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Home My WebLink About207-022MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, February 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 09-15A PRUDHOE BAY UNIT 09-15A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 02/17/2023 09-15A 50-029-20256-01-00 207-022-0 G SPT 8534 2070220 2134 1980 1986 1990 1988 0 0 0 0 4YRTST P Adam Earl 1/3/2023 4 Year MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 09-15A Inspection Date: Tubing OA Packer Depth 0 2753 2617 2570IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230106111741 BBL Pumped:6 BBL Returned:5 Friday, February 17, 2023 Page 1 of 1         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y Anne Prysunka at 4:18 pm, Oct 04, 2022 'LJLWDOO\VLJQHGE\'DYLG%MRUN '1FQ 'DYLG%MRUN RX 8VHUV 5HDVRQ,DPDSSURYLQJWKLV GRFXPHQW 'DWH 'DYLG%MRUN DSR-10/4/22 RBDMS JSB 100622 MGR09OCT2022 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name: Authorized Title: Authorized Signature: Date: Contact Name: Contact Email: Contact Phone: COMMISSION USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE COMMISSIONCOMMISSIONER PBU 09-15A Convert WAG to GI Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-022 50-029-20256-01-00 N/A ADL 0028324 & 0238327 15820 Conductor Surface Intermediate Liner Liner 8735 79 2703 7454 2767 5904 12047 20" 13-3/8" 9-5/8" 7" 4-1/2" 8812 29 - 108 28 - 2730 25 - 7479 7303 - 10070 9914 - 15818 29 - 108 28 - 2730 25 - 6891 6750 - 8669 8567 - 8735 13550 520 2670 4760 5410 7500 12047, 12579, 13550, 14249, 14755, 15100, 15230 1530 4930 6870 7240 8430 11705 - 11766 4-1/2"12.6# L-80 23 - 99208811 - 8810 Structural BKR S3, BKR HRD 4-1/2" MCX SSV 9863, 9914, 1998 8534, 8567, 1998 Date: Bo York Sr. Area Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 PRUDHOE BAY, PRUDHOE OIL 10/11/2021 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 1:27 pm, Sep 30, 2021 321-520 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.09.29 10:13:59 -08'00' Bo York X DLB 09/30/2021 MGR11OCT2021 10-404 DSR-9/30/21 dts 10/11/2021 JLC 10/11/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.11 13:35:36 -08'00' RBDMS HEW 10/12/2021 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ® Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. Mud Acid Stimulation 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number: 207-022 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Slratigraphic ❑ Service 0 6API Number: 50-029-20256-01-00 1 7 Property Designation (Lease Number): ADL 028327 & 028324 8. Well Name and Number: PBU 09-15A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL I t. Present Well Condition Summary: 12047, 12579, 13550, Total Depth: measured 15820 feet Plugs measured 14249,14755, 15100, 15230 feet true vertical 8735 feet Junk measured 13550 feel Effective Depth: measured 12047 feet Packer measured 9863 feet true vertical 8812 feet Packer true vertical 8534 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" 29-108 29-108 1530 520 Surface 2702 13-3/8" 28-2730 28-2730 4930 2670 Intermediate 2703 9-5/8" 25-7479 25-6890 5750/6870 3090 / 4760 Liner 2767 7" 7303-10070 6750-8668 7240 5410 Liner 5904 4-1/2" 9914-15818 8567-8735 8430 7500 Perforation Depth: Measured depth: 11705 -15650 feet True vertical depth: 8811 -8737 feet Tubing (size, graft measured and true vertical depth) 4-1/2" 12.6# L-80 23-9920 23-8570 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Penn Packer 9863 8534 true vertical depth) 4-1/2" Mi SSSV 1998 1998 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11705'- 11866' Treatment descriptions including volumes used and final pressure: Pump 60 bbis 12% HCI and 50 bbis 9.1 mud acid in 3 stages w/ Oilseeker diversion. 1st diversion stage increased treating pressure 500 psi, 2nd stage -400 psi. Performed a mini injectity test with 10 bbis of diesel, the well was already freeze protected the previous day with 70 bbis of diesel: 1 bpm @ -1150 psi, 2bpm @ -2033 psi. Final Pressures: OA = 20 psi, IA = 40 psi, TBG = 2180 psi. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 8266 7 2180 Subsequent to operation: 33032 40 2160 14. Attachments: (regmrea per 20 rine 2507025071, s 25.2113) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-570 Authorized Name: Lastufka, Joseph N Contact Name: Alatalo, Travis Authorized Title: Speci li Contact Email: Travis.Alataloabp.com Authorized Signature: Date: 2'V Contact Phone: +1 9075645351 Form 11 Revised 04/2017 � ,7o2A """"�''�Z;6 `6 RBDMS FEB 2 5 2020 Submit Original Only Daily Report of Well Operations PBU 09-15A ACTIVITVRATP cH umAev ***WELL INJECTING ON ARRIVAL SWCP 4521 ***(profile mod) DRIFT TO & EQUALIZE 4-1/2" MCX @ 1,998' MD W/ 3.805" G -RING, 4-1/2" X -EQ PRONG PULLED 4-1/2" MCX-SSSV (sn: MP -401) FROM 1,998' MD DRIFT W/ 11' x 2-7/8 DMY PERF GUNS (3.15 od), 3.70" CENT & 3" SAMPLE BAILER DEVIATE OUT @ 10,360' SLIM 1/18/2020 ***CONT WSR ON 01/19/20*** ***CONT WSR FROM 01/18/20*** (profile mod) SWCP 4521 RIG DOWN 1/19/2020 ***WELL LEFT S/I ON DEPARTURE*** CTU #8 1.75" coil 0.156WT Objective: Set CIBP. Add perf. Contingent Mud Acid MIRU. Make up and RIH with 2.900" logging carrier and 3.65" JSN. Load and kill well with 302 bbl of 1 % KCI. Tag at 12328 (high) and log up to 9750. Flag painted at 12000. POOH. 1/23/2020 ***Job Continued on 1/24/2020*** CTU #8 1.75" coil 0.156WT Objective: Set CIBP. Add perf. Contingent Mud Acid Continue POOH with logging tools. Good log shows a -13.5' correction, making corrected EOP at flag = 11976.27'. Makeup and RIH with 4.5" BOT CIBP to flag. Correct depth and set top of cibp ay 12,047'. Confirm plug set. Pooh. Make up and Rih with 2-7/8" x 31' SLB PJ pe gun ag correct depth. Perforate 11835- 11866'. Pooh. Makeup and Rih with 2-7/8" x 31' SLB PJO pert gun #2. Tag CIBP, correct depth. Perforate 11735'- 11766'. POOH. Makeup new CTC and MHA. Make up and Rih with 2-7/8" x 31' SLB PJO pert gun #3. 1/24/2020 ***Job Continued on 1/25/2020*** CTU #8 1.75" coil 0.156WT Objective: Set CIBP. Add perf. Contingent Mud Acid Continue RIH with 2-7/8" x 31' SLB PJO perf gun #3. Perforate 11705-11736. POOH. Perform injectivity test - 1.2bpm @ 2000psi. Load out acid. Made up and RIH w/ 2.5" JSN. Load well with 3% NH4CI w/ F103. 1/25/2020 ***Job Continued on 1/26/2020*** CTU #8 1.75" coil 0.156WT Objective: Set CIBP. Add pert. Contingent Mud Acid Continue injecting in 3% NH4CL. Bullhead 70 bbls of diesel down backside. Pump 60 bbls 12% HCI and 60 bbls 9:1 mud acid in 3 stages w/ Oilseeker diversion. 1st diversion stage increased treating pressure 500 psi, 2nd stage -400 psi. Performed a mini injectity tests with 10 bbls of diesel, the well was already freeze protected the previous day with 70 bbls of diesel: 1 bpm @ -1150 psi, 2bpm @ -2033 psi. Tags hung on well. RDMOL 1/26/2020 ***Job Com lete*** ****WELL SHUT IN ON ARRIVAL**** (Profile Modification) RAN 4-1/2" BRUSH, 3.80" G -RING TO X -NIP @ 1,998' MD SET 4-1/2" MCX-SSSV (Serial # BPX4-65, 1.30" bean) @ 2,001' SLM / 1,998' MD RAN CHECK SET TO MCX @ 1,998' MD (Sheared) 2/4/2020 ****WELL LEFT S/I & DSO NOTIFIED OF STATUS UPON DEPARTURE***** TREE= 4-1/16" CIW VIELLHEAD= 13-5/8'FMC ACTUATOR= BAKER KB. ELEV = 54' BF. R = 6 KOP= 2750' Max Angle = 96' @ 10689' Datum MD= 10395' DatumTVD= 8800' SS 09-1 20' CONDUCTOR 94#, FF40, D = 19.124" 100' TOP OF 7" LNR 7304' Minimum ID = 3.726" @ 9908' 4-1/2" HES XN NIPPLE 9-58" WHIPSTOCK (04/14/07) 748W 9-5M"FZSV(TAGGED 04/13/07) 7601' 9518" CSG, 47#, N -BO BTC, D = 8.681" H 7601" PERFORATION SUMMARY REF LOG: MWD / GR ON 05/04107 ANGLE AT TOP PERF: 91" @ 11705' Note: Rear b Production DB for Nsbrical perfdate SIZE SPF INTERVAL OprWSqz SHOT SOZ 2-718' 6 11705-11736 0 012520 12974 2-718" 6 11735-11766 0 012420 3.958' 2-718" 6 11835-11866 O 012420 2 2-7/8" 6 12229-12325 C 0726/18 4-12' X 5-3/4' 2-718" 6 12750-12846 C 04130/17 2-718" 6 13400-13500 c 10/08/14 2-718" 6 14000-14100 C 1027/12 2-718• 6 14560-14660 C 02/16/11 2-7/8" 6 15030-15055 C 08/01/09 2-78" 6 15055-15080 C 08/01/09 2-718" 6 15080-15105 C 08/01/09 2-718" 6 15105-15130 C 08101/09 2-718" 6 15350-15400 c 16/10/08 2-718" 6 15456-15500 c 10109/08 2-718 6 15550-15650 c 05/07/07 BKRCBP 1204T 20) BKR CBP 12579' i/18) FLSH- MILL & PUSFED —i BOT 2.4" OF 3.71' BURN SHOE (723118) 4-12" WFT CBP 1(1025/12) PBTD 15731' =3 1�R1R" n xw-, u=a.51j 2623' 1-19-5/8" FOC 9-518" X T BKR C-2 ZXP LTP w / 11.6' TIEBACK SLV, D = 6.32" 7322" 119-5/8" X 7" BKR HMC LNR HGR D = 6.35" 8-12" MLLOL)T W NDOW (09-15A) 7479' - 7492' 9M' j 7" X 4-02" BKR S-3 PKR D = 3.875' 988T 4-12" FES X NP, ID - 3.813" 9908' 4-12• FES XN NP, D= 3.725" 991—17" X 5" BKR HRD 9920' ZXP LTP, D = 4.410- 4-1/2" WLEG, D = 3.958" 9936' MIN D 7" X 5" BKR FLIX LOCK LNR HGR ID = 4.420' 4-12" X 5-3/4" 5" X 4-112" XO, D = 3.940" TAM SWELL PACKERS NO SIZE TOP DEPTH MIN D 6 4-12" X 5-3/4" 12278 3.958• 5 4-12' X 5-3/4' 12974 3.958" 4 4-112"X5-314" 13750 3.958' 3 4-12" X 5-3/4' 14321 3.958• 2 4-1/2" X 5-3/4' 14852 3.958" 1 4-12' X 5-3/4' 15298 3.958" 14�—j4-12-HM CBP(02/15/11) L 1 PRUDHOE BAY UNIT WELL: 09-15A PERMIT No:x1070220 API No: 50-029-20256-01 SEC 1 TI ON, R15E 99Y FSL & 150' FWL DATE REV BY COMMENTS DATE REV BY COMMENTS 09/18177 ROW 34 INITIAL COMPLETION OB/08/18 JDM/JM MLLED & SET CBPIFISH/ADPERFS 10/00187 PAA102 RWO 012820 JDMUMD SETCBP&ADPERFS 06/09107 N2ES SIDETRACK 09-1510 10/06/14 CT/ PJC SET CBP 10/08/14 TA/PJC ADPERFS SP Expbration(Alaska) 05/W/17 DWTJMD SET CBP&ADPERFS 042930/17 THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Travis Alatalo Production Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 09-15A Permit to Drill Number: 207-022 Sundry Number: 319-570 Dear Mr. Alatalo: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a ogcc. a laska. gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, la� Daniel T. Seamount, Jr. Commissioner DATED this1_day9 of December, 2019. 1BDMS��DEC 19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 C o 6 a 1. Type of Request: Abandon ❑ Plug Perforations 0 • Fracture Stimulate ❑S p 7 Repair Well ❑ IDP' ba'�dti0ns%s t Suspend ❑ Perforate 0 . Other Stimulate 0 Pull Tubing ❑a A ro �rogrem ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Mud Acid Stimulation 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit [o Drill Number: 207-022 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Shatigraphic ❑ Service 0 6. API Number: 50-029-20256-01-00 7. If perforating: / What Regulation or Conservation Ober governs well spacing in this pool? e. Well Name and Number: Will planned perforations require a spacing exception?r1;`i Yes [INo 0- /le9. PBU 09ASA Property Designation (Lease Number): 10. Field/Pools: ADL 028327&028324 PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): h MD: Effective Depth TVD: Plugs (MD): Junk Junk (MD): 15820 87359 8808 12579,135s0,14249 14755,15100,15230 13550 Casing Lengthize MD Burst Collapse SWctural Conductor 79" 29-108 29-108 1530 520 Surface 2703/8" 26 - 2730 0 #-8735 MTubing 4930 2670 Intermediate 7454/8" 25 - 7479 90 5750/6870 3090/4760 Liner 2767" 7303 - 10070 68 7240 5410 Liner 59042" 9914 - 15618 35 8430 7500 Perforation Depth MD (ft): Perforatioft): Tubing Size: Grade: Tubing MD (ft): 12229 - 15650 4-1 /2" 12.6# L -80L-80 23-9920 Packers and SSSV Type: 4-1/2" Baker S-3 Pemt Packer Packers and SSSV MD (ft) and TVD (ft): 9863/8534 4-1/2" MCx SSV 1998/1998 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 . 14. Estimated Date for Commencing Operations: 12/30/2019 • 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Alatalo, Travis be deviated from without prior written approval. Contact Email: Travis Alatalo@bp.cem Authorized Name: Alatalo, Travis Contact Phone: +1 9075845351 Authorized Title: Production Engineer Authorized Signature: Date: f Z l 6 ( i COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integnty O ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ iBDMS-*`' DEC 19 2019 Spacing Exception Required? Yes ❑ No l� Subsequent Form Required: /0— L16;y Approved by. COMMISSIONER COMMISSION Date:/2,/ 1 ACOMMISS1 BVTHE nroo (I P'c 12-1100 Form 10-403 Revised 04/2017 ORIGINAL #1&&17t g Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate 30-403 Sundry Application for Well PBU 09 -SSA PTD #207-022 Expected Start Date: December 30, 2019 Current condition of well: WAG Injection Well, Operable, Online: Water Injection Rate: 0 bw d Gas Idection Rate: 20933 Mscf/Da Injection Pressure: 2948 psi Reservoir Pressure: 3332 psi Program Objective(s): Add perfs for next MIST stage. Contingent acid stimulation to ensure sufficient injectivity. 09-15A has been injecting MI in the current MIST location for over a year and has reached its target cumulative MI. It is time to move uphole for the next bulb. Historically, this well has had poor injectivity post perforating, so we are planning a contingent acid stim to ensure the well can take the proposed rates. Since the well was not swapped to PWI during this cycle, no SBG is required. Proposed Program: 1. Pull MCX from X nipple at 1,998' MD. Drift for CT. 2. Set CIBP at 12,047' MD. 3. Add perfs according to attached perforating form. 4. Perform injectivity test with non freezable fluid. If injectivity is less than 2 bpm @ 2,000 psi perform contingent acid stim per attached procedure. 5. Set MCX for —20MM target rate in X nipple at 1,998' MD. Current MCX has 1.31" bean. BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU 09-15A PTD #207-022 Proposed Perforating Procedure: WOPROPOSED PERFORATING PROCEDURE global wells organization Wall, 09-15A API#: SD029-2025601-00 > miap M, 19071566-5351 Date: 12(3/2019 - Pmtl Engineer TauisMatab Secerbary Ph. (907)378-3949 CC m AFE: Reference Log Loc MWD/GR _ DATE-_ 5/612007 CompanyHagibunc Depths (from - to 11,705_il; 11,113Y 11,1 Requested Gun Size IOR TYPE Work Desor,mar. I � — Set CtBP=d perfs, cemngmtacitl stun. Tie -In Log Use shale at-11,80Dfort a in. Add 3 feet to the titin log to be on depth wrth the raference log H_L!� 25pp ..-to) Feet SPF Orientation Phasing Zone HIRE TYPE 11,762' W _ 6 Random _ 60' 42 ADD PERE_ 11,862_ _ 30' _ 6 _ _ Random by _ ZZ _ ADDPERF_ 2-7/8" Charge Maxfo�e Mn'Nxllbore lD: _ 3_73"_ Max Swell in liquid. 3.05" Max Swell in Gas: W hi Drawdown Necessary/Ocsired/Unnecessary During Perforating Preferred Amount of Drawdown/Suggestions to ANieve Drawdown Last Drift _12602 - fitmoon aiZ/2018 Ell Res -P. eswre@ 8.80 Dss_MD is 3332 psi BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Tie In Log: 10-403 Sundry Application for Well PBU 09-15A PTD #207-022 Apt Serial No. Section R Township anq:: r$ iir U 50-029-20256-01 1 10N 15E Logging Date 6 -Oct 2014 j Run NrxnN-r 1 Depth Driller _ .. 14249 It 14251.8 ft 14245 It ---- 1+600 It - -- — Various SaRYty,._. Density Fluid Level _ BITrCASINGrTUBING STRING Bpi Size From To -- - - Caslrxr/Tab-.rte Sr.e-.4.500 :n ... we fit 12.6 It wit i I lu"y r+o rt TO --- ----- - - - - 1581 F. h ---- --- _.._... . . -- - - --- - 1 - _— --_- - -. Maximum Recorded_ Temperatures Logger On Bottom Tim 5 -Oct --2014 1.33 UNt Number Location_ 59 Prudhoe Bev —By — ----onSurd --- --__. - - Recorded _ Jason Bu BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Memory Depth Determination �+ Lee GR/CCL r�NA 06 -Oct -2014 "t � a - "" 993.19' FSL & 150.25' FVJL Elev.: K.B. 46.50 It w $ At Surface G.L. U) LL 6 n < D.F. Td m o_ U Permanent Datum: AfSL Elev.: O.00 It Z a . rn O - - - - ..---- - -- Log Measured From RKB 4&50 R ... _. above Perm. Datum Drillinq Measured From: RKB Apt Serial No. Section R Township anq:: r$ iir U 50-029-20256-01 1 10N 15E Logging Date 6 -Oct 2014 j Run NrxnN-r 1 Depth Driller _ .. 14249 It 14251.8 ft 14245 It ---- 1+600 It - -- — Various SaRYty,._. Density Fluid Level _ BITrCASINGrTUBING STRING Bpi Size From To -- - - Caslrxr/Tab-.rte Sr.e-.4.500 :n ... we fit 12.6 It wit i I lu"y r+o rt TO --- ----- - - - - 1581 F. h ---- --- _.._... . . -- - - --- - 1 - _— --_- - -. Maximum Recorded_ Temperatures Logger On Bottom Tim 5 -Oct --2014 1.33 UNt Number Location_ 59 Prudhoe Bev —By — ----onSurd --- --__. - - Recorded _ Jason Bu BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 *, AI 5 =,l L,,.4 10-403 Sundry Application for Well PBU 09-15A PTD #207-022 Contingent CTU Acidize: Design Details Wellbore Volume 179 bbls to mid pert- 11,785' MD Volume Across Perfs 57 gallons — 90' in 4-1/2" liner Acid Design 12% HCI Acid @ 28 gpf — 60 bbls 9:1 Mud Acid @ 28 qpf-60 bbls Pm Tres 3332 psi & 1640F @ 8800' Datum SS Fluid Requirements Fluid Type Vol, bbl Vol, gal 3% NH4CI 590 24,780 3% NH4CI + 5% Musol 150 6300 3% NH4CI + 7.5% OilSeekeer 12 504 12% HCI 60 2520 9:1 Mud Acid 60 2520 Neat McOH 10 420 HCI & HF (L-80) Loading for: Function: Units: 12% HCI tot chemical 9:1 Mud Acid tot chemical Product Code: Function: per M al in HCI (qaIL per M al In 9:1 al A264 ACI 4 12.6 4 12.6 A201 Inhibitor Aid 0 0 0 0 A153 Intensifier 0 0 0 0 F103 Flowback aid 2 6.3 2 6.3 L058 Iron Control 20 63 20 63 W054 Antiemulsifier 5 15.8 5 15.8 0067 Mutual Solvent 0 0 50 158 Loadin For: 3% NH4CI Product Code: Function: Units: per M al tot chemical F103 Flowback aid al/M al 2 32.8 Loading For: 3% NH4CI + Musol Product Code: Function: I Units: per M al tot chemical F103 Flowback Aid al/M al 2 12.6 U067 Mutual Solvent I gal/Mgal 50 315.0 Loading For: 3% NH4CI + 7.5% OilSeeker Product Code: Function: Units: per M al tot chemical J570 OilSeeker al/M al 75 37.8 Neat McOH H al/M al 10 5.0 F103 Flowback Aid Gal/M al 2 1.0 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU 09-1SA PTD #207-022 Target Intervals We are targeting 90' of perforated interval. 11,705-11,765' & 11,836-11,865' Notes: • Tubing is in good condition, no need to hold pressure on IA. • No GL mandrels so no TIFL is required. MIT -IA passed 01/15. • Do not add friction reducer to stimulation fluids that will enter the perforations. • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. • Send an electronic copy of the treatment report to Travis Alatalo: travis.alatalo(o7bo com CTU Acidize 1. MU BHA including JSN for acid job. 2. RIH while loading well down backside then CT with 260 bbls of 3% NH4CI. 3. Injectivity should be low enough (pre -acid) where keeping positive WHP is easily achievable. 4. Pump the following fluids per schedule below. o Reciprocate nozzle across perforated interval during treatment. Try to maintain WHP of 1700 psi during acidizing by increasing rate as injectivity increases. Can go up to 3000 psi if diversion locks up formation. BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU 09-15A PTD #207-022 Step Description Fluid Comment Stage Fluid Vol, bbl Cum Vol 1 Spear McOH Pump down backside 5 5 2 Pre -flush 3% NH4CI + F103 Pump down backside 220 220 3 Pre -flush 3% NH4CI + F103 Pump down CT 40 260 4 Acid 12% HCI Swap to pumping down CT & reciprocating 20 280 5 Acid 9:1 Mud Acid 20 300 6 Over -flush I 30ANH4CI+F103 50 350 7 Diversion 7.5%OilSeeker 6 356 8 Shut Down Shut down for 10 minutes once all diversion is into formation 9 Spacer 3% NH4CI + F103 40 396 10 Acid 12% HCl Swap to pumping down CT & reciprocating 20 416 11 Acid 9:1 Mud Acid 20 436 12 Over -flush 3%NH4CI+F103 50 486 13 Diversion 7.5%OilSeeker 6 492 14 Shut Down Shut down for 10 minutes once all diversion is into formation 15 Spacer 3% NH4CI + F103 40 532 16 Acid 12% HCI Continue pumping down CT & reciprocating 20 552 17 Acid 9:1 Mud Acid 20 562 18 Over -flush 1%KCI+F103+5%Musol 150 712 5. POOH pumping diesel for CT displacement & RDMO. BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 E= 4-1/16" CJW 1IfA0=,3_5/8EIAK 09-15A LIATOR= BAKER EFL/ = ___.__._ . LE—v= _ A '-_ ng—_ -----`2750' le = 96` (§ 10689 IMMD= 10395' im D_- 88W SS 20" CON� 94#, 1440, D=19.124" 100' 9-518" I 2730' I TOP OF 7" LNR 7304' Minimum ID = 3.725" @ 9908' 4-1/2" HES XN NIPPLE I9-5/8" W1R8TOCK (04114/07) 9-5/8" FZSV (TAGGED 04/13!07) I- 12.6#, L-80 TCO, .0152 bpf, D= ?6#, L-80 BTC -M,.0383 bpf, D = PERFORATION SUMMARY REF LOG: MWD/ GR ON 05/04/07 ANGLEATTOP P92F: 89` @ 12229' Note: Refer to Production OB for historical perf data SQE SPF rrrE RVAL Opn/Sgz SHOT SW 2-7/8" 6 12229- 12325 O 07/26118 , 2-718" 6 12750 - 12846 C 04/30117 14852 2-7/8" 6 13400 - 13500 C 10108!14 2-7/8" 6 14000 - 14100 C 10/27/12 2-718" 6 14560-14660 C WJ16/11 2-718" 6 15030- 15055 C 08101!09 2-7(8" 6 15055- 15080 C 08101/09 2-7/8" 6 15080-15105 C 08/01/09 2-718" 6 15105- 15130 C 08/01/09 2-7/8' 6 15350- 15400 C 10/1008 2-7/8' 6 15450- 15500 C 10/09!08 2-718" 6 115550-1 C 05107107 i2. BKR CIBFI 12579' '25118)18) MLL & FL5F® 13550' 2.4' OF 3.71' VVFN CSP 1 Lam, 114) FES CUP 14249' D = 3.958" SAFETY NOTES: H2S READINGS AVERAGE 125 ppm WHEW ON MI —WELL REQUIRES A SSSV WHEN ON MI -'WELL ANGLE> 70° @ 10375 — MAX DOGLEG: 18.4" @ 103"' — 1998' 4-1/2"FES XW. D=3.813" 19518' FES ES CEMENTER I 73W �9-5/8• X 7• BKR C-2 ZXP LTP w / 11.6' TIEBACK SLV, D = 6.32" 7322' 9-5/8" X 7" BKR MAC LNR HGR, D = 63; 8-12" MLLOUT N04DOW (09-15A) 7479' - 7492' LATE REV BY COMMENTS OATS I REV BY I COMMENTS 09!18171 ROW 341NTIALCOMPLETION 08/08118 JDMJ MAL®& SET CERFISFVADPERFS 10108187 PAA 102 RWO 4-12"X53/4" 05109/07 WES SIDETRACK(09-15A) 3.958" 10/06/14 CT/PJC SET GBP 4-12" X 5-314" 10/08/14 TA/ PJC ADPERFS 3.958" 05103/17 DN/JM) SET CEP& ADPERFS(042930/17) 4-12" X 5314•W21 112' HES X NP, D= 3.813- X 4-12" BKR S3 PKR, = 3.875' 9887' -j4-12" FES X FP, D = 3.813" 9908' 4-1/2" FES XN W,, D _=3_725' 9914' 7' x 5' BKR FRD ZXP LTP, 9)=4.41K] 9920' 4-1/2" WLEG, D= 3.958" 9936' 7" X 5' 8KR FLIX LOCK LNR FGR, D = 4.420' '� 5'X41/2' XO,D=3.940" TAM SWELL PACKEIiS 6 4-10'X 5-3/4' 12278 3.958' 5 4-12"X53/4" 12974 3.958" 4 4-12" X 5-314" 13750 3.958" 3 4-12" X 5314•W21 3.958' 2 4-12" X 5-314" 14852 3.958" 1 4-12" X 53/4" 15298 3.958" 14755' 4-12"FES CBP(wjl5 15100' 4-1/2' FES C13P(02/13 1523W 47j12' WFDClBP(07/31 PRUDHOE BAY UNIT VAIL: 09-15A PERMIT No: 2070220 API No: 50-029-20256-01 TION, R15F_ 993 PSL & 150' FWL BP Blploration (Alaska) MEMORANDUM State of Alaska Packer Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Wednesday, January 23, 2019 P.I. Supervisor Q � SUBJECT: Mechanical Integrity Tests 1 1 BP EXPLORATION (ALASKA) INC. PTD 2070330 09-15A FROM: Jeff Jones PRUDHOE BAY UNIT 09-15A Petroleum Inspector BBL Pumped: 6.2 IBBL Returned: Ste: Inspector 5.3 Reviewed Byyi Interval P.1. Supry N,JDf-� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-15A API Well Number 50-029-20255-01-00 Inspector Name: Jeff Jones Insp Num: mitJJ190118141732 Permit Number: 207-022.0 .