RU test a ui ment and test casin to 3500 si and hold for 30 14:00 - 16:00 2.00 DRILL P PROD1 16:00 - 19:30 3.50 DRILL P PROD1 19:30 - 20:30 1.00 DRILL P PROD1 20:30 - 21:30 1.00 DRILL P PROD1 21:30 - 00:00 2.50 DRILL P PROD1 8/16/2008 00:00 - 02:00 2.00 DRILL P PROD1 02:00 - 04:00 2.00 DRILL P PROD1 04:00 - 04:30 0.50 DRILL P PROD1 04:30 - 05:00 0.50 DRILL P PROD1 05:00 - 12:00 7.00 DRILL P PROD1 12:00 - 00:00 12.00 DRILL P PROD1 8/17/2008 00:00 - 05:30 5.50 DRILL P PROD1 05:30 - 06:30 1.00 DRILL P PRODi mins w/chart. 98 strokes to pressure up to 3590 psi. 15 minute pressure 3570 psi, 30 minute pressure 3560 psi. RD test equipment. PJSM. PU 6-1/8" drilling BHA #14 w/MX-R18DX, 7/8 2 stage AIM Motor 1.5ABH w/float, NM Stab, NM Flex Lead DC, Impulse MWD, Sea NM Flex DC, Ball Catcher, CCV, Lead DC, Hyd Jars. RIH on 4" drill pipe from 227' to 1,215'. Shallow tested MWD at 1,215' - 240 gpm, 1065 psi. Continue RIH to 8,400' md. Slip and cut 110' of drilling line. Service top drive, crown and drawworks. Perform well kill /stripping drill with Johnston crew and Turner Crew (Changeout at 2100). Tag upon top of cement at 8 646' md. Drill cement down to 8,656' and (Plug depth). Drill on plug varying parameters attempting to drill out. PU - 175k, SO - 125k, RTW - 150k, 5-15k WOB 200 - 240 gpm, 1320 - 1650 psi 40 - 70 rpm, 7.1 k TO on, 6.8k TO off Tag up and drill plugs/landing collar & cement from 8,656' to 8,730'. 205 gpm, 1410 psi, 50 rpm, 7.2k tq. Found plugs on depth at 8.656'. Displace well f/10.2 LSND mud to 8.4 ppg Flo-Pro. 250 gpm, 1320 psi. Pump 75 bbls H2O followed by 45 bbls increased viscosity Flo-Pro between LSND and FloPro SF. Tag up on shoe and drill out at 8,739' and drill new hole to 8,760'. Pull back above 7" shoe at 8,739'. RU and Perform FIT to 10.6 ppg EMW w/8.4 ppg mud, 8,506', TVD w/ 975 psi. Directionally drill ahead from 8,760' to 9,005' md. PU - 180k, SO - 145k, RTW - 150k, 5-15k WOB 250 gpm, 1380 psi on, 1255 psi off 60 rpm, 3.5k TO on, 2.6k TO off MW - 8.4PP9 ART - 0.43 hrs, AST - 5.67 hrs ADT - 6.1 hrs. Directionally drill ahead from 9,005' to 9,500' md. PU - 182k, SO - 150k, RTW - 155k, 15k WOB 250 gpm, 1485 psi on, 1400 psi off 60 rpm, 5.Ok TO on, 4.5k TO off MW - 8.4+ ppg ART - 0.45 hrs, AST - 8.67 hrs ADT - 9.12 hrs. Directionally drill ahead from 9,500' to 9,722' md. PU - 182k, SO - 150k, RTW - 155k, 15k WOB 250 gpm, 1585 psi on, 1500 psi off MW - 8.5 ppg, AST - 3.73 hrs, no rotating time. Ciirculating hole clean - 1.2 bottoms up. Losses at 5-10 boh. 250 gpm, 1437 psi. Reciprocate 70' & rotate 60 rpm. Nnnteo: aizrzwe i i:ou:3a Hnn w ~ BP EXPLORATION Page 12 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES Date ~ From - To Hours ~ Task Code NPT Phase Description of Operations 8/17/2008 05:30 - 06:30 1.00 DRILL P PROD1 4.5k Tq off. PU - 185k, SO - 150k, RTW - 155k. Shut down, monitor well -static. MW in - 8.5 ppg, MW out 8.5 PP9 06:30 - 08:45 2.25 DRILL P PROD1 Rack back last stand (reciprocated during circulation). Attempt to pull 2nd stand without pumps. One 25k overpull at 9,435' md. Wipe to 10k. Pull third stand without pumps but several overpulls up to 35k. Run 3rd stand down and backream out from 9,430' to 8,750' md. Circulate bottoms up during last two reaming stands. Pull bit into shoe with pumps online but no rotation from 8,750' - 8,657' and PU - 185k, SO - 150k, RTW - 155k. 60 rpm, 3.Ok TO, 250 gpm, 1375 psi. 08:45 - 12:30 3.75 DRILL P PROD1 Shut down. Monitor well -slow loss. MW in 8.5, MW out 8.5. Pump salt weighted dry job once BHA inside casing shoe. POH from 8,657' and to top of BHA at 227' md. 8 bbl loss on tri out. 12:30 - 14:00 1.50 DRILL P PROD1 PJSM. Lay down or rack back BHA #14 as appropriate. Download MWD tools & re-program. Bit grade 3-4-LT-S-E-3-BT-BHA. Two 6 inch OD stabalizers behind bit 1.5' and 28' both still 6" OD. 14:00 - 15:00 1.00 DRILL P PROD1 PU 6-1/8" drilling BHA #15 w/ DTX-613M-B4 RR bit, 7/8 2 stage AIM Motor 1.5ABH w/float, NM Stab, NM Flex Lead DC, Impulse MWD, ADN, 3 NM Flex DC, Ball Catcher Sub, CCV, 15' Lead DC, Hyd Jars. 15:00 - 18:30 3.50 DRILL P PROD1 RIH on 4" DP from derrick from 283' to 8,657'. Shallow test MWD ~ 1,239' md, 240 gpm, 1150 psi - OK. Sea I 18:30 - 19:30 1.00 DRILL P PROD1 Fill pipe and continue to RIH on elevators into open hole. No problem RIH to 9,212' md. Work next 5 stands down on elevators with intermittant 25-30k slackoffs to 9,692' md. PU - 175k, SO - 150k 19:30 - 20:15 0.75 DRILL P PROD1 Unable to ass 9 692 w/o um s. Wash and ream down from 9,692' to TD ~ 9,722' md. 30 rpm, 4.5k TO, 240 gpm, 1578 psi. No fill seen on bottom. 20:15 - 23:00 2.75 DRILL P PROD1 MAD pass for gas oil contact from 9,722' to 9,172' bit depth. Losin fluid ~ 5-10 bph while backreaming. 23:00 - 23:15 0.25 DRILL P PROD1 Run back in hole to TD on elevators without problems. 23:15 - 00:00 0.75 DRILL P PROD1 Directionally drill ahead from 9,722' to 9,745' md. Losses healing up during drilling. PU - 185k, SO - 145k, 7k WOB 250 gpm, 1625 psi on, 1520 psi off MW - 8.5 PP9 ART - 0 hrs, AST - 0.3 hrs, ADT - 0.3 hrs. 8/18/2008 00:00 - 06:00 6.00 DRILL P PROD1 Directionally drill ahead from 9,745' to 10,100' md. See a e losses less than 5 b h. PU - 185k, SO - 145k, RTW - 155k, 10k WOB 250 gpm, 1720 psi on, 1625 psi off 65 rpm, 7.Ok TO on, 4.5k TO off MW - 8.5 PP9 06:00 - 12:00 6.00 DRILL P PROD1 Directionally drill ahead from 10,100' to 10,414' md. rnrnea: aiueuuo 1 I:JV:J4 HM ~ ~ BP EXPLORATION Page 13 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To Hours.... Task I Code NPT .Phase Description of Operations 8/18/2008 106:00 - 12:00 6.00 DRILL P PROD1 Seepage losses less than 5 bph. 12:00 - 00:00 I 12.001 DRILL I P 8/19/2008 00:00 - 00:30 0.50 DRILL P 00:30 - 02:00 1.50 DRILL P 02:00 - 04:00 2.00 DRILL P 04:00 - 05:00 1.00 DRILL P 05:00 - 05:45 0.751 DRILL ~ P 05:45 - 06:00 I 0.25 I DRILL I P 06:00 - 09:00 3.00 DRILL P 09:00 - 11:00 2.00 DRILL P 11:00 - 12:00 1.00 CASE P 12:00 - 15:00 3.00 CASE P 15:00 - 15:30 I 0.501 CASE I P 15:30 - 16:00 0.50 CASE P 16:00 - 20:00 4.00 CASE P 20:00 - 20:30 0.50 CASE P 20:30 - 21:00 0.50 CASE P PU - 185k, SO - 140k, RTW - 155k, 10k WOB 250 gpm, 1790 psi on, 1640 psi off 60 rpm, 7.Ok TO on, 5.Ok TO off MW - 8.5 PP9 AST - 4.5 hrs, ART - 3.82 hrs, ADT - 8.32 (00:00 - 12:00) PROD1 Directionally drill ahead from 10,414' to TD ~ 10,861' md. Steering performance and drilling ROP trending down. By 10,861' drilling slowed to less than 5 fph. Vary parameters for ROP increase without success. Consult geology and call TD at 10,861'. Losses reduced to zero -hole static. PU - 185k, SO - 140k, RTW - 155k, 10-15k WOB 250 gpm, 1785 psi on, 1680 psi off 60 rpm, 7.Ok TO on, 5.Ok TO off MW - 8.5 PP9 AST - 2.63 hrs, ART - 5.7 hrs, ADT - 8.33 PROD1 Ciculate 2 open hole volumes prior to backreaming. 250 gpm, 1650 psi, 100 rpm. PROD1 Backream out for hole cleaning from 10,861' and to 9,890' md. 80 rpm, 6k TO, RTW - 157k 250 gpm, 1650 psi. PROD1 MAD Pass at no faster than 500 fph pulling speed from 9,790' to 9,290' bit depth to relog for gas oil contact. PRODi Backream out for hole cleaning from 9,290' and to 8,680' md. 80 rpm, 6k TO, RTW - 145k 250 gpm, 1600 psi. PROD1 Drop ball & open circ sub. CCV opened w/ 1800 psi pressure spike. Circulate 1.5 bottoms up. Shakers cleaned up well. 540 gpm, 1300 psi, 80 rpm. PROD1 Shut down, monitor well -static. MW in 8.5, MW out 8.5. Pump dry job, remove blower hose, prepare to pull out of hole. Drop 2.25" rabbit. PROD1 POH from 8,680' and to top of BHA ~ 229'. PROD1 PJSM w/ all hands on handling nuclear sources. Lay down BHA #15. Bit Grade 8 - 2 - CR - N - X - 1 - BT - PR. Entire center structure of bit one and worn down to nozzle de th. Outer blades show more typical wear. RUNPRD RU liner running equipment. RUNPRD MU shoe track w/Bakerlok. RIH and check floats -function as required both ways. MU tq on IBT-M 3,600 ft lbs. RIH w/ 54 'oints of 4.5" 12.6# L-80 IBT-M liner strin at 1 't. per minute to 2,244' and filling each jt w/ 2" line, topping off every 10 joints. RUNPRD MU 4.5" x 7" Flexlock liner hanger2XP liner top packer C2 running tool w/ rotating dog sub to 4.5" liner. Lay down singles as necessary and PU 15' pup for spaceout to 2,426' md. RUNPRD Circulate 1.5 liner volumes - 51 bbls ~ 5 bpm, 150 psi. PU - 55k, SO - 55k RUNPRD RIH from 5,188' to 8,739' w/drillpipe from derrick. Losses at -2-3 bph while RIH. RUNPRD Stage up pumps at 7" casing shoe to 5 bpm, 615 psi. Pump 90 bbls. RUNPRD Service topdrive and blocks. Troubleshoot rig equipment rnntea: aiuewa i i:ov.,~v Hm • BP EXPLORATION Page 14 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES Date ~ From - To Hours I~ Task Code NPT Phase Description of Operations 8/19/2008 20:30 - 21:00 0.50 CASE P RUNPRD malfunction. Unable to keep pumps running. 21:00 - 22:00 1.00 CASE N RREP RUNPRD Troubleshoot and re air failure in power controls system. Pumps run fine, but automatic control system mal unctioning. Confirm ability to bypass automatic system and pump as normal before proceeding. 22:00 - 22:30 0.50 CASE P RUNPRD Circulate 71 bbls at 3 bpm, 480 psi. PU - 175k, SO - 135k. 22:30 - 00:00 1.50 CASE P RUNPRD RIH w/ 4.5" liner on drillipipe from 7" shoe at 8,739' and to 10,838' md. MU topdrive cementing head and single of drilpipe. Wash down last joint to TD ~ 2 bpm, 600 psi. PU - 175k, SO - 135k. 8/20/2008 00:00 - 00:30 0.50 CEMT P RUNPRD Wash down last'oint to TD C~ 10 861' md. Ta 1 foot. 2 bpm, 600 psi. PU - 175k, SO - 135k. 00:30 - 03:00 2.50 CEMT P RUNPRD Stage pumps up to 5 bpm, 960 psi. Circulate and condition while rigging up Schlumberger cementers. 03:00 - 04:45 1.75 CEMT P RUNPRD PJSM. Pump 5 bbls H2O w/Schlumberger pumps to floor and out to flow line. Shut in. Test lines to 4000 psi and walk lines. Pump mud push to rig floor w/Schlumberger pumps and overboard all H2O in lines via wash up line at floor. Pump a total of 27 bbls 11.5 ppg mud push down hole. At 03:35 start to pump 63.0 bbls class G tail slurry plus additives at 5.1 bpm. ICP - 590 psi, FCP - 333 psi. Shut down. Drop drill pipe wiper dart and note plug drop indicator trip. RU air and blow down through top drive and cement line to wash-up line. Bring pert pill to wash up line, close line and chase wiper dart w/ rig. Total displacement = 218 bbls. Pump 63 bbls 8.5 ppg FloPro mud ~ 5 bpm, 90 psi until catch cement. Slow to 3 bpm at 63 bbls away & see drill pipe wiper dart catch liner wiper plug ~ 86 bbls awav. and shear off at 2,200 psi. At 108 bbls away, reduce pump rate to 2 bpm forplug bump. See plugs bump landing collar as expected - 2015 strokes, 1404 psi.:Saw good liftin ressure throu hout dis lacement. No measureable losses during displacement. Cement in place at 04:30. Reci rocated i e in 20' strokes durin 'ob until 100 bbls of dis lacement awa . PU - 165k, SO - 130k. At plug bump bring pressure up to 3000 psi and hold f/3 mins to set liner hanger slips. 04:45 - 05:30 0.75 CASE P RUNPRD Setting hanger and packer after bumping plug. Pick up to 175k to set hanger in tension. Slack off entire string weight to 100k to check liner hanger. Hanger holding. Pressure to 3,500 psi. and hold for 3 minutes. Bleed off pressure to zero and check floats for bleedoff back to surface. Floats holding. Rotate 15 turns right to release C-2 running tool, pressure up to 1000 psi. PU until PBR packoff cleared liner top extension sleeve and pressure bled off to 400 psi. Circulate cement 20 bbls above liner top. PU rotating dog sub clear of liner top and slack off 100k. Rotate at 15 rpm. Slack off while rotating to set ZXP packer and see good indication of set. Repeat, and see no further indication. PU 20' to clear liner top w/stinger and put NOGG mark on drill pipe. Circulate 1.3 bottoms up at 490 gpm, 960 psi. Mudpush and 18 bbls of sidewalk cement seen at surface along with several bbls of contaminated cement strun out in mud. 05:30 - 07:00 1.50 CASE P RUNPRD Displace well from 8.5 ppg FloPro to 8.5 ppg brine. Printed: 9/Z/2008 17:bU::t4 ,4nn • • BP EXPLORATION Page 15 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 7ES Date From - To 'Hours Task Code NPT 8/20/2008 05:30 - 07:00 1.50 CASE P 07:00 - 07:30 0.50 CEMT P 07:30 - 08:00 0.50 CEMT P 08:00 - 10:00 2.00 CASE P 10:00 - 12:00 2.00 CASE P 12:00 - 12:30 0.50 CASE P 12:30 - 13:00 0.50 CASE P 13:00 - 20:30 7.50 EVAL P 20:30 - 21:30 1.001 CASE ~ P 21:30 - 22:30 I 1.001 PERFO~ P 22:30 - 00:00 1.50 PERFOB~ P 8/21/2008 100:00 - 01:30 1.50 ~ PERFOf3~ P 01:30 - 04:30 ~ 3.001 PERFOE3~ P 04:30 - 05:00 0.50 PERFOB~ P 05:00 - 05:30 0.50 PERFO P 05:30 - 06:00 I 0.501 PERFOBI P 06:00 - 06:15 0.25 PERFO P 06:15 - 11:00 4.75 PERFO P 11:00 - 11:30 0.501 PERFOB~ P 11:30 - 13:00 i 1.50 ~ PERFOB~ P 13:00 - 13:30 0.50 PERFO~ P 13:30 - 15:30 2.00 PERFO P 15:30 - 16:00 0.50 PERFO P Spud Date: 12/22/1982 Start: 8/4/2008 End: 8/22/2008 I Rig Release: 8/22/2008 Rig Number: 7ES Phase ~ Description of Operations RUNPRD 450 gpm, 1280 psi, 487 bbls pumped. RUNPRD Shut down and lay down cementing head and 1 single. RUNPRD Slip and cut 68' of drilling line. RUNPRD POH racking back stands from 8,583' to 2,400' md. RUNPRD POH laying down excess drill pipe from 2,400 to surface. RUNPRD Lay down running tools and inspect. Tattle tales dog sub sheared as expected. RUNPRD Service topdrive crown, and drawworks RUNPRD PJSM. Rig up Schlumberger E-Line. Log USIT cement bond log in 7" casin from 8 526' to 3 702' md. To of cement found at 4 980'. POH & RD E-Line. RUNPRD RU and pressure test 4.5" liner to 3,500 psi. Initial pressure 3525 psi, 15 minute pressure 3510 psi, 30 minute pressure 3503 psi -Pass. OTHCMP PJSM. RU &RIH with perforating guns to 970' md. Gun string consists of 37 fully loaded 20' guns, 7 partially loaded, and 1 blanks (none of the blanks w/ puncher charges) OTHCMP RU tubing handling equipment and RIH w/ 10 joints of 2-7/8" Fox tubing to 1,280' md. OTHCMP RIH on joints 11 - 42 of 2-7/8" Fox tubing to 2,276' md. RD tubing handling equipment. OTHCMP RIH on 89 stands of drillpipe from derrick and tag up on TD on depth at 10,773' md. PU - 170k, SO - 135k. OTHCMP RU to fire guns. PJSM w/ Schlumberger perforating hands. OTHCMP Pick up to upweight and 12' additional to bring guns on depth h t t 10 76 ' md. Clear surface equipment of air. Line up to pump down both sides. Close pipe rams. Send pressure sequence. Fire guns at 5 minutes after final bleed off. Well took initial 4 bbl loss. Perforated intervals: 9,820 - 9,920' and 9,940 - 10,030' and 10,060' - 10,310 and 10,340' - 10,760' and OTHCMP POH on stands from 10,760' - 9,730' and to clear bottom nose to above top perforation at 9,820' md. OTHCMP OTHCMP POH laying down drillpipe 1x1 to pipeshed from 9,730' - 3,033' md. OTHCMP RIH w/ remaining stands of drillpipe from derrick from 3,033' - 4,205' md. OTHCMP POH laying down drillpipe 1x1 to pipeshed from 4,205'to crossover to Fox tubing at 2,271' md. OTHCMP RU to handle 2-7/8" Fox tubing. OTHCMP Lay down 42 joints of Fox tubing from 2,271' - 963' md. OTHCMP PJSM. RU to lay down pert guns. 16:00 - 18:00 I 2.001 PERFOBI P OTHCMP ~ Lay down crossover, disconnect, firing head, and 45 pert guns. Clean and clear rig floor. Hole taking fluid 18:00 - 19:00 I 1.00 RUNCMP Pull wear bushing. Make dummy run w/ tubing hanger. Verify RKB to tubing spool flange = 25.18'. rnntea: ai[i[uuts ii:5u:sar+m • BP EXPLORATION Page 16 of 16 .Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES I Date From - To Hours Task Code NPT Phase j Description of Operations 8/21/2008 19:00 - 20:00 1.00 BUNCO RUNCMP RU 4.5", 13Cr80, 12.60#, Vam To tubin & com letion handling equipment w/"Torque Turn" torque contol equipment, 20:00 - 00:00 I 4.00 8/22/2008 00:00 - 05:30 5.50 05:30 - 07:00 I 1.50 07:00 - 10:00 I 3.00 10:00 - 11:30 I 1.501 RU recording unit, and compensator. RUNCMP MU tail pipe assembly to packer assembly and RIH w/ 4.5" 12.6# 13Cr80 Vam Top completion. Torque Turn set to 4,400 ft./Ibs optimum torque. RIH to 3,131' md. Hole taking fluid at less than 2 bbls/hr at 23:59. Hole took 24 bbls fluid for 24 hrs. RUNCMP Continue to RIH w/4.5" 12.6# 13Cr80 Vam Top Completion. Torque Turn set to 4400 ft./Ibs optimum torque. RIH and tag bottom of liner top extension sleeve. Hole taking fluid at 2 bbls/hr. RUNCMP Space out tubing as necessary to place WLEG into middle of PBR. Space out w/one pup jt below top joint of tubing. PU/MU landing joint w/hanger assy and land completion w/WLEG at 8 593" w/6' stun into Liner Top Extension Sleeve. Run in lock down screws per Cameron representative. Counted leftover jts 4.5" Vam Top and found 16 as expected. RUNCMP Hook up lines and reverse circulate 130 bbls of 8.5 ppg clean seawater followed by 90 bbls seawater w/corrosion inhibitor. Follow w/192 bbls clean seawater w/out corrosion inhibitor. Pumped at no more than 3 bpm to avoid eroding packer elements. RUNCMP Drop ball and rod to RHC plug. LD landing it. Close blind ram; and pressure down tubing against ball and rod 11:30 - 13:00 1.50 BOPSU P 13:00 - 17:00 4.00 WHSUR P 17:00 - 20:00 I 3.001 WHSUR I P 20:00 - 00:00 4.001 WHSUR ~ P Bleed tuom to 15UU si. rressure annuws to ~ouu ana recora test on chart for 30 mins. Bleed off annulus ressure to 0 si. Bleed off tubing to 0 psi. Pressure up on annulus and shear DCR shear valve at in GLM at 3,595' w/2200 psi. Pump both ways to ensure valve open. Install TWC and test to 1000 psi from below via annulus and sheared DCR valve. RUNCMP Nipple Down BOP stack & stand back on pedastool RUNCMP NU tree. Test adaptor, hanger, tree to 5000 psi. RU drill site maintenance and ull TWC w/lubricator. RUNCMP RU Hot Oil Services and pump 151 bbls 100 DegF diesel down IA while taking returns to surface via swab valve on tree taking returns directly to cuttings box. Shut in. Allow to U-tube to tubing. RD hoses. RUNCMP Install BPV w/DSM lubricator. Secure well. Prepare Bridle lines. Release rig at 23:59. Prepare f/move to DS 5-35. Printed: 9/2/2008 11:50:34 AM by ,~ ~~ t-< =_ ~, ~~~~~. D-22C Su Report Date: 19-Aug-08 Client: BP Exploration field: Prudhoe Bay Unit - WOA Structure /Slot: D-PAD / D-22 Well: D-22 Borehole: D-22C UWVAPI#: 500292073703 Survey Name /Date: D-22C /August 19, 2008 Tort /AHD / DDI / ERD ratio: 254.489° / 3350.68 ft / 6.011 / 0.371 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 70.29613049, W 148.75730761 Location Grid N/E Y/X: N 5959438.000 ftUS, E 653460.000 ttUS Grid Convergence Angle: +1.16995089° Grid Scale Factor: 0.99992675 Report Schlumberge~ Survey /DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 131.390° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 70.55 ft relative to MSL Base Flange Elevation: 43.13 ft relative to MSL Magnetic Declination: 23.061 ° Total Field Strength: 57676.691 nT Magnetic Dip: 80.903° Declination Date: August 10, 2008 Magnetic Declination Model: BGGM 2008 North Reference: True North Total Corr Mag North -> True North: +23.061 ° Comments Measured Inclination Azimuth SulrSea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de OOft ftUS ftUS Projected-up u.uu u.vu u.uv -iu .o5 u. vv u.uv v.uu u.vu ~.~~ v.w ~.~~ ~~~~yJO.~~ ~JJ~~~.~~ .. ~~.<~~IJ~~~ .. IYV. /J/JVIVI WRP 30.05 0.00 0.00 -40 .50 30. 05 0.00 0.00 0.00 0.00 0.00 0.00 5959438.00 653460.00 N 70.29613049 W 148. 75730761 SPERRY 1/19/83 AK- 82.05 2.13 50.60 21 .49 92. 04 0.18 1.15 1.15 0.73 0.89 3.44 5959438.75 653460.88 N 70.29613249 W 148. 75730040 BO-30007 GYRO 192.05 1.52 60.19 121 .43 191. 98 0.91 4.33 4.32 2.57 3.48 0.68 5959440.64 653463.42 N 70.29613751 W 148. 75727946 292.05 1.50 86.69 221 .40 291. 95 2.27 6.92 6.79 3.31 5.93 0.69 5959441.43 653465.87 N 70.29613952 W 148 .75725956 392.05 1.63 85.50 321 .36 391. 91 4.19 9.65 9.34 3.49 8.66 0.13 5959441.67 653468.59 N 70.29614003 W 148 .75723750 492.05 1.22 93.40 421 .33 491. 88 6.02 12.13 11.69 3.54 11.14 0.45 5959441.77 653471.06 N 70.29614016 W 148 .75721742 592.05 0.97 117.31 521 .32 591. 87 7.68 14.02 13.32 3.09 12.95 0.52 5959441.35 653472.89 N 70.29613893 W 148 .75720273 692.05 1.17 105.40 621 .30 691. 85 9.42 15.88 14.89 2.43 14.69 0.30 5959440.73 653474.64 N 70.29613713 W 148 .75718867 792.05 0.90 106.61 721 .28 791. 83 11.05 17.68 16.54 1.93 16.43 0.27 5959440.27 653476.38 N 70.29613577 W 148 .75717460 892.05 0.92 113.81 821 .27 891. 82 12.52 19.27 17.97 1.39 17.92 0.12 5959439.75 653477.88 N 70.29613427 W 148 .7571 992.05 1.10 111.61 921 .25 991. 80 14.19 21.03 19.55 0.71 19.54 0.18 5959439.11 653479.52 N 70.29613242 W 148 .75714 1092.05 0.75 114.20 1021 .24 1091. 79 15.72 22.65 21.03 0.09 21.03 0.35 5959438.52 653481.02 N 70.29613072 W 148 .75713733 1192.05 0.67 137.50 1121 .23 1191. 78 16.93 23.87 22.03 -0.61 22.02 0.30 5959437.84 653482.03 N 70.29612881 W 148 .75712930 1292.05 0.75 128.11 1221 .22 1291. 77 18.16 25.10 22.98 -1.45 22.93 0.14 5959437.02 653482.96 N 70.29612653 W 148 .75712193 1392.05 0.47 122.00 1321 .22 1391 .77 19.22 26.17 23.89 -2.07 23.80 0.29 5959436.42 653483.83 N 70.29612483 W 148 .75711495 1492.05 0.45 143.90 1421 .22 1491 .77 20.01 26.96 24.51 -2.60 24.38 0.18 5959435.89 653484.42 N 70.29612337 W 148 .75711026 1592.05 0.62 116.90 1521 .21 1591 .76 20.92 27.88 25.29 -3.17 25.09 0.30 5959435.35 653485.15 N 70.29612184 W 148 .75710448 1692.05 0.15 79.69 1621 .21 1691 .76 21.52 28.53 25.92 -3.39 25.70 0.51 5959435.14 653485.76 N 70.29612123 W 148 .75709953 1792.05 0.32 134.11 1721 .21 1791 .76 21.88 28.92 26.27 -3.56 26.03 0.26 5959434.97 653486.09 N 70.29612077 W 148 .75709686 1892.05 0.18 112.61 1821 .21 1891 .76 22.31 29.35 26.65 -3.81 26.38 0.17 5959434.73 653486.45 N 70.29612007 W 148 .75709407 1992.05 0.17 16.00 1921 .21 1991 .76 22.39 29.59 26.82 -3.73 26.56 0.26 5959434.81 653486.63 N 70.29612030 W 148 .75709256 SurveyEditor Ver SP 2.1 Bld( doc40x_100) D-22\D-22\D-22C\D-22C Generated 9/17/2008 3:38 PM Page 1 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure tt de de ft ft ft ft ft ft ft OOtt ftUS ftUS 'LU~J'L.Ub V.4V Z34.3U ZUZI.ZI LV~1./O LL.LD L~.yL CO.Oy -J./~ GO.JG V.J4 0~0~9J'k./o oOJYOOA.7 rv /V.caoicV~J vv IYO./J/VDYJJ 2192.05 0.32 249.50 2121.20 2191. 75 22.04 30.54 26.10 -4.09 25.77 0.12 5959434. 43 653485.85 N 70.29611930 W 148. 75709894 2292.05 0.18 338.20 2221.20 2291. 75 21.77 30.90 25.77 -4.05 25.45 0.36 5959434. 48 653485.53 N 70.29611944 W 148. 75710153 2392.05 0.60 56.50 2321.20 2391. 75 21.77 31.51 26.08 -3.61 25.83 0.59 5959434. 92 653485.90 N 70.29612062 W 148. 75709847 2492.05 1.08 89.69 2421.19 2491. 74 22.61 32.94 27.41 -3.32 27.21 0.66 5959435. 24 653487.27 N 70.29612143 W 148. 75708730 2592.05 1.17 86.19 2521.17 2591. 72 24.03 34.90 29.35 -3.24 29.17 0.11 5959435. 35 653489.23 N 7029612163 W 148. 75707142 2692.05 0.82 74.69 2621.16 2691. 71 25.14 36.63 31.02 -2.99 30.88 0.40 5959435. 64 653490.93 N 70.29612233 W 148. 75705759 2792.05 0.95 96.31 2721.15 2791. 70 26.21 38.16 32.52 -2.89 32.39 0.36 5959435. 77 653492.44 N 70.29612260 W 148. 75704533 2892.05 1.32 83.10 2821.13 2891. 68 27.66 40.13 34.48 -2.84 34.36 0.45 5959435. 86 653494.41 N 70.29612272 W 148. 75702940 2992.05 0.87 92.61 2921.11 2991. 66 29.02 42.04 36.37 -2.74 36.26 0.48 5959436. 00 653496.31 N 70.29612301 W 148. 75701400 3092.05 0.60 125.20 3021.10 3091. 65 30.13 43.29 37.58 -3.07 37.45 0.49 5959435 .69 653497.50 N 70.29612209 W 148. 757004 3192.05 0.72 124.11 3121.09 3191. 64 31.27 44.44 38.58 -3.73 38.40 0.12 5959435. 06 653498.46 N 70.29612030 W 148. 7569 3292.05 0.55 128.90 3221.09 3291. 64 32.38 45.55 39.54 -4.38 39.29 0.18 5959434 .42 653499.37 N 70.29611852 W 148. 75698 3392.05 0.52 166.00 3321.08 3391. 63 33.23 46.45 40.10 -5.12 39.78 0.34 5959433 .69 653499.87 N 70.29611649 W 148. 75698557 3492.05 0.70 166.81 3421.08 3491. 63 34.10 47.51 40.50 -6.16 40.02 0.18 5959432 .66 653500.14 N 70.29611366 W 148. 75698355 3592.05 0.50 163.31 3521.07 3591. 62 34.97 48.56 40.92 -7.17 40.29 0.20 5959431 .65 653500.42 N 70.29611090 W 148 .75698141 3692.05 0.32 171.61 3621.07 3691. 62 35.55 49.27 41.21 -7.87 40.46 0.19 5959430 .96 653500.60 N 70.29610900 W 148 .75698007 3792.05 0.65 166.50 3721.06 3791. 61 36.23 50.12 41.55 -8.69 40.63 0.33 5959430 .14 653500.79 N 70.29610674 W 148 .75697866 3892.05 0.50 155.81 3821.06 3891. 61 37.09 51.12 42.06 -9.64 40.94 0.18 5959429 .20 653501.13 N 70.29610414 W 148 .75697614 3992.05 0.55 147.40 3921.06 3991. 61 37.95 52.04 42.68 -10.45 41.38 0.09 5959428 .40 653501.58 N 70.29610195 W 148 .75697260 4042.05 2.08 135.61 3971.04 4041. 59 39.08 53.18 43.63 -11.30 42.14 3.09 5959427 .57 653502.36 N 70.29609963 W 148 .75696642 4092.05 3.82 127.70 4020.97 4091. 52 41.65 55.75 45.96 -12.96 44.09 3.57 5959425 .94 653504.35 N 70.29609507 W 148 .75695061 4142.05 5.75 129.61 4070.80 4141. 35 45.82 59.92 49.84 -15.58 47.34 3.87 5959423 .39 653507.65 N 70.29608793 W 148 .75692431 4192.05 7.47 126.70 4120.46 4191. 01 51.56 65.67 55.29 -19.12 51.88 3.50 5959419 .95 653512.25 N 70.29607826 W 148 .75688759 Tie-In Survey 4192.05 7.47 126.70 4120.46 4191. 01 51.56 65.67 55.29 -19.12 51.88 0.00 5959419 .95 653512.25 N 70.29607826 W 148 .75688759 Top Whipstock 4211.00 7.73 124.99 4139.25 4209. 80 54.06 68.18 57.71 -20.59 53.91 1.82 5959418 .52 653514.31 N 70.29607425 W 148 .75687114 (In+Trend) Base Whipstock 4228.00 9.30 116.00 4156.06 4226. 61 56.52 70.69 60.18 -21.84 56.08 12.08 5959417 .31 653516.51 N 70.29607081 W 148 .75685355 4245.88 9.19 116.00 4173.71 4244. 26 59.29 73.57 63.05 -23.10 58.66 0.62 5959416 .10 653519.12 N 70.29606737 W 148 .75683265 7 4299.81 7.23 91.05 4227.10 4297. 65 66.03 81.15 70.53 -25.05 65.93 7.45 5959414 .30 653526.42 N 70.29606204 W 148 .756 4396.48 6.04 46.23 4323.18 4393 .73 71.10 91.77 78.72 -21.64 75.69 5.35 5959417 .91 653536.11 N 70.29607136 W 148 .75669478 MWD+IFR+MS 4491.56 3.21 2.50 4417.97 4488 .52 69.85 99.10 80.92 -15.52 79.42 4.55 5959424 .10 653539.72 N 70.29608808 W 148 .75666458 4587.43 6.64 261.70 4513.59 4584 .14 64.57 105.64 75.29 -13.64 74.04 8.24 5959425 .88 653534.30 N 70.29609323 W 148 .75670811 4682.63 10.32 276.55 4607.75 4678 .30 54.00 119.60 61.61 -13.46 60.12 4.47 5959425 .77 653520.38 N 70.29609372 W 148 .75682085 4777.84 10.81 301.40 4701.39 4771 .94 38.20 136.79 44.71 -7.83 44.02 4.78 5959431 .07 653504.17 N 70.29610909 W 148 .75695122 4873.03 14.38 309.66 4794.28 4864 .83 17.59 157.51 27.64 4.37 27.29 4.19 5959442 .92 653487.20 N 70.29614242 W 148 .75708664 4969.78 19.93 313.55 4886.69 4957 .24 -10.92 186.03 24.19 23.41 6.08 5.85 5959461 .53 653465.60 N 70.29619445 W 148 .75725843 5064.29 21.08 316.04 4975.22 5045 .77 -43.96 219.13 49.88 46.75 -17.40 1.53 5959484 .38 653441.65 N 70.29625820 W 148 .75744848 5161.84 20.11 305.05 5066.57 5137 .12 -78.13 253.35 81.48 69.01 -43.32 4.08 5959506 .11 653415.29 N 70.29631903 W 148 .75765832 5258.53 21.57 298.75 5156.94 5227 .49 -112.00 287.72 113.34 87.11 -72.51 2.76 5959523 .61 653385.73 N 70.29636847 W 148 .75789471 5353.40 19.08 300.59 5245.90 5316 .45 -144.25 .320.67 144.65 103.39 -101.15 2.71 5959539.30 653356.76 N 70.29641295 W 148 .75812661 SurveyEditor Ver SP 2.1 Bld( doc40x_100) D-22\D-22\D-22C\D-22C Generated 9/17/2008 3:38 PM Page 2 of 5 Comments Measured Inclination Azimuth Sul>.Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft tt ft tt tt ft ft de 00 ft ftUS ftUS 544~.iib 1i5.yJ 3VZ. 4U b3J0.14 D4Vb.b`J -I/4. 6/ 3~1./O 1/4.~J 11. 03 -IL/. 00 V.04 a.7a~aa9..7.7 OJJJG.7.~Y Iv /V.GAVYO/JV vv IYO./OOJVI IJ 5544.31 19.38 299. 54 5426.32 5496.87 -205. 66 383.07 205.66 135. 74 -154. 51 1.09 5959570.54 653302.76 N 70. 29650130 W 148. 75855862 5639.64 19.80 301. 20 5516.13 5586.68 -237. 03 415.03 237.12 151. 90 -182. 08 0.73 5959586.14 653274.87 N 70. 29654545 W 148. 75878186 5734.40 18.49 303. 64 5605.65 5676.20 -267. 72 446.10 267.96 168. 54 -208. 32 1.62 5959602.24 653248.30 N 70. 29659091 W 148. 75899432 5830.43 18.60 305. 43 5696.70 5767.25 -298. 04 476.64 298.42 185. 85 -233. 48 0.60 5959619.03 653222.80 N 70. 29663821 W 148. 75919801 5925.82 19.29 311. 79 5786.93 5857.48 -328. 93 507.58 329.34 205. 17 -257. 62 2.28 5959637.85 653198.26 N 70. 29669099 W 148. 75939352 6023.55 19.75 313. 77 5879.04 5949.59 -361. 57 540.23 361.91 227. 35 -281. 58 0.82 5959659.54 653173.86 N 70. 29675158 W 148. 75958752 6119,80 19.75 313. 50 5969.63 6040.18 -394. 07 572.76 394.33 249. 80 -305. 12 0.09 5959681.50 653149.86 N 70. 29681289 W 148. 75977812 6212.61 19.48 311. 44 6057.05 6127.60 -425. 22 603.91 425.44 270. 83 -328. 10 0.80 5959702.06 653126.47 N 70. 29687036 W 148. 75996416 6309.02 18.76 309. 76 6148.15 6218.70 -456. 79 635.49 457.01 291. 39 -352. 07 0.94 5959722.12 653102.08 N 70. 29692651 W 148. 76015824 6404.20 19.37 316. 74 6238.12 6308.67 -487. 81 666.54 487.99 312. 67 -374. 65 2.48 5959742.94 653079.07 N 70. 29698466 W 148. 7603 6498.93 18.23 316. 58 6327.79 6398.34 -518. 21 697.07 518.31 334. 88 -395. 60 1.20 5959764.71 653057.67 N 70. 29704532 W 148. 4 76051 6593.52 20.94 312. 