- Inspection Date: 1/4/2019 Rel Insp Num: Wednesday, January 23, 2019 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-15A Type lnj c TVD 8514 - Tubing 2131 2179 2141. �r-1 PTD 2070330 TypeTest SPT Testpsi 2134 - IA 1-1 11x0-1 -.,, 2-163 BBL Pumped: 6.2 IBBL Returned: 5.3 OA 16 i- 1S 11) Interval I 4YRTST _P/F P Notes- I well inspected; no exceptions noted. - Wednesday, January 23, 2019 Page I of I THE STt _ E r °fLASKA I IL GOVERNOR BILL WALKER Bernhard Stechauner FS2 Lead PE BP Exploration (Alaska), Inc. P.O Box 196612 Anchorage, AK 99519-6612 Alaska Oil and Gas Conservation Commission SCAiAKD JUN U 6 2018 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 09-15A Permit to Drill Number: 207-022 Sundry Number: 318-22-0-- 2%A SY Dear Mr. Stechauner: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. 4t DATED this'--( day of June, 2018. Sincerely, Hollis S. French Chair ROM01 JUN 0 4 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM' 'ION APPLICATION FOR SUNDRY APPRG -,,LS 20 AAC 25.280 2111 EFEIVf D G 9t/! MAY a j, 70,98 3i 1. Type of Request: Abandon ❑ Plug Perforations 0 FractureStimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Pe 0 ' Other Stimulate 0 • Pull Tubing ❑ Change Approved Program J7 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter -Casing ❑ Other Set CIBP /Acid Stim 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number. 207-022 3. Address: P.O. Box 196612 AnchorageAK , 99519-6612 Stretigraphic ❑ Service 0- e. API Number: 50-029-20256-01-00 - 7. If perforating: �. 3t-% What Regulation or Conservation Order governs well spacing in this pool? 8, Well Name and Number: Will, II planned perforations require a spacing exception? Yes ❑ No 0 PBU 09-15A - 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028327 6 028324 PRUDHOE BAY. PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 15820 • 8735 13239 8793 13239,13550 14249 14755,15100,15230 None Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" 29-108 29-108 1530 520 Surface 2703 13-3/8" 28-2730 28-2730 4930 2670 Intermediate 7454 9-5/8" 25-7479 25-6890 5750 / 6870 3090 14760 Liner 2767 7" 7303-10070 6750-8668 7240 5410 Liner 5904 4-1/2" 9914- 15818 8567-8735 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade:Tubing MD (ft): 12750 - 15650 8801 - 8737 4-1/2" 12.6# L-80 23-9920 Packers and SSSV Type: 4-1/2" Baker S-3 Penn Packer Packers and SSSV MD (ft) and TVD (ft): 9863/8534 4-1/2- MCx BPx-480 SSV 1998 / 1998 12. Attachments. Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stretignaphic ❑ Development ❑ Service 0 - 14. Estimated Date for Commencing Operations: May 31, 2018 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG p GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is We and the procedure approved herein will not Contact Name: Stechauner, Bernhard be deviated from without prior written approval. Contact Email: Bemhard.Stechauneratild.com Authorized Name: Stechauner, Bernhard Contact Phone: +1 907 564 4594 Authorized Title: FS2LV PEii ^� Authorized Signature: Date: SJ/L/`0 �g COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ✓I v Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No f9 Subsequent Form Required: (/ APPROVED BYTHE I Approved by: COMMISSIONER COMMISSION Date: f e, /`1 ' vrl- 5/31/12r ORIGINAL RBDMS—(1'—"iJUN o c 2018 Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. '00�ZS/ Submit Form and Attachments in Duplicate 10-4undry Application for Well PBU 09-15A IR#207-022) Expected Start Date: May 31, 2018 Current condition of well: WAG Injection Well, Operable, Injecting: Gas Injection Rate: 25109 Mscf/Day Injection Pressure: 3004 psi Shut-in Wellhead Pressure: 2000 psi Reservoir pressure: 3332 psi Well objective(s): 09-15A has been injecting MI and water in the current MIST location for over a year and has reached its target cumulative MI. It is time to move uphole for the next bulb. Historically, this well has had poor injectivity post perforating, so we would like to perform an acid stim to ensure the well can take the proposed rates. All but one bulb location needed to be acidized to get any significant rates of MI into the reservoir. The one bulb that wasn't had about 30% less injectivity than the next poorest one. This new bulb should continue to support offset producers 04-01A, 04-31, 09-35A, 09- 33A, 04-46, 04-48, the planned 04-09 inejctor to producer conversion, and potentially the 09-36C injector to producer conversion. There are 2 additional MIST bulbs remaining after this propsed interval. Since the well was not swapped to PWI during this cycle, no SBG is required. Proposed program: 1. Pull MCX. rz,11 z 2. Mill out as many CIBPs as possible (max 36 hours), set CIBP at 12,580' MD, add izy 3 32,44 pelf's, acid stim. 3. Set MCX for -20MM target rate (current MCX has 1.30" bean). s a BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • W PENDING PERFORATING PROCEDURE global wells organization Well: 09-15A API#:50-029-20256-01 Date: 5/1112018 Prod Engr Bernhard Stechauner Office Ph: (907)564-4594 H2S Level: Home Ph: (907)677-0860 0 ppm Cell/Pager. (907)360-7485 CC or AFE: APBINJEC WBL Entries IOR Type Work Description Mill out CIBPs and push to bottom,set new CIBP,add perfs,acid stim Well Objectives and Perforating Notes: li Not much GR character,use shale at—11,800 for tie in. Attachment: Tie-in log with proposed perfs annotated Reference Log Tie in Log Add 3 feet Log: MWD/GR Lee GR/CCL to the tie-in log to be on Date: 5/6/2007 10/6/2014 depth with the reference log. Company: Halliburton ,SLB Depths(from-to) Depths(from-to) Feet SPF Orient. Phasing Zone PERF TYPE 12229' 12325' 12,226' 12,322' 96 6 Random 60° Z2 ADD PERF Requested Gun Size: 2-7/8" Charge: MaxForce Min Wellbore ID: 3.725 Max Swell in Liquid: 3.047 Max Swell in Gas: CR Is Drawdown Necessary/Desired/Unnecessary During Perforating Preferred Amount of DrawdownlSuggestions to Achieve Drawdown Last Drift: 13,240 ft MD on 4/30/2017 Est Res.Pres.@ 8,800'TVDss MD is 3332 psi Perforation Summary Summary Dist Well: 09-15A Town: Date: API 8: 50-029-20256-01 Prod Engr: Anch Prod Engr P.D.Center PBTD General Comments: Depths Balance Referenced to BHCS Gun Die. Orient SPF Phasing Zone Adperf/Reperf 0/B/U - 0/BIll - 0/B/U - 0/B/U 0/6/U 0/8/U - 0/8/U - 0/B/U - 0/B/U - 0/B/U - ili... • H2O Injector Minilog Techiog Protect.'DS/144,4,42foc Vedette sa17 Well: 09-15A Oirt+R ' I'.kwd...CAk.r WWI) Ct.tv..3f1J2OO17 Welt. €i....tem a. sr_a:rJ... cor,.try. tot*Psi. ,--,W.zr, xta,,,. f.o+�skr nr SyVertk Ltre,t¢. :,vuar�+:z+ `�a*✓ar=r •rx a+t. 111. a r.wwera ;�, Afi_SMAL I r 1j,.1,-__, . PE Notes ' s{ 'k swt artco, III nr' redo iia wire an mii LL ..... ... _. .,.,. .._... w.._, �..._.. .._... wrra .a..-_... rp tit ss– --.�'" ��e— •ho ii, ,:,,, ,UAW • - rxaa +t 5 ,4dt1 F'efi � :..........,:, ,7:::_,_-_---.;- 12.226–12,322'. D ' Set PI c IX' 12,5$0'Md ID,: t i.,.......e.. 3 I 9 ,... .- h 4. � .� P- ., Mel 0.. I iiirr:.- - ate- Pbogs Q: ili .._ ._ 13,23P - � iw! 13,55{ /W111111 14,755 1. 15,100 tW° 21P 1§,230 14 1111 di ,r flLl °SChillillibergaill • 1020448908 ININEIWIlill Company: BP Exploration (Alaska), Inc. FINAL Weil: 09-15A Reid; Prudhoe Bay Borough: North Slope State: Alaska ,.,. Memory Depth Determination , g .... Lee GR/CCL FINA i , , A 06-Oct--2014 8" 1 8 993,19 FSL& 1.50.25 FWIL., Elev.- K,B, 48.50 ft ' z Al Surface GL. ri7 b 0 D.F. _e. 17 it Permanent Datum, MSL Elev.; 0.03 ft I Log Meaured From: RKB 48.80 ft above Remy Datum -toed Fran): RkIli a -Il;i ci; API Serial No. Sect on Toverisnka Rot'gr.! 2 TID ° Li -J ,...., u 50-029-20256-01 1 10N 15E Logging Dale 6-Oct-2014 . Run Nionher 1 - Depth Driller 14249 ft Schlumberger Depth 14'251 R 4t ,--_, Bottom Log interad 14?45 it Top Log Interval '',1600 ft Casing Fluid Type Varira is Sal.riily Deftsiity Fluid Levd BIT/CASING/TUBING STRING - EA Size From To Csing-Tub A Size 4.500 in Weight 116 Ibmift Gr ;,.. L-80113T-M ___ From 9946 ft To 15818 ft Maximum Recorded Ternpurgures I. r- ; Logger On euttom Time 5 Oct-2014 1:33 I Unit Number i Locason 59 Pructioe Bay Ream -e By Jason BL1n1 '/V4twised By Cody Fenstermaker Sam Wag • • mmairiiiisss'ssii ®1 mo re=i5II..... s Kann 11111111 s -- ssssss_ tams. SWIM unsmi_� 11.3116 Emu m-ii iiii sass- ss___- -R= 4ais Mr___sIIJIM_ - --ssssssii s A161"1 rill ` I s s� ...'ss --s® MO ss®sss3C...i■. no ow,sam p lite . -!- ---. ®_:ss _ I ..tt Et Ii !UU U®iiia __* I Eli ---------=====s isams 0111.gnu 52"="1111111111111 r ��iiii---- a ell xzzc -- i-® so-- mitiviRMiti to �s_sssssss /lit iss s'- --- $�C i i 1 . .aniall IMMO=tea s C _ ia®sass �� I ®ssssssa-� --s 1ss ialligiiiii5 WREN Poll 1111111 i � � AddPerfi =Mr Zing 12,226 12 1 22'MD -- t . wilimirmimme EL.,am= liwurnai -ss �ssss..�...... r�OM! IIl� l__i �Si1�ii�iii � � s i inn s �s® mom Mai imam :ass allriiiliallilleni ME*JIM - ssss� n s..,... ----_ NSM_ u�cpi L.9.......! - lialill d I mom�_ s s isaron On.Min ima i �is®®s s E imainlinliW [ ls®ss� i swam ® _ aimmeame um ammunimall MM.MN sass .rs s I om s O- 4 a 11E11111 OMNI s • .. Eirtaltilimms ass ar -ss - am --- W d iimmo ass inim It 1 I.ZEN am sr ..______ sass 11111CikWent am l rmapin time =m ass- ...�.. �� sssssmmomuniallingilii ..E., _ Allin _ ora woo il al? ._: MI s®s IIMIIF 'Pill' III 124a° irilms...91111151—.ILIIIIM I.IN III -� W__-- -.21st 1 SWIM I a. � _ "1"1"0-.A112ssIti Iinimmot -s__ ___ .� __ No pinesson gm .= �mi.� ... --ass 12:2.1 • 9 _��u ramaw UMW MM.1111111111111111111__ MO a I ana MB al=Mal Inialli ma 1 MINI 1 NEI ON a _ _____ Elie Igo ; , MiliMilli uici ms -it t I1� �IPIIIIIWIIIMMIIIIM INN £s '2sx.' Elmo li- 10 ; 11111111111111 nesuese- H. bllF .. 4# EMBE.Mte Einw's li awl in : __ mi. plii i#sao'ma -} IIINIIIIIIIIIIIIIIIIMIMIIIIIIIIII ... man won imam. __. _..�. 3 .. , y ,. lap! = M , .a. a MINI 'JOhlil i , , x ,, III 1101 1aal I'i' : . : IIaIrt{}iiiiiii ailing. a ill ani I . ratinui ' z,,,; -iIMMEHE iiliniil 1110113111=111 � ,t sanordird NIMNINNIMISIMIIIIIIMIIIII NM NM 11110111111111111111 IS KINN V . atimintionli . __ �r' i. II II 1111 —r 101101111111101 ON.rarr IMMO MI MO MM. k ,- • • Contingent Acid Stimulation • Tubing is in good condition, no need to hold pressure on IA. • No GL mandrels so no TIFL is required. • Do not exceed 2000 PSI treating pressure once well is loaded. • Do not add friction reducer to stimulation fluids that will enter the perforations • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR 1. Pump fluids per attached Pump Schedule. 2. Perform injectivity test with diesel in 5 minute intervals at 0.5, 1, 2 and 3 BPM and record pressures. • • Fluids: Stage Fluid Type Vol (bbls) Vol (gals) Preflush 3% NH4CI + F103 290 12,180 Overflush 3% NH4CI + F103 120 5040 Spacer 3% NH4CI + F103 60 2520 Acid 12% HCI 60 2520 Mud Acid 9:1 Mud Acid 60 2520 Diversion Oilseeker 10 420 Displacement 3% NH4CI + F103 + U067 250 10,500 Freeze Protect Diesel 40 1680 Recipes: Loading for: 12% HCI Concentration Total volume Product Code: Function: (gal/Mgal) Gallons HCI 35% Acid 307 774 A264 Corrosion Inhibitor 4 10 L058 Iron Control 20 50 F103 Surfactant 2 5 W054 Anti-Emulsion 5 13 Loading for: 9/1 Mud Acid Concentration Total volume Product Code: Function: (gal/Mgal) Gallons HCI 35% Acid 252 635 AF 36% Acid 53 134 A264 Corrosion Inhibitor 4 10 F103 Surfactant 2 5 L058 Iron Control 20 50 W054 Anti-Emulsion 5 13 U067 Mutual Solvent 50 126 • • Loading for: Preflush, Overflush & Spacer Concentration Total Volume Product Code: Function: (gal/Mgal) Gallons F103 Surfactant 2 23 Loading for: Displacement Concentration Total Volume Product Code: Function: (gal/Mgal) Gallons F103 Flowback aid 2 5 U067 Mutual Solvent 50 12.5 Pump Schedule: Stage Fluid Tot Vol Stage Description Vol (BBLs) (BBLs) 0 60/40 Spear 10 10 1 Preflush 290 300 2 Acid 20 320 3 Mud Acid 20 340 4 Overflush 60 400 5 Diversion 5 405 6 Shut Down 10 Min (once diversion is behind pipe) 0 6 Spacer 30 435 7 Acid 20 455 8 Mud Acid 20 475 9 Overflush 60 535 10 Diversion 5 540 11 Shut Down 10 mins (once diversion is behind pipe) 0 12 Spacer 30 570 13 Acid 20 590 14 Mud Acid 20 610 15 Displacement 250 860 16 Freeze Protect 40 900 TREE= 4-1/16"CNV Y NOTES:H2S READINGS AVERAGE 125 ppm VV�LFEAD= 13-5/8'FMC • 41ON MI"'*WELL REQUIRES A SSSV WHEN ON MI ACTUATOR= BAKEf2 , g-15A """WELL ANGLE>70°@ 10375'"**MAX DOGLEG: KB.ELEV= 54 18.4"@ 10344'**" BF.ELEV= I I KOP= 2750' Max Angle= 96°@ 10689' Datum MD= 10395' ' I 1998" -14-1/2"HES X NIP,D=3.813" Datum TVD= 8800'SS a D - 2278" -I9-5/8"FES ES CEMBVTER 20"CONDUCTOR,94#,H-40,ID=19.124" H 100' - 2400' H9-5/8"FOC 9-5/8"CSG,40#,L-80 TG-11,D-8.835" --{ 2293' 2523' -19-5/8"FOC 13-3/8"CSG,72#,N-80 BTC,D=12.347" H 2730' 41 7304' -9-5/8"X 7"BKR C-2 ZXP LTP TOP OF 7"LNR H 7304' I-- w/11.6'TEBACK SLV,D=6.32" Minimum ID =3.725" ac 9908' 7322' -I9-5/8"X 7"BKR HMC LNR HGR,D=6.35" 4-112" HES XN NIPPLE 8-1/2'MILLOUT WtIDOW(09-15A)7479'-7492' 9-5/8"WHPSTOCK(04/14/07) --I 7480' < i ';•;',;< ,./ 9842' 4-1/2"FES X NB,D=3.813" ' �..- j 9-518"EZSV(TAGGED 04/13/07) - I 7501 9863' -7"X 4-12"BKR S-3 PKR, � ID=3.875" 111111. 111111, 41111 0 _0 .11111 04111111111111 ' 9887' -I4-112"I X NB,D=3.813" 1.1111111111.1. 11111111/1111111111 1111111111111111111 1111111111111111111 N�a 9908' -4-1/2"FES XN P,D=3.725" 1111111111111111111 11A.A.11t., 9914' -7"X 5"BKR FRO 9-5/8"CSG,47#,N-80 BTC,D=8.681" H 10028' ZXP LTP,D=4.410" (4-1/2"TBG,12.6#,L-80 TCI,.0152 bpf,D=3.958" H 9920' I =` 9920' -14-12"WLEG,D=3.958" 7'LNR,26#,L-80 BTC-M,.0383 bpf,D=6.276" -I 10070' -7"X 5"BKR FLEX LOCK LNR HGR,D=4.420" PERFORATION SUMMARY ICI .. ; • • -2-,0 ,O o 2'2._ WELL LOG TRANSMITTAL#904000973 To: Alaska Oil and Gas Conservation Comm. July 24, 2017 Attn.: Makana Bender RECEIVED 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 DATA LOQCit AUG 0 2 2017 1/%0/20,2 M.K.BENOEh. RE: Coil Flag Log: 09-15A Run Date:4/29/2017 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari,Halliburton Wireline&Perforating, 6900 Arctic Blvd.,Anchorage, AK 99518 09-15A Digital Data(LAS),Digital Log file(Field Data) 1 CD Rom 50-029-20256-01 Coil Flag Log(Field Print) 1 Color Log 50-029-20256-01 SCANNED !AUG 1 5 2017. PLEASE ACKNOWI.RDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com&AKGDMINTERNAL@bp.com Date: Signed: .41t.e"'"C RECEIVED D STATE OF OLASKA OIL AND GAS CONSERVATION COMMIS. JUL 31 2017 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed O1 GC Abandon 0 Plug Perforations m Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate Et Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 5Gt C6 OP__II 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number:v 0 0 2I a 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service m 6. API Number: 50-029-20256-01-00 7. Property Designation(Lease Number): ADL 0028324 8. Well Name and Number: PBU 09-15A 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 15820 feet Plugs measured See Attachment feet true vertical 8735 feet Junk measured feet Effective Depth: measured 13239 feet Packer measured See Attachment feet true vertical 8793 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"94#H-40 29-108 29-108 1530 520 Surface 2703 13-3/8"72#N-80 28-2730 28-2730 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet r. SCOW Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 23-9920 23-8570 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"MCX SSV 1998 1998 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12750'-12846'. Treatment descriptions including volumes used and final pressure: 685 Bbls 3%NH4CI w/F103,95 Bbls 3%NH4CI,28 Bbls 50/50 Methanol/Water,60 Bbls 12%HCL,60 Bbls 9:1 Mud Acid,1900 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: --NIT" — 669 710 1510 Subsequent to operation: -137513.s0 106 2874 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I3 Exploratory ❑ Development 0 Service ® 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 m GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-063 Authorized Name: Bernhard Stechauner Contact Name: Bernhard Stechauner Authorized Title: FS2 L ad PE Contact Email: Bernhard.Stechauner@bp.com Authorized Signature: Date: "7/2 7/1'--i Contact Phone: 564-4594 Form 10-404 Revised 04/2017 `�'�7 �v to` `'q--/ t-7- RBDMS VJ �'I'r - 1 2017 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 July 26, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug, Adding Perforations and Acid Stimulation covered by Sundry Application # 317-063 for Well 09- 15A, PTD # 207-022. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • Plugs Attachment PBU 09-15A SW Name Date MD Description 09-15A 04/30/2017 13239 4-1/2"WFD CIBP 09-15A 10/07/2014 13550 4-1/2"WFT CIBP 09-15A 10/26/2012 14249 4-1/2" HES CIBP 09-15A 02/15/2011 14755 4-1/2" HES CIBP 09-15A 02/13/2011 15100 4-1/2" HES CIBP 09-15A 07/31/2009 15230 4-1/2"WFD CIBP • • Packers and SSV's Attachment PBU 09-15A SW Name Type MD TVD Depscription 09-15A SSSV 1998 1997.89 4-1/2" MCX SSSV 09-15A TBG PACKER 7314.97 6759.08 7" Baker ZXP Top Packer 09-15A TBG PACKER 9862.81 8534.29 4-1/2" Baker S-3 Perm Packer 09-15A TBG PACKER 12278.04 8813.12 4.5"X 5.75"TAM Swell Packer 09-15A TBG PACKER 12973.47 8800.54 4.5"X 5.75"TAM Swell Packer 09-15A TBG PACKER 13749.34 8782.87 4.5"X 5.75"TAM Swell Packer 09-15A TBG PACKER 14320.86 8763.38 4.5"X 5.75"TAM Swell Packer 09-15A TBG PACKER 14851.69 8753.39 4.5"X 5.75"TAM Swell Packer 09-15A TBG PACKER 15298 8738.33 4.5"X 5.75"TAM Swell Packer • • m co N O` 0) CO CO .- O G ul N M Tr Tr Ns Ns ) N-up N- V CD CD CD 4g CC) M U) Os ONs Tr M M • 1.00) N- 00 00 N 'c Tr m Tr CC) CO CO Ns O D O D 00 O N v- O OD Ul O • M CD "Cr O CO M Is Ns N to 00 CO Ns U) N N N CO OD CO CO i i i a I I I Oo e- O Ns 0) 00 Ln 00 d' U) CO 01 N N N N Cn Ns LO N N N CO CO coCV CD ID C4) CD coV 00 c) N- N Cn T 0 11) O) N CV N N- 0) VCI LO 01 Q ' " CD001f) 0ODTrOT- cp =0ch O N N N N ( N- 00) N CZ000000 co CV V OM � �iI� NN N co co 0) 0) 07 4 4 t 0)0) O CO Cr)C0 CO O 0a) 0 N N N ct N in 00) W W W Qaa =� WaWww 15 U U 0 u_ CCCt cC x cLZ Z W W W W W m OHI— ZZ � • • d N m Tr T M r• O r` C) CO — N C'1 N N CO CC) Cn — M N 00 O CD CO r` UD CO Cn Cn O nr CD CO T- 00 CO CO r` CC) 00 T- Cn 00 CO OD r- N CD M CC) CO C) CA CA r` CO CO CO CD 00 N- CO r• CO O CC) Cfl CC) CC) ni CD O CO CO CO C.O CO CD C)) CD OD CO CO CO CO CO CO CO Cn Cn CC) CO T0 N nr nr nr co co M co co Cr) Cr) CD r` r` r` r` r` r` r` r` r` r` r• r` r` r` r` r• CO 0s 0- r` r• r• r• r` r` r• r` O CO CO CO CO CO CO 00 CO CO CO 00 CO CO CO OD CO CO OD OD OD CO CO CO 00 CO > H O. 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E2 V � L (r) >' 2 2 7 \ / \ = g . % d Ea | 72k � \ | § O2 3 414) O k \ - ] i = -0 c a m ' R X O % MLL < 2U2 $ 2c ' 2 $ c' f2 < tCO � OtAo . _I � 99 O � 0- 5 - off . 7 � 2o� k $ \ ® I / cD O• m `1 _ _ 0 f 2 / / 2 § : w + _ # 2 re // / \ 2 _ � � � @TD // � R \ a / c ® > , ? * 2 � 7 � 0_ ., < E > fW ƒ CU ® 2 o 2 § c _ 0 E —I , 2 5 m u 43 .- � � � � k / / 2 2 > u k < �0 Z k / / " 5 f % c) - r.) .-- (02z ct 06 0 2 2 0 ° ƒ 7 L / > LL (09 : U 7 . - _ a = O2g — c — . � gaA�2kCD •= ? a / / = � / _ & / f � _ o \- = c .= 0- e c o -1 ® _i 5 $ o Q -J < $ IInm- 2 �/ ( ©k / W / r1w # # / - f = 1 / = 2 0 g R = t E > \ O / s ¥ 2 , us to 2 2 . 2 m / / k & k q k ƒ _o•.r f i ƒ i | $ ƒ | / 10 \ \ 2 / / N 2 \ 2 N / / \ / 0 227 $ $ 222 2 / 2 CO 1 = _ 4o + + + 6 $ • TREE= 4-1/16"CNV_ • WELLHEAD= 13-5/8'FMC SAFETY NOTES:H2S READINGS AVERAGE 125 ppm ACTUATOR= BAKER 0 9-1 5A WHEN ON MI***WELL REQUIRES A SSSV WHEN ON MI ELEV_ 54' """WELL ANGLE>70°@ 10375'"""MAX DOGLEG: KB. 18.4"@ 10344'"" BF ELEV= I I KOP= 2750' Max Angle= 96"@ 10689' Datum MD= 10395' 1 ' 1998' —14-1/2"HES X NP,D=3.813" Datum TVD= 8800'SS 0 • 2279' H9-5/8"HES ES CEMENTER 20"CONDUCTOR 94#,H-40,ID=19.124" — 100' 2400' H9-5/8"FOC 9-5/8"CSG,40#,L-80 TC-11,D=8.835" H 2293' I 2523' —j 9-5/8"FOC 13-3/8"CSG,72#,N-80 BTC,D=12.347" H 2730' 7304' 9-5/8"X r BKR C-2 ZXP LTP TOP OF 7"LNR —I 7304' �w/11.6'TEBACK SLV,ID=6.32" Minimum ID =3.725" 9908' =; �= 7322' H 9-5/8"X 7"BKR HMC LNR HGR,D=6.35" 4-1/2" HES XN NIPPLE 8-1/2"MLLOUT\NDOW(09-15A)7479'-7492' 9-5/8"WHPSTOCK(04/14/07) t 7480' 9-5/8"EZSV(TAGGED 04/13/07) — 7507 9842' H4-1/2"HES X NP,D=3.813" I 9863' —7"X 4-1/2"BKR S-3 PKR, �1�1-- ID=3.875" II(iJ 11111 1111h• =' 11111, 9887' --j4-1/2"HESXNP,D=3.813" 1N1..1111111111111111111411111111119908' —j4-1/2"HES XN NP,D=3.725" 11111111111111 .1.1.0, 9-5/8"CSG,47#,N-80 BTC,D=8.681" --{ 10028 i:99.1/:9:9.99.11.i:i., 9914' —7"X 5"BKR I-FD ZXP LTP,D=4.410" _... __.. ._._. ....._.. [4-1/2"TBG, 12.6#,L-80 TC/ 9920' H4-1/2"\LEG,D=3.958".0152 bpf,D —'3.958" � 9920' "' I 7"LNR,26#,L-80 BTC-M,.0383 bpf,13=6.276" H 10070' 9936' —7"X 5"BKR FLEX LOCK LNR HGR,113=4.420" PERFORATION SUMMARY '-' 9946' H5"X 4-1/2"XO,D=3.940" REF LOG:MIND/GR ON 05/04/07 4-1/2"WFD CEP I 13239' ,-. I TAM SWELL PACKER'S ANGLE AT TOP PERF: 91°@ 127501 (04/29/17) 111 ND SIZE TOP DEPTH MN ID Note:Refer to Production DB for historical perf data 4-1/2"WFTCBP —j 13550' _ 6 4-1/2"X 5-3/4" 12278 3.958" SEE SPF NTB VAL Opn/Sqz SHOT SQZ (10/06/14) , 5 4-1/2"X 5-3/4" 12974 3.958" 2-7/8" 6 12750-12846 0 04/30/17 _,� 4 4-1/2"X 5-3/4" 13750 3.958" 2-7/8" 6 13400- 13500 C 10/08/14 4-1/2"HES CUP —j 14249' 3 4-1/2"X 5-3/4" 14321 3.958" 2-7/8" 6 14000- 14100 C 10/27/12 (10/25/12) 2 4-1/2"X 5-3/4" 14852 3.958" 2-7/8" 6 14560- 14660 C 02/16/11 , 1 4-1/2"X 5-3/4" 15298 3.958" 2-7/8" 6 15030-15055 C 08/01/09 2-7/8" 6 15055-15080 C 08/01/09 ._.up._, 14755' 41/2"FES CBP(02115/11) 2-7/8" 6 15080-15105 C 08/01/09 MII13 15100' —14-1/2"FES CUP(02/13/11) 2-7/8" 6 15105-15130 C 08/01/09 2-7/8"r 6 15350-15400 C 10/10/08 '_' 15230' --{4-1/2"WFOCBP(07/31109) 2-7/8" 6 15450-15500 C 10/09/08 2-7/8" 6 15550- 15650 C 05/07/07 PBTD —j 15731' 4-1/2"LNR,12.6#,L-80 IBT-M,.0152 bpf,D=3.958" —j 15818' ►"•.•.• DATE REV BY COMMENTS DATE REV BY COMVENTS PRUDHOE BAY UNIT 09/018/77 ROW 34 IMTIAL COMPLETION 01/10/12 TMWJMD ADDED 112S SAFE.'Y NOTE WELL: 09-15A 10/06/87 PAA 102 RWO 11/01/12 JJUJMD SET CEP&ADPT3RF(10/25.27/12) PERMT No:"`2070220 05/09/07 N2ES SIDETRACK(09-15A) 10/06/14 CT/PJCSETCBP AR No. 50-029-20256-01 09/09/09 RWfWTLH CEP SET/ADFERF(07/31/09) 10/08/14 TA/PJC ADPERFS SEC 1,T1ON,R15E,993'FSL&150'EWL. 02!11/11 MB/JMD ADDED SSSV SAFELY NOTE 05/03/17 DW/JMD SET CUP&ADFE RFS(04/29-30/17) 02/28/11 JMF/PJC CEP/ADPERFS(02/13-15/11) i BP Exploration(Alaska) • PVof T� • i 4), THE STATE Alaska Oil and Gas ti ►:-,' � �, of i. Conservation Commission t == $= z__- 333 West Seventh Avenue " GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS' Fax:Fax: 907.276.7542 www.aogcc.alaska.gov Bernhard Stechauner FS2 Lead PE BP Exploration(Alaska), Inc. SCANNED MAR 2 8 .h P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 9-15A Permit to Drill Number: 207-022 Sundry Number: 317-063 Dear Mr. Stechauner: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 6.0 day of March, 2017. RBDMS tVi 2 G 2017 • RECEIVED STATE OF*ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 2 L017 APPLICATION FOR SUNDRY APPROVALS p� 3/AOG2...e(? 20 AAC 25.280 C 1. Type of Request: Abandon 0 Plug Perforations 0• Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend❑ Perforate 0 • Other Stimulate ® • Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 1'fr1 vd ac)) 133---- 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 207-022 - 3• Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development ❑ 99519-6612 Stratigraphic ❑ Service 0. 