68 6416.90 6487.45 -549. 85 728.76 549.91 357. 09 -418. 20 3.18 5959786.45 653034.62 N 70. 29710599 W 148. 76069 6689.76 20.00 312. 42 6507.07 6577.62 -583. 50 762.42 583.55 379. 85 -443. 00 0.98 5959808.70 653009.37 N 70. 29716817 W 148. 76089453 6783.00 19.03 312. 24 6594.95 6665.50 -614. 64 793.57 614.68 400. 82 -466. 02 1.04 5959829.19 652985.93 N 70. 29722547 W 148. 76108098 6880.37 20.58 308. 52 6686.56 6757.11 -647 .61 826.55 647.66 422. 15 -491. 17 2.05 5959850.01 652960.35 N 70. 29728374 W 148. 76128458 6976.96 19.29 308. 12 6777.36 6847.91 -680 .49 859.48 680.56 442. 58 -517. 00 1.34 5959869.90 652934.11 N 70. 29733953 W 148. 76149377 7072.31 21.09 308. 53 6866.85 6937.40 -713 .35 892.38 713.45 462. 99 -542. 81 1.89 5959889.77 652907.89 N 70. 29739528 W 148. 76170279 7166.54 22.68 310. 59 6954.29 7024.84 -748 .45 927.50 748.56 485. 37 -569. 88 1.87 5959911.60 652880.38 N 70. 29745642 W 148. 76192191 7263.45 21.55 307. 92 7044.07 7114.62 -784 .90 963.98 785.03 508. 47 -598. 11 1.56 5959934.11 652851.68 N 70. 29751951 W 148. 76215051 7358.40 20.97 309. 85 7132.56 7203.11 -819 .29 998.41 819.44 530. 07 -624. 91 0.96 5959955.16 652824.45 N 70. 29757853 W 148. 76236753 7454.37 20.17 308. 70 7222.41 7292.96 -852 .99 1032.12 853.15 551. 42 -651. 00 0.93 5959975.97 652797.92 N 70. 29763685 W 148. 76257885 7549.80 19.52 307. 92 7312.17 7382.72 -885 .34 1064.52 885.53 571. 50 -676. 42 0.74 5959995.53 652772.10 N 70. 29769171 W 148. 76278468 7645.57 21.24 305. 46 7401.94 7472.49 -918 .57 1097.87 918.81 591. 40 -703. 18 2.01 5960014.88 652744.95 N 70. 29774607 W 148. 76300133 7741.74 21.19 305. 94 7491.60 7562.15 -953 .19 1132.67 953.51 611. 71 -731. 44 0.19 5960034.60 652716.28 N 70. 29780154 W 148. 76323018 7836.89 21.29 307. 86 7580.28 7650.83 -987 .55 1167.13 987.93 632. 41 -759. 00 0.74 5960054.73 652688.31 N 70. 29785807 W 148. 76345336 7935.02 20.96 308. 07 7671.82 7742.37 -1022 .86 1202.50 1023.28 654. 16 -786. 88 0.35 5960075.91 652659.99 N 70. 29791750 W 148. 76367915 8028.96 20.06 305 .70 7759.80 7830.35 -1055 .66 1235.41 1056.15 673. 92 -813. 19 1.30 5960095.13 652633.28 N 70. 29797148 W 148. 76389222 8124.08 19.43 306 .77 7849.33 7919.88 -1087 .67 1267.54 1088.23 692. 91 -839. 11 0.76 5960113.59 652606.98 N 70. 29802335 W 148. 7641 8220.56 18.73 305 .18 7940.51 8011.06 -1119 .06 1299.08 1119.70 711. 45 -864. 63 0.90 5960131.59 652581.09 N 70. 29807397 W 148. 7643 8315.00 17.99 306 .32 8030.14 8100.69 -1148 .66 1328.83 1149.39 728. 82 -888. 77 0.87 5960148.47 652556.60 N 70 .29812143 W 148. 76450428 8411.14 17.84 306 .06 8121.62 8192.17 -1178 .11 1358.40 1178.92 746. 28 -912. 64 0.18 5960165.44 652532.38 N 70 .29816912 W 148. 76469755 8506.53 16.87 306 .04 8212.67 8283.22 -1206 .45 1386.85 1207.33 763. 03 -935. 65 1.02 5960181.71 652509.04 N 70 .29821486 W 148. 76488385 8602.96 17.87 309 .82 8304.70 8375.25 -1235 .17 1415.63 1236.10 780. 73 -958 .32 1.56 5960198.95 652486.01 N 70 .29826323 W 148. 76506750 8680.39 17.21 309 .07 8378.53 8449.08 -1258 .49 1438.97 1259.43 795. 56 -976 .34 0.90 5960213.40 652467.69 N 70 .29830373 W 148. 76521342 7" C~ 8739'md 8742.62 16.91 308 .20 8438.02 8508.57 -1276 .72 1457.22 1277.69 806 .96 -990 .60 0.63 5960224.51 652453.20 N 70 .29833487 W 148. 76532890 8775.11 18.78 307 .80 8468.95 8539.50 -1286 .66 1467.18 1287.64 813 .09 -998 .45 5.77 5960230.47 652445.23 N 70 .29835161 W 148. 76539244 8806.41 21.94 307 .22 8498.29 8568.84 -1297 .53 1478.07 1298.52 819 .72 -1007 .09 10.12 5960236.92 652436.46 N 70 .29836971 W 148. 76546241 8838.45 24.35 308 .97 8527.75 8598.30 -1310.10 1490.66 1311.11 827 .49 -1016 .99 7.82 5960244.49 652426.40 N 70 .29839095 W 148. 76554261 8870.61 26.72 311 .37 8556.77 8627.32 -1323 .95 1504.52 1324.97 836 .44 -1027 .57 8.04 5960253.23 652415.64 N 70 .29841539 W 148 .76562830 8901.54 29.76 314 .40 8584.01 8654.56 -1338 .58 1519.15 1339.57 846 .41 -1038 .28 10.86 5960262.97 652404.73 N 70 .29844262 W 148 .76571501 SurveyEditor Ver SP 2.1 Bld( doc40x_100) D-22\D-22\D-22C\D-22C Generated 9/17/2008 3:38 PM Page 3 of 5 Comments Measured Inclination Azimuth SulrSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft it ft ft ft ft de 00 ft ftUS ftUS tSy:i:i.:iU .i1.`J:i :il /.i55 2Sb11.14 i3btll.by -IJbJ. V3 15:Sb.b/ 13JJ. ~b bbO. J3 -IUwa./ I i I.w/ .7~OVG/4. 00 OaGJ.7J.V0 ~v /t/.cyow/oio vv IwO./VJOV/VV 8965.57 36.47 318.09 8637.66 8708.21 -1373. 28 1554.03 1374. 12 871. 97 -1062.00 10.98 5960288. 05 652380.49 N 70.29851245 W 148. 76590715 8997.99 38.53 317.98 8663.38 8733.93 -1392. 88 1573.77 1393. 63 886. 65 -1075.20 6.36 5960302. 45 652367.00 N 70.29855254 W 148. 76601402 9029.54 41.86 316.12 8687.48 8758.03 -1413. 14 1594.13 1413. 82 901. 54 -1089.08 11.22 5960317. 05 652352.82 N 70.29859322 W 148. 76612642 9062.10 43.43 316.02 8711.43 8781.98 -1435. 12 1616.18 1435. 73 917. 43 -1104.38 4.83 5960332. 62 652337.20 N 70.29863661 W 148. 76625036 9094.99 46.01 315.08 8734.80 8805.35 -1458. 20 1639.32 1458. 76 933. 94 -1120.59 8.10 5960348. 80 652320.66 N 70.29868172 W 148. 76638162 9125.94 48.28 315.27 8755.85 8826.40 -1480. 84 1662.01 1481. 35 950. 03 -1136.58 7.35 5960364. 56 652304.34 N 70.29872568 W 148. 76651114 9158.08 50.55 315.19 8776.76 8847.31 -1505. 19 1686.42 1505. 65 967. 36 -1153.77 7.07 5960381. 53 652286.80 N 70.29877300 W 148. 76665035 9189.61 53.51 314.17 8796.15 8866.70 -1530. 00 1711.27 1530. 42 984. 83 -1171.45 9.73 5960398. 64 652268.78 N 70.29882073 W 148. 76679350 9220.85 56.12 312.63 8814.15 8884.70 -1555. 52 1736.80 1555. 91 1002. 37 -1190.00 9.27 5960415. 79 652249.87 N 70.29886863 W 148. 76694375 9252.90 59.15 311.14 8831.31 8901.86 -1582. 58 1763.87 1582. 96 1020. 44 -1210.16 10.24 5960433. 44 652229.35 N 70.29891798 W 148. 7671 9284.81 62.39 309.79 8846.89 8917.44 -1610. 42 1791.71 1610. 80 1038. 50 -1231.34 10.80 5960451. 07 652207.81 N 70.29896732 W 148. 0 7672 9316.18 65.82 309.02 8860.59 8931.14 -1638. 62 1819.93 1639. 02 1056. 41 -1253.14 11.15 5960468. 53 652185.64 N 70.29901624 W 148. 76745514 9347.93 69.26 308.48 8872.71 8943.26 -1667. 93 1849.26 1668. 35 1074. 77 -1276.03 10.95 5960486. 42 652162.39 N 70.29906639 W 148. 76764044 9382.10 71.27 306.34 8884.25 8954.80 -1700. 01 1881.43 1700. 47 1094. 31 -1301.57 8.33 5960505. 42 652136.46 N 70.29911974 W 148. 76784734 9413.75 71.88 303.23 8894.26 .8964.81 -1729. 83 1911.45 1730. 37 1111. 43 -1326.23 9.52 5960522. 04 652111.45 N 70.29916652 W 148. 76804704 9445.27 71.42 301.66 8904.18 8974.73 -1759. 38 1941.37 1760. 03 1127. 48 -1351.48 4.95 5960537. 57 652085.89 N 70.29921036 W 148. 76825150 9475.78 71.63 298.33 8913.85 8984.40 -1787. 75 1970.31 1788. 54 1141. 95 -1376.53 10.37 5960551. 52 652060.54 N 70.29924986 W 148. 76845443 9507.43 72.54 295.25 8923.59 8994.14 -1816. 88 2000.42 1817. 91 1155 .52 -1403.41 9.70 5960564. 54 652033.39 N 70.29928692 W 148. 76867212 9538.96 75.63 294.22 8932.24 9002.79 -1845. 93 2030.74 1847. 24 1168 .20 -1430.95 10.29 5960576. 65 652005.60 N 70.29932155 W 148. 76889512 9571.92 78.17 291.20 8939.71 9010.26 -1876. 33 2062.84 1878. 04 1180 .59 -1460.56 11.79 5960588. 43 651975.75 N 70.29935538 W 148. 76913491 9602.76 80.83 289.14 8945.33 9015.88 -1904. 59 2093.16 1906. 77 1191 .04 -1489.02 10.84 5960598. 30 651947.09 N 70.29938392 W 148. 76936539 9635.23 82.45 287.04 8950.05 9020.60 -1934. 10 2125.28 1936. 87 1201 .01 -1519.55 8.11 5960607. 65 651916.36 N 70.29941114 W 148. 76961267 9666.63 85.24 285.64 8953.42 9023.97 -1962. 38 2156.50 1965. 85 1209 .79 -1549.51 9.93 5960615 .81 651886.23 N 70.29943512 W 148 .76985525 9689.75 86.92 287.32 8955.00 9025.55 -1983. 29 2179.56 1987. 33 1216 .34 -1571.63 10.26 5960621 .90 651863.99 N 70.29945298 W 148 .77003436 9721.42 90.01 287.87 8955.84 9026.39 -2012. 26 2211.22 2017 .08 1225 .91 -1601.80 9.91 5960630 .85 651833.63 N 70.29947910 W 148 .77027872 9753.75 88.74 285.30 8956.20 9026.75 -2041. 60 2243.55 2047 .32 1235 .13 -1632.78 8.87 5960639 .45 651802.47 N 70.29950429 W 148 .77052960 9786.47 87.86 284.83 8957.17 9027.72 -2070. 91 2276.25 2077 .67 1243 .63 -1664.36 3.05 5960647 .30 651770.72 N 70.29952750 W 148 .77078536 9818.36 89.80 283.01 8957.82 9028.37 -2099. 20 2308.13 2107 .09 1251 .30 -1695.30 8.34 5960654 .33 651739.63 N 70.29954843 W 148 .7710 9850.51 90.90 283.95 8957.62 9028.17 -2127 .61 2340.28 2136 .73 1258 .80 -1726.57 4.50 5960661 .19 651708.22 N 70.29956888 W 148 .7712 9881.29 90.66 283.69 8957.20 9027.75 -2154 .89 2371.06 2165 .24 1266 .15 -1756.45 1.15 5960667 .93 651678.19 N 70.29958895 W 148 .77153116 9913.58 90.90 286.32 8956.76 9027.31 -2183 .81 2403.35 2195 .45 1274 .51 -1787.64 8.18 5960675 .65 651646.85 N 70.29961176 W 148 .77178369 9945.76 91.31 282.18 8956.14 9026.69 -2212 .44 2435.52 2225 .47 1282 .42 -1818.81 12.93 5960682 .93 651615.52 N 70.29963337 W 148 .77203618 9977.42 90.42 281.90 8955.67 9026.22 -2240 .03 2467.18 2254 .61 1289 .03 -1849.77 2.95 5960688 .90 651584.43 N 70.29965139 W 148 .77228690 10009.20 88.98 277.74 8955.83 9026.38 -2267 .10 2498.95 2283 .43 1294 .45 -1881.08 13.85 5960693 .67 651553.03 N 70.29966618 W 148 .77254043 10041.19 89.49 277.82 8956.26 9026.81 -2293 .74 2530.94 2312 .04 1298 .78 -1912.77 1.61 5960697 .36 651521.25 N 70.29967798 W 148 .77279708 10072.47 90.11 276.88 8956.37 9026.92 -2319 .66 2562.22 2339 .99 1302 .78 -1943.80 3.60 5960700 .72 651490.16 N 70.29968889 W 148 .77304830 10104.28 91.17 276.28 8956.01 9026.56 -2345 .77 2594.03 2368 .32 1306 .42 -1975.39 3.83 5960703 .72 651458.49 N 70.29969883 W 148 .77330419 10136.51 92.28 278.47 8955.04 9025.59 -2372 .48 2626.24 2397 .28 1310 .56 -2007.34 7.62 5960707 .20 651426.47 N 70.29971010 W 148 .77356290 10166.37 89.90 276.96 8954.47 9025.02 -2397 .32 2656.10 2424 .28 1314 .56 -2036.92 9.44 5960710 .61 651396.82 N 70.29972103 W 148 .77380245 10199.37 89.29 275.98 8954.71 9025.26 -2424 .37 2689.09 2453 .89 1318 .28 -2069.71 3.50 5960713 .65 651363.96 N 70.29973116 W 148 .77406798 SurveyEditor Ver SP 2.1 Bld( doc40x_100) D-22\D-22\D-22C\D-22C Generated 9/17/2008 3:38 PM Page 4 of 5 Comments Measured Inclination Azimuth Subsea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft tt tt ft ft de OOtt ftUS ftUS 1 VL3U.bb aa.ao cio.au aaoo.uc yVLOA/ -G4aV.VV ucv.oo LYOL.VG ioc i.ii -c ~vv. ov c.i~ uovvi ~v. .'v 10263.81 91.35 276.86 8954.76 9025.31 -2477.30 2753.53 2512.02 1325.71 -2133. 72 5.40 5960719 .77 10296.10 91.96 278.22 8953.83 9024.38 -2504.11 2785.81 2541.47 1329.94 -2165. 71 4.61 5960723 .35 10327.61 90.18 276.42 8953.24 9023.79 -2530.20 2817.31 2570.23 1333.96 -2196. 96 8.03 5960726 .72 10358.75 90.90 277.82 8952.94 9023.49 -2555.93 2848.45 2598.67 1337.82 -2227. 85 5.06 5960729 .95 10390.80 89.66 276.88 8952.79 9023.34 -2582.49 2880.50 2628.06 1341.92 -2259. 64 4.85 5960733 .40 10422.44 89.46 277.28 8953.03 9023.58 -2608.62 2912.14 2657.08 1345.82 -2291. 04 1.41 5960736 .66 10454.47 90.11 277.99 8953.15 9023.70 -2635.25 2944.17 2686.64 1350.07 -2322. 78 3.01 5960740 .26 10486.43 90.21 277.72 8953.06 9023.61 -2661.89 2976.13 2716.23 1354.44 -2354. 44 0.90 5960743 .98 10518.16 90.04 277.91 8952.99 9023.54 -2688.33 3007.86 2745.66 1358.75 -2385. 88 0.80 5960747 .66 10550.90 89.66 277.30 8953.08 9023.63 -2715.54 3040.60 2776.03 1363.09 -2418. 33 2.20 5960751 .33 10582.60 90.01 278.24 8953.17 9023.72 -2741.94 3072.30 2805.52 1367.37 -2449. 74 3.16 5960754 .97 10613.05 90.76 278.24 8952.96 9023.51 -2767.43 3102.74 2833.98 1371.74 -2479. 87 2.46 5960758 .72 10646.58 90.42 278.40 8952.62 9023.17 -2795.53 3136.27 2865.38 1376.59 -2513. 05 1.12 5960762 .89 10677.44 89.83 277.51 8952.55 9023.10 -2821.28 3167.13 2894.26 1380.86 -2543. 61 3.46 5960766 .53 10709.60 90.28 278.67 8952.52 9023.07 -2848.16 3199.29 2924.42 1385.38 -2575. 45 3.87 5960770 .41 10743.12 90.04 276.96 8952.43 9022.98 -2876.09 3232.81 2955.85 1389.94 -2608. 66 5.15 5960774 .29 10774.83 89.56 277.74 8952.54 9023.09 -2902.36 3264.52 2985.53 1394.00 -2640. 11 2.89 5960777 .70 Last Survey 10809.54 88.84 276.58 8953.02 9023.57 -2931.06 3299.23 3018.03 1398.32 -2674. 54 3.93 5960781 .32 TD (Projected) 10861.00 88.84 276.58 8954.06 9024.61 -2973.30 3350.68 3066.11 1404.22 -2725. 65 0.00 5960786 .17 Survey Type: Definitive Survey NOTES: BOSS GYRO - (Sperry-Sun BOSS gyro multishot -- Sperry Sun BOSS muttishot surveys ) INC+TREND - (Inclinometer + known azi trend --Inclination only surveys in nea r-vertical hole-where formation dip and experience enables direction of drift to be predicted. Replaces ex-BP "Inclinometer (azimuth in known quadrant)" model. MWD + IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processi ng. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) ( ftUSl Easting (X) (ftUSl Surface : 3729 FSL 1692 FEL S23 Ti 1 N R13E UM 5959438.00 653460.00 BHL : 5133 FSL 441 6 FEL S23 T11 N R13E UM 5960786.17 650706.45 651299.82 N 70.29975140 W 148.77458631 651267.75 N 70.29976294 W 148.77484543 651236.43 N 70.29977388 W 148.77509846 651205.46 N 70.29978440 W 148.77534868 651173.60 N 70.29979557 W 148.77560608 651142.14 N 70.29980620 W 148.77586035 651110.31 N 70.29981780 W 148.77611744 651078.57 N 70.29982971 W 148.77637383 651047.06 N 70.29984147 W 148.77662840 651014.53 N 70.29985328 W 148.77689 650983.04 N 70.29986496 W 148.77714 650952.82 N 70.29987685 W 148.77738960 650919.56 N 70.29989007 W 148.77765827 650888.92 N 70.29990171 W 148.77790578 650857.00 N 70.29991405 W 148.77816362 650823.70 N 70.29992647 W 148.77843255 650792.18 N 70.29993752 W 148.77868724 650757.67 N 70.29994931 W 148.77896610 650706.45 N 70.29996536 W 148.77938002 s SurveyEditor Ver SP 2.1 Bld( doc40x_100) D-22\D-22\D-22C\D-22C Generated 9/17/2008 3:38 PM Page 5 of 5 NELLHEAD = MCEVOY 1GTUATOR = OTIS CB. ELEV - 70.55' 3F. ELEV COP _ L _ - ~ ~Aax-Angle = 92° @ 10137 Yatum MD = 9196' )atum TV D = 8800' SS 9-5/8" CSG, 47#, L-80, BTC, ID = 8.681" 2089' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2684' Minimum ID = 3.725" @ 8581' 4-1 /2" HES XN NIPPLE TOP OF WHIPSTOCK 4150' 9-5/8" CSG, 47#, L-80, ID = 8.681 " H 4211' 9-518" Ezsv ~--I 4235' D-22C 9-5/8" x 7" ZXP LTP, ID = MILLOUT WINDOW (D-22C#) 4211' - 4227' I 8443' ~4-1/2" HES X NIP, ID = 3.813" I4-1/2" TBG, 12.6#, 13CR80, VAM TOP, ID = 3.958" ( 4-1/2" TBG, 12.6#, 13CR80, TCII, ID = 3.958" PERFORATION SUMMARY REF LOG : A NGLE AT TOP PEFtF: 90° @ 9$20' Note : Refer to Production DB f or historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9820-9920 O 08/21/08 2-7/8" 6 9940 - 10030 O 08/21 /08 2-7/8" 6 10060 - 10310 O 08/21/08 2-7/8" 6 10340 - 10760 O 08/21/08 17" LNR, 26#, L-80, BTGM, ID = 6.276" I ~4-1/2" LNR, 12.6#, L-80, IBT-M, ID = 3.958" ~ 8561' 8593' I 8739' I I 10860' I 8516' 7" x 4-1/2" BKR S-3 PKR, ID = 3.87" 8550' 4-1/2" HES X NIP, ID - 3.813" 8581' 4-1/2" HES XN NIP, ID = 3.725" 8583' 7" x 4-1/2" HR ZXP LTP, ID = 4.46" 8593' 4-1/2" WLEG, ID = 3.958" 8600' 7" x 5" BKR HMC LNR HGR, ID = 4.45" 8610' 5" x 4-1/2" XO, ID = 3.93" DATE REV BY COMMENTS DATE REV BY COMMENTS 01111/83 ORIGINAL COMPLETION 12/03/97 PARKER SIDETRACK (D-22A) 06/14/02 JDM/KA RIG SIDETRACK (D-226) 08123/08 N7ES SIDETRACK(D-22C) SA~NOTES: ***4-1 /2" CHROME TUBING"`** 2077' ~ 9-5/8" HES ES CEMENTER 21 $$' 4-1/2" HES X NIP, ID = 3.813" C;A S I IFf MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 1 3595 6435 3595 6338 0 19 MMG1 MMG1 DCR DMY BEK BK 0 0 08/20/08 08/20/08 PRUDHOE BAY UNff WELL: D-22C PERMIT No: '2081210 API No: 50-029-20737-03 SEC 23, 711 N, R13E, 1550' SNL & 1692' WEL BP 6cploration (Alaska) ~' ~~ 1 4~ C~' ^--- r SCHLUMBERGER Survey report Client ...................: BP Exploration Alaska Inc. Field ....................: Prudhoe Bay Well .....................: D-22C API number ...............: 50-029-20737-03 Engineer .................: S. Fell COUNTY :..................: Nabors 7ES STATE :.................... Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 41.83 ft KB above permanent.......: N/A ft DF above permanent.......: 70.55 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 295.69 degrees [(c)2008 IDEAL ID13_OC_10] 19-Aug-2008 13:53:49 Page 1 of 7 Spud date ................: 10-Aug-08 Last survey date.........: 19-Aug-08 Total accepted surveys...: 162 MD of first survey.......: 0.00 ft MD of last survey........: 10809.54 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2008 Magnetic date ............: 10-Aug-2008 Magnetic field strength..: 57677.97 GAMA Magnetic dec (+E/W-).....: 23.06 degrees Magnetic dip .............: 80.90 degrees ----- MWD survey Reference Criteria --------- Reference G ..............: 1002.00 meal Reference H ..............: 57678.00 GAMA Reference Dip ............: 80.90 degrees Tolerance of G...........: (+/-) 2.50 meal Tolerance of H...........: (+/-)300.00 GAMA Tolerance of Dip.........: (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.06 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.06 degrees (Total az corr = magnetic dec - grid cony) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • C~ .Y SCHLUMBERGER Survey Report 19-Aug-2008 13:53:49 Page 2 of 7 --- Seq -------- Measured ------ Incl ------- Azimuth ------ Course -------- TVD -- Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (f t) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 1 -------- 0.00 ------ 0.00 ------- 0.00 ------ 0.00 - 0.00 0.00 0.00 0.00 0.00 0.00 0.00 BP_ LTNKNOWN 2 30.05 0.00 0.00 30.05 30.05 0.00 0.00 0.00 0.00 0.00 0.00 BP_ iJNKNOWN 3 92.05 2.13 50.60 62.00 92.04 -0.49 0.73 0.89 1.15 50.60 3.44 BP_ BOSS GYRO 4 192.05 1.52 60.19 100.00 191.98 -2.02 2.57 3.48 4.32 53.53 0.68 BP_ BOSS GYRO 5 292.05 1.50 86.69 100.00 291.95 -3.92 3.31 5.93 6.79 60.89 0.69 BP_ BOSS GYRO 6 392.05 1.63 85.50 100.00 391.91 -6.29 3.49 8.66 9.34 68.04 0.13 BP_ BOSS GYRO 7 492.05 1.22 93.40 100.00 491.88 -8.50 3.54 11.14 11.69 72.37 0.45 BP_ BOSS GYRO 8 592.05 0.97 117.31 100.00 591.86 -10.33 3.09 12.95 13.32 76.59 0.52 BP_ BOSS GYRO 9 692.05 1.17 105.40 100.00 691.85 -12.19 2.43 14.69 14.89 80.61 0.30 BP_ BOSS GYRO 10 792.05 0.90 106.61 100.00 791.83 -13.97 1.93 16.43 16.54 83.28 0.27 BP_ BOSS GYRO 11 892.05 0.92 113.81 100.00 891.82 -15.54 1.39 17.92 17.97 85.58 0.12 BP_ BOSS GYRO 12 992.05 1.10 111.61 100.00 991.80 -17.30 0.71 19.54 19.55 87.92 0.18 BP_ BOSS GYRO 13 1092.05 0.75 114.20 100.00 1091.79 -18.92 0.09 21.03 21.03 89.77 0.35 BP_ BOSS GYRO 14 1192.05 0.67 137.50 100.00 1191.78 -20.11 -0.61 22.02 22.03 91.59 0.30 BP_ BOSS GYRO 15 1292.05 0.75 128.11 100.00 1291.77 -21.29 -1.45 22.93 22.98 93.61 0.14 BP_ BOSS GYRO 16 1392.05 0.47 122.00 100.00 1391.77 -22.34 -2.07 23.80 23.89 94.97 0.29 BP_ BOSS GYRO 17 1492.05 0.45 143.90 100.00 1491.77 -23.09 -2.60 24.38 24.51 96.10 0.18 BP_ BOSS GYRO 18 1592.05 0.62 116.90 100.00 1591.76 -23.98 -3.17 25.09 25.29 97.19 0.30 BP_ BOSS GYRO 19 1692.05 0.15 79.69 100.00 1691.76 -24.63 -3.39 25.70 25.92 97.51 0.51 BP _BOSS GYRO 20 1792.05 0.32 134.11 100.00 1791.76 -25.00 -3.56 26.03 26.27 97.78 0.26 BP _BOSS GYRO 21 1892.05 0.18 112.61 100.00 1891.76 -25.42 -3.81 26.38 26.65 98.23 0.17 BP _BOSS GYRO • 22 1992.05 0.17 16.00 100.00 1991.76 -25.55 -3.73 26.56 26.82 98.00 0.26 BP _BOSS GYRO 23 2092.05 0.40 234.30 100.00 2091.76 -25.36 -3.79 26.32 26.59 98.20 0.54 BP _BOSS GYRO 24 2192.05 0.32 249.50 100.00 2191.75 -25.00 -4.09 25.77 26.10 99.02 0.12 BP _BOSS GYRO 25 2292.05 0.18 338.20 100.00 2291.75 -24.69 -4.05 25.45 25.77 99.03 0.36 BP _BOSS GYRO 26 2392.05 0.60 56.50 100.00 2391.75 -24.84 -3.61 25.83 26.08 97.96 0.59 BP _BOSS GYRO 27 2492.05 1.08 89.69 100.00 2491.74 -25.96 -3.32 27.21 27.41 96.95 0.66 BP _BOSS GYRO 28 2592.05 1.17 86.19 100.00 2591.72 -27.69 -3.24 29.17 29.35 96.34 0.11 BP _BOSS GYRO 29 2692.05 0.82 74.69 100.00 2691.71 -29.12 -2.99 30.88 31.02 95.52 0.40 BP _BOSS GYRO 30 2792.05 0.95 96.31 100.00 2791.69 -30.45 -2.89 32.39 32.52 95.10 0.36 BP _BOSS GYRO [(c)2008 IDEAL ID13_OC_10] ,s SCHLUNIBERGER Survey Report 19 -Aug-2008 13:53:49 Page 3 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- 31 -------- 2892.05 ------ 1.32 ------ 83.10 100.00 2891.68 -32.20 -2.84 34.36 34.48 94.73 0.45 BP_ BOSS GYRO 32 2992.05 0.87 92.61 100.00 2991.66 -33.87 -2.74 36.26 36.37 94.32 0.48 BP_ BOSS GYRO 33 3092.05 0.60 125.20 100.00 3091.65 -35.08 -3.07 37.45 37.58 94.69 0.49 BP_ BOSS GYRO 34 3192.05 0.72 124.11 100.00 3191.64 -36.22 -3.73 38.40 38.58 95.55 0.12 BP_ BOSS GYRO 35 3292.05 0.55 128.90 100.00 3291.64 -37.31 -4.38 39.29 39.54 96.36 0.18 BP_ BOSS GYRO 36 3392.05 0.52 166.00 100.00 3391.63 -38.07 -5.12 39.78 40.10 97.34 0.34 BP_ BOSS GYRO 37 3492.05 0.70 166.81 100.00 3491.63 -38.74 -6.16 40.02 40.50 98.75 0.18 BP_ • BOSS GYRO 38 3592.05 0.50 163.31 100.00 3591.62 -39.42 -7.17 40.29 40.92 100.09 0.20 BP_ BOSS GYRO 39 3692.05 0.32 171.61 100.00 3691.62 -39.87 -7.87 40.46 41.21 101.00 0.19 BP_ BOSS GYRO 40 3792.05 0.65 166.50 100.00 3791.61 -40.38 -8.69 40.63 41.55 102.08 0.33 BP_ BOSS GYRO 41 3892.05 0.50 155.81 100.00 3891.61 -41.07 -9.64 40.94 42.06 103.25 0.18 BP_ BOSS GYRO 42 3992.05 0.55 147.40 100.00 3991.60 -41.82 -10.45 41.38 42.68 104.17 0.09 BP_ BOSS GYRO 43 4042.05 2.08 135.61 50.00 4041.59 -42.87 -11.30 42.14 43.63 105.01 3.09 BP_ BOSS GYRO 44 4092.05 3.82 127.70 50.00 4091.52 -45.36 -12.96 44.09 45.96 106.38 3.57 BP_ BOSS GYRO 45 4142.05 5.75 129.61 50.00 4141.35 -49.42 -15.58 47.34 49.84 108.21 3.87 BP_ BOSS GYRO 46 4192.05 7.47 126.70 50.00 4191.01 -55.04 -19.12 51.88 55.29 110.23 3.50 BP_ BOSS GYRO 47 4211.00 7.73 124.99 18.95 4209.79 -57.50 -20.59 53.91 57.71 110.90 1.82 BP_ BOSS GYRO 48 4228.00 9.30 116.00 17.00 4226.61 -60.01 -21.84 56.08 60.18 111.28 12.08 BP _BLIND 49 4245.88 9.19 116.00 17.88 4244.26 -62.88 -23.10 58.66 63.05 111.50 0.62 BP _INC+TREND 50 4299.81 7.23 91.05 53.93 4297.65 -70.27 -25.05 65.93 70.53 110.81 7.45 BP _INC+TREND 51 4396.48 6.04 46.23 96.67 4393.73 -77.59 -21.64 75.69 78.72 105.96 5.35 BP _INC+TREND 52 4491.56 3.21 2.50 95.08 4488.52 -78.30 -15.52 79.42 80.92 101.06 4.55 BP _MWD+IFR+MS 53 4587.43 6.64 261.70 95.87 4584.14 -72.64 -13.64 74.04 75.29 100.44 8.24 BP _MWD+IFR+MS 54 4682.63 10.32 276.55 95.20 4678.29 -60.01 -13.46 60.12 61.61 102.62 4.47 BP _MWD+IFR+MS 55 4777.84 10.81 301.40 95.21 4771.94 -43.06 -7.83 44.02 44.71 100.09 4.78 BP _MWD+IFR+MS 56 4873.03 14.38 309.66 95.19 4864.83 -22.70 4.37 27.29 27.64 80.91 4.19 BP _MWD+IFR+MS 57 4969.78 19.93 313.55 96.75 4957.24 4.67 23.41 6.08 24.19 14.55 5.85 BP _MWD+IFR+MS 58 5064.29 21.08 316.04 94.51 5045.77 35.94 46.75 -17.40 49.88 339.59 1.53 BP _MWD+IFR+MS 59 5161.84 20.11 305.05 97.55 5137.11 68.95 69.01 -43.32 81.48 327.89 4.08 BP _MWD+IFR+MS 60 5258.53 21.57 298.75 96.69 5227.49 103.11 87.11 -72.51 113.34 320.23 2.76 BP _MWD+IFR+MS [(c)2008 IDEAL ID13_OC_10] SCHLUMBERGER Survey Report 19-Aug-2008 13:53:49 Page 4 of 7 Seq Measured Intl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5353 40 19 08 300.59 94.87 5316.44 135.98 103.39 -101.15 144.65 315.63 2.71 BP_MWD+IFR+MS 62 5448.85 18.93 302.40 95.45 5406.69 166.90 119.63 -127.66 174.95 313.14 0.64 BP_MWD+IFR+MS 63 5544.31 19.38 299.54 95.46 5496.87 198.08 135.74 -154.51 205.66 311.30 1.09 BP_MWD+IFR+MS 64 5639.64 19.80 301.20 95.33 5586.68 229.93 151.90 -182.08 237.12 309.84 0.73 BP_MWD+IFR+MS 65 5734.40 18.49 303.64 94.76 5676.20 260.79 168.54 -208.32 267.96 308.97 1.62 BP_MWD+IFR+MS 66 5830.43 18.60 305.43 96.03 5767.24 290.96 67 5925.82 19.29 311.79 95.39 5857.48 321.10 68 6023.55 19.75 313.77 97.73 5949.59 352.31 69 6119.80 19.75 313.50 96.25 6040.18 383.25 70 6212.61 19.48 311.44 92.81 6127.60 413.07 71 6309.02 18.76 309.76 96.41 6218.69 443.58 72 6404.20 19.37 316.74 95.18 6308.67 473.16 73 6498.93 18.23 316.58 94.73 6398.34 501.67 74 6593.52 20.94 312.68 94.59 6487.45 531.66 75 6689.76 20.00 312.42 96.24 6577.61 563.87 76 6783.00 19.03 312.24 93.24 6665.50 593.72 77 6880.37 20.58 308.52 97.37 6757.11 625.62 78 6976.96 19.29 308.12 96.59 6847.91 657.76 79 7072.31 21.09 308.53 95.35 6937.40 689.86 80 7166.54 22.68 310.59 94.23 7024.83 723.95 81 7263.45 21.55 307.92 96.91 7114.62 759.40 82 7358.40 20.97 309.85 94.95 7203.10 792.92 83 7454.37 20.17 308.70 95.97 7292.96 825.69 84 7549.80 19.52 307.92 95.43 7382.72 857.31 85 7645.57 21.24 305.46 95.77 7472.49 890.04 185.85 -233.48 205.17 -257.62 227.35 -281.58 249.80 -305.12 270.83 -328.10 291.39 -352.07 312.67 -374.65 334.88 -395.60 357.09 -418.20 379.85 -443.00 400.82 -466.02 422.15 -491.17 442.58 -517.00 462.99 -542.81 485.37 -569.88 508.47 -598.11 530.07 -624.91 551.42 -651.00 571.50 -676.42 591.40 -703.18 298.42 308.52 329.34 308.53 361.91 308.92 394.33 309.31 425.44 309.54 457.01 309.61 487.99 309.85 518.31 310.25 549.91 310.49 583.55 310.61 614.68 310.70 647.66 310.68 680.56 310.57 713.45 310.46 748.56 310.42 785.03 310.37 819.44 310.31 853.15 310.27 885.53 310.19 918.81 310.07 0.60 BP_MWD+IFR+MS 2.28 BP_MWD+IFR+MS 0.82 BP_MWD+IFR+MS 0.09 BP_MWD+IFR+MS 0.80 BP_MWD+IFR+MS 0.94 BP_MWD+IFR+MS 2.48 BP_MWD+IFR+MS 1.20 BP_MWD+IFR+MS 3.18 BP_MWD+IFR+MS 0.98 BP_MWD+IFR+MS 1.04 BP_MWD+IFR+MS 2.05 BP_MWD+IFR+MS 1.34 BP_MWD+IFR+MS 1.89 BP_MWD+IFR+MS 1.87 BP_MWD+IFR+MS 1.56 BP_MWD+IFR+MS 0.96 BP_MWD+IFR+MS 0.93 BP_MWD+IFR+MS 0.74 BP_MWD+IFR+MS 2.01 BP_MWD+IFR+MS 86 7741.74 21.19 305.94 96.17 7562.14 924.31 611.71 -731.44 953.51 309.91 0.19 BP_ MWD+IFR+MS 87 7836.89 21.29 307.86 95.15 7650.83 958.12 632.41 -759.00 987.93 309.80 0.74 BP_ MWD+IFR+MS 88 7935.02 20.96 308.07 98.13 7742.37 992.68 654.16 -786.88 1023.28 309.74 0.35 BP_ MWD+IFR+MS 89 8028.96 20.06 305.70 93.94 7830.35 1024.96 673.92 -813.19 1056.15 309.65 1.30 BP_ MWD+IFR+MS 90 8124.08 19.43 306.77 95.12 7919.88 1056.55 692.91 -839.11 1088.23 309.55 0.76 BP_ MWD+IFR+MS U • [(0)2008 IDEAL ID13_OC_10] SCHLUMBERGER Survey Report 19 -Aug-2008 13:53:49 Page 5 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (f t) (ft) (deg) 100f) type (deg) 91 8220.56 18.73 305.18 96.48 8011.06 1087.58 711.45 -864.63 1119.70 309.45 0.90 BP _MWD+IFR+MS 92 8315.00 17.99 306.32 94.44 8100.69 1116.87 728.82 -888.77 1149.39 309.35 0.87 BP _MWD+IFR+MS 93 8411.14 17.84 306.06 96.14 8192.17 1145.94 746.28 -912.64 1178.92 309.27 0.18 BP _MWD+IFR+MS 94 8506.53 16.87 306.04 95.39 8283.22 1173.93 763.03 -935.65 1207.33 309.20 1.02 BP _MWD+IFR+MS 95 8602.96 17.87 309.82 96.43 8375.25 1202.05 780.73 -958.32 1236.10 309.17 1.56 BP _MWD+IFR+MS 96 8680 39 17.21 309.07 77.43 8449.08 1224.71 795.56 -976.34 1259.43 309.17 0.90 BP _MWD+IFR+MS 97 . 8742.62 16.91 308.20 62.23 8508.57 1242.50 806.96 -990.60 1277.69 309.17 0.63 BP _INC+TREND • 98 8775.11 18.78 307.80 32.49 8539.50 1252.23 813.09 -998.45 1287.64 309.16 5.77 BP _INC+TREND 99 8806.41 21.94 307.22 31.30 8568.84 1262.89 819.72 -1007.09 1298.52 309.14 10.12 BP _MWD+IFR+MS 100 8838.45 24.35 308.97 32.04 8598.30 1275.18 827.49 -1016.99 1311.11 309.13 7.82 BP _MWD+IFR+MS 101 8870.61 26.72 311.37 32.16 8627.32 1288.60 836.44 -1027.57 1324.97 309.15 8.04 BP _MWD+IFR+MS 102 8901.54 29.76 314.40 30.93 8654.56 1302.57 846.41 -1038.28 1339.57 309.19 10.86 BP _MWD+IFR+MS 103 8933.30 32.93 317.85 31.76 8681.68 1318.04 858.33 -1049.71 1355.96 309.27 11.47 BP _MWD+IFR+MS 104 8965.57 36.47 318.09 32.27 8708.21 1335.03 871.97 -1062.01 1374.12 309.39 10.98 BP _MWD+IFR+MS 105 8997.99 38.53 317.98 32.42 8733.93 1353.28 886.65 -1075.20 1393.63 309.51 6.36 BP _MWD+IFR+MS 106 9029.54 41.86 316.12 31.55 8758.03 1372.25 901.54 -1089.08 1413.82 309.62 11.22 BP _MWD+IFR+MS 107 9062.10 43.43 316.02 32.56 8781.98 1392.92 917.43 -1104.38 1435.73 309.72 4.83 BP _MWD+IFR+MS 108 9094.99 46.01 315.08 32.89 8805.34 1414.69 933.94 -1120.59 1458.76 309.81 8.10 BP _MWD+IFR+MS 109 9125.94 48.28 315.27 30.95 8826.39 1436.08 950.03 -1136.58 1481.35 309.89 7.35 BP _MWD+IFR+MS 110 9158.08 50.55 315.19 32.14 8847.30 1459.08 967.36 -1153.77 1505.65 309.98 7.07 BP _MWD+IFR+MS 111 9189.61 53.51 314.17 31.53 8866.70 1482.58 984.83 -1171.45 1530.42 310.05 9.73 BP _MWD+IFR+MS 112 9220.85 56.12 312.63 31.24 8884.70 1506.90 1002.37 -1190.00 1555.91 310.11 9.28 BP _MWD+IFR+MS 113 9252.90 59.15 311.14 32.05 8901.86 1532.90 1020.44 -1210.16 1582.96 310.14 10.24 BP _MWD+IFR+MS 114 9284.81 62.39 309.79 31.91 8917.44 1559.82 1038.50 -1231.34 1610.80 310.14 10.80 BP _MWD+IFR+MS 115 9316.18 65.82 309.02 31.37 8931.13 1587.23 1056.41 -1253.14 1639.02 310.13 11.15 BP _MWD+IFR+MS 116 9347.93 69.26 308.48 31.75 8943.26 1615.81 1074.77 -1276.02 1668.34 310.11 10.95 BP _MWD+IFR+MS 117 9382.10 71.27 306.34 34.17 8954.80 1647.30 1094.31 -1301.57 1700.47 310.06 8.33 BP _MWD+IFR+MS 118 9413.75 71.88 303.23 31.65 8964.81 1676.94 1111.43 -1326.23 1730.37 309.96 9.52 BP _MWD+IFR+MS 119 9445.27 71.42 301.66 31.52 8974.73 1706.65 1127.48 -1351.48 1760.03 309.84 4.95 BP _MWD+IFR+M5 120 9475.78 71.63 298.33 30.51 8984.40 1735.50 1141.95 -1376.53 1788.54 309.68 10.37 BP _MWD+IFR+MS [(c)2008 IDEAL ID13_OC_10] SCHLUMBERGER Survey Report 19-Aug-2008 13:53:49 Page 6 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (f t) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 121 9507.43 72.54 295.25 31.65 8994.14 1765.61 1155.52 -1403.41 1817.91 309.47 9.70 BP_ MWD+IFR+MS 122 9538.96 75.63 294.22 31.53 9002.78 1795.92 1168.20 -1430.95 1847.24 309.23 10.29 BP_ MWD+IFR+MS 123 9571.92 78.17 291.20 32.96 9010.26 1827.97 1180.59 -1460.56 1878.04 308.95 11.79 BP_ MWD+IFR+MS 124 9602.76 80.83 289.14 30.84 9015.88 1858.15 1191.04 -1489.02 1906.77 308.66 10.84 BP_ MWD+IFR+MS 125 9635.23 82.45 287.04 32.47 9020.60 1889.99 1201.01 -1519.56 1936.87 308.32 8.11 BP_ MWD+IFR+MS 126 9666.63 85.24 285.64 31.40 9023.96 1920.79 1209.79 -1549.51 1965.85 307.98 9.93 BP MWD+IFR+MS 127 9689.75 86.92 287.32 23.12 9025.54 1943.56 1216.34 -1571.63 1987.33 307.74 10.26 _ BP_ MWD+IFR+MS . 