6. API Number: 50-029-20256-01-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? ei a � �� 8 Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PRUDHOE BAY UNIT 09-15A ' Az,3 (7 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028324 • A�( , C.)cyz e.,3Z 7 .r 2,3_./7 PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 15820 • 8735 • 13550 8786 See Attachment Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20"94#H-40 29-108 29-108 1530 520 Surface 2703 13-3/8"72#N-80 28-2730 28-2730 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 23-9920 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 4-1/2 MCX SSV 1998, 1997.50 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 10 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service ®- 14.Estimated Date for Commencing Operations: 3/20/17 ✓ 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 • GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Stechauner,Bernhard be deviated from without prior written approval. Email Bernhard.Stechauner@bp.com Printed Name Stechauner,Bernhard Title FS2 Lead PE Signature C_ z-1,------------------- :-1, -- Phone +1 907 564 4594 Date 2-72/ I"'1 COMMISSION USE ONLY / Conditions of approval:Notify Commission so that a representative may witness Sundry Numbe: Integrity 3\--1 — G Ce Plug e9 ty 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: r`�=� �? 1311.1 Post Initial Injection MIT Req'd? Yes 0 No </. Spacing Exception Required? Yes 0 No1 Y Subsequent Form Required: J O— 41.)4 APPROVED BYTHE Approved by: COMMISSIONER COMMISSION2 Date:J"23„/7 7 1/77_ 3/23 /1:7_ ORIGINAL RBDMS tiv MAR z 4 20172%' Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 1 • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: 09-15A Well Type: WAG Injection Well API Number: 50-029-20256-01 Well Activity Conventional 4 Classification: Activity Description: MIST stage plug/pert Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Estimated Cost, YP Add Perf+ Prof Mod $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory None Sundry Form 10-403 requirements? Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Bernhard Stechauner Contact numbers: (907)564-4594 (907)360-7485 Well Intervention Engineer: Todd Sidoti Contact numbers: (907)564-5113 (907)632-4113 Lead Engineer: Danielle Ohms Contact numbers: (907)564-5759 (907)440-9082 Date Created: January 9, 2017 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injection Date Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Pressure Cut(%) (Mscf/Day) (psi) 1f7/2017 524 0 1,447 Current Status: Operable Flowing Inclination>70°at Depth(ft) 10,365' MD Recent H2S (date,ppm) NA 0 m Maximum Deviation(Angle and pp Depth) 10,689' MD _ Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 18° 10,344' MD Reservoir pressure(date, 10/15/2014 3,370psi Minimum ID and Depth psig) P 3.725" 9,908' MD Reservoir Temp,F 170°F Shut-in Wellhead Pressure 1,710 psi Known mech.integrity None problems(specifics) Last downhole operation(date, 11/9/2016 SL pulled MCX operation) Most recent TD tag(date,depth, 10/10/2014 13,550' MD Coil set 4.5°CIBP toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, 09-15A has been injecting MI and water in the current MIST location since 2014 and it is time to move background information, uphole for the next bulb. Historically,this well has had poor injectivity post perforating,so an injectivity test etc: with a contingent acid stim is proposed. This new bulb should continue to support offset producers 04-1A,04-31,09-35A,09-33A,and the proposed 04-09 inejctor to producer conversion.There are 2 additional MIST bulbs remaining after this propsed interval. The well is currenity on PW injection,so a SBG has to be performed to prevent organic matter from drying out in the wellbore and potentially causing injectivity issues. • • • Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: Time for next MIST bulb Specific Intervention or Well Objectives: 1 Add perfs for next stage MIST bulb and set plug to isolate all deeper perforations 2 Mill out as many CIBPs as possible for future re-MIST opportunity 3 Key risks,critical issues: Mitigation plan: 1 Handling acids Allow only essential personell on site and follow all SOPs/RPs 2 Milling multiple CIBPs Do not spend more than 24 hours milling on old CIBPs. 3 Job written assuming 32'guns available If we can't use 32'guns,make 4 runs with 25"guns 4 a..;rsg to strotonlc Mi. ming,plc.. ;cute this job aril/early May.OK to do now. Summary Service Line Activity Step# 1 F SBG 2 C Mill out as many CIBPs as possible,add perf, set CIBP, injectivity test, contingent acid stim 3 S SBHPS,set MCX Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 F SBG (WSL discretion if SBG to be carried out on coil during drift run) 2 C see detailed procedure 3 S SBHPS, set MCX Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: 20 BWPD: Expected Production Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: POI well on MI with"20MMscf/d target rate Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc • Coil Procedure: • Note: Due to well trajectory consider to using fenolic balls to set plug and perforate. See WSR of 02/14-02/15/2011 for issues during CIBP set- Finally saw positive indications that ball set with fenolic ball after multiple tries to get ball on seat. 1. RU 1.75" CT. a. Note: 1.75" CT has been able to get to at least 14500' without Safelube. b. Coil WSL discretion if SBG is to be performed on FB or on coil during the drift run 2. RIH with memory GR/CCL/drift for CIBP. Drift to top of CIBP @ 13,550. Flag pipe. PU, logging tie-in up pass from 13,550' up to 11,800' (flagging pipe at 12,750' MD with different color). POOH. 3. Tie- in Note: There is not much character in the GR log. Will need to tie into the HES MWD- GR at a good shale higher up (@ around 11,800'). Do not use the USIT-GR-CCL because it has not been depth shifted back to the open hole GR log. 4. Download memory tool data. Determine depth correction reference to Halliburton MWD log for the well, which was logged 12-Apr-07 to 6-May-07. 5. Pick up motor/mill and attempt to mill out as many CIBPs as possible: a. WFD CIBP @ 13,550' MD b. HES CIBP @ 14,249' MD c. HES CIBP @ 14,755' MD d. HES CIBP @ 15,100' MD e. WFD CIBP @ 15,230' MD • Do not spend more than 24 hours milling CIBPs. 6. RU for perforating. RIH and perforate with 2-7/8" MaxForce charges, 6 SPF, from 12,750' to 12,846' MD ref Halliburton MWD log. • Interval assumes 32' guns available. Call PE to discuss interval change if only 30 or 25' guns available. 7. MU BHA for CIBP. RIH, with CIBP. Correct flag depth and set CIBP at 13,250' MD per PE Manual guidelines. PU, tag CIBP. PT CIBP to 2500 psi. POOH. 8. Pull above the perforations and perform an injectivity test by pumping diesel down tubing at max pressure of 1500 psi. Pump for a minimum of 10 minutes. If the stabilized rate is greater than 2 bpm, RDMO. If the stabilized rate is less than 2 bpm at 1500 psi, continue to step 9 and perform the acid job. Note injectivity on WSR. POOH. 09-15Ai 2017-01 MIST CIBP PERF.docx • ! Acid Stimulation 9. RIH BHA including jet swirl nozzle (Note: Min ID = 3.725" @ 9908'). Load well with 125 bbls diesel down backside to achieve positive WHP. Pump fluids per attached Pump Schedule and reciprocate the pipe over 12,750' to 12,846' MD. 10. If needed to establish injection, go to 3000 psi WHP, but drop immediately to 2000 psi WHP as to not frac the well during the acid wash. When acid is on the perfs, max WHP should be 2000 psi. 11. Do an injectivity test post acid stim down the backside with diesel at no more than 1500 psi. Establish a stabilized rate and pressure to make certain of positive injection. POOH. FP top 2500' of well. 09-15Ai 2017-01 MIST CIBP PERF.docx • ! Fluids: Stage Fluid Type Vol (bbls) Vol (gals) Preflush 3% NH4CI + LoSurf-300D 90 3780 Overflush 3% NH4CI + LoSurf-300D 120 5040 Spacer 3% NH4CI + LoSurf-300D 60 2520 Acid 12% HCI 60 2520 Mud Acid 9:1 Mud Acid 60 2520 Diversion HEC 10 420 Displacement 3% NH4CI + LoSurf-300D + Musol 60 2520 Recipes: Loading for: 12% HCI Concentration Total volume Product Code: Function: (gal/Mgal) Gallons HCI 35% Acid 307 774 FE-1A Iron Control 10 25 FE-2A Iron Control 10 25 Losurf-300D Surfactant 4 10 AS-7 Anti-Sludge 4 10 Loading for: 9/1 Mud Acid Concentration Total volume Product Code: Function: (gal/Mgal) Gallons HCI 35% Acid 252 635 AF 36% Acid 53 134 ClaSta XP Clay Stabilization 10 25 FE-1A Iron Control 30 75 Losurf-300D Surfactant 4 10 AS-7 Anti-Sludge 4 10 Hal-OS Corrosion Inhibitor 10 25 09-15Ai 2017-01 MIST CIBP PERF.docx • • Loading for: Preflush, Overflush & Spacer Concentration Total Volume Product Code: Function: (gal/Mgal) Gallons LoSurf-300D Flowback aid 2 23 Loading for: Displacement Concentration Total Volume Product Code: Function: (gal/Mgal) Gallons LoSurf-300D Flowback aid 2 5 Musol Mutual Solvent 50 126 Pump Schedule: Fluid Stage Fluid Stage Description Path Vol (BBLs) 1 Preflush CT 90 2 Acid CT 20 3 Mud Acid CT 20 4 Overflush CT 60 5 Diversion CT 5 6 Spacer CT 3 7 Acid CT 20 8 Mud Acid CT 20 9 Overflush CT 60 10 Diversion CT 5 11 Standby for 2 mins CT 0 12 Spacer CT 30 13 Acid CT 20 14 Mud Acid CT 20 15 Displacement CT 60 16 POOH CT 09-15Ai 2017-01 MIST CIBP PERF.docx • . WELL SERVICE REPORT WELL DATE JOB SCOPE DAY SUPV 09-15A 2/15/2011 PROFILE MODIFICATION MOLLAYEV-SAMIR AFE Code DAILY WORK NIGHT SUPV APBDO9WL15 SET MECHANICAL PLUG; PERFORATING WEST MIN ID DEPTH TTL SIZE KEY PERSON UNIT 3.725" 9908 FT 4.5" DS-JOHNSON CTU#9 DAILY SUMMARY CTU 9, 1.75",0.134 wall CT. Job Scope: GR/CCL, CIBP,Ad-Perf,Acid Stim.:***Job continued from 02/14/11*** Normal weather condition restored. No CIBP found, possible been set @ - 15100'. RIH with second HES 3.66"OD CIBP. Set CIBP at 14755' ELMD. POOH. Ball recovered. RIH w/25ft of 2 7/8"290PJO guns @ 6 spf. (Run#1) ***Job Continued on 2/16/11*"* LOG ENTRIES Init Tb., IA, OA 40 0 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 06:00 0 _-1111111.111111 Arrived on location after waiting on weather. 07:57 0 Checked that all engine are running. 08:37 0 0 0 PJSM before BO lubricator with SLB and HES. 08:48 0 Pop off the well. Bring lubricator to backdeck. 08:55 0 No CIBP, setting tool have been stroked and 1/2"alumni and 1/2"delrin fenolic balls have been recovered on seat. 09:00 0 Can't get speed on injector head. Lower lubricator and injector head down on backdeck to troubleshoot. Deice counter. 10:56 0 PU injector back. 11:40 0 3500 2d Lined for PT BOT MHA with diesel, McOH truck couldn't start. Pressure up to 561 psi low and 3500 psi high. No leaks observed, bled down to 0 psi. 11:50 0 MU 4 1/2" HES EZSV CIBP. (2.25"OD x 1.37'CTC,2.13"OD x 1.38' MHA(with DBPV), 2.13"OD x 1.56' Disco (3/4 ball disconnect), 2.0" OD x 0.48' 1 1/2"x 1"CS hydril x/o, 2.72"x 7.19'setting tool, 3.66"x 2.10') OAL= 14.064' , OAL to center element of CIBP= 12.78'. 12:29 0 250 0 Stabbed on lubricator on BOP. PT lubricator from backside to 250 psi low for 5 min. 12:38 0 2049 MI - Go hie h 2000 .si for 5 min. 12:46 0 1886 11111111 Good test. Opened Swab valve and SSV. 12:55 0 Commenced RIH. 13:03 350 631 17 3m Possible fluid level. 14:04 6000 1298 1226 0 3m Weight check, 10.5k#. RBIH. 15:32 12030 1358 1299 0 3m Weight check, 18.5k#. RBIH. 15:57 14000 1334 1275 0 3m Weight check, 20k#. RBIH. 16:13 14775 1173 1121 0 3m At the flag (14760'RKB), 14782' mechanical. Correct the electronic counter from 14775'to 14760' RKB. 16:16 14760 910 869 0 3m RBIH. PU to 14755', there is a coupling at 14760'according to recent CCL log. 16:20 14755 708 667 0 3m At target depth 14755'CTMD. 16:28 14755 467 445 0 3m Lined up down coil with McOH. Opened choke manifold. 09-15Ai 2017-01 MIST CIBP PERF.docx s . 16:30 14755 459 1600 1 0 Drop a 1/2"fenolic ball. 16:58 14755 423 1183 0.51 30m Slow pump down. 16:59 14755 372 2929 0.6 31m Ball on seat. Positive indication of setting CIBP.WHP=370 psi, CTP=1108psi. 17:03 14755 440 568 0.6 34m Closed choke manifold. PU, 21k#. RBIH to tag the CIBP. 17:05 14729 342 541 0 34m 9k#running down weight.Tagged the CIBP. Set down weight 7k#. 17:10 14729 375 553 0 34m Lined up down coil with McOH to PT CIBP to 2500 psi DP. 17:28 14729 2508 2733 0.3 36m Pressure up against CIBP. 17:35 14729 2508 2653 0 36m Good 5 min test. Bled off pressure to 500 psi thru the choke manifold. 17:37 14729 348 430 0 36m POOH.While filling pipe displacement. 18:10 12055 593 12 0.3 8m Change out/continue POOH 20:01 754 65 0 0.3 42 PJSM w/HES to discuss popping off well and breaking down setting tool. 20:20 0 At surface. Isolate fluids. Close swab. 20:33 0 Pop off well. 20:43 0 Ball recovered 20:50 0 42 Line up with McOH down CT to fluid pack for MHA PT. 20:56 0 44 PT MHA 300 low and 3500 high. 21:08 0 44 PJSM with TCP to discuss making up perf gun#1 and stabbing on well. 21:43 0 44 Make up 25ft of 2 7/8"290PJO guns (Run#1) 21:56 0 44 Stab on well. 22:14 0 44 Fluid pack for PT 22:16 0 46 PT with McOH down backside: 230 psi low and 2500 high. 22:33 0 47 Open swab, RIH with 25ft of 2 7/8"2906PJO, @ 6 shot per foot((2.25" OD x 1.37'CTC, 2.13"OD x 1.38'MHA(with DBPV),2.13"OD x 1.56' Disco(3/4 ball disconnect), 2 7/8" Power Jet Omega perf guns 2.88"x 30.99') OAL=35.29' , OAL bottom shot=34.73'. 23:59 0 Job continued on 2/16/11 Final Tbg, IA, OA JOB COSTS SERVICE COMPANY-SERVICE DAILY COST CUMUL TOTAL HALLIBURTON $5,704 $5,704 ORBIS $1,300 $3,900 SCHLUMBERGER $0 $37,483 SCHLUMBERGER PLUS 13 PERCENT $0 $4,872 PDS $0 $4,850 BAKER OIL TOOLS $0 $0 CH2MHILL LABOR $0 $8,400 WS DISPATCHED $0 $2,800 WAREHOUSE $0 $21,246 TOTAL FIELD ESTIMATE: $7,004 $89,255 FLUID SUMMARY 3+36+48 bbls McOH 2+bbls Diesel bbls 1% KCL 09-15Ai 2017-01 MIST CIBP PERF.docx • ! Plugs Attachment PRUDHOE BAY UNIT 09-15A SW Name Date MD Description 09-15A 10/07/2014 13550 4-1/2"WFT CIBP 09-15A 10/26/2012 14249 4-1/2" HES CIBP 09-15A 02/15/2011 14755 4-1/2" HES CIBP 09-15A 02/13/2011 15100 4-1/2" HES CIBP 09-15A 07/31/2009 15230 4-1/2"WFD CIBP • m Q.o 0 0 0 0 0 0 0 N- RN r- CA (000 OO — cr0N- LOLO 0 N M V' U Z00000000 L M M Lt) N- M 7 IC) CA N. a) CC) N 'Cr d •ct In CO CO r"- CO CO co O N O CO Cn O CO 0) ct CA CO M ti N CC) CO CO N- IC) N N N CO CO CO CO H CO c- O I's CA CO V) CO ctCL7 CO 0.1NNN1.0r- tC) N N N CO CO +r Q Er () ON) ct N- O N N C C() 0 N N N r` - O) V {.i z QCA r CO CO CO Cf) CO O c N N N N L.0 M CA N M N N r- O) LLI O OO O O O O OV CO CO CO O CO Cb cam ZZCO C d = Lt * * *k J Cep 0 CO CO C\O -C\D CV N (V Q. OM N r r M 0) o) V 4 .0 +' M N- CO CO ct CO a)O) O CO Nu-t M (0 O C) C N- N- N — O) N- 0) CO J N N N d (NI C[) O) W W W Q _Q Q co w 0 0 0 •— owwww O O c Z Z w W w w W pp ODHH ~ ZZD 0 Z Z Z 4 S of m N- O N- 0) to r N M N N to LU LU r M N a0 O) CA a0 N LU M t d' O) to r CO O O In In 00 CO M r N O to Mtn GNOCOOOM MN OCOtocOd' tntnd• CO ) OOOCOCO w ODa0 ) a) c00000 to to tf) � d tid d d MMMMMMM a0 a0 a0 a0 a0 ap ap a0 ao O a0 aD 0O M m CO CO a0 a0 O CO O ap CO H a 0 F' r N C) N- r L r N d' N N to to r M O ao CA M a0 N- t� w O d' CA to M CO O O CA to ao r O (0M r r O to M to O a0 aL 00 N- OO O) CO N- N- N- O O N CO d' to to N- O cO c0 6 CO C0 d 0000OCON- a) OCOto toK d• ti �td- MMMMMMM a0 CO CO 0O M a0 a0 ao 00 CO 00 00 00 CO CO OO aO a0 0O 00 00 00 I- a) N Q W s to O to O Co O to 0 to O to O to O O to 0 0 0 0 0 0 0 0 4.0 N N- ON Oo0rM (fltoOOOMOooOCOaoO r a d' d' d' to O O O r to cp Cfl O O O r r r M M V d' d' to Cfl �1= 1 8 M MMM V V d' d' d' d' d' d' to LUto �n to LU LU toto W . . . . . . . . . . to LU U) 0) c- r r E O N t I— 2 M ' 4 = a O Q t Oto O to O to O to O to O Lo O to O O to 0 0 0 0 0 0 0 O mN. O N to N- O N to N- O a0 r M M to M O O to M a0 to O ao LO d' d' d' d' O O O O to to M O O O O r r (Y) C') M V d' d' to C M M M M d' d' d V NI d d' to to to to to to to to to to to to mN r r r r r . . . . . . r . . . . . . r r r r r r AO 2 W re a a8 C roaaa. aaaaaaCLMMMMO aa � O LQ LO QQQQQmmmmmmmmmmmmmmmmmmmm 0 a, d a a) to• d• d- d- d- d• d- d- d• - d- d- d- d d d d d- d- 0 r r r r r r r =r =r r r r =r r-r r r r r r r r r r r r C 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O N N N N N N N N N N N N N N N N N N N N N N N N "' N- N- N- N- CO O CO CO cO CO O O O CO O O M cO COM O CO CO O y O O O O O O O O O O O O O O O O O O O O O O O O a = . . . . . r r r r r r r r r r r r r r r r r r 0 a7 E f0 Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Z to t() to to to to to to to to to to to LU to Lo to Lo to to to to to to � r r r r . . . . . . r r r r r r r r r r r r r r O 8) CA O) ) CA (S) CA C) ) CA O CT CA CA CA C)) O O O CA ) C) CA O O O O O O O O O O O O O O O O O O O O O O O O • • ❑ w > 0 0 ❑ ❑ wU z H FW- O W ❑ g g Y U O > O O ww U U w J J J a s W JU U U W W U 7 0 aWQ 1 0 0 a< ❑ ❑ W OHO U 0 0 LU uJ LLI 0- 2 2 2 O ci cn can co «a U U O to 0_ 2 2 2 O ccnn c) cn v) ccn H ❑ > > O 0 W 1 a < Lu N N W W ❑ L -111j Z a 9 :7 w ❑iL W w w m ❑ D 1' W J -=-1 ^J J O W W < a m a m cn u. LL 4 CJ) 0- IL IL a U O W N W mU mQ ¢ m cnc ® • Packers and SSV's Attachment PRUDHOE BAY UNIT 09-15A SW Name Type MD TVD Depscription 09-15A SSSV 1998 1997.89 4-1/2" MCX SSV 09-15A TBG PACKER 7314.97 6759.08 7" Baker ZXP Top Packer 09-15A TBG PACKER 9862.81 8534.29 4-1/2" Baker S-3 Perm Packer 09-15A TBG PACKER 12278.04 8813.12 4.5"X 5.75"TAM Swell Packer 09-15A TBG PACKER 12973.47 8800.54 4.5"X 5.75"TAM Swell Packer 09-15A TBG PACKER 13749.34 8782.87 4.5"X 5.75"TAM Swell Packer 09-15A TBG PACKER 14320.86 8763.38 4.5"X 5.75"TAM Swell Packer 09-15A TBG PACKER 14851.69 8753.39 4.5"X 5.75"TAM Swell Packer 09-15A TBG PACKER 15298 8738.33 4.5"X 5.75" TAM Swell Packer TREE=• 4-1/16'CM/ . WaLHE4 D= 13 5/8'FMCSAFETY NOTES:112S READINGS AVERAGE 125 ppm ACTUATOR= BAKER 0 9-1 5A WHEN ON MI***WELL FiE3QURES A SSSV WHEN ON MI KB. ELEV= 54' "'WEAL ANGLES 700 @10375'""MAX DOGLEG: BF TEV= 18.4" 10344 °" KOP= 2750' Max Angle= 96° 0 10689' Datum M)= 10395' i ' 1998' H4-1/2"FES X NP,D=3.813" Datum TVD= 8800'SS • )} 2279' -9-5/8"HES ES CEIU13YTt32 20"CONDUCTOR,94#,H-40,D=19.124' 100' Is---� / � 2400' -�9-5/8'FOC 9-518'CSG,40#,L-80 TC-11,D=8.835' - 2293' -'- 2523' H9-5/8"FOC 13-3/8"CSG,72#,N-80 BTC,D=12.347' H 2730' , ' 7304' -9-5/8'X 7'BKR C-2 ZXP LTP TOP OF 7'LNR - 7304' j w/11.6'TET3ACK SLV,D=6.32" Minimum ID = 3.725" 9908' =; ' 7322' --r9-5/8"X 7'BKR HMC LNR HGR,D=6.35" 4-1/2" HES XN NIPPLE 8-1/2"MLLOUT VVNDOW(09-15A)7479'-7492' 9-5/8'W1iFSTOCK(04/14/07) H 7480' 9-5/8"EZSV (TAGGED 04/13/07) - 7501' _ 9842' -4-1/2'FES X NP,D=3.813" 1166111111111,111k 1 9863' J-7"X4-1/2'BKR53PKR�1�1�1ID=3.875' • 1111..- $- 111111111111,114.1...4 ` 9887' i--+4-1/2"FES X NF',D=3.813"1 .1y1f1/1.111111111v1, 111111/1111111111111 1•••••••••41 111111111111111111111 _ 9908' --H 4-1/2"HES XN NP,D=3.725' 111111111111111111111 1.•................... 9914' - X 5"BKR I-RD 9-5/8'CSG,47#,N-80 BTC,D=8.681" H 10028' • 1 7" ZXPLTP,D=4.410' 4-1/2"TBG, 12.8#,L-80 TCI,.0152 bpf,D=3.958" f 9920' I ►= 9920' H4-1/2"WLEG,D=3.958` t\ 7"LNR,26#,L-80 BTC-M,.0383 bpf,D=6.276" - 10070' tel( 9936' -7'X 5'BKR FLEX LOCK LNR HGR,D=4.420' PERFORATION SUMMARY _ 9946' 1---I5"X 4-1/2'XO,D=3.940" REF LOG:MD/GR ON 05/04/07 ® ,_ TAM SWELL PACKER'S ANGLE AT TOP PERF: 94°@ 14000' 1 NO SIZE TOP DEPTH MN ID Note.Refer to Production DB for historical perf data 4-1/2"WFT GBP 13550' = 6 4-1/2"X 5-3/4" 12278 3.958" SIZE SPF INTBNAL Opn/Sqz SHOT I SQZ (10/06/14) I5 4-1/2"X 5-3/4' 12974 3.958" 2-7/8" 6 13400-13500 0 10/08/14 2: 1.1, 4 4-1/2"X 5-3/4' 13750 3.958" 2-7/8" 6 14000- 14100 C 10/27/12 4-1/2"HES CSP -1 14249' 3 4-1/7 X 5314" 14321 3.958' 2-7/8" 6 14560- 14660 C 02/16/11 (10/25/12) � 2 4-1/2"X 5-3/4" 14852 3.958" 2-7/8" 6 15030-15055 C 08/01/09 ' 1 4 1/2'X 53/4" 15298 3.958' 2-7/8" 6 15055- 15080 C 08/01/09 ' \ 14755' -14-1/2"IES CSP(02/15/11) 2-1/8" 6 15080- 15105 C 08/01/09 IIII CO 2-7/8' 6 15105-15130 C 08/01/09 —'I 15100' H4-1/2"I-ES CEP(02/13/11) 2-7/8"r 6 15350- 15400 C 10/10/08 — 2-7/8' 6 15450- 15500 C 10/09/08 ='y 15230' -14 1/2"WFDCEP(07/31/09) 2-7/8" 6 15550-15650 C 05/07/07 IPBTD - 15731' 4-112'LNR, 12.6#,L-80 DST-M,.0152 bpf,ID=3.958" H 15818' 11s!!i DATE REV BY COMMENTS DATE REV BY COMMENTS PRIDHOEBAY LINT 09/018/77 ROW 34 INITIAL COMPLETION 01/10/12 TMNUMD ADDED H2S SAFETY NOTE' WELL: 09-15A 10/06/87 PAA 102 RWO 11/01/12 JJL/JMD SET CSP 8 ADPITF(10/25-27/12) P RMT Nb:`2070220 05/09/07 N2ES SIDETRACK(09-15A) 10/06/14 CT/PJC SET CSP AR No: 50-029-20256-01 09/09/09 RM-YTLH CEPSET/ADFERF(07/31/09) 10/08/14 TA/PJC ADPERFS SEC 1. TION, R15E 993 FSL 8 150'RNL 02/11/11 M3IJA43 ADDED SSSV SAFELY NOTE [02/28/11 JMF/PJC CSP/ACFERFS(02/13-15/11) BP Exploration(Alaska) • • loepp, Victoria T (DOA) From: Catron, Garry R(Wipro) <Garry.Catron@bp.com> Sent: Friday, March 17,2017 7:44 AM To: Loepp,Victoria T(DOA) Cc: Stechauner, Bernhard Subject: FW:09-15A Attachments: 09-15Ai 2017-01 MIST CIBP Perf.pdf c.31(..)7 atas Follow Up Flag: Follow up Flag Status: Flagged Victoria. Attached please find the SOR for 09-15A to be included as an attachment to the currently pending approval Sundry Application for the setting of a CIBP and Adding Perforations. Thank you, Garry Catron PDC PE 907-564-4424 From: Stechauner, Bernhard Sent:Thursday, March 16, 2017 2:52 PM To: Catron, Garry R(Wipro) Subject: 09-15A Hi Garry, Just talked to Victoria, looks like we didn't submit the SOR for this job. Could you please forward a pdf of the SOR (stripped of all the confidential information you usually remove)to her as an e- mail? Thanks, Bernhard Bernhard Stechauner Lead Petroleum Engineer FS2 Area Team BP Exploration (Alaska) Inc. Office: 907-564-4594 Cell: 907-360-7485 1 • • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday, March 15, 2017 1:52 PM To: Stechauner, Bernhard (Bernhard.Stechauner@bp.com) Subject: PBU 09-15A(PTD 207-022, Sundry 317-063)Acid Stimulation Bernard, Please include a short well history and summary of procedure with your submitted sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeopCa alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg k rcr 2'1115 DATE: Thursday,February 05,2015 P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 09-15A FROM: Bob Noble PRUDHOE BAY UNIT 09-15A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-15A API Well Number 50-029-20256-01-00 Inspector Name: Bob Noble Permit Number: 207-022-0 Inspection Date: 1/29/2015 Insp Num: mitRCN150202165203 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-15A Type Inj W JTVD 8534 Tubing 2184 . 2184 - 2191 2153 - PTD 2070220 Type Testl SPT Test psi+ 2134 - IA 239 - 2607 2592 - 2592 Interval 4YRTST — P/F P ' OA Notes: ',r s S6 Thursday,February 05,2015 Page 1 of 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Thursday, February 05, 2015 4:49 PM r) To: Regg, James B (DOA) IVeta ZI G(1 Subject: RE: PBU 09-15A (PTD 2070220) Attachments: Injector 09-15A (PTD#2070220) TIO Plot.docx Jim, Enclosed Is the TIO plot for Injector 09-15A(PTD#2070220). Kevin Parks BP Alaska -Well Integrity Coordinator C=1,1c:f1� Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, February 05, 2015 4:38 PM To: AK, D&C Well Integrity Coordinator Subject: PBU 09-15A (PTD 2070220) Please send 90day TIO plot for review. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. 1 Injector 09-15A(PTD#2070220) TIO Plot Of 15 • 1 , -0-TOA IA OA 000 ♦-0000 a 1 Image jest Well History File Cr 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 fite. (~ ~ - ~ ~ ~ Well History File Identifier Two-sided III II'III II III II III ^ Rescan Needed III II'III II II III III Orgamz~ng (done) ^ RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: DIGITAL DATA Diskettes, No. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: NOTES: ^ Logs of various kinds: ^ Other:: BY'Maria ~ Date: ~`~ ~ ~~7 /s/ ~ ~ ~ Pro-ect Proofin ! g III 111111 IIIII II III BY: Maria Date: ; (~ /s/ Scanning Preparation ~ x 30 = BY: ~ Maria ~_ Date:. Production Scanning + ! - t- =TOTAL PAGES ~~ (Count does not include cover sheet) (~ Isl Stage 1 Page Count from Scanned File: ,~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ ®~ /s/ ~~ ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scannin is com late at this point unless rescanning is required. II I II ~I II I II II I I III 9 P ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III III II'I III 10/6/2005 Well History File Cover Page.doc • STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMOON NOV 2 12012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well Plug Perforations U Perforate 12j Other Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ • Change Approved Program ❑ Operat. Shutdowr0 Stimulate - Other ❑ Re -enter Suspended Well❑ ' 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development❑ Exploratory ❑ , 207 -022 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service 0 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20256 -01 -00 7. Property Designation (Lease Number): s 8. Well Name and Number: ADL0028324 PBU b9 -15A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): — To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 15820 feet Plugs measured See Attachment feet true vertical 8734.7 feet Junk measured None feet Effective Depth measured 14755 feet Packer measured See Attachment feet true vertical 8754.36 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 72 20" 94# H-40 28 - 100 28 - 100 1530 520 Surface 2704 13 -3/8" 72# N -80 27 - 2731 27 - 2730.88 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet FEB t7 2 Q V Q'a True Vertical depth See Attachment feet NEp Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 24 - 9920 24 - 8570.48 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4 -1/2" MCX SSV 1998 1997.89 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 1063 0 1867 1 Subsequent to operation: 0 11586 0 0 3103 1 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: , Oil ❑ Gas ❑ WDSPLIJ GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email G Printed Name Garry Catron / Title PDC PE Signature �� ei.1 Phone 564 -4424 Date 11/20/2012 RPDMS NOV 26 1012 ij 27•/v ` 1y 2.6(2 Form 10-404 Revised 10/2012 Submit Original Only • • 09 -15A 207 -022 -0 Plugs Attachement SW Name Date MD Description 09 -15A 10/26/2012 14249 4 -1/2" HES CIBP 09 -15A 2/15/2011 14755 4 -1/2" HES CIBP 09 -15A 2/13/2011 15100 4 -1/2" HES CIBP 09 -15A 7/31/2009 15230 4 -1/2" WFD CIBP 1 • Packers and SSV's Attachment ADL0028324 SW Name Type MD TVD Depscription 09 -15A SSSV 1998 1949.39 4 -1/2" MCX SSV 09 -15A PACKER 9863 8485.9 4 -1/2" Baker S -3 Packer 09 -15A PACKER 12278 8764.62 4.5" X 5.75" TAM Swell Packer 09 -15A PACKER 12974 8752.03 4.5" X 5.75" TAM SweII Packer 09 -15A PACKER 13750 8734.36 4.5" X 5.75" TAM SweII Packer 09 -15A PACKER 14321 8714.88 4.5" X 5.75" TAM SweII Packer 09 -15A PACKER 14852 8704.88 4.5" X 5.75" TAM Swell Packer 09 -15A PACKER 15298 8689.83 4.5" X 5.75" TAM SweII Packer Casing / Tubing Attachment ADL0028324 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 20" 94# H-40 28 - 100 28 - 100 1530 520 LINER 2766 7" 26# L -80 7304 - 10070 6750.32 - 8668.61 7240 5410 LINER 5904 4 -1/2" 12.6# L -80 9914 - 15818 8566.64 - 8734.73 8430 7500 PRODUCTION 2267 9 -5/8" 40# L -80 26 - 2293 26 - 2292.89 5750 3090 PRODUCTION 2267 9 -5/8" 47# N -80 26 - 2293 26 - 2292.89 6870 4760 PRODUCTION 5199 9 -5/8" 47# N -80 2293 - 7492 2292.89 - 6900.42 6870 4760 SURFACE 2704 13 -3/8" 72# N -80 27 - 2731 27 - 2730.88 4930 2670 • TUBING 9896 4 -1/2" 12.6# L -80 24 - 9920 24 - 8570.48 8430 7500 • 1 1 Perforation Attachment ADL0028324 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 09 -15A 10/28/2012 APF 14000 14025 8771.31 8769.85 09 -15A 10/27/2012 APF 14025 14050 8769.85 8768.61 09 -15A 10/27/2012 APF 14050 14075 8768.61 8767.62 09 -15A 10/25/2012 APF 14075 14100 8767.62 8766.73 09 -15A 10/25/2012 BPS 14560 14585 8757.94 8757.52 09 -15A 10/25/2012 BPS 14585 14610 8757.52 8756.82 09 -15A 10/25/2012 BPS 14610 14635 8756.82 8756.15 • 09 -15A 10/25/2012 BPS 14635 14660 8756.15 8755.55 09 -15A 10/25/2012 BPS 15030 15055 8747.7 8746.85 09 -15A 10/25/2012 BPS 15055 15080 8746.85 8746 09 -15A 10/25/2012 BPS 15080 15100 8746 8745.31 09 -15A 10/25/2012 BPS 15100 15105 8745.31 8745.13 1 09 -15A 10/25/2012 BPS 15105 15130 8745.13 8744.22 09 -15A 10/25/2012 BPS 15350 15360 8737.19 8736.98 09 -15A 10/25/2012 BPS 15360 15380 8736.98 8736.59 09 -15A 10/25/2012 BPS 15380 15400 8736.59 8736.39 09 -15A 10/25/2012 BPS 15450 15460 8736.53 8736.58 09 -15A 10/25/2012 BPS 15460 15480 8736.58 8736.67 09 -15A 10/25/2012 BPS 15480 15500 8736.67 8736.75 09 -15A 10/25/2012 BPS 15550 15650 8736.87 8736.76 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK • BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • /I � .� t 01 (Al) t9 (1 . Daily Report of Well Operations ADL0028324 ACTIVITYDATE SUMMARY CTU #9w/1.75 "ct. Job Objective: Drift -GR- CCL /CIBP / Adperf. «< Continue WSR from 10/26/12 >» Wait on TCP to return from Nordic. RIH w / gun run #2, CBF firing head & 2.875 "x 26.17' HSD -PJ OMEGA 2906 -HMX 6 spf 60 phase pert gun. Correct bottom shot to ELM using plug. Perforate 14,050' - 14,075'ELM. POOH. Confirm guns fired. RIH w/ gun run #3, CBF firing head & 2.875 "x 26.17' HSD -PJ OMEGA 2906 -HMX 6 spf 60 phase pert gun. Correct bottom shot to ELM using plug. Perforate 14,025' - 14,050'ELM. POOH. Confirm 10/27/2012 guns fired. « <In Progress »> CTU #9 w/1.75" ct. Job Objective: Drift-GR- CCL /CIBP /Adperf. «< Continue WSR from 10/27/12 »> RIH w/ gun run #4, CBF firing head & 2.875 "x 26.17' HSD -PJ OMEGA 2906 -HMX 6 spf 60 phase pert gun. Tag plug and correct bottom shot to ELM. Perforate 14,000 - 14,025' ELM. POOH. Displace hole to diesel. Perform injectivity test —0.5 bpm © 2000 psi w / diesel down backside. RIH w / 2" BDN & displace diesel out of well with slick KCI. Performed another injectivity test pumping slick KCI down CT —2 bpm @ 2150 psi from 10/28/2012 12000'CTM. lnj test passed per Town PE. POOH. FP. RDMO. «< Job Complete »> * ** *WELL S/I ON ARRIVAL" ***(post- crip =adperf/acid -stim) BRUSHED NIPPLE FROM 1980' SLM, TO 2020' SLM SET 4 -1/2" MCX W/ (4 3/16" PORTS, 1.30" BEAN, OAL =40" SER# BPX 476) @ 1998' SLM, 1998' MD. RAN 4 -1/2" CHECK SET, S/D @ 1997' SLM, CHECK SET SHEARED. 11/4/2012 * ** JOB COMPLETE, WELL TURNED OVER TO DSO * ** IIIIP TR = 4 -1/16" CM/ • 'MLLFEAD = 13 -5/8' DAD SA NOTES: H2S READINGS AVERAGE 125 ppm ACTUATOR = BAKER 0 O -15 A WHEN ON ML WELL REQUIRES A SSSV WHEN ON 54' ML WB-L ANGLE> 70° @ 10375'. BF. ELEV = KOP = 2750' Max Angie = 96° @ 10689' Datum Mil - 10395' I 1998' - 14 - 1/2" HES X NP, D = 3.813" Datum ND = 8800' SS • 1 2279' H 9 HES ES CEMENTER 120" CONDUCTOR, 94 #, H-40, ID = 19.124" H 100' 2400' -� 9 -518" FOC I9 -5/8" CSG, 40#, L -80 TC-11, D = 8.835" H 2293' 2523 -� 9 -5/8" FOC 113 - 3/8' CSG, 72#, 14.80 BTC, D = 12.347" IH 2730' I 7304' - 9 X 7" BKR C ZXP LW TOP OF 7" LI R H 7304' w/ 11.6' TIEBACK SLV, D = 6.32 " Minimum ID = 3.726" @ 9908' N 7322• H 9-5/8" x 7" BKR HMC LNR HGR, D = 6.35" I 4 -112" HES XN NIPPLE 8-1/2" M LLOUT WINDOW (09 -15A) 7479' - 7492' I9 -5/8' V1hIPSTOCK (04/14/07) H 7480' 1 9-5/8" EZSV (TAGGED 04/13/07) - 7501' 9842' 4112" X NP, D = 3.813" 9863' I- 7" X 4 -1 /2" BKR S-3 PKR, •4•4•r ID = 3.875" - - WOO 1 - - I _. ►_� �� , 4 4 98$7' - 14 -1/2" FES X NP, ID = 3.813" •••••4 � � X � 4144411444' 14444444441 • 1 9908' - 14 -1/2" tES XN MR D = 3.725" ••••••••••4 ,•••••••••• ,••••••••••• 4••••••••• 9914' - 7^ X 5" BKR HRD .44 ••••••••••4 ZXP LTP, D = 4.410" / 4.4.1.4.4.4.4.4.4. t 19 -5/8" CSG, 47 #, N-80 BTC, ID = 8.681" -1 10028' 7,avg eLLeOi•Oi ® Pi 9920' - 14 -1/2" WLEG, ID = 3.958" I Pi i 4 -1/2" 113G, 12.6#, L -80 TCI, .0152 bpf, D = 3.958^ 9920' 9936' 17" X H BKR FLEX LOCK �� ---- - -._.. LNR HGR, D = 4.420" 17" LNR, 26#, L -80 BTC-M, .0383 bpf, D= 6.276" 10070' 8946' 1-15" X 4 -112' XO, ID = 3.940" FERFORATIDN SUM�AARY ✓ TAM SWIRL PACKER'S Fill LOG: MEND / GR ON 05/04107 ._. NO � SIZE TOP DEPTH MN D ANGLE AT TOP PERF: 94° @ 14000' 6 41/2" X 5-3/4" 12278 3.958" 4-1/2' HES CBP -I 14249' 5 4 -112" X 5-314" 12974 3.958" Note: Refer to RoMxtion DB for historical pert data 4 4112" X 5-3/4" 13750 3.958" SIZE , I<,(TERVAL___,Opril _ -- 1 (10(25/12) 3 41/2" X 5314" 14321 3.958" 2 -7/8" 6 14000 - 141.1 O 10/27/12 = ' =' 2 41/2" X 5-3/4" 14852 3.958" -7 ': 6 4560 - 4660 C 02/16/11 _ ' 1 4-1/2" X 5-3/4" 15298 3.958" 2 -7/8" 6 15030 - 15055 C 08/01/09 2 -7/8" 6 15055- 15080 C 08/01/09 „ 14755' - {41!2" t�5 CBP(02/15 /11) 2 -7/8" 6 15080- 15105 C 08/01/09 �' 15100' -14-1/2. HES CBP(02/13/11) 2 -7/8" 6 15105- 15130 C 08/01/09 I 2 -7/8" r 6 15350 - 15400 C 10/10/08 15230' -14-1/2 WED CBP (07/31/09) 2 -7 /8" 6 15450 - 15500 C 10/09/08 ' 2 -7/8" 6 15550 - 15650 C 05/07/07 pBTp I I 15731' ►.•�•�• I4 -1/2" LW, 12.6#, L -80 DT -M, .0152 bpf, ID= 3.958" -1 15818' ► DATE REV BY CONVENTS DATE REV BY CONSAENTS PRUDHOE BAY UNIT 091018/77 ROWAN 34 INITIAL COMPLETION 09/09/09 RM-VTLH C33P SET /ADFERF (07/31/09) WELL 09-15A 10/06/87 PAA 102 RWO 02/11/11' ME/14D ADDED SSSV SAl-EI Y NOTE PERNT No: "2070220 05109/07 N2ES SIDETRACK (09 -15A) 02/28/11 JMF /PJC CEFY ADPERFS (02/13- 15/11) AF'1 No: 50- 029 - 20256 -01 02/15/08 PJPIPJC DRLG DRAFT CORRECTIONS 01/10/12 TMNUMD ADDED FQS SAFETY NOTE SEC 1, T10N, R15E, 993' FSL & 150' FWL 03/18/08 PJP/PJC REF LOG FERFS (02/18/08) 11/01/12 JJUJMD SET CEP & ADPERF (10125- 27/12) 10/13/08 GLNPJC PERFS (10/10/08) _ ' BP Exploration (Alaska) ,, • • sifar[E o[F n[LnisEL SEAN PARNELL, GOVERNOR ALASKA OIL ` GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chidi Igbokwe �-- Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, 09-15k4004.- ;., Sundry Number: 312 -341 cut Dear Chidi Igbokwe: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy u. Foerster Chair, Commissioner DATED this 12th day of September, 2012. Encl. RECEIVED , • • SEP 06 2012 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION A APPLICATION FOR SUNDRY APPROVALS �� --'++ V 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations 0 • Perforate Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ s timulate U Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 207 -022 -0 • 3. Address: Stratigraphic ❑ Service Ei . 6. API Number: P.O. Box 196612, Anchorage, AK 99519 -6612 50 -029- 20256 -01 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 PBU 09 - 15A • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0028324 . PRUDHOE BAY, PRUDHOE OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15820 • 8735 • 14755 8754 See Attachment None Casing Length Size MD TVD Burst Collapse Structural Conductor 72 20" 94# H-40 28 -100 28 - 100 Surface 2704 13 -3/8" 72# N -80 27 - 2731 27 - 2730.88 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 4 -1/2" 12.6# L -80 L -80 24 - 9920 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths 4 -1/2" MCX SSSV 1998', 1997.89' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program Ell BOP Sketch ❑ Exploratory ❑ Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas L ' • ,\ 1 " WDSPL Suspended ❑ 16. Verbal Approval: Date: WINJ Ill GINJ ❑ A ' / 1 WAG Abandoned ❑ Commission Representative: J GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Prepared by Garry Catron 564 -4424 Printed Name Chidi Igbokwe Title Production Engineer Signature .^ cam. Phone Date ft‘ ■ �� 564 -4795 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: la _ •-. 3+1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: APPROVED BY Approved by: X , / 4 COMMISSIONER THE COMMISSION Date: — / 2. -( 2 Form 10 403 Revised 1/2010 V V C 4 12 ubm i Dupli to `v �I 0RIGINAElagifp ��1. • • Perforation Attachment ADL0028324 Well Date MD Plug Type TVD 09 -15A 2/15/2011 14755 4 -1/2" HES CIBP 8754 09 -15A 2/13/2011 15100 4 -1/2" HES CIBP 8745 09 -15A 7/31/2009 15230 4 -1/2" WFD CIBP 8740 Casing Summary ADL0028324 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 72 20" 94# H-40 28 100 28 100 1530 520 H-40 LINER 2766 7" 26# L -80 7304 10070 6750 8669 7240 5410 L -80 LINER 5904 4 -1/2" 12.6# L -80 9914 15818 8567 8735 8430 7500 L -80 PRODUCTION 2267 9 -5/8" 40# L -80 26 2293 26 2293 5750 3090 L -80 PRODUCTION 5199 9 -5/8" 47# N -80 2293 7492 2293 6900 6870 4760 N -80 SURFACE 2704 13 -3/8" 72# N -80 27 2731 27 2731 4930 2670 N -80 TUBING 9896 4 -1/2" 12.6# L -80 24 9920 24 8570 8430 7500 L -80 • • • • Perforation Attachment ADL0028324 Well Date Perf Code MD Top MD Base TVD Top TVD Base 09 -15A 2/17/11 APF 14560 14585 8758 8758 09 -15A 2/16/11 APF 14585 14610 8758 8757 09 -15A 2/16/11 APF 14610 14635 8757 8756 09 -15A 2/16/11 APF 14635 14660 8756 8756 09 -15A 2/16/11 BPS 15030 15055 8748 8747 09 -15A 2/16/11 BPS 15055 15080 8747 8746 09 -15A 2/16/11 BPS 15080 15100 8746 8745 09 -15A 2/16/11 BPS 15100 15105 8745 8745 09 -15A 2/16/11 BPS 15105 15130 8745 8744 09 -15A 2/16/11 BPS 15350 15360 8737 8737 09 -15A 2/16/11 BPS 15360 15380 8737 8737 09 -15A 2/16/11 BPS 15380 15400 8737 8736 09 -15A 2/16/11 BPS 15450 15460 8737 8737 09 -15A 2/16/11 BPS 15460 15480 8737 8737 09 -15A 2/16/11 BPS 15480 15500 8737 8737 09 -15A 2/16/11 BPS 15550 15650 8737 8737 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • . Packers and SSV's Attachment ADL0028324 Well Facility Type MD Top Description TVD Top 09 -15A SSSV 1998 4 -1/2" MCX SSSV 1998 09 -15A PACKER 9863 4 -1/2" Baker S -3 Packer 8534 09 -15A PACKER 12278 4.5" X 5.75" TAM SweII Packer 8813 09 -15A PACKER 12974 4.5" X 5.75" TAM SweII Packer 8801 09 -15A PACKER 13750 4.5" X 5.75" TAM SweII Packer 8783 09 -15A PACKER 14321 4.5" X 5.75" TAM SweII Packer 8763 09 -15A PACKER 14852 4.5" X 5.75" TAM SweII Packer 8753 09 -15A PACKER 15298 4.5" X 5.75" TAM SweII Packer 8738 0 . Packers and SSV's Attachment ADL0028324 Well Facility Type MD Top Description TVD Top 09 -15A SSSV 1998 '4-1/2" MCX SSSV 1998 09 -15A PACKER 9863 4 -1/2" Baker S -3 Packer 8534 09 -15A PACKER 12278 4.5" X 5.75" TAM SweII Packer 8813 09 -15A PACKER 12974 4.5" X 5.75" TAM SweII Packer 8801 09 -15A PACKER 13750 4.5" X 5.75" TAM Swell Packer 8783 09 -15A PACKER 14321 4.5" X 5.75" TAM SweII Packer 8763 09 -15A PACKER 14852 4.5" X 5.75" TAM SweII Packer 8753 09 -15A PACKER 15298 4.5" X 5.75" TAM Swell Packer 8738 • • by SUNDRY REQUIRED To: J. Bixby /R. Liddelow Date: June 11, 2012 AK D &C Wireline Team Leads From: Chidi Igbokwe AFE: DS 04 & 09 PE Est Cost: Subject: 09 -15Ai CIBP /SBG/ PERFORATION IOR: 200 Step Unit Operation 1 S Pull MCX. Drift &Tag 2 F Perform Schmoo -B -Gone 3 C Set CIBP /Shoot Perf from 14000' to 14100' MD 4 CP Perform Acid Stimulation- (pending injectivity test) 5 S Set MCX Current Status: WAG Injector - Online on MI Max Deviation: 96° @ 10689' and Last Test: 06.09.2012: 3138 -psi on MI (28,734 Mscfd) BHP: None. Estimated is 3350 -psi @ 8800 SS based on 2009 pressure map Min. ID: 3.725" @ 9908' (4 -1/2" XN Nipple) Last TD tag: Tag CIBP @ 14760' (as corrected on coil counter to ELMD) 02.18.2011 Last DH Ops: 02.23.2011: Set MCX Last H2S: No Data- DS 09 is a high H2S site OBJECTIVE Set CIBP and shoot 100' of perforations per MIST strategy. Background: Well 09 -15A was sidetracked in 2007 as a horizontal MI injector. The well path curves around .- ..1- . '•'- • , -I•' - s• ' • -'•. • • I • •f MI ar•und the •atteri The strategy is to inject a prescribed volume of MI in the toe of the well and progressively work up hole with other MI cycles. The 4 -1/2" liner was cemented in place with 6 swell packers. The swell packers were run as a safety precaution to ensure isolation between target MI slug intervals. The first two MI cycles have been completed, so the existing perfs will be isolated with a CIBP and new perfs added. The original 100' of perfs were shot in May 2007. Prior to injection, an SCMT was tractored into the hole in June 2007. The tractor job encountered debris from the completion and pushed it downhole. Initial injectivity was low, so a mud acid treatment was pumped in December 2007. A FCO of the liner followed by 100' of adperfs and a mud acid job were performed in October 2008. MI injection started in November 2008 at about 35MMCFD. The well was swapped back to water injection in May 2009 and continued on water injection at average rates of 1500bwpd until fall 2009 when work began to swap to MI for the second bulb. 09 -15Ai 2012 _06 MIST CIBP PERF.doc • • In August 2009 the well was plugged with a CIBP set at 15230' MD, perforated in the 27P, and stimulated with mud acid to prepare for the second bulb. The second bulb ended in April 2010 due to problems with MI from CGF. A total of 7.7 BCF of MI was injected, slightly higher than the predicted 5 BCF, due to great results in offset producers. The main beneficiary of MI injection on the second bulb was well 04 -31 which went from making around 1000bopd to i 4000bopd due to proximity and placement of the bulb. Although the response only lasted three months, it was big enough to justify another 27P MI slug. The third bulb was initiated in February, 2011 and has reached a total of 9.3 BCF (slightly higher than required). MIST well 09 -15Ai is now ready for the fourth set of perfs and MI slug which will be placed in the 27P. The fourth bulb is expected to benefit 04 -01 and 04 -31. Contact Chidi Igbokwe © 564 -4795 (W), 206 - 790 -2449 (C). Cc w/ att: Well File Slickline: 1. Pull MCX 2. Drift to max deviation w/ dummy CIBP Fullbore- Schmoo -B -Gone 3. MIRU to 09 -15Ai and pump 5 bbls methanol spear down tubing 4. Pump 260 bbls (1.2x wellbore volume) of - 150 °F Schmoo -B -Gone treatment down the tubing at no more than 3 -5 bpm (do not exceed a WHIP of 1500 psi) 5. Pump 5 -bbls of Methanol to flush SBG from surface lines. 6. RDMO, notify operations (659 -5409) to let the SBG soak for 6 -12 -hours if possible (extended soak period is essential to maximize the effectiveness of SBG treatment ) 7. Put 09 -15Ai back on injection and target -4000 bwpd or 1200 psi (whichever comes first) and record final injection rates & pressures once stabilized Coil Procedure: 8. RU at least 16,000' of 1.75" CT. Rig up hard line to be able to pump down tubing for injectivity test. Check that the well is shut in at lateral and wing valves. a. Note: 1.75" CT has been able to get to at least 15650' without safelube. 9. RIH with memory GR/CCL/drift for CIBP. Drift to top of CIBP @ 14,755'. Flag pipe. PU, logging tie -in up pass from 14755' up to 11800' (flagging pipe at 14,250' MD with different color). POOH. 10. Tie- in Note: There is not much character in the GR log. Will need to tie into the HES MWD- GR at a good shale higher up (@ around 11,800'). Do not use the USIT- GR -CCL because it has not been depth shifted back to the open hole GR log. 09 -15Ai 2012 _06 MIST CIBP PERF.doc • • 11. Download memory tool data. Determine depth correction reference to Halliburton MWD log for the well, which was logged 12- Apr -07 to 6- Mav -07. 12. MU BHA for CIBP. RIH, with CIBP. Correct flag depth and set CIBP at 14250' MD per PE Manual guidelines. PU, tag CIBP. PT CIBP to 2500 psi. 'POOH. a. flag pipe as necessary for depth control 13. RU for perforating. RIH and_erforate with 2 -7 /8" PowerJet Omega charges, 6 SPF, _ from 14000' to 14100' MD ref Halliburton MWD log. Do not use 3 -3/8" guns due to concerns about residual fill. 14. Pull above the perforations and perform an injectivity test by pumping with diesel down 4 -1/2" tubing @ max pressure of 2000 psi. Note injectivity on WSR. POOH. If rates are less than 2bpm, move to step 15 to perform acid stimulation otherwise RDMO. Note: if injectivity is 2bpm or greater, hold injection steady for at least 30 mins at whatever max injectivity we are able to achieve to ensure injectivity (of —2bpm or more) is sustainable. Acid Stimulation 15. RIH CT with a 2" — 2 1/4" jet swirl nozzle (Note: Min ID = 3.725" @ 9908'). Pump fluids per attached Pump Schedule. 16. If needed to establish injection, go to 3000 psi WHP, but drop immediately to 2000 psi WHP as to not frac the well during the acid wash. When acid is on the perfs, max WHP should be 2000 psi. Before POOH complete the overflush to ensure acid has been pushed away. 17. Do an injectivity test post acid stim down the backside with diesel at no more than 200 - psi for about 30 mins. Establish a stabilized rate and pressure to make certain of positive injection. POOH. FP top 2500' of well. Fluids: Stage Fluid Type Vol gallons Load & Overflush 3% NH4CI + F103 460 bbls 19320 Cap Diesel 115 bbls 4830 Spacer 3% NH4CI + F103 + U067 105 bbls 4410 Acid 12% HCI 75 bbls 3150 Mud Acid 9:1 Mud Acid 75 bbls 3150 Foam Liquid 3% NH4CI + F103 10 bbls 416 Foam N2 N2 30,431 ft3 327 09 -15Ai 2012 _06 MIST CIBP PERF.doc . • • Acid Additives: tot tot Loading for: 12% HCI 9/1 mud acid chemical chemical Product Code: Function: Units: per Mgal per Mgal in HCI in Mud acid A264 ACI gal/Mgal 6 6 19 gal 19 gal A201 Inhibitor Aid gal/Mgal 15 15 47 gal 47 gal F103 Flowback aid gal/Mgal 2 2 6 gal 6 gal L058 Iron Control lb/Mgal 20 20 63 Ibs 63 Ibs W054 Antiemulsifier gal/Mgal 5 5 16 gal 16 gal U067 Mutual Solvent gal/Mgal 0 50 0 gal 158 gal Spacer & Overflush Additives: tot Loading for: Overflush Spacer chemical tot chemical Product in Code: Function: Units: per Mgal per Mgal Overflush in Spacer F103 Flowback aid gal/Mgal 2 _ 2 6 gal 6 gal U067 Mutual Solvent _ gal/Mgal 0 50 0 gal 158 gal Diverter Additives: Loading for: Diverter tot chemical Product Code: Function: Units: per Mgal in Diverter F103 Flowback aid gal/Mgal 2 1 gal 09 -15Ai 2012 _06 MIST CIBP PERF.doc • • 1 fluHHIflfl, ilk fill 1 1 , f t 3£ 3 i t S t g t IIIIIIIII� i�� a v 1'1 itiM4000010000•000000 It J ; a missistoom firal IL tli ProtiAttIRAVAIMARIAR: a H I !u!rssarrrr ; ": vm INOsamitmAnmAnnaman ji jibtibbbObbbbbbbbbtsb O S 1+ 1 !1! 