128 9721.42 90.01 287.87 31.67 9026.39 1974.90 1225.91 -1601.80 2017.08 307.43 9.91 BP_ MWD+IFR+MS 129 9753.75 88.74 285.30 32.33 9026.75 2006.82 1235.13 -1632.78 2047.32 307.11 8.87 BP_ MWD+IFR+MS 130 9786.47 87.86 284.83 32.72 9027.72 2038.96 1243.63 -1664.36 2077.67 306.77 3.05 BP_ MWD+IFR+MS 131 9818.36 89.80 283.01 31.89 9028.37 2070.17 1251.30 -1695.31 2107.09 306.43 8.34 BP_ MWD+IFR+MS 132 9850.51 90.90 283.95 32.15 9028.17 2101.59 1258.80 -1726.57 2136.73 306.09 4.50 BP_ MWD+IFR+MS 133 9881.29 90.66 283.69 30.78 9027.75 2131.71 1266.15 -1756.45 2165.24 305.79 1.15 BP_ MWD+IFR+MS 134 9913.58 90.90 286.32 32.29 9027.31 2163.43 1274.51 -1787.64 2195.45 305.49 8.18 BP_ MWD+IFR+MS 135 9945.76 91.31 282.18 32.18 9026.69 2194.96 1282.42 -1818.81 2225.47 305.19 12.93 BP_ MWD+IFR+MS 136 9977.42 90.42 281.90 31.66 9026.21 2225.72 1289.03 -1849.77 2254.61 304.87 2.95 BP_ MWD+IFR+MS 137 10009.20 88.98 277.74 31.78 9026.38 2256.29 1294.45 -1881.08 2283.43 304.53 13.85 BP_ MWD+IFR+MS 138 10041.19 89.49 277.82 31.99 9026.81 2286.72 1298.78 -1912.77 2312.04 304.18 1.61 BP_ MWD+IFR+MS 139 10072.47 90.11 276.88 31.28 9026.92 2316.41 1302.78 -1943.80 2339.99 303.83 3.60 BP_ MWD+IFR+MS 140 10104.28 91.17 276.28 31.81 9026.56 2346.47 1306.42 -1975.39 2368.32 303.48 3.83 BP MWD+IFR+MS 141 10136.51 92.28 278.47 32.23 9025.59 2377.05 1310.56 -2007.34 2397.28 303.14 7.62 BP_ MWD+IFR+MS • 142 10166.37 89.90 276.96 29.86 9025.02 2405.44 1314.56 -2036.92 2424.28 302.84 9.44 BP_ MWD+IFR+MS 143 10199.37 89.29 275.98 33.00 9025.26 2436.60 1318.28 -2069.71 2453.89 302.49 3.50 BP_ MWD+IFR+MS 144 10230.66 89.56 276.80 31.29 9025.57 2466.13 1321.77 -2100.80 2482.02 302.18 2.76 BP_ MWD+IFR+MS 145 10263.81 91.35. 276.86 33.15 9025.31 2497.50 1325.71 -2133.72 2512.02 301.85 5.40 BP MWD+IFR+MS 146 10296.10 91.96 278.22 32.29 9024.37 2528.17 1329.94 -2165.71 2541.47 301.55 4.61 BP_ MWD+IFR+MS 147 10327.61 90.18 276.42 31.51 9023.79 2558.07 1333.96 -2196.96 2570.23 301.27 8.03 BP_ MWD+IFR+MS 148 10358.75 90.90 277.82 31.14 9023.49 2587.58 1337.82 -2227.85 2598.67 300.98 5.06 BP_ MWD+IFR+MS 149 10390.80 89.66 276.88 32.05 9023.33 2618.00 1341.92 -2259.64 2628.06 300.70 4.86 BP_ MWD+IFR+MS 150 10422.44 89.46 277.28 31.64 9023.58 2647.99 1345.82 -2291.04 2657.08 300.43 1.41 BP MWD+IFR+MS [(c)2008 IDEAL ID13_OC_10] SCHLUMBERGER Survey Report 19-Aug-2008 13:53:49 Page 7 of 7 Seq Measured Incl Azimuth Course TVD .Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 151 10454.47 90.11 277.99 32.03 9023.70 2678.44 1350.07 -2322.78 2686.64 300.17 3.01 BP _MWD+IFR+MS 152 10486.43 90.21 277.72 31.96 9023.61 2708.86 1354.44 -2354.44 2716.23 299.91 0.90 BP _MWD+IFR+MS 153 10518.16 90.04 277.91 31.73 9023.54 2739.06 1358.75 -2385.88 2745.66 299.66 0.80 BP _MWD+IFR+MS 154 10550.90 89.66 277.30 32.74 9023.63 2770.19 1363.09 -2418.33 2776.03 299.41 2.20 BP _MWD+IFR+MS 155 10582.60 90.01 278.24 31.70 9023.72 2800.35 1367.37 -2449.74 2805.52 299.17 3.16 BP _MWD+IFR+MS 156 10613.05 90.76 278.24 30.45 9023.51 2829.39 1371.74 -2479.87 2833.98 298.95 2.46 BP _MWD+IFR+MS 157 10646.58 90.42 278.40 33.53 9023.17 2861.39 1376.59 -2513.05 2865.38 298.71 1.12 BP _MWD+IFR+MS 158 10677.44 89.83 277.51 30.86 9023.10 2890.79 1380.86 -2543.61 2894.26 298.50 3.46 BP _MWD+IFR+MS 159 10709.60 90.28 278.67 32.16 9023.07 2921.44. 1385.38 -2575.45 2924.42 298.28 3.87 BP _MWD+IFR+MS 160 10743.12 90.04 276.96 33.52 9022.97 2953.34 1389.94 -2608.66 2955.85 298.05 5.15 BP _MWD+IFR+MS 161 10774.83 89.56 277.74 31.71 9023.08 2983.44 1394.00 -2640.11 2985.53 297.83 2.89 BP _MWD+IFR+MS 162 10809.54 88.84 276.58 34.71 9023.57 3016.35 1398.32 -2674.54 3018.03 297.60 3.93 BP _MWD+IFR+MS 163 10861.00 88.84 276.58 51.46 9024.61 3064.96 1404.22 -2725.65 3066.11 297.26 0.00 Projected_TD [(c)2008 IDEAL ID13_OC_10] w ~ Schlumaer er 9 Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Christine Mahnken Well No D-22C Date Dispatched: 22-Aug-08 Installation/Rig Nabors-7ES Dispatched By: Franklin Medina LWD Log DeliveryV2.1, 03-06-06 Data No Of Prints No of Floppies Surveys 2 1 Received By: Please sign and return to: ~~ ~ Drilling & Measurements LWD Division ~'~ v 2525 Gambell Street, Suite 400 Anchorage, Alaska 99501 fclarke3@slb.com Fax:907-561-8317 SARAH PALlN, GOVERNOR COHSERO r, ~ 51~7rv-~ 333 W 7th AVENUE. SUITE 100 t..~ Ql` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-22C BP Exploration Alaska Inc. Permit No: 208-121 Surface Location: 1550' FNL, 1692' FEL, SEC. 23, T11N, R13E, UM Bottomhole Location: 181' FNL, 4523' FEL, SEC. 23, T11N, R13E, UM Dear Mr. Hobbs: 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). Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~O day of July, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~ -08 ALASiC~IL AND GAS CONSERVATION COMMI NJ' PERMIT TO DRILL /'~~/~ . ~'~~ ~ ~' 200 20 AAC 25.005 ~in~i~a t'~il ~ ~~w (''~n< i~nvxirv~ic~inn 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if wellA~~1 ~ for: ^ Coalbed Methar~e~~'[~as Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU D-22C 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10944' TVD 9019' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1550' FNL 1692' FEL SEC 23 T11 N R13E UM 7. Property Designation: ADL 028285 Pool , , . , , , Top of Productive Horizon: 360' FNL, 3310' FEL, SEC. 23, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 26, 201~j Total Depth: 181' FNL, 4523' FEL, SEC. 23, T11N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 21,050' 4b. Location of Well (State Base Plane Coordinates): Surface: x-653460 y-5959438 Zone-ASP4 10. KB Elevation Plan (Height above GL): gg feet 15. Distance to Nearest We11 Within Pool: 520' 16. Deviated Wells: Kickoff Depth: 4340 feet Maximum Hole An le: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3757 Surface: 2907 8. Casin Pro ram: S ecificatio ns To -.Settin De th -Bo ttom uantit of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data Tieback 9-5/8" 47# L-80 dril 563 2175' Surface Surface 2175' 2175' 992 cu ft Class'G' 8-1/2" 7" 26# L-80 BTC-M 4792' 3920' 3920' 8712' 8499' 697 cu ft LiteCrete 162 cu ft Class'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 2382' 8562' 8288' 10944' 9019' 331 cu ft Class'G' 1 g. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 10945" Total Depth TVD (ft): 9003' Plugs (measured): 8617' Effective Depth MD (ft): 10856' Effective Depth TVD (ft): 9010' Junk (measured): None Casing . Length- Size Cement Volume MD TVD Conductor /Structural 110' 20" x 30" 9.6 cu ds Concrete 110' 110' Surface 2646' 13-3/8" 3720 cu ft Permafrost'C' 2684' 2684' Intermediate 8243' 9-5/8" 1170 cu ft Class'G' 130 cu ft PF'C' 8278' 8040' Production Liner 676' 7" 222 cu ft Class'G' 8141' - 8817' 7910' - 8507' Liner 2327' 4-1/2" 342 cu ft Class'G' 8618' - 10945' 8343' - 9003' Perforation Depth MD (ft): Below Plug: 10150' - 10650' Perforation Depth TVD (ft): 9026' - 9025' 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 "s true and correct. Contact John Rose, 564-5271 Printed Name Greg Ho s Title Engineering Team Leader Prepared By Name/Number: Si nature Phone 564-4191 Date ~f9 ~?~ Terrie Hubble, 564-4628 Commissions Use Oinl Permit To Drill Number: D~~a?/O API Number: 50-029-20737-03-00 Permit A oval See cover letter for Date: ~ ~ other re uirements Conditions of Approval: If box is checked, well may not used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes G~No Mud Log Req'd: ^ Yes [1~No ~~~ ~~~5~ ~ ~ ~~~~~~ HZS Measures: ~p Yes ^ No Directional Survey Req'd: Yes ^ No Other: Date APPROVED BY T COMMIASSIONER Form 10-401 Revised 12/2005 ~ R f G { N A L Submit In Duplicate by To: Alaska Oil & Gas Conservation Commission From: John Rose, ODE Date: July 8, 2008 Re: D-22C Sidetrack Permit to Drill In preparation for the proposed GPB D-22C rotary sidetrack (planned Zone 2 Ivishak producer), Sundry approval has been granted for the following well work (Sundry Number 308-207): 1. P/A the existing perforations (10,150' -10,650' MD) with cement. 2. Cut and pull the existing 4-1/2" completion f/~8567' MD. 3. Set a CIBP at -4172' MD. 4. Cut and pull the existing 9-5/8" production casing from above TOC at 2175' MD, run a premium threaded 9-5/8" tie-back casing string (w/ES Cementer) and fully cement the 9-5/8" x 13-3/8" annulus back to surface. With the Sundry work completed, the sidetrack plan for this well will include the following: 1. Sidetrack the well with an 8-1/2" bit from the existing 9-5/8" casing at 4141' MD. 2. Drill an 8-1/2" intermediate hole to the top Sag casing point 8712' MD and run and fully cement a 7" drilling liner with a planned TOL at 3920' MD. 3. Drill a 6-1/8" production hole to the final well TD at 10,944' MD (includes -1227' of horizontal hole in Zone 2) and run and fully cement a 4-1/2" production liner with the TOL at --8562' MD. 4. Perforate 800' of target sands. 5. Complete the well with a 4-1/2" chrome completion with the WLEG positioned into the top of the 4-1/2" production PBR at 8569' MD. Please note the attached Wellplan Summary for additional details for this planned GPB sidetrack: D-22C Permit to Drill Application Page 1 D-22C Wellplan Summary (07/08/08) Horizontal Well D-22C Well Sidetrack Target Zone 2B Type Producer Objective AFE Number: PBD4P2781 API Number: 50-029-20737-03 Surface Northin Eastin Offsets TRS Location 5,959,438 653,460 1551' FNL / 1692' FEL 11 N, 13E, 23 Target Northin Eastin Offsets TRS Locat ons 5,960,595 651,816 360' FNL / 3310' FEL 11 N, 13E, 23 Bottom Northin Eastin Offsets TRS Locat on 5,960,750 650,600 181' FNL / 4523' FEL 11 N, 13E, 23 Planned S ud Date: 08/26/08 Planned KOP: 4141' and / 4140' tvd Planned TD: 10,944' and / 9019' tvd Ri Nabors 7ES CBE: 40.5' RTE: 69.0' Directional Program A roved Well Ian: P8 Exit oint: 4141' and / 4140' tvd Maximum Hole Inclination: ~90° in the tanned 6 1/8" roduction section. Proximit Issues: None. Surve Pro ram: Standard MWD/IFR/MS Nearest Well within ool: D-27A 520' Nearest Pro ert Line 21,050' North Lopping Program Hole Section: Required Sensors /Service 9-5/8" casin GR log for KOP optimization 8 1/2" intermediate: Real time MWD Dir/GR/PWD throu hout the interval 6 1/8" production: Real time MWD Dir/GR/Res in the build Real time MWD Dir/GR/Res/ABI/Den/Neu in the lateral. MAD pass build for Den/Neu. Sam les as directed b Wellsite Geolo ist. Cased Hole: None tanned O en Hole: None tanned D-22C Drill and Complete Program Page 1 Mud Program Hole Section / o eration: KOP in the 9 5/8" casin at 4141' and to to HRZ T e Densit MBT PV YP API FL H LSND 9.0-9.3 <12 10-18 30-35 <6.0 9.0 - 10.0 Hole Section / o eration: Drillin 6 1/8" roduction interval T e Densit LSRV PV YP API FL H FloPro SF 8.4 - 8.6 >20,000 8 -12 22 - 28 6 - 8 9.4 - 9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connection Length Top and / tvd Bottom and / tvd 9-5/8" 47# L-80 H dri1563 2175' Surface 2175'/2175' 8'/z" 7" 26.0# L-80 BTC-M 4792' 3920'/3920' 8712'/8499' 6 1/8" 4 ~/z" 12.6# L-80 IBT-M 2382' 8562'/8288' 10,944'/9019' Tubin 4'h" 12.6# 13Cr VamTo 8569' Surface 8569'/8295' Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9 5/8" casin Bride lu to surface 30 min recorded 3,500 si surface 9 5/8" casing window 20' new formation beyond FIT KT = 10.7 ppg EMW ECD = 11.7 EMW 7" liner Float a ui ment to surface 30 min recorded 3,500 si surface 7" casing shoe 20' new formation beyond FIT KT = 8.8 ppg EMW ECD = 10.7 EMW 4'/z" roduction liner Float a ui ment to surface 30 min recorded 3,500 si surface Cementing Program Casin Strin 9-5/8" Casin Tie-Back Casin Slur Desi n Basis: 2175' 9-5/8" x 13-3/8" annulus lus 40 bbls excess cement Pre-Flush None tanned Fluids Sequence /Volume: S acer 10 bbls Water at 9.8 Plu Slur 165 bbls / 992 cf / 795 sxs 15.8 Class "G"; 1.17 cf/sxs Casin Strin 7", 26#, L-80, BTC-M intermediate liner Lead slurry: 200' of 4" x 9-5/8" annulus, 3682' of 7" x 8-1/2" open-hole plus Slurry Design Basis: 30% excess, 221' of 9-5/8" x 7" liner lap (TOL at 3920' MD). " ' " " ' of 7 , 26# annulus with 30% excess, plus 80 of 7 X 8-1/2 Tail slurry: 889 shoe track. Pre-Flush None tanned Fl id S / V l • S acer 40 bbls MudPUSH at 10.9 u s equence o ume f Lead Slur /sxs 124 bbls / 697 cf / 251 sxs 11.5 LiteCrete, 2.77 c Tail Slur 29 bbls / 162 cf / 140 sxs Class `G', 15.8 ; 1.17 cf/sk. D-22C Drill and Complete Program Page 2 Casin Strin 4 1/2", 12.6#, L-80, IBT-M solid roduction. liner Lead slurry: none planned Slurry Design Basis: Tail slurry: 2232' of 4 1/2" X 6 1/8" annulus with 30% excess, plus 80' of 4 1/2 , 12.6# shoe track, plus 150 of 7 X 4 /z Ilner lap, plus 200 of 7 X 4 drill i e annulus. Pre-Flush 25 bbls CW 100 Fl id S /V l S acer 50 bbls MudPUSH at 10.0 u s equence o ume: Lead Slur None tanned Tail Slur 59.2 bbl / 331.4 cf / 285.8 sx Class `G', 15.8 ; 1.17 cf/sk. Well Control Well control equipment consisting of S,000psi working pressure pipe rams (2), blindlshear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the calculations below, BOP equipment will be tested to 3,500 psi. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8 1/2" intermediate interval Maximum anticipated BHP: 3,757 psi at 8499' TVD. ,~ ~:.