1 " I l ie ALA 09 -15Ai 2012 _06 MIST CIBP PERF.doc • • Slickline Procedure: 3. Run MCX. RDMO Note: Consider using delfrin fenolic balls. See WSR of 02/14- 02/15/2011 for issues during CIBP set- Finally saw positive indications that ball set with fenolic ball after multiple tries to get ball on seat. TREE= 41/16" CNN WELLHEAD - 13 5/8' FMC SAFETY NOTES H2S READ NGS AVERAGE 125 ppm ACTUATOR = BAKER Q WHEN ON M I . WELL REQUIRES A SSSV WHEN ON KB ELEV = 54' V -15A M(. WELL ANGLE> 70" e 10375'. BF ELEV = t - - I KOP= 2750' Max Angle -. 96" © 10689' C9tum MD = 10395' I i r 1998' 1 14 -112 I i_s .). N P 1) = 3 81 Datum WO = 8800' SS Q 2279' I - - -I9-5,5' HLS LS C:WEN `ER C2C" CONDUCTOR, 94X, H -40, ID = 19 124" 100'._...1 r 2400' - - - {9-5/8" FOC- 19 •518 CSG 40X, L •80 7011 ID; 8 835" 2293' 2523' r - 3t31' r OL1 [13 -318" CSG 72X, N -80 8TC ID = 2.347" -f 2730' 7304' I - X 7 134R r., 2 7X ITP '. TOPOF 7' LNR Ft 7304' w r 1 B I IFBA (K SI V I) 8 3 Minimum ID = 3.726e @ 9908'1 7322' 1-19-5t8" X 7" BKR HMC LNR HCR nJ_ 6 35'0 4 -1/2" HES XN NIPPLE _.... __ ._ 8-± MiLLOUT WINDOW (05.15A) 7479' 7497 I9 -518' WH`PSTOCK(04 /14/07) !- 7480' �` (9- 518 "EZSV (TAGGED 04 /1311Th) i 7501 1 \ \ \. 9842' !--141!2" HES X NIP, ID 3813 9863' - 7" X 4 -112" BKR S 3 PKR, MIMI • 0 3875' 49••41 - -194••9 _ � 9 4 9 j 9 • 911 ►- -+ • , 4 , 4 , • 9 . 9' ' 9887' !H 4-1/2 HES X NIP, ID 3 813" I • �9 4 4 4 4 4 44 N 944/999/4 4444449/4 4444444044 . ' HES XN NIP, ID = 3.725" 44444449494444414441 9908 �� 41 }2- _ 44444•4•44' 449••9119 ••V. 994 9914" !- T X 5" BKR HRO I A �1 4!..0.. ZXPLIP,ID=4410` _ [9-5 CSG. 47X 14808 I , - 11681 ' P • • i 9 4.1/ WL EG 10 = 3 958 — 9938' 1- 7° X 5' SKR Fl FX LOCK [4 7 TBG, 1 2 8X -8C TCII 0152 bpt ID = 3.958" I--__ 9920' LNR NOR, ID= 4 420" 7" LNR. 260, L -80 BTC-M 0383 W, 0 = 6 276' I--{ 10070 9946' 0 -15 °' X 4 - :2" XO. ID = 3940" I IAht SWELL PACKERS PFRFORATON SUMMARY ._, ,_, NC SIZE TOP DEPTH MIN ID REF LOG. MWD 1 GK ON 05/04/07 6 4112' X 5 -314' 12278 3.558" - - 5 4 -1 /7' X 5 -3/4" 12974 3.958" ANGLE AT TOP SERF 91' • 14560' 4 4 - X 5 -3/4" 13750 3.958" Note. Refer to Production DB for hisforleal per,` data - _ 3 4 '12" X 14321 3958 " I SIZE SPF INTERVAL Opn /Sq2 DATE .. - "l7 2 -7/8" 6 14560 - 14660 0 ' .7.. 02/16/11 I 2 4112' X 5 -314" 14052 4. 3.955" 2-7/8" 6 15030 - 15055 C 08101/09 g 1 4-'12' X 5 -314" 155258 298 3.958 2-7/8" 6 15055 - 15080 C 08I01/09 -� _ ` 14755' H4-1/2 HES CIBP (0215/1 I 2.7/8" 6 15080 -15105 C 08/01 /C9 :a� •• _ .._. 2 -7/8" 6 15105- 15130 C 08/01/C9 j 15100' 1- {41 HES Ci3P(02/13/1] 2 -7/8" ' 6 15350- 15400 C '0110/C8 _ 15230' -- 1 41/2' WFDCIBP(07 /31/09) I 2 -7/8" 6 15450 - 15500 C 10/09/08 ' 2 7/8" G 1 °5550 - 1W50 PB j- 15731 4 -'2" LNR, 12.60, _- 0018 - M C'52 opf ID -3.958" H 15818' OA& DATE REV BY COMMENTS DATE RHV BY COMMFNTS PR,JDHOE BAY LI 091018/77 ROWAN 34 INITIAL COM PLET 10/13/08 GLM/PJC PERFS (10/10/08) WELL. 09 15A 10/06187 PAA 102 (NO -_ - -- _ - 0628/09 PJPTTLH MIN ID CORRECT'ON PERIAfT No 070220 05/09/07 N2ES SIDETRACK (09-15A) 09/09/09 RMHVTLH CIBPSET /ADPERF(07/31/09) A No 50- 0292025601 02/13/08 PJPfPJC DRLG DRAT'.: CORR .CfDNS 02/11/11 M81JMD ADDED SSSV SA "E'Y NOTE SEC 1, "ON, R15E, 993 FSL & 150 FWL 02/15/08 PJP/PJC OSLO DRAFT CORRECTIONS 02'28/11 JMFIPJC CIBPIADFERFS O2/ "3- 15/11) 03/18/08 PJPIPJC REF LOG PERFS (02/181083) 01/10/12 TMNfJMD ADDED H2S SAFETY NOTE BP Exploration (Alaska) 09 -15Ai 2012 _06 MIST CIBP PERF.doc , • • HALLIBURTDN ROP Rate Of Penetration DGR Dual Gamma Ray � EwR -Phase 4 Pawefl'd y j ITE Horizontal Presentation 1 : 600 / 1 : 240 Sperry Drilling Services Company : BP Exploration (Alaska) Inc. Rig Nabors 2ES o i s Well 09 -15A z I,44 _ z Field Prudhoe Bay Unit S. fi D a 'I 'T W Country United States a a API Number : 50- 029 - 20256 -01 Z a o o m 2 z Latitude : 70° 14' 43.38" North , SO-Vies o 0 Longitude ' 148° 14' 4.35" West PWD DOS ABI 3 8 m Q , v AK State Plane X = 718,541.52 ft NAD 27 > i` , AK State Plane Y = 5,942,466.30 ft NAD 27 Permanent Datum Mean Sea Level Elevation : 0.00 ft Elev. KB Log Measured From : Drill Floor 48.50 ft Above Permanent Datum OF 48.50 ft Drilling Measured From : Drill Floor MD LOG GL 20.00 ft WD Depth Logged : 7,480.00 ft To 15,820.00 ft Unit No. 116 Job No. :AK-MW-0004971247 Date Logged 12- Apr -07 To 06- May -07 Total Depth MD 16,820.00 ft TVD 8,734.69 ft Plot Type: Final Spud Date . 12- Apr -07 Plot Date : 17- Sep -08 Borehole R told (MO Borehole Record ND Run No Run No. Si7a EiCD3 _ T Si7g Frnm' To 1 A film in 7,46{),00 ft _ 7 504 nn fi 2 8.500 in 7,504.00 ft 9, 499.00 ft — — 3 8.500 in 9,499.40.ft � 10.079.00 ft 4 6.125 in , 10.079.00 ft 10,563.00 ft Casing Record (MO) 5 6,12510 10 563.0Q ft 14,850.00 ft Size Weig - ht From To 6_______.. 6 in 14 850 00 (t 15 8 9 Fi95 in 4 7 fl of SURFACE 7 dfitl fly ft 7.000 in 26.00 lhpf 7.430,00 ft 10.070 ft 09 -15Ai 2012 _06 MIST CIBP PERF.doc . • • .... __ - ®. R r { + It a ■11:x'1 -- '''' 11= MEMENIBIOW IMMO MEM MI NIIIMMINE MINOM r rrail�.�.r •.rrl.r•aA!��. all ! imm #I00{ ir Tie-In GR signature to look „ra f at - �118U0' SID as seen on maim FM al IITNIMP E M II IIMEMPOITI1 amok lia rIMI attached reference iog p ...,r ... , _ 111=M � 1111PPR ..rrri Ifl1 ! I IIIfliItiiIfli wim ...._,.. ik -- r ainil� .. r � �..n N .0• MIMI E 111= 111111W"1111110111 I =MA INNEININUIRINTE �1•� {.. Ii{ {' II M ¢ Ill I " -- r r ...........:......,,--7010 mains-e....L.Ennit i .. .., --� _.M.., =AMU i n i i iiMI MIIIII �rr'i lii i mirr.a� RIM= illErarri O 09 -15Ai 2012 _06 MIST CIBP PERF.doc • • E . , 4 -. - - l _I- Hi 11s111lnm1 .. - k ,.. /11/1 Proposed Pert. depth: 14000 - 14100' MD SI Ref Log: ` Halliburton MWD 04.1 .2007 to • c .ir 11000 • I 05.06.2007 } '} . 1111 111 i lli�►7111 i i 1 " ' i. •11 11 1NJ S " 1111 �1 .f' �rrr� _ _ �� ? _ .. ;, 7 1110111111r •. .uIll�i 1 MM.,1 ill i 1 a : 1111•111111141 �• i f_ 1 ..._.... . . !ate __ _ `. 111I..I. J •, 'w _ r MEMO IM J1 ■ / 1 MIN �.- poss...„ I rF' � !flIIi i E p � �� 1 � r — M1r11 — 111 . 1.. l G111111111•11111011111101111111111 111 ,k # ' 14100 . 0111011111•011'101111111M111110111 ! = _1=1111:1161111=121,111 i.. ill il i 1 _ I . -mom t _ i1HI! : :. �1 NI ii iiiiii iu m 1 , .,1_ ma um .. a ■MlIIM ,m .■.111I� .,., — miiiiillirriA1B:if EMI ,,..r MM11 I — 7 ��iui mum S m 1 11M IoM■ I _ - �� ;' __ inil Man — t - - - '": - I — l= . -- 11111111111/rIg i 1� ■ s � ii_ —.7-* �� 1 1111 M/Y1..- Y inialtill■ mom 09 -15Ai 2012 _06 MIST CIBP PERF.doc , • • . 14200 .. ..818Nti11 111111.1M111111111.9 slil low millift111111101111111111111111 rim t N! ---_.sill - _ alaNUui61® i1N' � ti1 :I::I -44 Proposed CIBP Set Depth: 14250' MD "z.;- Ref Log: Halliburton MWD 04.12.2007 to ' 05.06.2007 s _A. III■11■ ■■ui,il111111I■■1111 •t H I ill11111 .,.,. imisammtr,si memminvo ■ IIIIMINMWANI IIIIIIIIIIIIIIIII MI II I III I LIM Alli MIK 111111111111•11•111: Alai 1 ■1,i■E■wn�r ■ Ill _ _ ' E 1,4111111111111111111111111114 OMR ill I E11/1= IN MUI 1 illI �.■■ Ili /MUM ! Ill 1■11M111111 --. .. IllpililiMardpr =1.1.1.11:11411111 Elva . oommor _ U • - ..1 � u•u is 1111111111111101111161111111111 1.11 i 1111 .....t. lisitil III 1111111•1•1111•111111111 _ = / 1 1.uI11� 1 = = uu a 1111_1 11111 �.�. ...i -. ...■ =MEE inglintrib tt ; E , � � p mi —MEM 14300 1311� '� ■!lH %Ni®II1 N1 111111111111111111111111111 11� a l l i�1 �111ft1E MN 0n1 t 111111111111111 a, _ �■MIIIII it i i ■ =111 filo IN ' . _ _ �..■ a ■■ { .... .. _. _ . ■ ■1■!!_I __.. J �II t IRE i �1 ll�lllll . . .. 1 l :C . . 1 1 III � ■1■1�1 I .A - X11111111 III 5 1111 '1Ii11M' i I 1 t r 7 IWIRMI•. :-- r ., _ 1 i. ■ ■n11�1.111f _ t . g 09 -15Ai 2012 _06 MIST CIBP PERF.doc • • j ai PERFORATING PROCEDURE 1111111 rerrrrw•rer Well: 09 -15A API #: 50 -029- 20256 -01 Date: June 5, 2012 Prod Engr Chidi Igbokwe Office Ph: 907 -564 -4795 H2S Level: Home Ph: 907 - 222 -2854 No -Data Cost Est: Cell /Pager: 206- 790 -2449 CC or AFE: WBL Entries IOR Type Work Description S Pull MCX 200 C Set CIBP at 14250' MD C Perforate 14000 - 14100' MD Well Obiectives and Perforating Notes: Shoot 100' of Perfs Attachment: Tie -in log on 5/ 100' scale with proposed addperfs annotated Reference Log Tie in Log Add /Subtract 0 feet Log: MWD /GR to the tie -in log to be on Date: 5/6/2007 depth with the reference log. Company: Haliburton Depths (from -to) Depths (from -to) Feet SPF Orient. Phasing Zone Ad/Reliperf 14,000' - 14,100' - 100' 6 Random 60° 27P Add Perfs Requested Gun Size: 2.875" HSD Charge: 2906 PJ Omega, HMX Is Drawdown Necessary/Desired /Unnecessary During Perforating Unnecessary Preferred Amount of DrawdownlSuggestions to Achieve Drawdown Last Tag: 14,762 ft MD on 2/18/2011 Est Res. Pres. @ 8800' TVD is 3350 psi Perforation Summary Summary Dist Well: 09 -15A Town: Date: API #: 50- 029 - 20256 -01 Prod Engr: Anch Prod Engr P.D. Center PBTD General Comments: Depths Balance Referenced to BRCS Gun Dia. Orient. SPF Phasing Zone AdperflReperf 0/B/U O /B /U - O /B /U - O /B /U - 09 -15Ai 2012 _06 MIST CIBP PERF.doc . , • 0 0 Minilog for Welt Techl@g• 09-15A P�aryOOx htlU iV1T 0/1i4/1 LAURA J. LAFSCN :ae t 4000 Dale 9r5'201 t Injector 'Wel : 09 -15A UWI. 50010242540t 4N,ce .n. 43.5 k: COO yPi.l) 41f 7001- 04•1•011;0u:00 'nu-rel uSA ;,ntat Haas 0? t0 ?1 idttrn tnt r PI Y lost Ga, 1,.ru•, 1.1. 504705°0700.00:00 FotU: MD/WE Wig vtrn. EIFIL.t51TE C* 14.1 15a. ",,,14: ;It 15020 L. - ,;ttr?t - Eae.274S144 ',Wu, , ,ia•.. 11Ias1J tnnir.:. t• ,,, , , -- 14111027 611 I Am .& 70.24!30td .pest: : MA cr.,, APYA i 1.11 PBU.Pn -N MWD 0 - P 15 i GR T4055 112 Notes ll'.rft 1 MAO FRU..GRIAA4 NWD IhI ih1 - , i'11kt u, OP FWR MWp 1:n306 1:6000 I: i ' . � _ ... - _-�-. _ .,- 10s00 L Ilk III "ft IV _ _ 7 1 ,...... , trA �� 11300 81 bQ s ' B- a.r.ta. I AMR illi � 11sCU 1.4.0in .__.› - VP 12500 ® tialliell MIN 1 75110 J s - -- ft E— i - 2P-- -- 1j — Proposed Perforation depth: 14000- 14100' MD r 'L- Fill= "40 13500 / ° y ..., Ilk'. W. 11E' / .rT �4.1 i�— --- .:. --- 3,82S' II I ® 8170 „,0,0 � ._ 1! Ammo mom= : : t , Proposed CIBP set depth: 14250' MD • \ . r a amm 14504 • it 1 27P ■ l l g7D3 15040 IL 111111111111111111 I' „00 SGP FP' 09 -15Ai 2012 _06 MIST CIBP PERF.doc • • WELL SERVICE REPORT WELL DATE JOB SCOPE DAY SUPV 09 -15A 2/15/2011 PROFILE MODIFICATION MOLLAYEV- SAMIR AFE Code DAILY WORK NIGHT SUPV APBDO9WL15 SET MECHANICAL PLUG; PERFORATING WEST MIN ID DEPTH TTL SIZE KEY PERSON UNIT 3.725 " 9908 FT 4.5 " DS- JOHNSON CTU #9 DAILY SUMMARY CTU 9, 1.75 ", 0.134 wall CT. Job Scope: GR /CCL, CIBP, Ad -Pert, Acid Stim.: ** *Job continued from 02/14/11 * ** Normal weather condition restored. No CIBP found, possible been set © — 15100'. RIH with second HES 3.66" OD CIBP. Set CIBP at 14755' ELMD. POOH. Ball recovered. RIH w/ 25ft of 2 7/8" 290PJO guns @ 6 spf. (Run #1) ** *Job Continued on 2/16/11 * ** LOG ENTRIES Init Tb9, IA, OA I 40 I 0 I 0 I TIME DEPTH I TBG I CTP I BPM I BBLS COMMENTS 06:00 0 I I I I Arrived on location after waiting on weather. 07:57 0 I I Checked that all engine are running. 08:37 01 0 0 I I PJSM before BO lubricator with SLB and HES. 08:48 01 I I I Pop off the well. Bring lubricator to backdeck. 08:55 0 No CIBP, setting tool have been stroked and 1/2" alumni and 1/2" delrin fenolic balls have been recovered on seat. 09:00 0 Can't get speed on injector head. Lower lubricator and injector head down on backdeck to troubleshoot. Deice counter. 10:56 I 0 I I I PU injector back. 11:40 0 3500 2d Lined for PT BOT MHA with diesel, McOH truck couldn't start. Pressure up to 561 psi low and 3500 psi high. No leaks observed, bled down to 0 psi. 11:50 0 MU 4 1/2" HES EZSV CIBP. (2.25" OD x 1.37' CTC, 2.13" OD x 1.38' MHA (with DBPV), 2.13" OD x 1.56' Disco (3/4 ball disconnect), 2.0" OD x 0.48' 1 1/2" x 1" CS hydril x/o, 2.72" x 7.19' setting tool, 3.66" x 2.10' ) OAL = 14.064' , OAL to center element of CIBP = 12.78'. 12:29 0 250 0 Stabbed on lubricator on BOP. PT lubricator from backside to 250 psi low for 5 min. 12:38 0 1 2049 I Go high 2000 psi for 5 min. 12:46 0 1 1886 I Good test. Opened Swab valve and SSV. 12:55 0 I I Commenced RIH. 13:03 350 631 17 I 3m Possible fluid level. 14:04 6000 1298 1226 0 3m Weight check, 10.5k #. RBIH. 15:321 12030 1358 1299 0 3m I Weight check, 18.5k #. RBIH. 15:571 14000 1 1334 1275 0 3m I Weight check, 20k #. RBIH. 16:13 14775 1173 1121 0 3m At the flag (14760' RKB), 14782' mechanical. Correct the electronic counter from 14775' to 14760' RKB. 16:16 14760 910 869 0 3m RBIH. PU to 14755', there is a coupling at 14760' according to recent CCL log. 16:20 14755 I 708 I 667 I 0 3m At tar•et de•th 14755' CTMD. 16:28 14755 I 467 I 445 I 0 3m Lined up down coil with McOH. Opened choke manifold. 16:30 14755 I 4591 1600 I 1 I 0 Drop a 1 /2_fenolic ball. 16:58 14755 I 4231 1183 I 0.5 I 30m Slow pump down. 16:59 14755 372 2929 0.6 31m Ball on seat. Positive indication of setting CIBP. WHP =370 psi, CTP= 1108psi. _ 17:03 14755 440 568 0.6 34m Closed choke manifold. PU, 21k #. RBIH to tag the CIBP. 17:05 14729 342 541 0 I 34m 9k# running down weight. Tagged the CIBP. Set down weight 7k #. 17:10 14729 375 553 0 I 34m Lined up down coil with McOH to PT CIBP to 2500 psi DP. 17:28 14729 2508 2733 0.3 I 36m Pressure up against CIBP. 17:35 14729 2508 2653 0 36m Good 5 min test. Bled off pressure to 500 psi thru the choke manifold. 17:37 I 14729 348 430 0 36m POOH. While filling pipe displacement. 18:101 12055 593 12 0.3 8m Change out/continue POOH 09 -15Ai 2012 _06 MIST CIBP PERF.doc + Y • • 20:01 754 65 0 0.3 42 PJSM w/ HES to discuss popping off well and breaking down setting tool. 20:20 0 At surface. Isolate fluids. Close swab. 20:33 0 Pop off well. 20:43 0 Ball recovered 20:50 0 42 Line up with McOH down CT to fluid pack for MHA PT. 20:56 0 44 PT MHA 300 low and 3500 high. 21:08 0 44 PJSM with TCP to discuss making up perf gun #1 and stabbing on well. 21:43 0 44 Make up 25ft of 2 7/8" 290PJO guns (Run #1) 21:56 0 44 Stab on well. 22:14 0 44 Fluid pack for PT 22:16 0 46 PT with McOH down backside: 230 psi low and 2500 high. 22:33 0 47 Open swab, RIH with 25ft of 2 7/8" 2906PJO, @ 6 shot per foot ( (2.25" OD x 1.37' CTC, 2.13" OD x 1.38' MHA (with DBPV), 2.13" OD x 1.56' Disco (3/4 ball disconnect), 2 7/8" Power Jet Omega perf guns 2.88" x 30.99') OAL = 35.29' , OAL bottom shot = 34.73'. 23:59 0 Job continued on 2/16/11 Final Tbg, IA, OA JOB COSTS SERVICE COMPANY - SERVICE DAILY COST CUMUL TOTAL HALLIBURTON $5,704 $5,704 ORBIS $1,300 $3,900 SCHLUMBERGER $0 $37,483 SCHLUMBERGER PLUS 13 PERCENT $0 $4,872 PDS $0 $4,850 BAKER OIL TOOLS $0 $0 CH2MHILL LABOR $0 $8,400 WS DISPATCHED $0 $2,800 WAREHOUSE $0 $21,246 TOTAL FIELD ESTIMATE: $7,004 $89,255 FLUID SUMMARY 3 + 36 + 48 bbls McOH 2 + bbls Diesel bbls 1% KCL 09 -15Ai 2012 _06 MIST CIBP PERF.doc STATE OF ALASKA ALASKA L AND GAS CONSERVATION COMMISSIOO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate El OthcJ Performed: Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waiver Time Extensi4j Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended W❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory [ + 207 -0220 3. Address: P.O. Box 196612 Stratigraphic❑ Service L.6. API Number: Anchorage, AK 99519 -6612 . 50- 029 - 20256 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028324 • PBU 09-15A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 15820 feet Plugs (measured) 15230 15100 14762 feet true vertical 8734.7 feet J�nk (measured) None feet F—B b� U Effective Depth measured 15731 Packer (measured) 9863 12278 14852 12974 13750 14321 feet i 15298 true vertical 8736.17 feet (true vertical) 8534 8813 8753 8801 8783 8763 feet 8738 Casing Length Size MD TVD Burst Collapse Structural Conductor 20" 94# H -40 28 - 100 28 - 100 1530 520 Surface 13- 3/8 "72# N -80 27 - 2731 27 - 2731 5380 2670 Production 9 -5/8" 40# L -80 26 - 2293 26 - 2293 5750 3090 Production 9 -5/8" 40# N -80 2293 - 7492 2293 - 6900 5750 3090 Liner 7" 26# L -80 7304 - 10070 6750 - 8669 7240 5410 Liner 4 -1/2" 12.6# L -80 9914 - 15818 8567 - 8735 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 24 - 9920 24 - 8570 "gyp Packers and SSSV (type, measured and true vertical depth) 7" X 4 -1/2" BKR S -3 PKR CV 8534 5 -3/4" SWELL PKR 12278 12974 8813 8801 5 -3/4" SWELL PKR 13750 14321 8783 8763 5 -3/4" SWELL PKR RECEIVE.* 95298 8753 8738 12. Stimulation or cement squeeze summary: Intervals treated (measured): FEB 2 4 2011 Treatment descriptions including volumes used and final pressure: aka 90 & Gas Coe Commission 13. Representative DailAnnOtagaluction or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 318 1889 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ❑ ServicO Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ . WAG 151 GINJ❑ SUSPO SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -014 Contact Joe Lastufka Printed Nam - • •e Lastui -�i Title Data Manager Signatu - ' .� Phone 564 -4091 Date 2/23/2011 V R8 DMS FEB 2 4 1011 liffrAz Z.zs lr Form 10-404 Revised 10/2010 dAt /zg� Submit Original Only 09 -15A 207 -022 PERF ATTACHMENT - Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 09 -15A 5/6/07 PER 15,550. 15,650. 8,736.87 8,736.76 09 -15A 10/8/08 PER 15,480. 15,500. 8,736.67 8,736.75 09 -15A 10/9/08 PER 15,450. 15,460. 8,736.53 8,736.58 09 -15A 10/9/08 PER 15,460. 15,480. 8,736.58 8,736.67 09 -15A 10/10/08 PER 15,350. 15,360. 8,737.19 8,736.98 09 -15A 10/10/08 PER 15,360. 15,380. 8,736.98 8,736.59 09 -15A 10/10/08 PER 15,380. 15,400. 8,736.59 8,736.39 09 -15A 7/31/09 BPS 15,230. 15,650. 8,740.32 8,736.76 09 -15A 8/1/09 PER 15,105. 15,130. 8,745.13 8,744.22 09 -15A 8/1/09 PER 15,055. 15,080. 8,746.85 8,746. 09 -15A 8/1/09 PER 15,080. 15,105. 8,746. 8,745.13 09 -15A 8/2/09 PER 15,030. 15,055. 8,747.7 8,746.85 • 09 -15A 2/14/11 BPS 15,100. 15,350. 8,745.31 8,737.19 09 -15A 2/15/11 BPS 14,762. 15,030. 8,754.33 8,747.7 09 -15A 2/16/11 APF 14,635. 14,660. 8,756.15 8,755.55 09 -15A 2/16/11 APF 14,585. 14,610. 8,757.52 8,756.82 09 -15A 2/16/11 APF 14,610. 14,635. 8,756.82 8,756.15 09 -15A 2/17/11 APF 14,560. 14,585. 8,757.94 8,757.52 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN • OH OPEN HOLE • • 09 -15A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 2/13/2011 iCTU 9 1.75 ", 0.134 wall CT. Job Scope: GR/CCL, CIBP, Ad -Perf, Acid Stim.: * *Job !continued from 02/12/11 ** *MIRU on DS 09 -15A. Make up & RIH with PDS GR/CCL in 2 3/8" carrier and 3.65" JSN. Tagged CIBP at 15208' mechanical and 15216' 1 CTMD (15229' RKB), PU 30' to 15175' CTMD & flagged the pipe. Log GR/CCL from 115205 to 9500' up CTMD. POOH. Make u and RIH with HES 4 1/2" ***Job Job continued on 2/14/11 * ** * * * ** 2/14/2011 CTU 9, 1.75 ", 0.134 wall CT. Job Scope: GR/CCL, CIBP, Ad -Perf, Acid Stim.: * *Job continued from 02/13/11 * ** RIH with HES 4 1/2" CIBP to flag at 15175 ft. P/U to plug I setting depth. Launch 1/2" ball. Pump 2 coil volumes, ball is not on seat. Launch 1/2" aluminum ball . Pump 2 coil volumes, ball is not on seat. Go to Phase III weather. 1 Decision made to POOH. FP CT and well. WOW. ** *Job Delayed due to Weather i I 2/15/2011 CTU 9, 1.75 ", 0.134 wall CT. Job Scope: GR/CCL, CIBP, Ad -Pert, Acid Stim.: ** *Job continued from 02/14/11 * ** Normal weather condition restored. No CIBP found, possible been set @ - 15100'. RIH with second HES 3.66" OD CIBP. Set CIBP at 14755' EL_ I ' OOH. Ball recovered. RIH w/ 25ft of 2 7/8" 290PJO guns @ 6 spf. (Run #1) ** *Job Continued on 2/16/11*** 2/16/2011 1 Assist CTU heat upright tank to 125 *F. } • • 2/16/2011 CTU 9, 1.75 ", 0.134 wall CT. Job Scope. GR/CCL, CIBP, Ad -Pert, Acid Stim.: ** *Job continued from 02/15/11** ;Call APE. Town print of tie in log ( Sperry Sun MWD /GR/CCL logged from 12 -APR- 07 to 06- May -07) is a final print. Print available at PBOC is a field copy, there is 1roughly an +8ft difference. APE has given verbal apporval to correct plug setting depth and tie into Final Log copy that was printed out from Anchorage. Cast Iron Bridge Plug is corrected to be set at 14,763 ft center of element (Top of plug is at 14762.2 ft) !Perforate: 14635 - 14660 w/ 2 7/8" PJ Omega (gun #1) Perforate: 14610 - 14635 w/ 2 7/8" PJ Omega (gun #2) ;Perforate: 14585 - 14610 w/ 2 7/8" PJ Omega (gun #3) ** *Continued on 02/17/11*** 2/17/2011 CTU9, 1.75 ", 0.134" wall CT. Job Scope: Ad -Perf, Acid Stim. ** *Job Continued from ;02/16/11*** Perforate: 14560 - 14585 w/ 2 7/8" PJ Omega (gun #4) ;Displace well to NH4CL, diesel underbalance. Prepare to pump acid stimulation. ** *Continued on 2/18/11 * ** 1 1 E j i., 2/18/2011, CTU 9, 1.75" CT, 0.134" wall; Acid Treatment ** *Continued from 2/17/11 WSR * ** i RIH and tag CIBP, correct counter to 14762.2 ELMD. POOH to top of perfs 14660' ELMD. Jet Stage #1 of 12% HCL and 9:1 Mud acid to 14626' ELMD. POOH while ;jetting to 14593' ELMD for Stage #2 of 12% HCL and 9:1 Mud acid. POOH while ;jetting to 145603' ELMD for Stage #3 of 12% HCL and 9:1 Mud acid. Postflush and ;Displace from 14560' to 14660' ELMD with 3% NH4CI +F -103 and 3% NH4CI +F- 1 103 +U067 respectively. Performed post -acid injectivity down coil: WHP= 1088psi @ 31.5bpm. WHP =1100 psi @ 2bpm. WHP =1156 psi @ 1.5bpm. WHP= 1000 psi @ 1 1 bpm. WHP =1141 psi @ 2bpm. FP CT. POOH. RDMO. ` ** *Job Complete * ** FLUIDS PUMPED BBLS 566 McOH 440 3% NH4C1 + F -103 105 3% NH4C1 + F -103 + U067 356 1% KCL 180 FRESH WATER 237 DIESEL 1884 TOTAL TREE= 4- 1/16" CM/ • SAFETY : WELL REQUIRESA SSSVWHEN ON WELLHEAD 13 -5/8' FMC ACTUATOR =‘ BAKER KB. ELEV = 5 09- . 1 O�_ 5A ML WELL GLE >70° @10375'. BF.ELEV= I KOP = �. 2750' Max Angle = 96" @ 10689' Datum MD = 10395' ' , 1 1998' 1- 14 -1/2" HES X NIP, ID = 3.813" I Datum TV D = 8800' SS 1� 9 518" HES ES CEMENTER 120" CONDUCTOR, 94 #, H -40, ID = 19.124" H 100' 2400' 119 -518" FOCI 19 -5/8" CSG, 40 #, L -80 TC-11, ID = 8.835" H 2293' 1 2523' 1 FOC 1 1 13 -3/8" CSG, 72 #, N -80 BTC, ID = 12.347" 1 - 1 2730' 1 4 7304' 1 - 9 -5/8" X 7" BKR C-2 ZXP LTP 1 TOP OF 7" LNR H 7304' 1 w/ 11.6' TIEBACK SLV, ID = 6.32" 7322' H9 -5/8" X 7" BKR HMC LNR HGR, ID = 6.35" 1 Minimum ID = 3.725" @ 9908' 4 -1/2" HES XN NIPPLE 8 -1/2" MILLOUT WINDOW (09 -15A) 7479' - 7492' 19 -5/8" WHIPSTOCK (04/14/07) H 7480' 1 19-5/8" EZSV (TAGGED 04/13/07) 1 7501' 9842' 1-14-1/2" HES X NIP, ID = 3.813" 1 9863' 1 X 4 -1/2" BKR S -3 PKR, ► ID = 3.875" _. _ ' 1 4. 4 .18 . 