~v~ '~ (~" Maximum surface pressure: 2,907 pSl (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: 50 bbl with 10.7 ppg EMW (FIT to 11.7 ppg f/ECD management) Planned BOPS function/pressure tests: 250 psi low / 3,500 psi high 7 day test cycle (Pre drilling phase) 14 da test c cle Drillin o erations Well Interval: 6 1/8" roduction interval Maximum antici ated BHP: 3,195 si at 8,921' TVDss. , ' Lbw (a Maximum surface ressure: 2,303 SI (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 8.8 EMW FIT to 10.7 f/ECD mana ement Planned BOPE function/ ressure tests: 250 psi low / 3,500 psi high - 14 day test cycle (Drilling operations) Planned com letion fluid: 8.4 seawater / 6.8 Diesel DISpOSaI Annular Injection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 Fluid Handling: for injection. For the disposal of Class I wastes, contact the GPB Environmental Advisors Bill Dawle and Brian Collver at 659-5893 D-22C Drill and Complete Program Page 3 Geologic Prognosis -__/ Fst. Fo rmn[ion To s Uncertainty Cononercia[ H_vdroca rbon Bea rin Fst. Pore Press. Est. Pore Press. FOTntQtlOrl (TVDss) (jeeU (Yes/No) (Psi) (ppg EMW) NOTE All formation tots are required from IUOU' aboe proposed KOP to TD for s idetraeks NOTE AI I formation to are re 'red from s urface to TD far all new wells SVS -2452 20 No SV4 -2625 20 No IJG4 -4176 20 No UG3 -0452 20 No IIGl -4835 20 No 8.6-9.1 WS2 -5432 20 No WSl -5686 20 No CM3 -5798 20 No CM2 -6276 20 No CNIl -6850 20 No THRZ -7150 20 No BHRZ -7380 20 No TJE -7656 20 No •rJD -7967 zo Nn TJC -8116 20 No TJB -8252 20 No T,fA -8333 20 No TSGR -8430 20 Yes T511U -8461 20 Yes TSAD -8535 20 Yes TCGL -8711 20 Yes BCGL -8779 20 Yes 23SB -8852 20 Yes 3795 7.0 2215 -8900 20 Yes 21 TS -8952 20 Yes Fault Prognosis Throw Formation Where Ercounter Fault MD Intersect TVD Intersect Est. Throw Direction Uncertainty Fault #1 - 7.2B Well will robab not cross 510 ft D to West DuesOOnable Fault Fault #2 - Fault #3 - Fault #4 - c am.~a~ The planned D-22C RST is located in NW quadrant of the D Pad, in an area designated as having "Moderate" lost circulation potential by the WURD study. The heel portion of [he planned D-22C RST will pass within 150 ft of Fault #1. This is a very small (existance questionable), 51 O ft, down to the west fault. Fault #1 appears to cut only part way up through the section and does not cut TSHU. There is no known history of lost circulation on this fault. Fault #2 is a 20-30 ft, down to the west fault that cuts the entire Ivishak section, and is located approximately 500 ft NE of the planned well. Fault #2 definately has a history of significant lost circulation! The closest significant lost circulation incident was about 1000 ft SE of the planned well, in D-06A which lost 5127 BBL into Zone 2, along. Fault #2. D-06 and DO6AP81 also had significant losses associated with Fault #2. Fault #2 should be avoided at all cost! Based on the WURD assessment, and the fact that the planned D-22C will be 500 ft from Fault #2 at its closest and is drillirtg away from the fault, the overall risk of lost circulation is considered to be moderate. Well Type BBL MD SSTVD Zone X V Comments D-01 rig 775 10130 9235 Below BSAD 651573 5857739 cementing D-03 rig 100 8250 6876 Above Sag-LCU 652211 5961991 D-03 rig 200 10686 9012 Below BSAD 651826 5963080 D-03 rig 350 10802 9119 Below BSAD 651823 5963124 circulating for casing D-06 rig 200 6875 6632 Above Sag-LCU 653383 5959524 D-06 rig 1100 9074 8685 ZONE 4 653197 5960249 coring D-06 rig 300 9194 8799 ZONE 2 653196 5960289 coring D-06A rig 5127 9504 8872 ZONE 2 653123 5960303 D-06AP61 rig 1224 9486 8972 ZONE 1 653708 5960396 D-07 rig 600 8427 6595 Above Sag-LCU 653029 5962287 D-07A rig 159 10900 8343 Kingak 652487 5963847 D-11A rig 140 8960 7752 Abode Sag-LCU 651051 5959262 D-22 rig 400 7273 7008 Above Sag-LCU 654366 5958837 D-22A coil 300 9245 8817 655298 5958404 D-26 rig 120 10689 8816 ZONE 2 649276 5961184 D-31 rig 2165 10244 8891 ZONE 2 652051 5954863 D-31A rig 2895 11848 8948 ZONE 2 653916 5959546 H-36 rig 2600 71446 8829 ZONE 2 649267 5962474 Fault Coordinates for 'n X V TVD Fault #1 First Point 652020 5960985 Fault #1 Second Point 652080 5960730 possible fault? Fault #1 Third Point 652790 5960375 Fault #2 First Point 652'225 5961165 (Not intersected) Fault #2 Second Point 652490 5960950 Fault #2 Third Point 652750 5960590 Fault #2 Founh Point 653220 5960175 D-22C Drill and Complete Program Page 4 • PBU Sidetrack D-22C Operations Summary Proposed Pre-Rig Work: 1. MIT-IA to 3000 psi. MIT-T to 3000 psi. (MIT-OA failed Feb. 2006.) 2. Perform a PPPOT -T. (PPPOT-IC failed 10/2/02). 3. Cycle all LDS, repair or replace as needed. 4. Pull PXN plug at 8617' MD. 5. Drift for service coil to PBTD. 6. Using service coil, seta 22.9 bbls class G cement plug from 10856' (PBTD) to 9351' MD (~ 100' TVD above top perf at 10,150' MD) displacing the tubing to seawater above the cement plug. 7. Jet cut 4-1/2" tubing at 8567' with a-line. 8. Circulate the tubing and IA above cement plug to seawater. 9. Perform CMIT-IA x T to 2230 psi to test cement plug (.25 psi/TVDft). 10. Freeze protect IA and T with seawater and 2200' TVD of diesel. 11. Set a BPV and test to 1000 psi from tubing annulus (or maximum allowable up to 1000 psi). 12. Secure the well. 13. Remove well house and flow lines. Level the pad as necessary. Proposed Drilling Rig Operations: 1. MI/RU Nabors rig 2ES. PuII BPV. 2. Circulate out diesel freeze protection and displace the well to seawater. 3. Set and re-test TWC to 1,000 psi from above and below. 4. Hook up OA to a bleeder tank and monitor (OA will not pass pressure test / no OA test required). 5. Nipple down tree. Nipple up and test BOPS to 3,500psi. Pull TWC. 6. R/U & pull 4 '/z"tubing from the cut depth at 8567' MD. 7. RU E-line and RIH w/GR/CCUJB to 4400'. (NOTE: The GR log will be used to find a good shale for the actual KOP for this well (the deepest shale above 4400' MD). 8. RIH with HES EZSV bridge plug on E-line and set at 4172' MD, as required to avoid cutting a casing collar while milling the window. Test CSG to 3500 psi. POOH. 9. String shot 9-%" casing at back off point (two joints above where USIT indicates TOC~2,175') to ease break out. RD a-line. i0. MU a Baker 9-%" cutting assembly. RIH picking up DP. Cut the 9-%" casing per Baker representative instructions. Cut ~4' above the string shot casing collar. POOH, UD assembly. 11. Change out to 9-%" rams, and test rams. 12. BOLDS, RU/MU casing spear assembly, and unseat the 9-%" Circulate the annulus. Pull the 9-%" casing from the cut (will attempt to pull casing through wellhead/BOPE). 13. MU wash-over assembly and 13-%"casing scraper. 14. RIH, clean-out the 13-%"casing, and the 9-%"casing stub, POOH, UD the assembly. ~~ 15. RU back-off assembly, RIH, and back off the 9-%"casing joint. POOH, L/D assembly. ,., 16. MU casing spear assembly, RIH, recover cut stub. POOH. 17. MU 9-%" ES Cementer on screw in sub w/baker ball and seat and RIH w/new 9-%'; Hydril 563 casing. 18. Test new 9-5/8"/ ES cementer /screw in sub to 2000psi for 10mins. 19. Shear open ES cementer and cement 9-%"x 13-%"annulus with class G 15.Sppg cement (2,175' of 13-%" x 9- "plus 40 extra bbls). 20. Split stack and install FMC 13" x 9-5/8" emergency slips with primary pack off per FMC wellhead specialist in the casing head. Set slips. Cut and LD excess 9-5/8" casing. Set back BOPS test breaks to 3500 psi and test packoff to 3800 psi. NU BOPS Change BOP rams back to VBR's and test rams. 21. Set test plug and test stack to 250psi/3500psi. 22. PU 4" DP and mill tooth bit. Make clean out run through the ES Cementer. 23. Pressure-test the 9-%"casing to 3,500 psi for 30 minutes. Record test. 24. P/U and RIH with 9-%"Baker bottom-trip anchor whip stock assembly. Orient whip stock and set on EZSV bridge plug. Shear off of whip stock. (End Work Under Sundry Approval #308-207/Begin Work Under PTD #xxx-xxx) `, ~~ 25. Displace the well to 9.2 ppg LSND based milling fluid (as required to control possible cretaceous pressures). Completely displace the well prior to beginning milling operations. D-22C Drill and Complete Program Page 5 26. Mill. window in 9-5/a" casing at 4150' MD, plus approximately 20' of new hole beyond middle of window and circulate well-bore clean. (NOTE: See comment concerning the actual KOP in Step #7 above.) 27. Pull up into 9 5/8' casing and conduct a FIT to a minimum 10.7 ppg EMW. POOH. 28. M/U 8-'/z" Dir/GR/Res/PWD assembly. RIH, kick off and drill the 8-'/z" intermediate section to the top of the HRZ. Weight-up to 10.2 ppg prior to entering HRZ. Continue drilling to top of Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. 29. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. 30. Test the 9 s/6" casing X 7" liner to 3,500psi for 30 minutes. Record the test. 31. M/U 6 1/8" Dir/GR/Res assembly. RIH to the landing collar. 32. Drill out the 7" liner float equipment and cement to the shoe. 33. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 34. Drill out the 7" shoe plus drill ~20' new formation; pull up into the shoe and conduct a FIT to a minimum 8.8 ppg EMW. Drill ahead to horizontal landing point. 35. POOH for bit / BHA change. PU PDC bit and Neu/Den real time and Mad pass build section up to 100' above PGOC in real time before drilling lateral. 36. Drill horizontal section to planned TD, short trip as necessary. 37. Circulate, short trip, spot liner running pill. POOH. 38. Run and cement a 4-'h", 12.6#, L-80, IBT-M solid production liner. POOH UD all drill pipe. 39. RIH with 2-7/8" perf guns and perforate ±800'. 40. R/U and run 4-'/z", 12.6#, 13 Cr-80, VamTop completion tubing. Land the tubing RILDS. 41. Reverse circulate inhibited seawater to the packer depth. 42. Drop ball & rod and set packer and individually test the tubing and annulus to 3,500psi 30 minutes. Record each test. 43. Shear the DCK valve and pump each way to confirm shear. 44. Set a TWC and test to 1000 psi from above and below. 45. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. Pull TWC w/lubricator. 46. Freeze protect the well to 2,200' with diesel. 47. Install BPV and secure the well. 48. Rig down and move off. Post-Rig Operations: 1. MI / RU slick line. 2. Pull the ball and rod / RHC plug from landing nipple below the production packer. 3. Install gas lift valves. 4. Install well house and instrumentation. D-22C Drill and Complete Program Page 6 • D-22C Potential Drilling Hazards Post on Rig • Pre-job HAZOP's and Safety meetings are recommended when there is a clear change in workscope. If at any time things don't feel or look right, STOP the job and discuss the situation before making the next move. • Flash Points o Dead Crude= <40degF o Methanol (neat)= 52degF o Diesel=100degF • Hydrogen Sulfide o D-Pad is not an H2S pad. However, Standard Operating Procedures for H2S precautions should still be followed at all times. o Highest H2S Reading: D-15A of 50 ppm on 01/02/05. • Cretaceous Injection Pressure o Possible cretaceous inject pressure to ~9.1 ppg @4452' TVDss. • Bottom Hole Pressure 0 3195 psi (7.0 ppg) @ 8852' TVDss o The 8.5 ppg drilling fluid will provide a 690 psi static overbalance in the reservoir. • Maximum anticipated wellhead pressure: 0 2303 psi w/full column of gas • Potential for loss circulation o Moderate • Faults o None • Close Approaches o D-28 - 64' ctr - ctr 4150' MD. o D-27 - 308' ctr - ctr 4152' MD. o D-26 - 328' ctr - ctr 4150' MD. o D-19 - 346' ctr - ctr 4151' MD. o D-07 - 342' ctr - ctr 4678' MD. D-22C Drill and Complete Program Page 7 by Schlumherger D-22C (P8) Proposal Report Date: June 11, 2008 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Vertical Section Azimuth: 295.690° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: D-PAD / D-22 ~ ~ I!~ ~~ ~y TVD Reference Datum: Rotary Table Well: D-22 ~' ~ TVD Reference Elevation: 69.0 ft relative to MSL Borehole: Plan D-22C ~ea Sea Bed 1 Ground Level Elevation: 40.50 ft relative to MSL UWIIAPI#: 500292073703 Magnetic Declination: 23.020° Survey Name I Date: D-22C (P8) I June 10, 2008 Total Field Strength: 57676.322 nT Tort 1 AHD 1 DDI I ERD ratio: 141.648° / 3386.22 ft 15.764 10.375 Magnetic Dip: 80.915° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: September 10, 2008 Location LaVlong: N 70.29613049, W 148.75730761 Magnetic Declination Model: BGGM 2007 Location Grid NIE YIX: N 5959438.000 ftUS, E 653460.000 ftUS North Reference: True North Grid Convergence Angle: +1.16995089° Total Corr Mag North -> True North: +23.020° P,rid Scala Faefnr 0 9AA97fi75 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty N de de N ft N N N de de 1100 N Index NUS NUS o~ ,~ ~o~ z n~ z nQ coGOnzz zo aGZ~m aG ni ~n ~oann~az 1A/ 1dR 7~.RQ7d41 lie-In survey 414UAU ~./D ILy.01 4U/U.OV 91J.-7.OV -9D.YG -ia.oo Yi..i-r ~c.+~~ v.v. ...vv vav..~w.v.. ........... ....~ ~. ....~-......... .... .. ..,,.. ,,.,,.