3 1 ' 9887 - 14 -1/2" HES X NIP, ID = 3.813" 1 ♦ 11111 .. A . • • 1 •1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ■ 9908' H4-1/2" HES XN NIP, ID = 3.725" 1 1 1 / 1 / 1 / 1 / 1 / 1 1 11 1 1 1 1 1 4 1111111111 11111111114 1 1 1 / 9914' 1--j 7" X 5" BKR HRD 1�11111�1�111�1�111�1 ZXP LTP, ID = 4.410" 1 9 - 5/8" CSG, 47 #, N - 80 BTC, ID = 8.681" 1 - J 10028' 7 v4 E 9920' 1 WLEG, ID = 3.958" I r 9936' J - 7" X 5" BKR FLEX LOCK 14 -1/2" TBG, 12.6 #, L -80 TCII, .0152 bpf, ID = 3.958" I - 1 9920' LNR HGR, ID = 4.420" 9946' 1 - 5" X 4 -1/2" XO, ID = 3.940" 1 17" LNR, 26 #, L -80 BTC -M, .0383 bpf, ID = 6.276" H 10070' 1-- PERFORATION SUMMARY 12278' H5 - 3/4" SWELL PKR, ID = 3.958" 1 REF LOG: MWD / GR ON 05/04/07 ANGLE AT TOP PERF: 91° @ 15030' : .:• 12974' H5-3/4" SWELL PKR ID = 3.958" I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE C 6r p 13750' H5 -3/4" SWELL PKR, ID = 3.958" 1 2 -7/8" 6 15030 - 15055 O 08/01/09 ASS _ 14321' H5-3/4" SWELL PKR, ID = 3.958" 1 2 -7/8" 6 15055 - 15080 O 08/01/09 .. - �'� „� i � , 2 -7/8" 6 15080 - 15105 0 08/01/09 • 11111 14852' 1--15 - 314" SWELL PKR, ID = 3.958" 1 2 -7/8" 6 15105 - 15130 O 08/01 /09 2 -7/8" 6 15350 - 15400 C 10/10/08 1 15230' H4 -1/2" WFD CIBP (07/31/09) 1 2 -7/8" 6 15450 - 15500 C 10/09/08 ' =' 15298' I- -3/4 " SWELL PKR, ID = 3.958" 1 2 -7/8" 6 15550 - 15650 C 05/07/07 ' 1PBTD1 - 15731' **** ** 14 -1/2" LNR, 12.6 #, L -80 IBT -M, .0152 bpf, ID = 3.958" 1-1 15818' 1,-•-• DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/018/77 ROWAN 34 INITIAL COMPLETION 10/13/08 GLM/PJC PERFS (10/10/08) WELL: 09 -15A 10/06/87 PAA 102 RWO 06/28/09 PJP/TLH MIN ID CORRECTION PERMIT No: P 070220 05/09/07 N2ES SIDETRACK (09 -15A) 09/09/09 RMH/TLH CIBP SET /ADPERF (07/31/09) API No: 50- 029 - 20256 -01 02/13/08 PJP /PJC DRLG DRAFT CORRECTIONS 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE SEC 1,1 R15E, 993' FSL & 150' FWL 02/15/08 PJP /PJC DRLG DRAFT CORRECTIONS 03/18/08 PJP /PJC REF LOG PERFS (02/18/08) BP Exploration (Alaska) 0 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, February 11, 2011 TO: Jim Regg Z it t / « P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09 -15A FROM: Bob Noble PRUDHOE BAY UNIT 09 -15A Petroleum Inspector Src: Inspector Reviewed By, P.I. Supry c NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 09 -15A API Well Number: 50- 029 - 20256 -01 -00 Inspector Name: Bob Noble Insp Num: mitRCN110210155615 Permit Number: 207 -022 -0 Inspection Date: 2/10/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well T 09 -15A ' Type Inj. w ` I TVD 1 8534 ' IA 10 4000 - 3970 3970 - P.T.D 2070220' TypeTest SPT Test psi I 4000 - OA 1 0 0 0 0 Interval 4YRTST P/F P - Tubing , 1900 1900 1900 i 1900 J Notes: la f. r7d 4e a 13 3p5� S', =mA1 ,MFR 1 2Ol1 Friday, February 11, 2011 Page 1 of 1 • • KELE 0[.F nILLEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Matt Brown Well Intervention Engineer ta0 7 - 0 2 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09 -15A Sundry Number: 311 -014 Dear Mr. Brown: ED JAN 2 1208 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. S Chair DATED this 21 da of January, 2011. Encl. STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSI• 1 ' �r // APPLICATION FOR SUNDRY APPROVALS 1. ) 20 AAC 25.280 ... 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations p Perforate El - Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate El - Alter Casing ❑ Other: El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 207 -0220 - 3. Address: P.O. Box 196612 Stratigraphic ❑ Service Ei - 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20256- 01 -00. 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ PBU 09 -15A 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028324 - Prudhoe Bay Field / Prudhoe Bay Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15820 - 8734.7 , 15731 - 8736.17 15230 7/31/09 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 94 #Hh-40 SURFACE 110 SURFACE 100 1530 520 Surface 2731 13 -3/8" 72# n -80 SURFACE 2731 SURFACE 2731 5380 2670 Production 7479 9 -5/8" 47# N -80 SURFACE 7479 SURFACE 6890 6870 4760 Liner 2766 7" 26# L -80 7304 10070 6750 8669 7240 5410 Liner 5904 4 -1/2" 12.6# L -80 9914 15818 8567 8735 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# L -80 >URFACI 9920 Packers and SSSV Tvoe: 4 -1/2" BAKER S -3 PKR Packers and SSSV MD and TVD (ft): 9863 8534 5-3/4" SWELL PKR 12278 8813 5 -3/4" SWELL PKR 12974 8801 5 -3/4" SWELL PKR 13750 14321 8783 8763 5 -3/4" SWELL PKR 14852 15298 8753 8738 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El _ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/24/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG Q Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Brown Printed Name :r. . Title Well Intervention Engineer Signature if ; / Phone Date it '' 564 -5874 1/17/2011 Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 1 1 -h i 1 �E . Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: JAN 18 201' Ao Gil Rt Ga$ pus" Cn) issi.n Subsequent Form Required: / Q - yOil ' nCIIIIr if je ^� APPROVED BY I I Approved by , COMMISSIONER THE COMMISSION Date: L (/ J 1 FiBD S JAN 2 O ,Zo t Form 10 -403 Revised 1/2010 R �� l�0 Submit in Duplicate �I LLLrrr / `! 09 -15A 207 -022 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 09 -15A 5/6/07 PER 15,550. 15,650. 8,736.87 8,736.76 09 -15A 10/8/08 PER 15,480. 15,500. 8,736.67 8,736.75 09 -15A 10/9/08 PER 15,450. 15,460. 8,736.53 8,736.58 09 -15A 10/9/08 PER 15,460. 15,480. 8,736.58 8,736.67 09 -15A 10/10/08 PER 15,380. 15,400. 8,736.59 8,736.39 09 -15A 10/10/08 PER 15,360. 15,380. 8,736.98 8,736.59 09 -15A 10/10/08 PER 15,350. 15,360. 8,737.19 8,736.98 09 -15A 7/31/09 BPS 15,230. 15,280. 8,740.32 8,738.8 • 09 -15A 8/1/09 PER 15,055. 15,080. 8,746.85 8,746. 09 -15A 8/1/09 PER 15,080. 15,105. 8,746. 8,745.13 09 -15A 8/1/09 PER 15,105. 15,130. 8,745.13 8,744.22 09 -15A 8/2/09 PER 15,030. 15,055. 8,747.7 8,746.85 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • by • 4111 iii ora To: C. Olsen/T. Norene Date: January 11, 2011 J. Bixby /R. Liddelow From: Kaity Longden, DS 09 Production Engineer Matt Brown, Wells Group Engineer Subject: DS 09 -15Ai CIBP, Add Perf, and Acid Stimulation PBD09WL15 -C Capacity Sustainment Attached is a CT procedure that includes the following steps: 1. S Pull MCX 2. C Set CIBP, Adperf, Mud Acid Stim 3. S Set MCX 4. 0 Put well on water injection Status: WAG injector, injecting 438 BWPD at 1885 psi, 12/27/10 Max Deviation: 95.6 deg @ 10,689' MD Deviation at top perf: 91 deg @ 15,050' BHP: 3350 psi @ 8800' estimated from 2009 pressure map Min. ID: 3.725" @ 9908' MD, 4 -1/2" XN Nipple Last TD tag: 08/02/09: CT acid wash, tag CIBP @ 15229' corrected MD Last Downhole Ops: 08/30/09: Set 4 -1/2" MCX H2S Level: No data - DS 09 is an H2S site Sundry Required Well History: Well 09 -15A was sidetracked in 2007 as a horizontal MI injector. The well path curves around the central pattern injector 4 -09i and is being used to place slugs of MI around the pattern. The strategy is to inject a prescribed volume of MI in the toe of the well and progressively work up hole with other MI cycles. The 4 -1/2" liner was cemented in place with 6 swell packers. The swell packers were run as a safety precaution to ensure isolation between target MI slug intervals. The first two MI cycles have been completed, so the existing perfs will be isolated with a CIBP and new perfs added. The original 100' of perfs were shot in May 2007. Prior to injection, an SCMT was tractored into the hole in June 2007. The tractor job encountered debris from the completion and pushed it downhole. Initial injectivity was low, so a mud acid treatment was pumped in December 2007. A FCO of the liner followed by 100' of adperfs and a mud acid job were performed in October 2008. MI injection started in November 2008 at about 35MMCFD. The well was swapped back • • to water injection in May 2009 and continued on water injection at average rates of 1500bwpd until fall 2009 when work began to swap to MI for the second bulb. In August 2009 the well was plugged with a CIBP set at 15230' MD, perforated in the 27P, and stimulated with mud acid to prepare for the second bulb. The second bulb ended in April 2010 due to problems with MI from CGF. A total of 7.7 BCF of MI was injected, slightly higher than the predicted 5 BCF, due to great results in offset producers. The main beneficiary of MI injection on the second bulb was well 04 -31 which went from making around 1000bopd to 4000bopd due to proximity and placement of the bulb. Although the response only lasted three months, it was big enough to justify another 27P MI slug. MIST well 09 -15Ai is now ready for the third set of perfs and MI slug which will be placed in the 27P. The well currently is on produced water injection at very low rates due to really low water injectivity. The plan forward is to use coil to plug, perforate, and stimulate then fullbore SBG immediately prior to swap. Objective: The objectives of this job are to isolate the current perforations, add 100' of new perfs from 1 o b . 14560' to 14660' and stimulate the perfs with a mud acid job. The mud acid job will use Foam for diversion, with acid pumped in three stages. If you have any questions or comments regarding this procedure, please call: Matt Brown Kaity Longden 564 -5874 (w) 564 -5554 (W) 223 -7072 (c) 360 -6002 (C) 344 -1130 (h) 644 -8299 (H) Cc : Well Files • • Slickline Procedure: 1. Pull MCX. Coil Tubing Procedure: CIBP 1. RU at least 16,000' of 1.75" CT. Rig up hard line to be able to pump down tubing for injectivity test. Check that the well is shut in at lateral and wing valves. Note: 1.75" CT has been able to get to at least 15650' without safelube. 2. RIH with memory GR/CCL /drift for CIBP. Drift to top of CIBP @ 15,229'. Flag pipe. Log tie in pass from 15229' up to 11800'. POOH. Tie- in Note: There is not much character in the GR log. Will need to tie into the HES MWD- GR at a good shale higher up (@ around 11,800'). Do not use the USIT- GR -CCL because it has not been depth shifted back to the open hole GR log. 3. Download memory tool data. Determine depth correction reference to Halliburton MWD log for the well, which was logged 12- Apr -07 to 6- May -07. 4. Displace the well with 345 bbls 3% NH4CI (this is Stage 1 of attached Pump Schedule). MU BHA for CIBP. RIH with CIBP. Correct flag depth and set CIBP at 14760' per PE Manual guidelines. PT CIBP to 2500 psi DP. POOH. 5. RU for perforating. RIH and perforate with 2 -7/8" PowerJet Omega charges, 6 SPF, from 14560' to 14660' MD ref Halliburton MWD log. Do not use 3 -3/8" guns due to concerns about residual fill. 6. Pull above the perforations and perform an injectivity test by pumping down 4 -1/2" tubing @ max pressure of 2000 psi. Note injectivity on WSR. POOH. Acid Stimulation 7. RIH CT with a 2" — 2 1/4" jet swirl nozzle (Note: Min ID = 3.725" © 9908'). Pump fluids per attached Pump Schedule. If needed to establish injection, go to 3000 psi WHP, but drop immediately to 2000 psi WHP as to not frac the well during the acid wash. When acid is on the perfs, max WHP should be 2000 psi. Before POOH complete the overflush to ensure acid has been pushed away. 8. Do an injectivity test post acid stim down the backside. Establish a stabilized rate and pressure to make certain of positive injection. POOH. Slickline Procedure: 9. Run MCX. RDMO Operations 10. Turn well over to the DSO to put on produced water injection. 1 . . . • VIM • 4-1/16 I , 13-69 fAFETY /CMS: WELL ANCILE3. 70'42 10375' I Y411.1-EA (3 RAC ACIAJA7CR 71------- 09-1 5A 14 F3F aE' • I I fop . 2750 Mu Angle- • 96' @ 10689 D • I 1 199W H4-1/7 I X PIP 13 • 3213 I Calurn N 10399 1 teis■ , - - 6115 - 9 S13 i ID I 2279' H9-5/17 KM D3 CENENtER 1 120 0314XICTER, 918, 1+40, • • 19 124" H 100 2400' 9-518 FOC 19-98 10 1 , L-so TC-11, 13 • 8.835' h 2293* 2S 9-581" FCC I 13-3nr csG, 721, N-80 eic, 13 • 12347- H 273� nor 119-5.6- x r ERR C-2 ZXPL7P 170P OF r L/44 H 7304' 1 vv.! ii 0 TIEBACK SLV, D • 6.32" 732X 1-19-ra'• x r sot MC LNR FGR, 10 • 635' 1 I Minimum ID = 3.725" @ 99081 4-1/2" HES XN NIPPLE 1 b- 117 IALLOUT WROCAV (09. UN 7479' - 7437 I 19-5113'984P311301t (04J14/70) _hi 7418' 1 984r j-Ltt2- 11•3 X HP, 13 • law 19-500'15313V (TAGGED 0103/07) H 7911' 1 3.11 1 11/1/ Ir X 4- VT WV B-3 %WM ID • 3875" rrnilligh1.4•40 i t e tttly IQ 11.4 I #1411 pi 9117' 11 RP ES X , 1) • 13 IHM11.4 0.1•010 willill lq$04,4141•0441 4 1 . 1.1.4**04 , 41 .S*014.00,04 990r H.--Irr He; )2/111P, • • 3,225 I *1•444.1■44 11114.4,41.444 4 1411 , 0“1416. 0.011.$4.41.001 +41114110•00 /I 9914' F 7" X 5'131IP PM 0•101.01.0111 *000)44••• OAMAt....21.0 DtPLTP, 13.4 A10' . . . . . . . . . . 9-518 CSG, 478, 11-80 BTC, D • 81581' H loo2r "1".17■"■•■•■•■•■■•■•■ • • 992W 4-117 VALEG, 13 • 3.958' Iri l' 913W r x 5' SKR FLOC LOCK 14-12" 1BG, 12.51, L-80 'ICA D152 bpi, D • 3 958- H enr L.NRIGR, 13 420 1018 I 5 X 4- 11 X0 ID• 3980" 17' LW 266, 1-80 BTGAI, .0383 brit, 11) • 6276 H 10070 1227W swILLFKR 13 al 3.95s f RPFCRAT1ON SOMMARY .'.:.• •:. REF LOG: WAD/ CR 01405101MA ANGLE AT TCPPERP. 91' 0) 150:30' -:- ,.:, 17974' 1 61143JL FKR 0 • 325r ( Pt•to Refer to Production DB for NaloStal pert &La SIZE SPF IMERVAL OfINSqz GATE 11/4/44.) •:. ,, 1379y H 54, %sex Ftuk 0 a 3.958" 1 2-713' 6 15030 - 15055 0 (mime C-1 BP .., taw I-15.314 w" FKR 13* 33358' i 2-7fir 6 15055 - 15080 0 08/01439 s 's.............. ) , :. - IP-- 2-71( 6 15080 - 15105 0 084)109 -:• .-., law H 5. Ir MR31 PIM II • 3.968' f 2-71(' 6 15105-15130 0 08131039 ,,,—. - 2-718" 6 15350- 15400 C 10/10438 ....- I law H4_117 %WO CEP(W/31/091 2-718" 6 15450 - 15500 C 100394)8 ':' . 1922W H5-34" SWELL PIN; ID • 39ST ( 2-70' 6 15550 - 15650 C 05074)7 1 FigrD 15731' I , *4 4 le 4 14-10'1143 1264,1-03 137-114 0152 bpi, 13 • 38 1511, ■••• DATE REV BY COMENTS DATE REV BY 0138111134TS (R.831-13E BAY U1411 (W018177 )WAN 34 INTIAL C0MIPLET1C1/4 1013/08 GUSPJC PEWS (10/1308) WELL 09-15A 108311117 PAA 102 RNO 06128109 PJF111.11 WI ICI 03FRELTEN PERNFT Na 2070220 0500017 NM 110ETRACK ((0 54) 09109/09 RIAIVTLH CRP SET/AOFERF (07014)9) API Not 50-029-20256-91 02/1108 P.64 CFILG CRAFT CORRECIDN3 SEC 1, 71014, R15E. gar FS_ & 150' FWL 02/1508 PJAPJC ONG CRAFT CCRRECTD0413 03718138 PJPIPJC FEf LOG FERFS (02103E9 BP Dtploradon (A)aska) . • Fluids: Stage Fluid Type _ Vol gallons Load & Overflush 3% NH4CI + F103 460 bbls 19320 Cap Diesel 115 bbls 4830 Spacer 3% NH4CI + F103 + U067 105 bbls 4410 Acid 12% HCI 75 bbls 3150 Mud Acid 9:1 Mud Acid 75 bbls 3150 Foam Liquid 3% NH4CI + F103 10 bbls 416 Foam N2 N2 30,431 ft3 327 Acid Additives 12% 9/1 mud tot tot Loading for: HCI acid chemical chemical Product in Mud Code: Function: Units: per Mgal per Mgal in HCI acid A264 ACI gal /Mgal _ 6 6 19 gal 19 gal A201 Inhibitor Aid gal /Mgal 15 15 47 gal 47 gal F103 Flowback aid gal /Mgal 2 2 6 gal 6 gal L058 Iron Control lb/Mgal 20 20 63 Ibs 63 Ibs W054 Antiemulsifier gal /Mgal 5 5 16 gal 16 gal U067 Mutual Solvent gal /Mgal _ 0 50 0 gal 158 gal H2S A255 Scavenger * gal /Mgal 2 2 6 gal 6 gal Spacer & Overflush Additives tot tot Loading for: Overflush Spacer chemical chemical Product in Code: Function: Units: per Mgal per Mgal Overflush in Spacer F103 Flowback aid gal /Mgal _ 2 2 6 gal 6 gal U067 Mutual Solvent gal /Mgal 0 50 0 gal 158 gal Diverter Additives Loading for: Diverter tot chemical Product Code: Function: Units: per Mgal in Diverter F103 Flowback aid gal /Mgal 2 1 gal 9 0 Ii 0 §IV Z i it iI 0 ii II li 1 Oil 11 1 0 il fi 11 . ' " , : Ug g gig F(ggig in in r r 21 0 ili i . 40 3 o . pi 3I! 1,2 en 12 r r i2 En e+ aD i— r- '- g s;31 cm§@§@,-;,,,Agegg?,§§ g g 19 gi E 0 1iI 1 C3C3 © CD ©©4141 <3°° °a°° ° °a 0. 5 i ll il li g v . 1'1 Fl R 0 Fi 1'1 Fl R 41 i4 VI V1 63 K1 VI W th t au i t M ;; ;a t V t i.i ca t t t 0 es gi ii 8 E � 8 ,,,,c 8 a 888 t t t i k t t f t f C A diA ls� fA t 4 Al ts ;AAA I ,,,, A __, S3 * 8 11 4s 5 _1 11 a 1 •- Pit {q o In O4 t OD C* ca .= CA p;= V2 V2 a ca Ca • • X j HALLISURTON ROP Rate Of Penetration DGR Dual Gamma Ray EWR- Phase 4 I S'TE Horizontal Presents on nr 1 1 : 600 / 1 : 240 I Sperry Drilling Services � Company : BP Exploration (Alaska) Inc. Rig : Nabors 2ES Well : 09 -15A 1 Field : Prudhoe Bay Unit g 4 4 ;.t Country : United States 2 s e API Number : 50 -029- 20256 -01 Latitude : 70° 14' 43.38" North Other Servlaes Longitude :148° 14 4.35 West PWD DOS A81 cg AK State Plane X = 718,541.52 ft NAD 27 .J AK State Plane Y = 5,842,466.30 ft NAD 27 Permanent Datum : Mean Sea Level Elevation : 0.00 ft Bev, KB Log Measured From : Drill Floor 48.50 ft Above Permanent Datum DF 48.50 ft GL DrigMeasured iyg Measured From :Drill Floor MD LOG I 20.1 ft I Depth Logged : 7,480.00 ft To 15,820.00 ft Unit No. : 116 Job No. :AK - MW 00ase l2 7 Date Logged : 12-Apr -07 To 08OMay07 Totat Depth MD : 16,820,00 ft TVD; 8.734.65 ft Plot Type : Final Spud Date : 12- Apr-07 Plot Date : 17- Sep-08 Borehole Read , : 1 , .a Racoon Run No. St7n From To Run No. Sine From To ,11� .4 1i1. x .1.1. is : . e� N ll Ill � ,7 Ls i � 111 i •zfACi}I7t 1 1 JiI 4 i19h1'1']tCILIIIIItV• V. 1.. ;777Wit 5 +, :3.00 R Weis rom To • • 11700 Mil II�IIIIIIIIII�!R9",� 1111111111111111111111111111.111111 -- i 11111111ier=11111111111 ...„, WI, w ow s'� IT , _. II�IIIIII� allill IIWIIIIIIIIII ,I w al . am mar. i im i e - MI ., 11104111111111. ININIIIIIINNMomMINI NNW I EL •-• NI NMININNIIMUININNIMININN f ' MO 111111111 111111111 - - MEM ' I i MI f , i 1.111W41111111111.111 .. MP ~ 1111111111111111111 i NI ' MI . • air . IIE INIMMILMMINIIMINIMIMMIIIINIMI IMI ' _, „. is I - ME i I 1 . • ,4 MIIIIIIIIIIIIIMMEMEMI I L.. .r IM, �. �� _;,.,4 , _ NW= ' Tie in to shale gamma signature at 11800 1 11794 MD as seen in this scanned copy of the reference log. 1 i �i LI r �— a . � mlt a 1 wpr,IllNalilimilimillimill:dimij'lllmillimillir:""";"Ill , 1 . , im me at 1 anummulemmen 1 I MIS MIMI= 0111 NI f _ter NN ItIIImmoY �� , , �' = am .-- -"ImmisiMlin moire... , , MI 111111111111= ' MI MI i El y .._•- ' ME 110111.111.1.11.1111111 MI * . y . t 1. Is f EN _.. .. - t 4 , - t,..,- Mil 11900 IM ID F • • 14400 m11111 mi111111 111111��l111111 - :.- ■i1 M im�i111111 �11I111imi 1 1 1 ■ ii Iii r iu111 EM111111 1IIMI III `1 111TH MMIIUII 11111I� It MMIIIIMIIMthIllTh 11111111111111111111111111111111111111111111111111111111111 .::. •1I11111 - Vd11111i11111111U11111 ■1111111 M a' ■ ■111111 ®1, I111111�11>11 m®111111� ,_...1•- 1111111 �[ I111111 i1O II �uII �IIII OM ■ �M11IIii 111/11111 11 �.I1111II •�11111i �' 111111■■ �- 11111�Iu1I111No a m 1 4500 1111111111111111111111111111Mminnumummim 11M1111111 1111E1 •u111111 I� 01111111M I1MIIIIMI ■11111[ / M/ i 1M•II Il� 111411111111IIIIIIIIIIIMI •i1111i 1111MMh U IIIIIIMII11111111111 Nf1111 MINI IIII11tU•IIIII IMEM111111 IIMSIIMNIIIIIIIE 95( ' ■[111111 X1 111111.1 I II1-r11111111� ■111111 i1 111111�1■ 1111�R■11111I� "MUM "MUM 4 �11111 III 1m•111111ii- III �1 ■1111r ■�11111in. oros.im �+ esoo I�1mo Proposed adperf depths 14560'- ■i1111i 11!! o ■E1 11 it 14660 MD a on the X111 X1111111 reference log MUM 11 ' R R ■111111 tiaa .u .....iR1111111 � p mm111111� 111111I� �111 Bk „ ■■11111imPd1i. i •I111111�N .- . ■u11111 i1I11!!UI ■s111111��u111i11 vi ■ 11111i1�i -milli uu1111ii�•11111ii1 .. ■I111111� /i■11IJIII NI111111�UIIIIIII •■1111II Iiu11 ■ ■111111 ®UU1111i i. woo ■a11111i�rJu11 .t ■■111111IIII•I11II11OM MILIMIIIIIIIII 1 -• .. 111111MItIU1 1 ■■111111�UU11111I� ,� ■IIII NUE ,, u _11 11 I i _. ■u111111�Mu11 . ■ IIII�l i 11 UI111111MI •1111 I� • N 11111�L' . 11IIi U1111111 ■11M I- ■111111�L'llIiiilM�N11111i U /IIIII� irramm :. - •111111[1 ' IM1__UI111111 111111- mummm :' ""''" manuuilA 11 1 �_UH1111 rummin EN ai11 Proposed CIBP depth @ 14760' MD 11111111111111 .1111111MIIIIIIIMINI MIL 11111111111111. iiIiiii!iiiiiii111i1111u1i1 111 Mill 100 ■•111111 i '1111IIMr 111 MMIII11 � . IBM ■131111iM� i Illi ®M■111[1 mum nil ::, MU11111I IMMUMIMMIUM11111111111111 MI •1111111 1111PAIIIIIMMUMIMIIMMIIMUI IN mui11111 EMU" um ` R ., MI • E x i s ti ng swell packer @ 14852 MD X111111 uriniommemai Swett iminn I. Fetkrf , •Im � immuu1 �UuuumIMMl1I11 INIMIIIIIIammeal ti � 9 5 Z Nom H o ma, d ■u1111II �< 1L .1 ■EM In�11 :d11111 E1111111� ■[111 O ` , _ " 14900 .1111 �. f 1PWIM ai11IIII� u.1I1�� .. �11i�su11111 111 MI 1 ■m1111�mi I. 1111�uu1111i1 11 11 EN ■111111 •uulli 1 b 0 PERFORATING PROCEDURE welt: os-1 }. APt t~ 50. -25S t D ata _ ,,.,..... ,.1 . t a 1 J ...,....., P w :: ........ Oif a P<9 ...,......, 584-55Si ..... .......... i.a • L ' 3 nab .,,...,,...• . 1212... ,..,,...,.< . home PCI: ,....,. ,,.,. .,. a., . ................ No gala Ce Cast �g 1;] ' r 3' 902 ;s i+ 2r: = ; s ; ., C „. �l;Page '....,., ..,.,,.................... ....0 ... .. ............................, 1112,.. CCorAFE: AP 1Dt Ally- DR: . WELL Entries Type, Work Da nn= Pron 'CCv Rti°_t?� � ..... . „ R... . . J......... ....... ...... ..................... 2 a.... a ..A....., .. .. A lai q;1P;. il;f � °,';'T•'- •• ,Pv tith a;, �N,'• I. ..•..•.... ..,.... .•..... . ..... ......,.... . 1212, 1112, .................... ..,.....,. `� . . .L . . .n...r ti ...... .� ..,..,,..,...,,......, .,.....,,....,....,,..,,,,,.,,. wp®t7111ectbtes and Perforating Noes: AM IS 3721' ip 11C ]' 8, 4-1.7 6ES XN apple. Angle ad Mht Et- :3O deg . M a x Angie W stars - 92-leg e s 160 MD. A n g l e of to a l =ma P ratio's - 9 f+ 19237 taxi scud slimUalmn. nearly Ma oast acd stmt Attachment: Fte'arer.lco wet, OOeda-715 = J :tCTSOFA Log top Sentence Log atop ;>r d>&`mac- i _ ..._..._......._......_........ tees L , aa 12 12 .. tt tie de-1n lag m beta coo: ' 3' `a'��`"• depth oat the lenience log Depths �haat•to} �� Depth {noettol Feet SPF Mot Phasing Zone AWFb97perf ,. mr: ....,.001 ,1.,.,00401 1101001010 ..,.,. ` . ..... 1.......0,.,. ..0,,000 ..... 1..., ........... .• 0010.,1 ............. 0.0.,001 ..,,....0,....,..,, .... ...0,.. ,•....•. 2 .1(.21...,... •.0,.,...1., 1,12.........1.......... .....,. .....•,•.... ............. 0..0. . ..... 1.,,, .......10 , .,. 11..• .......,..............,....•..• ...,_.,,.....,..,.,01..,,,..... ,,,,. 1.,. ,...1,..•.,0......,..,..,,.,. Fbenthan0 Gun She: Z7 3.. Charge: 2 =':'7 7 h:%Es;: I s Mordant' eleaese t During Perforating is erasar C... 1.................... 0•.•......................•......... ............. ...•...•.•....................» .. P inioned A49aeel of Dtanrtonta$ttgpestllrm9 to labium Onronarn ..............•...... ...............,. ......................•... ...••.,.•...................... ........,...•.............. 0001 Last ink . 1 : 895 lan1WHIP 431 _..... EOM !'Era bcm CT acid wash t 15229 ft AS) 00 1 Est Flea. Pies. @ SS 110 is 3350 pa 'WWI rselass ttsl Perforation SuMillaff Swami 0151 Wei: —13A :0Nt Das: API t: a 2w I PRIt Eno: ....... rch Poi E(17 ., ,,. .... .............01. , ....12 e . .....u........,.,.....,........ Pm. center PBZtf ,...,,..,.,. •............•.......,•. eeee.al Consents: ......................................................•. ..... ..... ......... ....... ...• ....... ........•......... ..•..,.......•................∎ ...., ........ 0..00 .......... 4.. ._..._ ............._..._..._..._..._..._..._..._.........._..__..._......._..._... ...._..._......._.._..._..._... _..........._..._..._..._..._..._..._......_..._..._..._..._..._....... ........_..._......_..._....... _1212._. Depths Balance Relete col in BIfZS Gen Dia Ghent SPF Phasing Zone Ai perLingerf 0; 3l ti ., ,..... ..,. ........................... . ......,.,..,..•................ ..................................•... ...., ,.............. . ............,.. ................., 1121,.. ,. . , Dr3 :4! - D; 3 U 1211,,. .. ......, ,,..,......•... . ....,... ....................... .. ...... . ...................,.,......... 0 .' 3. U 0 1212,... .......,,,.,,0 ............... .................... ..... ...... .......,. ........ ..... ...... .........,..,,.,..., , .,.,..•.,.•.•..,..,......,0,.,. ......... .,. .....,...•.,......1.0....... o, u - Ot $f'J 1121,.... .,..:,... ........ ...... ............................... . ..,..,.,.....,...............•. ,..... ...... ...........,. ..... .. ...... .. 0 . ` 3 lJ ...,. ..,...11.....00.. ..... ...,.,.,. ........•4..110....• ..1..1 ,.1., ..... ........ ..................... ..... "tat ..0010..•.,....•.......,....•. ,........ .....,,0..,.,1...,,.., a: a: U .. ...... ...........:................... 1.................., ........ ............................... .................,.............. ................................ ....... . 0, 11U • ~~ .~ _- ~.. .. <~ ~ ~~/,~ x r:.g. _.,bV w ~~ ~y 11 MICROFILMED .6/30/2010 DO NAT PLACE ANY. NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfitm_Marker.doc STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMM~ON REPORT OF SUNDRY WELL OPERATIONS ~..~@F~~~~ ~.. '/.~IY• ~v~ ~-~~~~7 a ~ ~~Q~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations Q Stimulate0 ~ p~~~ s~, ~-~ „~ ~~~~ ~*i~mrrs~ ;3~ ~ . ~~ ; > . Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ Perforate 0 Re-enter Suspended Well ~~~~`~`~r~~w 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: rvame: De~elopment I~ Exploratory ~ 20~-0220 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage,AK 99519-6612 50-029-20256-01-00 7. KB Elevation (ft): 9. Well Name and Number: 48.5 KB PBU 09-15A 8. Property Designation: 10. Fieid/Pool(s): ADLO-028324 Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: V Total Depth measured 15820 feet Plugs (measured) 15230 CIBP 7/31/09 true vertical 8734.7 feet Junk (measured) None Effective Depth measured 15731 feet true vertical 8736.17 feet Casing Length Size MD ND Burst Coliapse Conductor 80 20" 94# h-40 Surface - 100 Surface - 100 1530 520 Surface 2731 13-3/8" 72# N-80 Surface - 2731 Surface - 2731 5380 2670 Production 7479 9-5/8" 47# N-80 Surface - 7479 Surface - 6890 6870 4760 Liner 2766 7" 26# L-80 7304 - 10070 6750 - 8669 7240 5410 Liner 5904 4-1/2" 12.6# L-80 9914 - 15818 8567 - 8735 8430 7500 Le~'G~~Y ' !-~y k `K~' j ~~~v Of i V~ 4 i r ~ .,,, . r ~.w pe _ J Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 9920' ~ T~1 ~c S wc~ 1~ 0 0 Packers and SSSV (type and measured depth) 4-1/2" BAKER S-3 PKR 9863' ~ 0.t~~~ eQ`r 5-3/4" SWELL PKR 12278 12974 13750 14321 14852 15298 ~ 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to weli operation: 997 752 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory T~ De~elopment ~'" Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG ~; GINJ ~ WINJ ~ WDSP~ ~ 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: 309-204 Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 8/6/2009 Form 10-404 t~evised 04/2006 ?~.r~~~e~~ r,~e ~. ~ .s. r. , cstu,~ )!P ~ ~ ~ Submit Original Only ~l~j ~~;w~ r`.~`'r , r 09-15A 207-022 PERF ~4TTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 09-15A 5/6/07 PER 15,550. 15,650. 8,736.87 8,736.76 09-15A 10/8/08 PER 15,480. 15,500. 8,736.67 8,736.75 09-15A 10/9/08 PER 15,450. 15,460. 8,736.53 8,736.58 09-15A 10/9/08 PER 15,460. 15,480. 8,736.58 8,736.67 09-15A 10/10/08 PER `~ 15,380. 15,400. 8,736.59 8,736.39 09-15A 10/10/08 PER 15,360. 15,380. 8,736.98 8,736.59 09-15A 10/10/08 PER 15,350. 15,360. 8,737.19 8,736.98 09-15A 7/31/09 BPS 15,230. 15,280. 8,740.32 8,738.8 09-15A 8/1/09 PER 15,055. 15,080. 8,746.85 8,746. 09-15A 8/1/09 PER 15,080. 15,105. 8,746. 8,745.13 09-15A 8/1/09 PER 15,105. 15,130. 8,745.13 8,744.22 09-15A 8/2/09 PER 15,030. 15,055. 8,747.7 8,746.85 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRQDDLE PQCK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE . • ~ 09-15A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY BBLS 374 2% KCL ~ 140 DIESEL 395 3% NH4C1 75 12% HCL 1 50/50 METH 75 MUD ACID 1060 Total • n _ ~ ~ ~ `'~ 4 s ~ ~ ~ , ~ ~~; ~~~ SARAH PALIN, GOVERNOR ~a.- ~ 1~ ~~+ ^^_~ ~ ta~tr~ taL[~SBA OiiJ ~ ~ ~~ 333 W. 7th AVENUE, SUITE 100 CO1~T5~RQA'i`IOI~T COMI~IISSIOIQ ANCHORAGE, ALASKA 99501-3539 i~ PHONE (907) 279-1433 ! FAX (907) 276-7542 Matt Brown Well Intervention Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU 09-15A Sundry Number: 309-204 °4 Dear Mr. Brown: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of June, 2009 Encl. (~ STATE OF ALASKA .,_ "' •~~ ALAS IL AND GAS CONSERVATION COMMIS N , , 6-/~~ ~ 09 ~~'~ APPL~TION FOR SUNDRY APPRO~LS `~~~~ " ~' f' ' ~ ~n nn~ ~~ gun ,~,__. !~J ~~~'1 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ PertQte- Wai er ~°' ~tn~Y *~ Alter casing ^ Repair well ^ Plug Perforations ^~ ~ Stirr~te- Time Extens~r t~~{•' Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 207-0220 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-20256-01-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ PBU 09-15A - 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADLO-028324 0 48.5 KB PRUDHOE BAY Field / PRUDHOE BAY Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15820 - 8734.7 - 15731. 8736.17 - NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 Surface 100 Surface 100 1530 520 Surface 2731 13-3/8" 72# N-80 Surface 2731 Surface 2731 5380 2670 Production 7479 9-5/8" 47# N-80 Surface 7479 Surface 6890 6870 4760 Liner 2766 7"26# L-80 7304 10070 6750 8669 7240 5410 Liner 5904 4-1/2" 12.6# L-80 9914 15818 8567 8735 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2' 12.6# L-80 SURFACE - 9920' Packers and SSSV Type: 4-1/2" bkr s-3 pkr Packers and SSSV MD (ft): 9863' 5-3/4" swell pkr 12278 12974 13750 14321 14852 15298 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ~ ' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 6125!2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~' GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Brown Printed Name ATT B WN Title Well Intervention Engineer Signature Phone Date 564-5874 6/11/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness ~ Sundry Number: Plug Integrity ^ BOP Test ^ Mechanica l Integrity Test ^ Location Clearance ^ - Other: 3~OQ(~gt~ ~~r\~--\vd`-~..~~ ~_~~~ ~S`~ Subsequent Fonn Required: yv~,,,` APPROVED BY / l Approved by: COMMISSIONER THE COMMISSION f Date: Cp r ~ Form 10-403 Revised 06/2006 ~` ~~~~~~ GRIGINAL ~s Submit in Duplicate 09-15A 207-022 PERF OTTOrNMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth To Tvd Depth Bas 09-15A 5/6/07 PER 15,550. 15,650. 8,736.87 . 8,736.76 09-15A 10/8/08 PER 15,480. 15,500. 8,736.67 8,736.75 09-15A 10/9/08 PER 15,450. 15,460. 8,736.53 8,736.58 09-15A 10/9/08 PER 15,460. 15,480. 8,736.58 8,736.67 09-15A 10/10/08 PER 15,350. 15,360. 8,737.19 8,736.98 09-15A 10/10/08 PER 15,360. 15,380. 8,736.98 8,736.59 09-15A 10/10/08 PER 15,380. 15,400. 8,736.59 8,736.39 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVE SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • b ~ ~ p ~~s ~~~ ~,~'~/~ To: Jerry Bixby/Clark Olsen Date: May 27, 2009 Well Operations Supervisor From: Patti Phillips, DS 09 Production Engineer Matt Brown, Wells Engineer Subject: DS 09-15Ai CIBP, Ad Perf and Acid Stimulation Est. Cost: $300M PBD09WL15-C Capacity Sustainment IOR: 600 Attached is a CT procedure that includes the following steps: 1. S Pull MCX 2. C Set CIBP, Perf 15030-15130, Mud Acid Stim 3. S Set MCX 4. O Put well on water injection Status: WAG injector, injecting 1378 BWPD at 1538 psi, 6/1/09 Max Deviation: 95.6 deg @ 10,689' MD Deviation at top pert: 90 deg @ 15,550' BHP: 3280 psi @ 8800', 180 F average for DS09 Min. ID: 3.725" @ 9908' MD, 4-1/2" XN Nipple Last TD tag: CT acid wash down to 15650' but did not tag Last Downhole Ops: 10/18/08 Drift/brush SSSV nipple H2S Level: No data - DS 09 is an H2S site Well History: Well 09-15A was sidetracked in 2007 as a horizontal MI injector. The well path curves around the central pattern injector 4-09i and is being used to place slugs of MI around the pattern. The strategy is to inject a prescribed volume of MI in the toe of the well and progressively work up hole with other MI cycles. The 4-1/2" liner was cemented in place with 6 swell packers. The swell packers were run as a safety precaution to ensure isolation between target MI slug intervals._The first MI cycle has been completed so th Pxi~tincr nom---" __ will hP immolated with a CIBP and new perfs added._ The original 100' of perfs were shot in 5/07. Prior to injection, an SCMT was tractored into the hole in 6/07. The tractor job encountered debris from the completion and pushed it downhole. Initial infectivity was low, so a mud acid treatment was pumped in 12/07. A FCO of the liner followed by 100' of adperfs and a mud acid job were performed in 10/08. MI injection started in 11/08 at about 35MMCFD. The well was swapped to water injection in 1/9 • C~ 5/09 and is ready for its next MI cycle once the old perfs are isolated and the new perfs added. Objective: The objectives of this job are to isolate the current perforations, add 100' of new perfs from 15030' to 15130' and stimulate the perfs with a mud acid job. The mud acid job will use Foam for diversion, with acid pumped in three stages. Mutual solvent is included in the Preflush and Postflush stages. If you have any questions or comments regarding this procedure, please call: Matt Brown Patti Philli s 564-5874 w) 564-4578 W 223-7072 c 240-3742 C) 344-1130 (h) 346-1755 (H) Cc :Well Files Attachments: Wellbore Schematic Acid Pump Schedule Minilog Tie in Log Strip with Aperf ints Injection Plot 2/9 n ~~ Slickline 1. Pull MCX. Coil Tubing Procedure: CIBP 1. RU at least 16,000' of 1.75" CT. Rig up hard line to be able to pump down tubing for injectivity test. Check that the well is shut in at lateral and wing valves. Note: 1.75" CT has been able to get to at least 15650' without safelube. 2. RIH with memory GR/CCL/drift for CIBP. Drift to15300'. Flag pipe. Log tie in pass from 15300' up to 11800'. POOH. Tie- in Note: There is not much character in the GR log. Will need to tie into the HES MWD- GR at a good shale higher up (C 11,800'). Do not use the USIT-GR-CCL because it has not been depth shifted back to the open hole GR log. 3. Download memory tool data. Determine depth correction reference to Halliburton MWD log for the well, which was logged 12-Apr-07 to 6-May-07. 4. Displace the well with 345 bbls 3% NH4C1 (this is Stage 1 of attached Pump Schedule). MU BHA for CIBP. RIH with CIBP. Correct flag depth and set CIBP at 15230' per PE Manual guidelines. PT CIBP to 2500 psi DP. POOH. 5. RU for perforating. RIH and perforate with 2-7/8" PowerJet charges, 6 SPF, from 15,030' to 15130' MD ref Halliburton MWD log. Do not use 3-3/8" guns due to concerns about residual fill. 6. Pull above the perforations and perform an injectivity test by pumping down 4-1/2" tubing C max rate of 2000 psi. Note injectivity on WSR. POOH. Acid Stimulation 7. RIH CT with a 2" - 2 1/4" jet swirl nozzle (Note: Min ID = 3.725" @ 9008'). Pump fluids per attached Pump Schedule. If needed to establish injection, go to 3000 psi WHP, but drop immediately to 2000 psi WHP as to not frac the well during the acid wash. When acid is on the perfs, max WHP should be 2000 psi. Before POOH complete the overflush to ensure acid has been pushed away. 8. Do an injectivity test post acid stim down the backside. Establish a stabilized rate and pressure to make certain of positive injection. POOH. 3/9 n U Slickline Rum MCX. RDMO • Operations 10. Turn well over to the DSO to put on produced water injection. 4/9 • • TREE= 4-1116" CI4V ITOPOF7" LNR ~ 7304' F-- Minimum ID = 3.725" @ O8 4-1 J2" HES XN NIPPLE 19-518" EZSV (TAGGED 04!131071 47#, N-80 BTC, ID = 8.681" 10028' 4-112" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" 7" LNR 26#, L-80 BTGM .0383bpf, ID = 6.276" PERFORATION SUMMARY REF LOG: MWD I GR ON 05!04/07 ANGLE AT TOP PERF: 91 ° @ 15350' Note: Refer to Roduction DB for historical pert data SQE SPF INTERVAL OpnlSgz DATE 2-718" 6 15350 - 15400 O 10/10/08 2-718" 6 15450 - 15500 O 10/09/08 2-7/8" 6 15550 - 15650 O 05/07/07 1/2" LNR 12.6#, L-80 IBT-M, .0152 bpf, ID = 199$' '--14-1/2" HES X NIP, ID = 3.813" 2279' 9-5/8" HES ES CEMENTER 2400' 9-5/8" FOC 7304 9-518" X 7" BKR G2 ZXP LTP w! 11.6' TIEBACK SLV, ID = 6.32" 7322' 9-518" X 7" BKR HMC LNR HGR ID = 6.35" 8-1/2" MILLOIfi WINDOW (09-15A) 7479` - 7492' DATE REV BY COMihABdTS DATE REV BY OOMMBJTS 09/018/7 ROWAN 34 INITIAL COMPLETION 10/13!08 GLM/PJC PERFS (10/10/08) 10/06/87 PAA 102 RWO 05/09107 N2E3 SIDETRACK 09-15A 02/13!08 PJPYPJC DRLG DRAFT CORRECTION 02/15108 PJFiPJC DRLG DRAFT CORRECTION 03!18/08 PJP/PJC REF LOG PERFS (02/18/08) 4-1 /2" HES X NIP, ID = 3.813" I 7" X 4-912" BKR S-3 PKR ID = 3.875" 4-112" HES X NIP. ID = 3.813" 99Q$' H4-1/2" HESXN NIP, ID= 3.725" I 9914' 7" X 5" BKR HRD ZXP LTP, ID = 4.410" 9920' 4-112" W LEG. ID = 3.958" 9g36' 7" X 5" BKR FLEX LOCK LNRHGR ID=4.420" 9g4$' 5" X 4-1 /2" XO, !D = 3.940" 12278' 5-314" SWELL PKR ID = 3.958" 12974 5-314" SWELL PKR, ID = 3.958" 13750' S-3/4" SWELL PKR, ID = 3.958" 14321' 5-3/4"SWELL PKR ID = 3.958" 14852' 5-314"SWELL PICK, ID = 3.958" 15298' S-314" SWELL PKR, ID = 3.958" PRUDHOEBAY UNIT WELL: 09-15A ~--~ PERNAT Na: a1070220 API No: 50-029-20256-01 SEC 1, T10N, R15E, 993' FSL & 150' FWL BP 6cploration (Alaska) O ~ -15 ~ SAFETY NOTES: WELL ANGLE> 70° c~ 10375' 5/9 19-5!$" CSG, 40#, L-80 TC-11, ID = 8.835" I-I 229$' I' 13-318" CSG. 72#, N-80 BTC, ID = 12.347" 2730' 09-15A Pump Schedule Stage Description Fluid Fluid Stage Stage Stage Cum Stage Stage Stage Stage Cum Start End Run Cum Path Fluid BH Inj Fluid Fluid Pump Foam N2 N2 N2 Depth Depth Speed Pump Vol Rate Rate Vol Time Vol Rate Vol Vol Time bbl b m b m bbl min bbls scf/m scf scf ft ft f m min 1 Flukl Swap 3% NH4C1+ F103 Both 345 4.0 4.0 345 86 - - 0 86 2 DieselCap Diesel Backside 115 4.0 4.0 490 29 - - 0 115 3 Preflush 3% NH4C1+ F103 + U067 CT 40 1.0 1.0 530 40 - - 15130 15100 1 155 4 Acid 12% HCI CT 25 2.0 2.0 600 13 - - 15100 15067 3 168 5 Mud Acid 9:1 Mud Acid CT 25 2.0 2.0 630 13 - - 15067 15100 -3 180 6 Overflush 3% NH4C1+ F103 CT 30 2.0 2.0 665 15 - - 15100 15067 2 19 7 Diverter Foam CT 12 2.0 0.6 669 20 40 1,610 32,513 32,513 15067 15100 -2 215 8 S acer PUH 3% NH4C1+ F103 + U067 CT 20 0.5 0.5 674 40 - 32,513 15100 15063 1 255 9 Acid 12% HCI CT 25 2.0 2.0 749 13 - 32,513 15063 15096 -3 268 10 Mud Acid 9:1 Mud Acid CT 25 2.0 2.0 824 13 - 32,513 15096 15063 3 280 11 Overflush 3% NH4C1+ F103 CT 30 2.0 2.0 904 15 - 32,513 15063 15096 -2 295 12 Diverter Foam CT 12 2.0 0.6 913 20 40 1,610 32,513 65,026 15096 15063 2 315 13 S acer PUH 3% NH4C1+ F103 + 0067 CT 20 0.5 0.5 918 40 - 65,026 15063 15030 1 355 14 Acid 12%HCI CT 25 2.0 2.0 993 13 - 65,026 15030 15063 -3 368 15 Mud Acid 9:1 Mud Acid CT 25 2.0 2.0 1068 13 - 65,026 15063 15030 3 380 16 Overflush 3% NH4C1+ F103 CT 30 2.0 2.0 1153 15 - 65,026 15030 15063 -2 395 17 Postflush 3% NH4C1+ F103 + U067 CT 25 0.7 0.7 1278 36 - 65,026 15063 15130 -2 431 18 Displacement 3% NH4C1+ F103 CT 25 1.0 1.0 1308 25 - 65,026 15130 15030 4 456 19 PO 0 H CT 0.0 0.0 1308 - 65,026 456 U rn • 13 8 , 09-15Ai Minilog BP,Exploration Sidetracked into lower Zone 2C, short Well Name: 09-15A above the 25N and HOT W Name'. DRILLSITE 09 NO 15A Operator BPX L RVN DATE: Dnlletl Dep5~. 15820' puo Date: 2007-Ot•18 00:00:00 X Coortllnate: 118512 easurement Ref KB Y Coortlinate~. 5942186 et EleraBOn: X6.5 Deptn Range: -20'-70 ayout Name: Ijl horizontal VeAical Scale-.16000 WORD ICL Fluids R`JFM DEPTH TVD Perfs ropy rope ~olgnar. ~ - - it n~ - - -c rear SS GRMM Borehole Profile EWR MWD 1 ~o roar ee_o r.ec: .._ . _ ::.~ ,0,90 10~ _.__ _ _. __ ,Q300 ,0350 i _ 10400 10450 - -8810 ... 24P -- - 1Q-M ,ono ~ - ,oeoo '~ ae,o ~ _ _. ,0700 _6800 i ~ ~--.. ,oleo ,~ -.-_ _ ,oeeo ~~ ~~ ----r- 24P ~ ,~ i ( „ooo ~-~1--~.- _ ,,,ao „200 .. :I. __ _ 24N - - ,1250 . + „300 - -- 25P _ i i 400 -6770 _ - ...:.:. _ . _ _ ,1450 ... _. iii _ ~-- t,800 „n0 - _.... __.~ _.. 11]00 _ _. 11790 - 1,900 11930 _. ... - 11 GOO 11050 .. -____ - 6P - ,2000 205 _. ,2,00 ;_~ ,2230 ,2300 ~ - _. -~.!~' .. ~, .- , 2350 ,2400 ,2.50 ~ --Lt'"~-~ ' -- - -- ~~ ,2350 -9700 ~~H ~~. z. ,~ ~- - - ,2700 ,2790 ,2600 - .-'~!'r--- -- - -. -- 1289D ,2000 . ,_ f~__' TS AD ---- _ +~ ** 13000 ,3oso 1, 13100 -8790 13190 13200 - 13250 _- - 13300 13350 -8740 _ . i~,'.. . ~ _ ...-. - 13400 13450 , 13500 13550 ~ 25N i3~no _.. ~}-• 5' 13700 , 3790 i'l!1~-. ~- , 3830 0 0 .a73o • 4~ -, ~. c, ,3 0 t3Ge0 .. --. '~ .. ,+400°050 -8720 - ._ __ ~.~~~ ___ _ ~ - 14,00 ,4,90 14200 __ .. _ _... _.. _. . 14250 - ~ ..~ --~•. t-.-_. 14300 11350 _..._j_.-._..a~...}.._~.. I 10400 ~ 4n,o ~ ~ ii7 5o .. ~ . 1*i4.-. ,4eoo ~ ~ -- t}- . ' : 147ao ._ .. . ,4750 ~Ci ' ,5000 ,5050 .s7oo r !4 -~ - - .... . 13,00 13150 ,5200 i _ ,5230 1 ,3300 -fi8G0 1545D ~ ~ IBBAA) q$p'~¢~ e[{[{ ~~ 15700 ,5630 8 =93 1 ? ,5500 i, 1x -rer rwr ,9870 15700 1 T50 1-888 7/9 ~ HES MWD Log for tie in Adperfs 15030'-15130' 15200 C I BP set depth 15230' ,s„o ~ Swell packer 15298' 8/9 10, 000 9, 000 8, 000 7, 000 a s, o00 G 5,000 a m 4, 000 3,000 2, 000 1,000 0 09-15A Injection Data I• ST to New Loc ~ SCMT • SL to 10452' • Mud Acid Stim ... fw-•.. rn~,~ PW SW W ELLHEAD_PRES MI • FCO to 15690 i Aperf r Mud Acid ,~ :; ,~ ;; ;~• SBG treat ,; :; ., ., ., ., ., :; ~: May-07 May-08 60, 000 50, 000 40, 000 30, 000 ~ 20, 000 10, 000 ~ ~ 0 May-09 ~~~~ DATA SUBMITTAL COMPLIANCE REPORT 6/912009 Permit to Drill 2070220 Well Name/No. PRUDHOE BAY UNIT 09-15A Operator BP EXPLORATION (ALASKAa INC API No. 50-029-20256-01-00 MD 15820 TVD 8735 Completion Date 5/9/2007 Completion Status WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: DIR / GR, RES / PWD, DIR / GR /RES / ABI. USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH ! ly mea~rrmi rvumoer Name acme nieaia No ssart ~[op ~n Kecervea comments D D Asc Directional Survey 7479 15820 Open 6/12/2007 og Cement Evaluation 5 Col 1 9400 15650 Case 6/20/2007 SCMT Maxtrac ~~ Conveyance 1-Jun-2007 D C Las 15481'~Induction/Resistivity 7246 15820 Open 10/3/2007 GR, ROP, RPM w/EMF Graphics pt 15750 LIS Verification 7261 15830 Open 12/13/2007 LIS Veri, GR, FET, RPS, D RPD, ROP t C Lis 15750~Induction/Resistivity 7261 15830 Open 12/13/2007 LIS Veri, GR, FET, RPS, RPD, ROP D C 16958~duction/Resistivity 0 0 9/30/2008 PDF, CGM and EMF in TVD and MD EWR graphics og Induction/Resistivity 25 Col 7480 15820 Open 9/30/2008 MD ROP, DGR, EWR o Induction/Resistivity 25 Col 6890 8374 Open 9/30/2008 TVD DGR, EWR D C Las 16994ee Notes 0 15335 Case 10/13/2008 Coil Tubing, CCL, CR i ~D C Las 16999f.~See Notes 0 15293 Case 10/13/2008 Coil Tubing, CCL, CR Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 6/9/2009 Permit to Drill 2070220 Well Name/No. PRUDHOE BAY UNIT 09-15A Operator BP EXPLORATION (ALASFC~ INC API No. 50-029-20256-01-00 MD 15820 ND 8735 Completion Date 5/9/2007 Completion Status WAGIN Current Status WAGIN UIC Y ADDITIONAL INFORN~pjION Well Cored? Y~/i.D!]' Daily History Received? N Chips Received? ''fT~1-' Formation Tops Analysis Received? Comments: Compliance Reviewed By: Date: _~~ U'~'L s 4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~SION REPORT OF SUNDRY WELL OPERATIONS /Ov??-d8 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate Q ~ Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown Perforate Q ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De~lopment Exploratory ~ 207-0220 - 3. Address: P.O. Box 196612 Stratigraphic Service - ' 6. API Number: Anchorage, AK 99519-6612 50-029-20256-01-00 7. KB Elevation (ft): 9. Well Name and Number: 48.5 KB PBU 09-15A - 8. Property Designation: 10. Field/Pool(s): ADLO-028324 ~ Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 15820 ' feet Plugs (measured) None true vertical 8734.7 - feet Junk (measured) None Effective Depth measured 15731 - feet true vertical 8736.17 - feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 Surface - 100 Surface - 100 1530 520 Surface 2731 13-3/8"72# N-80 Surface - 2731 Surface - 2731 5380 2670 Production 7479 9-5/8" 47# L-80 Surface - 10028 Surface - 8941 6870 4760 Liner 2766 7" 26# L-80 7304 - 10070 6750 - 8669 7240 5410 Liner 5904 4-1/2" 12.6# L-80 9914 - 15818 8567 - 8735 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: Tubing: (size, grade, and measured depth) 4-1 /2" 12.6# L-80 SURFACE - 9920' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BKR S-3 ~ ,~ 9~8"63' (6) 5-3/4" SWELL PKR :c~34 13750 14321 14852 15298 0 E~C~ _~ ~~~~~0 12. Stimulation or cement squeeze summary: ~ t ~£r5 ~vii~. ~Oftlrrlt~S~Q~4 Intervals treated (measured): ~f1 ~~Eti'3j~tr Treatment descriptions including volumes used and final pressure: ~ ;~"~1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 128 1692 Subsequent to operation: 3910 1129 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~~ GINJ WINJ ' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-098 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature ~ Phone 564-4944 Date 10/15/2008 Form 10-404 Revised~2006 /~ Submit Original Only 111 09-15A 207-0220 PFRF ~TT~(:HMFNT Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth lop Tvd Depth Base 5/6/07 PER 15,550. 15,650. 8,736.87 8,736.76 10/8/08 APF 15,480. 15,500. 8,736.67 8,736.75 10/9/08 APF _ 15,450. ~ 15,480. 8,736.53 8,736.67 10/10/08 APF 15,350. 15,400. 8,737.19 8,736.39 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE i 09-15A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY CACTIVITYDATE SUMMARY 10/8/2008 CTU #6 Log /Perforate. <InterAct publishing > RIH w /PDS logging tool for 'coil flag. 15500' log up C~ 50 fpm. Paint flag at 15300' ctmd for reference. 'Continue logging up to 11700' ctmd. POOH. Good data recovered from tools. Correction of -8' for depth correction (correlated to Halliburton DGR Dual Gamma Ray MWD dated 6 May 2007). Make up pert gun BHA #1 with 2 x 10' '2-7/8" guns loaded with PJ2906 Omega charges. RIH and correct depth at ,flag. Fire guns using 1 %KCI from 15480' to 15500'. POOH. OOH Recovered 1/2" a a s o s ire on gun run # H with gun run #2. *** Job continued on WSR 10/09/2008 "*" 10/9/2008 10/10/2008 CTU #6. Perforating *'`'`Cont` WSR from 10/8/08'`*" <InterACT publishing > Running in hole w/ BHA #2 with 2 x 10' 2-7/8" guns loaded with PJ2906 Omega charges. Correct depth to flag @ 15300'. Guns fired C 2700 psi top shot at 15460' bottom shot at 15480`. POQH. At surface, all shots fired and recovered 1/2" aluminum ball all shots fired on run #2. RIH with run #3 { 1 x 10' 2-7/8"} gun loaded with PJ2906 Omega charges. Correct depth at flag. Shoot from 15450' to 15460' using 1 %KCI and 60/40 meth fluids. POOH. At surface, all shot fired. Perform pipe management and weekly BOP test. Makeup PDS memory logging tools w/carrier.