~..,. Top Whipstock 4150.00 6.07 128.93 4080.25 4149.25 -50.37 -16.20 48.10 85.00E 3.50 3.09 5959422.79 653508.42 N 70.29608624 W 148.75691818 Base Whipstock 4166.00 6.53 111.86 4096.15 4165.15 -52.10 -17.07 49.60 --- 12.00 3.14 5959421.95 653509.94 N 70.29608386 W 148.75690601 KOP Crv 4/100 4178.00 6.53 111.86 4108.07 4177.07 -53.46 -17.58 50.87 167.68E 0.00 3.15 5959421.47 653511.21 N 70.29608247 W 148.75689576 4200.00 5.67 109.96 4129.95 4198.95 -55.79 -18.41 53.05 165.79E 4.00 3.18 5959420.67 653513.41 N 70.29608018 W 148.75687809 UG4 4246.21 3.91 103.28 4176.00 4245.00 -59.60 -19.55 56.73 159.14E 4.00 3.24 5959419.61 653517.11 N 70.29607707 W 148.75684831 4300.00 2.04 81.26 4229.71 4298.71 -62.18 -19.83 59.46 333.15M 4.00 3.29 5959419.39 653519.85 N 70.29607631 W 148.75682619 4400.00 2.86 333.15 4329.66 4398.66 -61.67 -17.33 60.10 316.12M 4.00 3.37 5959421.90 653520.43 N 70.29608314 W 148.75682105 4500.00 6.65 316.12 4429.30 4498.30 -54.26 -10.93 54.95 12.10E 4.00 3.47 5959428.20 653515.16 N 70.29610063 W 148.75686268 UG3 4522.88 7.54 314.66 4452.00 4521.00 -51.60 -8.92 52.97 10.65E 4.00 3.50 5959430.16 653513.13 N 70.29610612 W 148.75687876 4600.00 10.59 311.56 4528.15 4597.15 -39.99 -0.66 44.06 7.58E 4.00 3.59 5959438.24 653504.06 N 70.29612869 W 148.788 4700.00 14.57 309.46 4625.73 4694.73 -18.93 13.44 27.47 5.54E 4.00 3.72 5959451.99 653487.18 N 70.29616720 W 148.75 523 4800.00 18.55 308.25 4721.57 4790.57 8.83 31.29 5.26 4.37E 4.00 3.85 5959469.38 653464.62 N 70.29621596 W 148.75726506 End Crv 4800.78 18.58 308.24 4722.31 4791.31 9.07 31.44 5.06 --- 4.00 3.85 5959469.53 653464.42 N 70.29621638 W 148.75726664 UG1 4919.67 18.58 308.24 4835.00 4904.00 46.05 54.89 -24.70 --- 0.00 3.95 5959492.37 653434.19 N 70.29628044 W 148.75750758 WS2 5549.51 18.58 308.24 5432.00 5501.00 241.97 179.12 -1$2.34 --- 0.00 4.27 5959613.35 653274.05 N 70.29661984 W 148.75878398 WS1 5817.48 18.58 308.24 5686.00 5755.00 325.32 231.98 -249.41 --- 0.00 4.35 5959664.82 653205.92 N 70.29676423 W 148.75932706 CM3 5935.64 18.58 308.24 5798.00 5867.00 362.08 255.29 -278.99 --- 0.00 4.39 5959687.52 653175.88 N 70.29682790 W 148.75956653 CM2 6439.93 18.58 308.24 6276.00 6345.00 518.94 354.76 -405.21 --- 0.00 4.51 5959784.38 653047.66 N 70.29709963 W 148.76058856 CM1 7045.51 18.58 308.24 6850.00 6919.00 707.31 474.21 -556.78 --- 0.00 4.62 5959900.70 652893.69 N 70.29742593 W 148.76181589 THRZ 7362.01 18.58 308.24 7150.00 7219.00 805.77 536.64 -636.00 --- 0.00 4.67 5959961.50 652813.22 N 70.29759646 W 148.76245737 BHRZ 7604.66 18.58 308.24 7380.00 7449.00 881.25 584.50 -696.73 -- 0.00 4.70 5960008.11 652751.53 N 70.29772720 W 148.76294917 WeIlDesign Ver SP 2.1 Bld( doc40x_100) D-22\D-221PIan D-22C\D-22C (P8) Generated 6/11/2008 9:59 AM Page 1 of 2 Comments Measured Inclination Azimuth SutrSea ND ND Vertical NS EW Mag I Grav DLS Directional Northing Easting Latitude Longitude Depth Section .Tool Face Difficulty ft de de ft _ _ _ _ ft __-- -- ft _-. -- ft _ -- -- ft _-- -- de de 1100 ft ,..... Index . „ ftUS ~ ........... ... ftUS crnc~~ cn •, ~n nn~oo wnn w Iwo ~coconoc IJt TJD TJC TJB TJA TSAG 7" Csg Pt TSHU Crv 9/100 TSAD TCGL BCGL 23S8 22TS 21 TS Target / Crv 4/100 Crv 4/100 roa~.OY /o.ao 8223.94 18.58 8381.14 18.58 8524.62 8610.08 8712.40 8712.41 8712.42 18.58 18.58 18.58 18.58 18.58 8745.12 8780.41 8800.00 8823.72 8900.00 9000.00 9031.83 9100.00 9129.08 9200.00 9259.25 9300.00 9305.16 9306.32 9378.29 9400.00 9500.00 9594.67 9600.00 9700.00 9717.12 9800.00 9842.12 9900.00 18.58 18.58 20.35 22.48 29.35 38.34 41.21 47.34 49.96 56.34 61.68 65.34 65.81 65.81 69.77 71.00 76.83 82.52 82.84 88.95 90.00 93.32 95.00 92.82 JVO. LY 308.24 308.24 308.24 308.24 308.24 308.24 308.24 308.24 308.24 308.31 308.38 308.53 308.66 308.69 308.74 308.76 308.80 308.83 308.85 308.85 308.85 303.32 301.71 294.56 288.11 287.76 281.13 280.00 280.00 280.00 279.21 / V:JV.VV 7967.00 8116.00 8252.00 8333.00 8429.99 8430.00 8430.01 8461.00 8494.45 8512.92 8535.00 8603.57 8686.54 8711.00 8759.79 8779.00 8821.50 8852.00 8870.17 8872.30 8872.78 8900.00 8907.29 8935.02 8952.00 8952.68 8959.84 //LJ.VV J/ I.VL 8036.00 1073.88 8185.00 1122.78 8321.00 8402.00 8498.99 8499.00 8499.01 8530.00 8563.45 8581.92 8604.00 8672.57 8755.54 8780.00 8828.79 8848.00 8890.50 8921.00 8939.17 8941.30 8941.78 8969.00 1167.41 1193.99 1225.82 1225.82 1225.83 1236.00 1246.98 1253.35 1261.79 1294.29 1348.52 1368.36 1414.70 1435.97 1491.22 1540.67 1576.18 1580.75 1581.78 1647.28 8976.29 9004.02 9021.00 9021.68 9028.84 8960.00 9029.00 8957.60 9026.60 8954.55 9023.55 8950.60 9019.60 End Crv 9976.99 89.93 278.16 8948.75 9017.75 TD / 4-1/2" Lnr 10943.67 89.93 278.16 Legal Descriation: Surface : 3729 FSL 1692 FEL S23 T11 N R13E UD Target : 4919 FSL 3310 FEL S23 T11 N R13E UP TD / BHL : 5099 FSL 4523 FEL S23 T11 N R13E UD 8950.00 9019.00 1667.58 1763.47 1856.24 1861.48 1959.20 1975.73 2055.48 2095.92 2151.40 2225 00 706.65 -851.74 737.66 -891.08 765.96 -927.00 782.81 -948.39 803.00 -974.00 803.00 -974.00 803.00 -974.00 809.45 -982.19 816.41 -991.02 820.46 -996.14 825.83 -1002.93 846.55 -1029.02 881.26 -1072.50 893.98 -1088.40 923.74 -1125.52 937.40 -1142.54 972.93 -1186.76 1004.76 -1226.32 1027.63 -1254.72 1030.58 -1258.38 1031.24 -1259.21 1070.43 -1313.04 1081.41 1126.59 1160.40 1162.03 1186.86 1190.00 1204.38 1211.68 1221.31 1232 94 -1330.28 -1414.96 -1501.64 -1506.67 -1603.17 -1620.00 -1701.57 -1742.94 -1799.87 -1875.95 3146.81 1370.23 -2832.83 --- 0.00 --- 0.00 --- 0.00 --- 0.00 --- 0.00 --- 0.00 --- 0.00 --- 0.00 0.76R 0.00 0.70R 9.00 0.64R 9.00 0.50R 9.00 0.39R 0.37R HS HS HS HS HS 53.36E 51.27E 9.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 0.00 9.00 50.73E 48.74E 47.58E 47.54E 47.06E HS HS 160.09E 160.14E Northing (Yl fftUSl Easting (Xl (ftUSI 5959438.00 653460.00 5960594.59 651816.16 5960750.00 650600.00 9.00 9.00 9.00 9.00 9.00 9.00 4.00 4.00 4.00 4.00 0.00 4.78 5960127.06 652594.07 N 70.29806087 W 148.76420438 4.79 5960157.26 652554.11 N 70.29814557 W 148.76452300 4.81 5960184.82 652517.63 N 70.29822287 W 148.76481382 4.82 5960201.23 652495.90 N 70.29826892 W 148.76498703 4.83 5960220.88 652469.88 N 70.29832405 W 148.76519444 4.83 5960220.89 652469.88 N 70.29832405 W 148.76519446 4.83 5960220.89 652469.88 N 70.29832406 W 148.76519448 4.83 5960227.17 652461.57 N 70.29834167 W 148.76526075 4.84 5960233.95 652452.59 N 70.29836069 W 148.7629 4.85 5960237.89 652447.39 N 70.29837173 W 148.7 78 4.87 5960243.12 652440.49 N 70.29838640 W 148.76 77 4.94 5960263.30 652413.99 N 70.29844301 W 148.76564003 5.02 5960297.12 652369.81 N 70.29853782 W 148.76599216 5.04 5960309.51 652353.66 N 70.29857257 W 148.76612089 5.09 5960338.50 652315.94 N 70.29865384 W 148.76642149 5.12 5960351.81 652298.64 N 70.29869117 W 148.76655939 5.17 5960386.43 652253.71 N 70.29878821 W 148.76691747 5.21 5960417.44 652213.51 N 70.29887514 W 148.76723786 5.23 5960439.72 652184.65 N 70.29893761 W 148.76746787 5.24 5960442.59 652180.94 N 70.29894566 W 148.76749749 5.24 5960443.24 652180.10 N 70.29894748 W 148.76750420 5.28 5960481.31 652125.48 N 70.29905450 W 148.76794019 5.30 5960491.95 652108.02 N 70.29908451 W 148.76807982 5.36 5960535.38 652022.44 N 70.29920789 W 148.76876554 5.42 5960567.42 651935.10 N 70.29930021 W 148.76946752 5.42 5960568.94 651930.03 N 70.29930466 W 148.76950827 5.48 5960591.79 651833.06 N 70.29937244 W 148.77028972 5.48 5960594.59 651816.16 N 70.29938100 W 148.704 5.52 5960607.30 651734.32 N 70.29942025 W 148.77108661 5.53 5960613.75 651692.81 N 70.29944015 W 148.77142.166 5.55 5960622.22 651635.70 N 70.29946643 W 148.77188267 5.58 5960632.29 651559.41 N 70.29949814 W 148.77249876 5.76 5960750.00 650600.00 N 70.29987238 W 148.78024783 WeIlDesign Ver SP 2.1 Bld( doc40x_100) D-22\D-22\Plan D-22C\D-22C (P8) Generated 6/11/2008 9:59 AM Page 2 of 2 by Schlumberger WELL FIELD STRUCTURE D-22C (P8) Prudhoe Bay Unit - WOA D-PAD Magrellc Parameters Surtara Lwabon NAD2] Alaska Sute Planes. Zone 04. US Feet r, an i~. Model: BGGM 200] DiO. 60915° Dale: SeOtember 10. 2006 Lat: N]01]4fi 0]0 6ing 595943800 ftU5 Gdd COnv X116996069` _ NO ReI. Rotary Table 16900 Xabove MSL) Maq Dec. .23020° fS'. 5]6]6.3 nT W1a6 a52fi 30] Easling. 6534fi0.00 fiU5 Scale Facr.0999929]524 Pa.l Srvy DAe Juna 10. 2008 0 800 1600 2400 3200 ~_ 0 C I I N f0 U H 4000 4800 5600 6400 7200 _.._.._.._.._.._ ._.._.._ M~.._.._.._ .._.._.._.._.._.._.._. _ _.._.._.._.._.._.._.._. _.._.._.._.._.._.._.._ _ _.._.._.._ .... •. .. ....i ....... .. .. .. I~Vz... .. •. •. ...........•. .•.... .- •. ...... ....... .. • .... .. .. ...........,•............. .._.._.._.. _.._.;-.. _.._.. _.._.._.._.._ ._.._.._.._.._.._.._.._i._.._.._.._.._.._.._.._..~.._.._.._.._.._.._.. _.._..s.._.._.._.._.. o_ ._.._.._. _ _.._.._.._.._.._.._.._. _.._.._.._.._.._.._.._ _ _.._.. .. . _.._.. _.._j._.._.._.._.._.._.. _.._...j.._.._.._.. _.. _.._.._.._..~.._.. _.. rJ~ 8000 .......................:....................... .. _.. _.._.._.._.t_.._.._.._.. _.._. . _.._.._.._.._.t-.._.._.._.._.._. 8800 .._.._.._.._::-:.~-:: -:: -::.- ::- ::-•. 9600 .............................................. Target I Crv 41100 Crv 4000 4800 5600 6400 7200 8000 ::_.._::.:••z•:-::-::-::-::-::.:::,.._....._.._.._.._.,, 8800 't2L'(Fdj-.._.. End Cry Tp ~ 4-i12" Lnr 100 ....................................................................... 9600 0 800 1600 2400 3200 Vertical Section (ft) Azim = 295.69°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V by Schlumberger ~" D-22C (P8j FIELD Prudhoe Bay Unit - WOA STRUDTDRE D-PAD Magn&ic Parameters Suttace Lowlron NAD21 HUSka Stale Planes. Zone 04, US Feel Miscellaneous Motel. BGGM 2001 Dip: 80.915° Dale: SeDlem6er 10, 2008 Lal: NTO t ] 4fi 010 Nwlfling: 5959438.00 flU5 Gritl Conv: •1.16995099° Slob. 622 ND Rel: Rotary Table Ifi9 00 tt above MSL) Mag Dec: •23020° FS'. 51616.3 nT ton: W14845 2fi.301 Easling: 6534fio 0011US Scale Fact: 0.999926]524 Plan: D-22C (PB) Srvy Dale: June 10, 2006 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 1500 n n n Z ~ 1000 0 0 c a~ m U 500 v v v 0 1500 1000 100 l -3500 -3000 -2500 -2000 -1500 -1000 -500 0 «< W Scale = 1(in):500(ft) E »> - ~1~ ATas~ - - _._ -_ --~-rr~rco~nsion~-- -eport _ _ - -- . _._ __ _ --- Company: BP Amoco Uate: 6/11!2008 Time: 09:46:12 Page: 1 rield: Prudhoe Bay Reference Site. PB D Pad Co-ordinate(NE}Reference: Well: D-22, True North- Reference Well: D-22 Vertical (TV D) Reference: D-22C Plan 69.0 Reference Wellpath: Plan D-22C Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are tN2Ii'Hoeells in thisRt+i~dlpal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Y Maximum Radius: 1291.52 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 6/10/2008 Validated: NO Version: 2 Plaun€d->tirom--To----- _ purvey - - Toelsede- _ -_Toel-Name - - - - -- ft ft _- 90_.50 4140.50 - -_ _ __ D-22 Srvy 1 BOS$-Gyro 90.50-9 - -- BOSS-GYRO _ Sperrv_Sun BOS__S_gyro multi shot _ 4140.50 4450.00 Planned: Pla n #8 D-22C V1 GYD-GC-SS Gyroda ta gyro single shots 4450.00 8660.00 Planned: Pla n #8 D-22C V1 MWD+IFR +MS MWD + IFR + Multi Station -8660.0040943~ ~ - P+arrnec~Pla rr#8-D-22~V~ -~vIWl3+1€R+MS - ~1WD ~° IFR # Multt~tatiorr - ---- Casing Points - - _ _ NID TVD Diameter 1-fole Sue Name ft ft in in 2674.50 2674.16 13.375 17.500 13 3/8" 4150.00 4149.25 9.625 12.250 9 5/8" -8~'I~4'L_~499:00 -- X000- _ X500- -~ -_ _ _ - _ --- 10943.67 9019.00 4.500 6.500 4-1 /2" Summary - -- - _ <--------- Offset Wellpath -- -------> Reference Offset Ctr-Ctr No-Go ~UloHable Site Well Wellpath MD 111D Distance Area Deviation Warning ft ft ft ft ft -RB-I}Pad-- -~ -~3 -- --~3-©3 V'~-- - - -X451-73 43500 303.9 1170-- _-~2'L Pas~MajoFRisk - PB D Pad D-03 D-03A V1 4151.73 4350.00 303.91 117.70 186.21 Pass: Major Risk PB D Pad D-05 D-05 V1 4336.38 4320.00 588.87 55.11 533.76 Pass: Major Risk PB D Pad D-06A D-06A V3 8188.34 8525.00 372.21 207.66 164.55 Pass: Major Risk PB D Pad D-06AP61 D-06AP61 V5 7250.53 7505.00 523.87 127.69 396.18 Pass: Major Risk PB D Pad D-06 D-06 V1 7538.30- 7800.00 547.37 154.47 392.90 _ Pass: M_a~Risk _- _ PB DPad D-07 _ D-07 V3 4675.62 4975.00 341.84 150.55 191.29 Pass: Major Risk PB D Pad D-07 D-07A V2 4678.03 4980.00 342.24 150.95 191.29 Pass: Major Risk -PB-Dad - - D-E37- - ~-07B V'F--- -_4678-03-- 11980-00- -3424- =X51.06 1918 - amass: Major-Risl~-- PB DPad D-11 D-11 V1 4923.89 5410.00 1136.22 68.89 1067.33 Pass: Major Risk PB D Pad D-15A D-15A V2 4630.70 5025.00 611.48 155.43 456.05 Pass: Major Risk -- - -PAD Pad - - ~15 ~=TSV -4630.70- 5025:Off- _6fi1:48- 15543 -4b6:05 _ Risk Pass: Major PB DPad D-18 D-18 V17 4150.00 4230.00 694.69 50.03 644.66 Pass: Major Risk PB D Pad D-18 D-18A V11 4151.15 4230.00 695.97 50.05 645.92 Pass: Major Risk PB D Pad D-19 D-19 V6 4151.22 4145.00 345.65 50.74 294.91 Pass: Major Risk PB D Pad D-19 D-19A V2 4151.16 4145.00 345.65 50.74 294.91 Pass: Major Risk -P6-0 Pad--- ^-19- - ~-196-V2 ~152~~- -4145:OE) -34573 576 ~94~- ~ass:~Aajor R+sl~- PB DPad D-20 D-20 V1 4151.36 4215.00 684.13 65.93 618.20 Pass: Major Risk PB D Pad D-21 D-21 V1 Out of range - PB 6Pad-_ _ _ ~=22- -~Z2 Vim- -_- 4160:50- 4i7Q:00- -- O:fiT- _T2:9i _fiZ:8l~ FAIL: IG1iho~72Q~ PB D Pad D-22 D-22A V2 4160.50 4170.00 0.11 12.91 -12.80 FAIL: Minor 1/200 PB D Pad D-22 D-22AP61 V3 _.___4160.50 4170.00_ _0.11 _. 12.9.1_._ _ -12.80 FAIL: Minor 1/200 PB D Pad D-22 _ D-226 V13 4162.17 4165.00 0.15 12.92 -12.77 FAIL: Minor 1/200 PB D Pad D-23A D-23A V2 4167.54 4345.00 906.59 70.08 836.52 Pass: Major Risk -PB-0-Pad- _ _- -0-~3-- _ --0-23 V'1 - 467-54 -43400 90fr.59- X0-08- X36.-52 -Kass: Major Risl~ PB D Pad D-26 D-26 V3 4150.18 4205.00 327.73 65.83 261.90 Pass: Major Risk PB D Pad D-26 D-26A V1 4150.18 4205.00 327.73 65.83 261.90 Pass: Major Risk PB D Pad D-26 D-266 V6 4150.99 4205.00 328.51 65.86 262.66 Pass: Major Risk PB D Pad D-27 D-27 V1 4151.88 4230.00 307.93 59.67 248.26 Pass: Major Risk PB D Pad D-27 D-27A V3 - -_ 4151.88__ -4230.00 - 307.93 59:40 248.54 __ Pass_M~r Risk - PB DPad D-28A _ D-28A V1 4150.05 4160.00 63.79 55.59 8.20 Pass: Major Risk PB D Pad D-28AL1 D-28AL1 V1 4150.05 4160.00 63.79 55.59 8.20 Pass: Major Risk -RB{}Pad--_ -D-28 _ D-28~~ 4~5E~04 ~60:00 63.84 -559-- --~25 Pass:-MajorRlsk PB DPad D-33 D-33 V1 9478.22 12277.00 995.58 199.42 796.17 Pass: Major Risk i ~. .~_ -3 1 3 300 200 100 0 2 100 200 1300 --- 1 __~ FieldPrudhoe Bay SitePB D Pad We1].eathEl~n_._D-2.2~_' ~- P ~ - From KOP to TD Scan interval- Scale 1:100 0 D-221j~'B1 I Tar~et: D-22~ Geo poly! Site: PB I~ Pad I ~ ~ ~ ~ ~ wel~. ll-z~ ~ ~ ~, ~, Drilling Target ~onf.: ~5% 'i Based on: Plannt~d Program , Descri tidn: i Vert cal Depth: 950.00 ft be ow Mean S 'a Level p ~ I f i ~ ' - - - - .I . J.. ,.._~,. ,.., a , I r ,.,...i ~~.v Ic. i'~9.22 ft I 32.82 ft 5'48.892W i ~ , Map N ft 596 886.00 596 ~ 368.00 ~~, 596 368.00 596Q905.00 __ - --_," l '' ~ ' I I i~ TREE = 6" MCEV OY t~ A ILT/ \IATCC-. ff*I A M/I /~ll~A\IC 1 1\I~*** DATE REV BY COMMENTS DATE REV BY COMMENTS 01111183 ORIGINAL COMPLETION 08/29/06 RDW/TLH WANER SFTY NOTE DELETED 12/03/97 PARKER SIDETRACK (D-22A) 12/19/07 TFA/PJC SET PXN PLUG (12/13/07) 06/14102 JDM/KA RIG SIDETRACK (D-22B) 10/03/02 TLH/TP CORRECT 9-5/8" CSG DEPTH 09/03/04 WRR/TL GLV GO 03/16/06 ELZ/PAG WANERSAFETY NOTE (03/08106) PRUDHOE BAY UNff WELL: D-226 PERMff No: `2021050 API No: 50-029-20737-02 SEC 23, T11 N, R13E, 1550' SNL & 1692' WEL BP Exploration (Alaska) TREE = 6" MC;EV OY WELLHEAD= MCEVOY ACTUATOR= OTIS KB. ELEV = 71.8' BF' E1EV = 43.13' KOP = 8278' Max Angle = 95 @ 10786' Datum MD = 9275' Datum TV D = 8800' SS ~ D-22B ***POST PRE-RIG WORK*** 27' ~~ 7" X 4-1 /2" XO, ID = 3.958" 4-1/2" HES X NIP, ID = 3.813" 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 3.725" @ 8617' 4-1 /2" HES )C~ ~1~'r GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3257 3257 0 MMGM DMY RK - 09/03/04 3 5291 5245 22 MMGM DMY RK - 09/03/04 2 6661 6507 21 MMGM DMY RK - 06/14/02 1 7728 7519 18 MMGM DMY RK - 06!14/02 MILLOUT WINDOW - 8278' - 8294' PERFORATION SUMMARY REF LOG: SPERRY MWD/GR ON 11/18/97 ANGLE AT TOP PERF: 88 @ 10150' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 10150 - 10650 ~ 06/11/02 8567° ~-~Tubinp Cut 9-5/8" CSG, 47#, L-80, ID = 8.681" 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~14-1/2" HES X NIP, ID = 3.813" i 72' 7" X 4-1 /2" BKR S-3 PKR, ID = 3.875" 8596° 4-1/2" HES X NIP, ID = 3.813" 8617' 4-1/2" HES XN NIP, ID = 3.725" 4-1/2" LNR, 12.6#, 13-CR-80, .0013 bpf, ID = 3.958" ~--~ 8628' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" -C 4-1/2" LNR, 12.6#, .0013 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 01/11/83 ORIGINALCOMPLETION 08/29/06 RDW/TLH WAIVERSFTYNOTEDELETED 12/03/97 PARKER SIDETRACK(D-22A) 12/19/07 TFA/PJC SET PXN PLUG (12/13!07) 06/14/02 JDM/KA RIG SIDETRACK (D-22B) 07/08/08 jgr post pre-rig w ork f/D-22C Sidetrack 10/03/02 TLHlTP CORRECT 9-5/8" CSG DEPTH 09/03/04 WRR/TL GLV GO 03/16/06 ELZlPAG WAIVERSAFETY NOTE (03/08/06) 8147' ,~ 9-5/8" X 7" ZXP LNR TOP PKR 8277 TOP OF BKR WHIPSTOCK PRUDHOE BAY UNfT WELL: D-22B PERMff No: 2021050 API No: 50-029-20737-02 SEC 23, T11 N, R13E, 1550' SNL & 1692' WEL BP F~cploration (Alaska) TREE = 6" MCEVOY WELLHEAD= MCEVOY ACTUATOR = OTIS KB. ELEV = 71.8' BF. ELEV = 43.13' KOP = 8278' Max Angle = 95 @ 10786' Datum MD = 9275' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" SAFETY NOTES: ***4-1 /2" CHROME LINER*** ~D-22B Sundry HES ES Cementer, 9-5/8", 47#, L-80, Hydril 563 Casing - -2175` MD Minimum ID = 3.725" @ 8617' 4-1 /2" HES XN NIPPLE PERFORATION SUMMARY REF LOG: SPERRY MWD/GR ON 11/18/97 ANGLE AT TOP PERF: 88 @ 10150' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 10150 - 10650 ;w~ ??'%??7? $277' TOP OF BKR WHIPSTOCI MILLOUT WINDOW - 8278' - 8294' 9-518" CSG, 47#, L-80, ID = 8.681" 8618' I 7" X 4-112" ZXP LNR ~ TOP PKR, ID = 4.430" ,= 8629' 4-1/2" WLEG /TOC at -9351 ` MD 10856' ~-~ PBTD 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" EZSV CIBP - 4172` MD 8147' 9-5/8" X 7" ZXP LNR TOP PKR 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~4-1/2" LNR, 12.6#, .0013 bpf, ID = 3.958" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 01/11/83 ORIGINAL COMPLETION 08/29/06 RDW/TLH WANERSFTY NOTE DELETED 12/03/97 PARKER SIDETRACK (D-22A) 12/19/07 TFA/PJC SET PXN PLUG (12/13/07) 06/14/02 JDM/KA RIG SIDETRACK (D-22B) 06/06/08 JGR D-226 Sundry Application 10/03/02 TLHITP CORRECT 9-5/8" CSG DEPTH 09/03/04 WRRITLP GLV C/O 03/16/06 ELZ/PAG WANER SAFETY NOTE (03/08106) ~4-1/2" LNR, 12.6#, 13-CR-80, .0013 bpf, ID = 3.958" i Tubing Cut at - 8567` MD 8572' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8596' 4-1 /2" HES X NIP, ID = 3.813" 8617' 4-1/2" HES XN NIP, ID = 3.725" PRUDHOE BAY UNIT WELL: D-226 PERMfT No: 2021050 API No: 50-029-20737-02 SEC 23, T11 N, R13E, 1550' SNL & 1692' WEL BP Exploration (Alaska) CIW 4-1116" SK WELLHEAD = MCEVOY ACTUATOR= OTIS KB. ELEV = 71.8' 8F. ELEV = 43.13' KOP = 8278' Max Angle = 95 @ 10786' Datum MD = 9275' Datum TVD = 8800' SS D-22C ~oposed Nirrmm ID=3.725' @881T 4'U2' FBS JON NPPLE SAFETY NOTES: 2175' HES ES Cementer, 9-5/8", 47#, L-80, Hydrill 563 2200' 4-1/2"'X' Landing Nipple, ID=3.813" 2684' 13-3/8"CSG, 72#, L-80, ID=12.347" 3920' 9-5/8" X 7" ZXP LNR TOP PKR 4150' TOP OF BKR WHIPSTOCK D- 2B L ¢SV CIBP 4172' GAS LIFT MANDRELS ZXP LNR TOP PKR $147' 4-1/2" TBG CUT 8567' 7" X 4-1 /2" BKR S-3 8572' PKR 9-5/8" CSG, 47#, 8745' L-80, ID=8.681 " ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3 2 3750 3750 0 4.5x1.5 SV 1 6440 6345 19 4.5x1.0 DMY 8469' 4-1/2"'X' Landing Nipple, ID=3.813" 8489' 13-3/8"CSG, 72#, L-80, ID=12.347" 7" LNR, 26#, L-80, 8815' ID=6.276" Top of Cement ~ 9871' 4-1/2" LNR, 12.6#, 10945' L-80, ID=3.958" PERFORATION SU1M ~ LC)G: ANGLE AT TCM~ PEf f~bte: Refer to R~oduction DB for histc SQE SPF INTB7VAL C 8519' 4-1/2"'X' Landing Nipple, ID=3.813" 8549' 4-1/2"'XN' Landing Nipple, ID=3.725" 8569' 4-1/2", 12.6#, 13G-80, VamTOP 8562' 7" x 4-1/2" ZXP LNR TOP PKR, ID=4.430" 8712' 7" 26#, L-80, BTGM LNR, ID=6.276" 10944' 4-1/2" LNR, 12.6#, L-80, IBT-M, ID=3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 01/11/83 ORIGINAL COMPLETION 08/29/06 RDW/TLH WA V ER SFTY NOTE DELETED 12/03/97 PARKER SIDETRACK (D-22A) 12/19/07 TFA/PJC SET PXN PLUG (12/13/07) 06/14/02 JDM/KA R)G SIDETRACK (D-22B) 06/23/08 JGR Proposed Side track D-22C 10/03/02 TLH/TP CORRECT 9-5/8" CSG DEPTH 09/03/04 WRR/TLP GLV C/O 03/16/06 ELZ/PAG WAVER SAFETY NOTE (03108/06) PRUDHOE BAY UNff WELL: D-22C PERMIT No: 2021050 API No: 50-029-20737-03 SEC 23, T11 N, R13E, 1550' SNL & 1692' WEL BP Exploration (Alaska) D-22C PTD and Waiver Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, July 29, 2008 4:16 PM To: 'Vazquez, Eleazar' Cc: Hobbs, Greg S (ANC); 'Chasity R Smith ;Colombie, Jody J (DOA) Subject: RE: D-22C PTD and Waiver Page 1 of 1 ~. ~ `~. Eli, The permit is being worked on. I cannot tell you the status other than that. If you wish further information, please contact Ms. Chasity Smith at 793-1223 or Ms. Jody Colombie at 793-1221. Regarding the "stack clearance", the plan is acceptable since MASP is less than 3000 psi. Tom Maunder, PE AOGCC From: Vazquez, Eleazar [mailto:vazge0@BP.com] Sen#: Tuesday, July 29, 2008 4:10 PM To: Maunder, Thomas E (DOA) Subject: D-22C PTD and Waiver Good afternoon Tom, The drilling rig Nabors 7ES may move to D-22C in the next 4 days and the drilling permit has not come back to us. I was wondering if you could let me know what the status on that permit to drill is. Finally, given rig floor height limitations, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool and the MASP is s 3000 psi. Where existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams, a waiver is requested to allow the following operations on the initial BOP tests following nipple up: Full test of the stack and all its components with the exception of the lowest set of rams when there is equipment interference. When this interference occurs, the stack, with two tested rams and one tested annular, and the lowest rams with a body test only will be used to pull tubing on the subject weft. Following the removal of the tubing, a test plug will be set and the lowest rams tested before any other operations are undertaken in the well program. Please let me know if you have any questions or if you need any further assistance. Eli Vazquez BP Exploration Alaska GPB Rotary OrilUng Engineer Direct: 907.564.5918 Mobile 1:907.240.8137 Mobile 2: 915.346.6430 '7/30/2008 Alaska Department of Natural Resources Land Administration System Page 1 of~ ~ -t:a ~ ~ -._ . _ ~ :- ;~-.~ <<= r ~ur~~€'s Search State Cabins ~I~tu1~ ~ 4.1C~?~S _.....,,~.,. Alaska D Case Summary ~S Ntenu i Case Abstract i Case Detail i Land Abstract File: 1UL 2R2Rj "''` Sr:arch fc~r 5tat~5 Plat Updates ~~, ~,I 07'?-~%2008 Customer: 000107377 BP EXPLORATION (ALASKA)1NC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: ~~ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2560.000 Dcrte Initiated: 05/28/1965 Office of Primary ResPo~sibilit}~: DOG DIV OIL AND GAS Last Trarrsactior~ Date: 12/04/2006 Case Subt}~e: ~~ NORTH SLOPE LastTransactior~: AA-NRB ASSiGNMENTAPPROVED Ll~~rrdrrarr: U Township: O1 1N R~r~{fie: 013E .S'ecti~»1: 13 Sc~c~Gnn ,lc~r~~s: 6=1(1 Search Pats ;llrriJi~m: U 1 uu~n~ehih: 01 I \~ Rarz~~rc~.~ U I ; E S'rr~ ~i~,i~: 1 ~ Src~lrusz . arres: 6~0 ;ll~~ricliu~r: ~~ 7inr~tsi~ih: OI1N Ran,~r~,~.~ OI;I~; ,1'r~~Iiun: ~_; .ti'c~cllurt:tc~rc.~~: (i=~0 I~Ic~j~rrliur~.~ [1 lrnr~z~~laip: O11N R~r~t~rr°.~ Ul ~F .S'~~~~7ic~~~: "'~l 5~~rctru~t ]~:~~es: 610 Leal I)cscri~tiun OS-2b'-196 * * *SALE NOTICE LEGAL DESCRIPTION* C14-96 TI1 N-R13E- UM 13,14, 23, 2=l 2, 560.00 LISI3URNE PARTICIPATING AREA DESCRIPTION T. 11., R. 13 E., U. M. SECTION 13: _ALL 640 ACRES CONTAINING 6-10 ACRES, MORE OR LESS. http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28285&... 7/24/2008 TRANSMITTAL LETTER CHECKLIST WELL NAME ~~'L~ Q-v?v?G PTD# _ a?O~/a2/O ,~' - ' ~ . /Development~ Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: POOL: Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit Nv. API No. 50- - - API number are , between 50-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (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 / infect is contingept upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur.. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of weU) until after (Company Namel has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Namel must contact the Commission to obtain advance approval of such water well testing ro am. Rev: 111 I/2008 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Weli Name: FRUDHOE BAY UNIT D-22C Program DEV Well bore seg ^ . PTD#:2081210 Company BP EXPLORATION (RLASIUI) INC initial Classil'ype DEV I PEND GeoArea 890 Unit 11650 OniOff Shore On Annular Disposal ^ Administration 1 Pe[m_itfseaftaciled - --- ---- --- -- -- - - - --- --- NA -- ------- --- -- --- ---- ---- --- - -- -- ----- 2 Lease numberappropriate ------- --- - -- -- -- -__ Yes - ---- --- ---- -- - --- ---- --- -- --- - -- - --- 3 Unique well name andnttmbeC- ---- ---- - --- - -- - --Yes- ------ -- -- - ---------- --- ---- --- - -- --- -- 4 _Wt<IUccatedin.adeflnedpocl-----.------------------- ------------Yes-- ----PtudhoeBay9ilPCOL---_----------------------------------------------- 5 Waliigcatedpropardistapcef[omdrtllingunitboundary----------- -----------Yes-- -------..---------------------------------------------------_~--- -- 6 Wall iQCatad proper distance f[om etherwells- - - - - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 Sufficient acrEage ayBilAbla in_driping unit- - - - - - - - - - - - - - - - - -Yes - - - - 2569 acres. - - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 if-deviated~is.y~ellboreplat-tncluded-- ---- -- --- --- Yes- - --- --- - -- ----- - ---- --- - --- - - ----- ----- -- 9 Opscatoronlya8ectedRadY--- ----- --- - --- - -- --- Yes-- -- -- - - --------- ---- ------------ --- - - - --- -- -- - --- 10 Operator bas-appropriate.hondin_force-------------------- -------------Yes-- ----.BlanketSor~#6184193•--------.-------------------------------------------- 11 Pe[mitcanbe'lssuedwitb4utconseNati9aorder--------------- -------------Yes-- ---------------------------------~--------------- -- ....--- ------- --- Appr Date 12 PemaitcanbelssuedwJtbcufadministtatiYe_approval------------ -------------Yea-. ---..-------------------------------...------ --- ----- .. - -- ------ 13 CanRermitbeaRprovedbefgrsl5-day.wait- - ---- - -- -- -- --- - Y~ ------ -- --- ---- ----- --- --- -- -- -- -- - -- ----- ACS 7/2412008 14 VYalUocated wbhin area and_strata authorized bylnjection Orde[ # (putl~ in.commen~).(For- -NA - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 Aliwells_utithin114_milearea_ofreviswbentified(Fo[seruiceweliCnty)__ ______________NA--. ------------------...----------------------------- -- --- - - -- ----- 16 Pte-preducedinjectCr,duration-ofpreproductiCn lessthan3menths-(Forsarvicewallanly).--NA-- ---------------------------------------------- -- .---- - ---- ---- 17 _Konconven,gas_cCnfCrmBicAS31.05.09Q(j.1.A),(62.A-i)) - ----- - - ---NA-- --- -- ------- -- - ------ ----- ------ --- - ----- --- ------------- Engineering 18 Conductorst[ing.Rrev~ed-------------------- - -- ---- -----~-- ----CcnduCtOrsetinD-22jt82.053)------------------------------------------------- 19 SutfacecasingRrotectealiknoNmUSDWS------------------ --------------NA- ----_Alla4uifersexempted,-AEO1.-._.---------------------------------------------- 20 CMT_voladequateigr~rculaakeonconductot8surf_ca9----------- -------------NA-- ------Surfas~casingsetinD-22,------------.-.------------------------------------- 21 CMTv_oladgquatet9tiedn_Iengatringtosurfcsg_._-.__----__. --_-------_-Yes. __----Newt"-linerwilltlefulty cemented,__________._--------------------_---_-.------ 22 CMT will coverahknown-prcxluctiveberizons----------------- -------------Yes- -----.-.-------------------------------------- - --- --- - ----------- 23 Casing designs adequatefotC,T,B&-Petmaftost-------------- -------------Yes- -------------------...------------------------- -- --- -...-- - ---- 24 Adequate tankage or resenrepit - _ - - _ . - . _ _ _ - - - - - - - - - - - - - - - - - - - Yes . _ _ - - _ _ Rig equipped with steel pits, Notesenre pit planned.- Ali weste_t4approved dispoBalwelt(s), - .. - - - .. - - . - _ 25 If_are-dtilGhas_a10.40$f4rehandvnmentbeenaRproved--------- ------------Yes- ------3Q8.207-----.------------------------------------------ -- ------ 28 Adequate-wellbore separationpropCSed - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes . - - - _ - _ Proximity anatysis perfo[med, T[aveling Cylinder path calculated, Paths diverge ftom KQP._ - - . _ - - - - - - . - - 27 If dwe[tQrlequilQd,doeaitmeetre®uleiipns-.--------------- -------------NA- ---..-BOPStackwiU already-be-inRiace,---------.-.---------------•----------------.. Appr Date 26 Drilling fluidprogtam schematic & equip list_adaquate- - - - - - - - - - - - - - - - - - - - - - - -Yes - - . _ - - - Maximum expected fo[mation pressure6,5_EMW1n 8.5"hole MVy Rlanned 1Q,2 ppg, - - - - - - . - . - _ - .... - TfM 712912008 29 BOPI=s,-do_ttleymeetrsgulation ---- -- - - -- - - - -- Yes- -- - --- ----- --- -- --- --- --- ----- -- --- --- - J'~a~~ 30 BOPE-press rating app[opriate; tflst to_(Aut psig in cCmments)_ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ MASP Calculated at 2207psi, 3500_psi_BOP tesiplanned, 6QL' 31 Choke-manlfeldcempiiaswiAPlRp-53(May$4)-_____________ _______--_._Yes_ - - - - - - - - - - - - - - - - --____-...-_ 32 -VY4rkwihoccutwithout_operatronsbutdown----------------- -----------.Yes- -----------.------------------------------------- -- --- --- - 33 Is presence of H2S gas probable - - - -- - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - -Yes _ _ - - - _ UR to 59 ppm H2S repoded_on D pad, Mud shouid_preclude H2S en rjQ. Rig hae aensCrs and alarms, - _ . - _ _ - 34 _Mechanlcal_cCnditionofvtellswithigA4Ry8rifiad(FCrservicewellonty~- ----------.-NA-- ----------------------------------------------- - --- --- - --- ------ Geology 35 Pe[mitcanbalsauedwtohydr_ogertsulfidameassxes--------- -------------N°-- ----.-WeilD-15AMax.H2$59RRm41f210;i)•-------------------------------------------- 36 Data_presentedonpotentialQVerpressuresCnes--------------- ------- -----Yes- ----------------------------------------------- --- -- --- - ---- Appr Date 37 Seismicanalysis Qf shailcwgas zon8s- - - - - - - - - - - - - - ~- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ACS 7!2412008 38 SeabedcCnditronsurvey_(ifo~-shote)--------------------- ------------- NA- -- 39 ContaCtnamelphoneforweekly_pregressrepCrts_[explotatoryenty]---- ------- -----Yes- -----JohnRCSe-564-5271,_----------------.-------._.--------.-----------__-- Geologic Commissioner: Engineering Date: Commissioner: Date m ner Date ~-3a^ o8 C~