\ Paint white flag at 15300' ctmd for reference. Continue logging up to 11700' ctmd. POOH. *"* Job continued on WSR 10/10/2008 """ CTU #6 Perforating Cont` WSR from 10/9/08 (InterAct is publishing ) Confirmed good data. Correction of -15' for depth correction (correlated to Halliburton DGR Dual Gamma Ray MWD dated 6 May 2007). Make up pert guns BHA #4 with 2 x 10' 2-7/8" guns loaded with PJ2906 Omega charges. Guns fired at 2600 psi top shot at 15380' bottom shot is at 15400' POOH. At surface, all shots fired. Make up perf guns #5 with 2 x 10' 2-7/8" guns loaded with PJ2906 Omega charges. Correct to top shot depth at flag. Fire guns from 15360' to 15380' using 1 %KCI w/0.6% SafeLube and 60/40 meth. Repaint flag and POOH. At surface, all shots fired. Make up perf gun #6 with 10' of 2-7/8" gun loaded with PJ2906 Omega charges. Fire qun from 15350' tc 15360' using 1 % KCL w/ 0.6% safe lube and 60/40 meth. POOH. At surface all shots fired UD gun & firing head. '`"" Job continued on WSR 10/11/2008 **" 10/11/2008 CTU #6 Acid treatment *** Cont` WSR from 10/10/08 *** <InterACT publishing> RIH w / 2.5" JSN. Pump 80 bbls of ammonium chloride water w/ 0.2% F103 reciprocating from 15350' to 15650' ctmd. Initial injectivity with 3% Ammonium chloride was 0.6 bpm at 1950 psi. When 3% ammonium chloride with U67 was laid across perf interval, WHP started to slow fall. Pump 60 bbls of 12% HCI acid with a good acid break observed in WHP, reciprocating interval with down-up-down pass. Pump 60 bbls of 9:1 mud acid reciprocating perf interval with adown-up-down pass. Over displace mud acid with 100 bbls of 3% ammonium chloride with 0.2% F103 with 1 pass through the interval. POOH pumping 1 %KCI down backside of CT to keep wellbore loaded. At 2000', performed injectivity test with 50 bbls oft %KCI. Final injectivity at 5.0 bpm at 1360 psi. Freeze protect CTand top of wellbore per discussion with DSO. RDMO CTU. Notify DSO of well status and to place back on injection. Final WHP = 0/0/0. *** Job Complete *** FLUIDS PUMPED BBLS 190 1 % KCLT 53 60/40 METH 180 3% NH4C1+F103 60 12% HCI 60 9:1 MUD ACID 15 3% NH4C1+0.2% F103+5% U067 561 TOTAL b' V~~ ~~ __ , >. ~.~ ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn:_ Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 uz~ ao~--a2a /~g4~( j°t `1-OTC( 1 Co 995 1) Leak Detection - WLD 06-Aug-08 F-23A 2) Coil Flag 09-0ct-08 09-15A Signed Print Name: .~,~~ I^-e~ V /~ ~f 1 Color Log / EDE 50-029-21658-01 EDE _ 50-029-20256-01 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 w. INTERNATIONAL AIRPORT RD SUrrE C, ANCHORAGE, AK 99518 PHONE: (907)245-8957 FAX: (907)2458952 E-nnaL : ~r3~~sac9~flrar~°~e~a~~;:or+i9~~ WEBSITE : www.t~aea~flr~lo~.~as ~~ C:1Documan6 and Settings\Owner\Desktop\Transmit_BP.doc V 1/~L ~~-- ~:- ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection[Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Bhrd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 vsc ~o~--o a a ~~o99~i 1) Coil Flag 2) Signed Print Name: 07-0ct-08 09-15A ~~{~ %~~ ~-- ~~dc.,~ ~ EDE 50-029-20256-01 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-$951 FAX: (9D7)245-88952 E-MAIL : ~~3swl~~~t~r~Ov C~.~'13~r7+3~'Ii~~3.es~-"i- WEBSITE : ~r~n,•v.~rsr;®~vl~g.~~;?~ C:\Documents and Settings\Owner\Desktop\Transmit BP.doc C~ WELL LOG TRANSMITTAL To: State of Alaska September 23, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 09-15A AK-MW-4971247 09-15A: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20256-0 l 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20256-0 l Digital Log Images: 1 CD Rom 50-029-20256-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska} Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 ......Date:.. Signed: 4 ~ i~ ~ ~~~~~~ _ .`II STATE OF ALASKA Q~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~'` MqR 2 7 ,tip APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Oii & Gas Cons. Commi5Si0n 1. Type of Request: Abandon Suspend Operational shutdown Perforate ~ Wai () tag@ Othe Alter casing^ Repair well ^ Plug Perforations^ Stimulate 0 Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development^ Exploratory ^ 207-0220 / 3. Address: P.O. Box 196612 Stratigraphic^ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20256-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 09-15A _ Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): , ADLO-028324' 48.5 KB Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15820 l 8734.7 15731 8736.17 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 94# H-40 Surface 100' Surface 100' 1530 520 Surface 2731' 13-3/8" 72# N-80 Surface 2731' Surface 2731' 5380 2670 Production 7479' 9-5/8" 47# L-80 Surface 10028' Surface 8941' 6870 4760 Liner 2766' 7" 26# L-80 7304' 10070' 6750' 8669' 7240 5410 Liner 5904' 4-1/2" 12.6# L-80 9914' 15818' 8567' 8735' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 15550 - 15650 8736.87 - 8736.76 4-1/2" 12.6# L-80 Surface - 9920' Packers and SSSV Type: 7"x4-1/2" BKR S-3 Packers and SSSV MD (ft): 9863' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/10/2008 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Dafe: WAG [I'~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Patti Phillips Printed Name Patti Phillips Title Pad Engineer Signature Phone 564-4578 Date 3/27/2008 COMMISSION USE ONLY ~Jg _ ~ / Conditions of a roval: Notif Commission so that a re resentati nd N mber it S pp y p :` ve may w ness u ry u Plug Integrit y ^ BOP Test ^ Mechanical integrity Test ^ Location Clearance ^ ~ /~ Other: ~~®~~l M~e~\~--~~11v~ ~,~ ~~~ ~5~-- Subsequent Form Required: ~`It1 APPROVED BY ~ ~') A d b J ( pprove y: I ION THE CO ISSI N Date: i / Form 10-403 Revised 06/2006 ' ~ K , ~~'~ '~ 1`( ~~~~ ~~ C.~~~ ~ubmit in Duplicate To: Jerry Bixby/Clark Olsen Well Operations Supervisor Date: March 24, 2008 From: Patti Phillips, DS 09 Production Engineer Genevieve Shope and Abraham Zambrano, SWS Wells Group Engineers Subject: DS 09-15Ai Coil FCO. Perf and Acid Stimulation Est. Cost: $150M PBD09WL15-C Cauacity Sustainment IOR: 600 attached is a CT rocedure that includes the followin ste s: 1. C FCO w/ N2. Perf 100'. Mud acid (deepest FCO depth is 16,000', does not require test separator) Well Status: Max Deviation: Deviation at top pert: Current perforated interval: Proposed perforations: BHP: Min. ID: Last TD tag: Last Downhole Ops: H2S Level: Well History: WAG injector, injecting 331 bwpdQ 1709 psi, 03/23/2008 95.6 deg @ 10,689' MD 90 deg @ 15,550' 15,550'-15,560' 15,350'-15,400', 15,450'-15,500' 3251 psi C~ 8600', 12/26/03 in parent well, 09-15 3.725" C«~ 9909' MD, 4-1/2" XN Nipple 6/2/2007, Tractored in hole to 15650', no tag since sidetrack 12/27/2007, CTU acid wash of perfs, 12/27/2007 No data - DS 09 is an H2S site Well 09-15A is a horizontal MI injector sidetrack drilled and perforated in the 27P of Zone 2C on 05/09/07 in the 04-09i PWI pattern. The well is a `fish hook' horizontal MI well drilled around a central PW injector. The plan is for the well to have six sets of 100' of perforated interval, with each set separated by a CIBP. MI will be injected into each set with each `plug- n-pert' MI injection cycle lasting 1-2 years. The well has 4-1/2" L-80 tubing with perforations from 15550' - 15,650'. The rig shot the original perforations on 5/6/2007. On 6/1/2007, "debris" was pushed with tractor from 10,900' to 15,730'. The well was brought on injection on 6/29/2007 and started out injecting 3900 bwpd and died immediately. Injection continued for one month to let the well inject all it could. The DSO did a short injectivity test and the well took 3/4 bpm at 2800 psi. On 10/05/2007, a step rate test to establish injectivity was performed, and could only inject 1 bpm at 3000 psi. On 12/27/2007, a coil tubing mud acid job was pumped. Coil was parked above perfs at 1.5,336'. Coiled tubing was unable to reach further due to the short length. of the coil tubing. Injection rate increased from 0.5 bpm at 2000 psi to 2.2 bpm at 2050 psi. The well was put back on injection on 12/29/2007 at a rate of 2660 bwpd (1.5bpm) at 1594 psi. The well increased injection rates to 3234 bwpd (2.2 bpm), but dropped off after only ten days of injection to 1300 bwpd (0.95 bpm) at 1750 psi. Injection rates have continued to drop to 331 bwpd as of 3/23/2008. Obiective• Debris from the liner following the acid job may have fallen back and plugged perforations. A coil FCO is needed to dislodge and remove any debris, possibly lying on the lowside of the horizontal section and plugging the perforations. Perforations will be shot from 15,350'- 15,400', 15,450'-15,500'. A small volume of mud acid stimulation will be pumped to improve infectivity. If you have any questions or comments regarding this procedure, please call: Patti Phillips 564-4578 (W), 240-3742 (C), 346-1755 (H) Jennifer Julian 564-5663 (W), 240-8037 (C), 274-0929 (H) Abraham Zambrano(SLB) 564-4098 (W), 529-4112 (C) Brian Sinosic (SLB) 564-4164 (W), 223-8136 (C) Cc :Well Files • Coil Tubing Procedure: NOTE: Contact Jennifer Julian prior to performing the job to discuss doing testing with and with out Safelube to evaluate its effectiveness. FCO w/N2 .and Perforate 1. RU at least 16,000' of 1.75" CT. Rig up hard line to be able to pump down tubing for injectivity test. Check that the well is still shut in at lateral and wing valves. 2. Perform FCO from surface as slowly as practical with slick water and N2 as necessary with Biozan as the gel sweep fluid to ensure entire horizontal liner section is free of debris. Safelube to be used in order to reach TD of the well. Prior attempts without were unsuccessful. Minimum ID is 3.725" @ 9909' MD (4-1/2" XN Nipple). Prior operations came up around 500 ft short of 15,731' (made it to 15,336'). However, this was because the coil was too short, not because of lockup. 3. Jet @ 80% to surface to remove all debris and possible schmoo from the liner and tubing. If unable to reach TD with Safelube, plan on picking up agitator. Important to the success of this iob is to be able to reciprocate across the entire length of liner. 4. RIH and perforate with 2-7/8" PowerJet Omegas, 6 SPF, from 15,350'-15,400' and 15,450'-15,500' MD. Do not use 3-3/8" guns due to concerns about residual fill. Tie- in Note: There is not much character in the GR log. Will need to tie into the MWD- GR at a good shale higher up (@ 11,800'). Do not use the USIT-GR-CCL because it has not been depth shifted back to the open hole GR log. 5. Displace the well to 3% NH4CI. Load liner with 10 bbls of 3% NH4C1 at 1-2 bpm with no friction reducer. while reciprocating across all perfs. Pull above the perforations and perform an injectivity test by pumping down 4-1/2" tubing @ max rate of 2000 psi. Note injectivity on WSR. ~ ~ Acid Stimulation 6. RIH CT with a 2" - 2 1/4" jet swirl nozzle using Safelube as necessary (Note: Min ID = 3.725" @ 9909'). If unable to reach TD with Safelube, plan on picking up agitator. Pump the following fluid schedule while reciprocating slowly across all perfs. Pump from as deep as possible if you can not make it to the bottom. 80 bbls 3% NH4C1 + F103 15 bbls 3% NH4C1 + F103 + U067 60 bbls 12% HCI 60 bbls 9:1 Mud Acid 100 bbls 3% NH4C1 + F103 If needed to establish injection, go to 3000 psi WHP, but drop immediately to 2000 psi WHP as to not frac the well during the acid wash. When acid is on the perfs, max WHP should be 2000 psi. Before POOH complete the overflush to ensure acid has been pushed away. 7. Do an infectivity test post acid stim down the backside. Establish a stabilized rate and pressure to make certain of positive injection. 8. Turn well over to the DSO to put on produced water injection. 09-15Ai Acid Program ~~ ~«~ ~,~ sou a,Lhxs~a. AK pmt ~ ~ Exprci~m tnc. ~~imw~ t ~. Pattf fhiNips S4rvki Distrld; f SCMI~I~'~P „~ 1M~#1 t+l~% 09~t5Ai i#al+~ 8~y F+inre F~u~ S~st; 64 b61: 9~1 Re~u1~ 14t~d Aced 2 GU bbts 12~ HC! ~.~ 96 A~t1 Q,~ 9fe ,bait ~Nbitgr fl3 9L f103 ~x 610 02 !~ F -03 Swfa~-t. EAU ?U.8 psi ~~ Ira-9tabl¢r a0A pyt [c~5~ k~Stzrr 4,5 9b '~'~~:~ Ncra~rxisifyrspA~nt E-S 9ir ','~)5s Non6~dp~gAq~t U.5 "~ lbrifo Sk,d~s a.d Enu~ia~ 14w4.~r ~S ~, ,'tea ~ F~v~saer 4.2 9~ fttiQ t Elfflil ~}~ ~ ftn3 EZfA.a al1.U ppt J~+ cFderi~ `,r4.0 ppt .!:`B5 ~b~ide 5~ "1o U067 NIuA~Salra~ !: BNSf =156'F, vafl~:n c t-8d t~ulxs. k~ibita aa~ ' ~ ea bs J~.sigad aac~rgr. Cho~ical Req~rv~ne Tatal l'aqui~ lo~~ 3~~ bbd ft gel A~Sf kat 27 A+~ f-i~ ~ F~'3LU J85 Arm.a~n tNai~r i0i ~- L~l`8 knn~hif¢~r 32 qai U~3a7 M~ S~rur Qal `~,~,s Nar-~mu1 2~ ~ ti'r~3 N9rFERR1~NfY7f~ Alit ~ ~ 09-15Ai Daily Infection Plot Wellbore Schematic ACTLl#TQR = BA KE IC B. ELEV = ~ 54' Bf.aEV_. _,, _ ... ,. KOP= 2750' hl3x Argta = 96' ~ 10689' Datum 41D= 10395 DatumTVD= 8800'5 8-1J2' t.~LOtJT WClCK~iitf {~»1 SA) 7479" - 7497 DATE REV BY CC83TS DATE f~V BY {7CETtfS 9d018?77 ROWAN 34 1MTlAL COMPLETi(>rk 1or9sre7 PAA 1Q2 RWD 051~f07 N21'sS SiDETRACK{09•iSA) U2113A78 P.i~1P.FC DRLGDRAfTGCM~AE~T10N5 02 15A$ P.~VPJC ORiG C~4Ff CC7(iRE~TiONS BAY iNtfi VY13L 09-15A PERAfT No: 207(1220 APl hta; 50-029-2~5B~U'1 S13;1. T10N. R1 ~, 993' FSL 8150 FlAS_ E3P 8[piaeaUott {A]>~ka) ~ ~ ~~ ~~ ~ SAFETYt~gTP3:IN61 Ah@GI_Es 70°~ 1Q37S 09-15Ai Miniloq Sidetracked into lower Zone 2C, above BP~Exploration the 25N and HOT by Short Well Name: 09-15A W Name: DRILLSITE 09 NO 15A Operator: BPX L RUN_DATE: Drilled Depth: 15820' pud Date: 2007-04-16 00:00:00 X Coordinate: 718542 easurement Ref: KB Y Coordinate: 5942466 ef. Elevation: 48.5 Depth Range: 10100''-'20 ayout Name: Ijl_horizontal Vertical Scale: 1:6000 RGPf~1 DEPTH TVD Perfs WURD ICL Fluids , _ _ _ _ _ TupS Tops ~nll91n alp FT MP --= FCCi SS GRMM Borehole Profile EWR 1 ~ i=P1 _~~ ,910 T.. C•~:' d:~pp ~~._ :'H I.II.I _~ 10150 10200 10250 ~ +0300 10350 - 10400 10450 -3810 _ 10500 10550 ~ 10500 10550 10700 10750 10800 10850 _ 10800 10930 ++000 ~ 11050 _ 11100 11150 ~ - 11200 11230 11300 11350 - 11400 11450 11500 11550 11500 11550 1+700 +1750 11800 11830 1+800 11750 12000 12050 12100 12150 - ~ 12200 - ~ - _ 12230 1~~~ 12330 - 12400 12450 12500 - _ 12550 - 125ao - - 1z55o +z7oo 12750 _ 12800 - 12650 12000 12750 ----- 13000 13050 _ I_ ~^ 13100 - 13150 I - 13200 _'rt'- 13250 i.-' 13300 13350 _ - 13400 +3450 _-- 13500 13550 s --- 13500 ' _^ 13550 ~ _ 13700 1 3750 ~ ' I _ - - ~ - 13600 ~ _'~ ~~ -- 13650 13000 13750 14000 ~ --i ~ -~-~- 14050 - - --'' 14100 ...„..,-t ,.=-. 14150 I~`fi - - 14200 ~~ ' 1 ~ ~ -~ 14250 - 14300 14350 -}~: 14400 ' , ' 14450 '. 'i' T 14500 ~ +4550 ~ -' 14500 14550 Add Pe - - 14700 14750 ~• - 14800 14850 "'~ -- 14700 14750 i i 1 - ~~ 13000 15050 - - - i ' -" 15100 15150 - y-- - ;s3o8 urrent perfs 155 0'-15 ~ _ 15350 f .. _ ~ ~~ 15400 ~ _.-" "I"-" _' - 15450 15500 ~ - ~--~ 15550 15500 15550 ~ Is soo-~sawa -n.r^oo'r 13750 15800 09-15Ai 5" MWD-GR log ~~~~ rr'. t 51Gf3 _- -- ~-•- _._- F ~~- - ---1-- ~ __ . _. - - _. ~,. ~,.-- - -- = 1$33 r ..._____ ..-.__ -- _.... _ _ m ~. _ _.... ~. _. _ __~ . - t ,a....... ~. ~...___ ... W___.. _......t_... _ .: .. - _-~_--._.~_ - ~ _ f__ __ __ _,~_- f ~._ ~~ ~ -r L ti x.._~ 3 '4Y -__ _ r _ - _._..... i, 4 ~ ' ~. - ~ ~ ~ -- r- ,__ _ !_ _ t - ~ -- __ _ _.. i 163e0 .. t _ ____ ~~_ . --- ____ _.-- i ~ -_ - _.' ~__. i ~._. i, . _ _ _ _ _ _~. ' - --- -- - - ~-----'--- • i - - - -- - ~ f G' J~.~ z~ ~` -- - - "1 ----`-- - ..... _.-.. 'r - --- . _ .. .-... ~ ~ ----E ~ - ..'- ~{ _. __.__.. .- _ ._ _. I _~ __. ~___ .._ ~_ ~ l _. _ . __ ._ r- f _ .. __ ___. _.____~~ r ____. __~ ~. . _ _ _. .._~__ - __ -~_ _... __..__.~ e ~ .~-}1.. .. ... _ - ... 3 ~ - ..... .~-. _ -T ~ ' __-__ ___ ..___.... .e.-. r ~ ~ ~ __ _.. ...___ _.. ~___ _ _ _.______-.._~.~ i __ __.~. __.- ..~ ___ ~ .. ._.... _-!- _.„mow _. .__ _. __._ _. _.. _ _. __ __~._ T, _ .__..___. ` _ ~ ~_ - - . _____-__ • a _-4- .. te ~ . ~--r .. _t. . ... _.____ __-.. _. _ r _-_ - ` __.__. ~1, ~ ~ . __.__ ~_...__ __. ... .. ~-__ _.____.._. _._ _.~ .._ __. -jjj_ -..i' ~ _ ~ ~ ___~ _ _.__ .. ..... } r.._r_~. _- ___. .. _ _ . ... _ _ _ __- - -- ~ - - - - _ r - - __ --- - -- ._f _ -- ... _ ~i - -_ _. _. -' _- . __- - _ i-- WELL SERVICE REPORT WELL 09-15A JOB SCOPE SIDETRACK UNIT CTU #8 DATE 1.2/27/2007 DAILY WORK ACID TREATMENT DAY SUPV HARRIS COST CODE PLUS PBD4P2592-D KEY PERSON DS-WOLD NIGHT SUPV IMM MIN ID 3.725 " DEPTH TTL SIZE 9909 FT 4.5 " DAILY SUMMARY CTU#8 Cont' WSR From 12/26/07 Mud Acid stimulation Park coil above perfs 15336 Injection. rate is .50 bpm C~ 2000 psi. pump acid treatment as per procedure. perform final infectivity test 2.2 bpm C~ 2050 psi.( well freeze protected). Bleed IA to zero. Notif DSO of well status. *"'ob com lete"` LOG ENTRIES Init T b , IA, OA 46 1 871 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:01 0 Finished R/U Hold PJSM with crews 00:31 15336 461 1000 5 PT all surface a ui LPT 00:47 15336 3900 HPT 00:48 15336 490 3000 1.7 30 Be in um in 3% NH4CL + F103 50 bbls total 01:14 15336 1654 1707 .75 33 Shut in well start bull headin 01:42 15336 2046 1837 .50 50 Swa to 3% NH4CL + F103 + U67 10 bbls total 02:03 15336 1900 1683 .50 60 Swa to 12% HCL Acid 50 bbls total 02:48 15336 1895 1674 .70 82 Increase um rate to .70 b m 03:14 15336 1564 1380 .70 100 Injection ressure dro 03:26 15336 1500 1846 1 110 Swa to 9:1 Mud acid 03:31 15336 1143 3400 2 120 Increase um rate to 2 b m 03:55 15336 279 3063 2 160 Swa to 3% NH4CL+F103 04:43 15336 400 3100 2 250 Swa to 2% KCL 05:13 0 291 Swa to Methanol for freeze rotect 05:32 15336 500 3600 2 326 Shut down um POOH 06:08 12694 32 0 0 327 c/o IMM to Harris. cont ooh 07:43 6900 27 0 0 335 cont ooh 08:56 0 4 0 0 341 ooh 09:01 0 4 0- .5 341 m line u 60/40 down tb 09:07 0 70 0 1.5 347 increase rate 09:10 0 560 0 3 352 increase rate 09:19 0 1385 0 4 384 ressure startin to fall off. increase rate to 4 b m. max rate for ctu um 09:23 0 2066 0 decrease rate to maintain 2000 si at surface 09:28 0 2086 0 2.1 403m well stable ~ 2.2 b m ~ 2050 si 09:29 0 dro in 0 0 0 shut down 09:35 0 0 0 0 bleed IA back to zero 09:53 0 be in ri down 12:00 0 rd com lete Final Tb , IA, OA 0 0 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL CH2MHILL LABOR $1,406 $3,746 HOT WATER PLANT $212 $212 ORBIS $2,600 $6,500 SCHLUMBERGER $9,650 $41,266 SCHLUMBERGER PLUS 15 PERCENT $15,584 $17,376 WAREHOUSE $6,815 $10,909 EQUIPMENT FLEET $0 $4,725 TOTAL FIELD ESTIMATE: $36,267 $84,734 FLUID SUMMARY 98 bbls of meth xxx bbls of 2% KCL WELL SERVICE REPORT WELL JOB SCOPE UNIT ~9-15A SIDETRACK CTU #8 DATE DAILY WORK DAY SUPV 12/26!2007 ACID TREATMENT HARRIS COST CODE PLUS KEY PERSON PBD4P2592-D DS-WILLIAMS NIGHT SUPV IMM MIN ID 0" DEPTH OFT TTL SIZE 0" DAILY SUMMARY CTU #8 (Mud acid stimulation) continued from 12-25-07. finish rigging up coil unit. load IA with diesel and pressurize to 1000 psi. RIH stop ~ 15357' "*`'ob in ro ress*"" LOG ENTRIES Init T b , IA, OA 90 1000 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:01 0 cont from 12-25 coil crew on stand down. 02:00 0 ctu crew on loc. hold PJSM rior to cont ri u 03:07 0 CH2MHILL on location to ri 'um er to 09-46 03:30 0 MU BHA (CRC 1.9"x .11), DFCV (2"x 1.07), Stinger(2" x 3.54) ,Stinger (2" x 3.75 X-O 2.14x .30 JSN 2.25x .58 OTL + .35 04:30 0 lubricator on BOPs 05:30 0 hardline finish 09-46 tie in. 06:00 0 CT c/o PJSM 07:00 0 on line with 60/40 to fluid ack lines 07:13 0 219 171 LPT hardline 07:15 0 4037 4063 HPT 07:20 0 3998 4015 end test bleed down 07:52 0 on line with diesel down IA 07:57 0 1056 si. isolate valve stb on com an man c/o 11:30 0 on location. hold PJSM and call DSO for ermission to backflow to 09-46 12:30 0 DSO on location. settin u to take returnes 12:42 0 92 99 0 0 start rih 13:33 3842 321 48 0 0 cont rih 13:46 5000 209 141 0 0 wt ck = 9500. rih wt = 5600 14:09 7000 314 281 0 0 wt ck = 12000 rih wt = 7700 14:44 9900 321 370 0 0 wt ck = 17500 rih wt = 11600 15:06 11500 203 280 0 0 wt ck = 18500 rih wt = 11600 15:30 13300 230 310 0 0 wt ck = 20000 rih wt = 11200 15:55 0 called SLB for acid. 15:57 15357 303 410 0 0 wt ck = 22600. ark coil, 16:02 15357 8.3m line u to f hardline to 09-46 16:18 15357 1893 467 .5 13m on line w/ meths acer down backside 16:31 15357 1960 438 .5 1 d swa to diesel 16:52 15336 1900 264 .3 15d move coil to make sure not stickin 17:34 15336 2253 206 .5 27.2 increase rate 18:53 15336 1890 1950 .5 67.1 On line w/ um down coil for in'ectivit 19:00 0 Stb for cementers 22:49 15336 138 99 cementers AOL R/U 23:59 0 Continue R/U Final Tb , lA, OA JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL CH2MHILL LABOR $2,160 $2,340 EQUIPMENT FLEET $4,725 $4,725 ORBIS $3,900 $3,900 SCHLUMBERGER $17,896 $31,616 SCHLUMBERGER PLUS 15 PERCENT $1,056 $1,792 WAREHOUSE $3,852 $4,094 TOTAL FIELD ESTIMATE: $33,589 $48,467 FLUID SUMMARY 4 +13 + bbls of meth 63 + bbls of diesel WELL SERVICE REPORT WELL 09-1 5A JOB SCOPE PRESSURE TEST (RES SURV) UNIT LRS 42 DATE 10/5/2007 DAILY WORK ATTEMPT; INJECTIVITY TEST DAY SUPV CULPEPPER COST CODE PLUS PBD09WL15-R KEY PERSON LRS-ROBUSTELLINI NIGHT SUPV BOYLES MIN ID 0" DEPTH OFT TTL SIZE 0" DAILY SUMMARY T/I/0=200/vac/vac Attempt Step Rate Test -Attempt to establish injectivity down tbg w/30 bbls 60/40 methanol water. Injectivity 1 bpm ~ 3000 psi. Step rate test canceled due to low injectivity. Verify casing valves open to gauges, tag well & notif o erator. Final WHP's=50/vac/vac LOG ENTRIES Init-> 200 -0 -0 TIME BPM BBLa FLWD TEMP TBG IA OA COMMENTS 10:00 Start ticket, simmo s w/s-line & DHD, o en uw w/o erator 10:20 PJSM discuss hi h wind hazards 10:40 Be in RU hard line to tree ca ,flan e u to IA 11:30 Finish RU, s of in & RU trans rots, fuel unit 12:10 PJM w/CH2MHill, LRS crews & co re 12:37 BP challen er on location, site/'ob orientation & safet briefin 12:51 PT lines to tree ca & IA to 4000 si 13:03 Good t, ressure u ssv & function test 13:10 Line u to um tb 13:17 0.7 st/0 60/40 meth 250 vac vac Start um tb w/60/40 meth-water, walkin u rate 13:19 3 4 350 vac vac 13:20 1 9 2000 vac vac Reduce rate 13:22 0.6 10.5 2100 vac vac Reduce rate 13:23 0.45 11 2175 vac vac Reduce rate 13:27 0.45 13 2250 vac vac Rate stead , TP slowl climbin 13:30 0.3 14 2200 vac vac Reduce rate, co re discussin w/town 13:32 0.3 15 2175 vac vac 13:34 0.75 16 2350 vac vac Increase rate 13:36 i 17 2550 vac vac Increase rate 13:38 1 19 2750 vac vac TP slowl climbin 13:39 1 20 2775 vac vac Increase rate to 1.3 b m 13:40 1.3 21 2850 vac vac 13:41 1.3 22 3000 vac vac Reduce rate to 1 b m 13:42 1 23.5 3000 vac vac 13:43 1 25 3000 vac vac TP stead 3000 si ~ 1 b m 13:48 1 30/sd 60/40 meth 3000 vac vac Shutdown 13:49 2800 vac vac Static ressures @ shutdown 13:58 1000 vac vac 10 min static ressures 14:08 500 vac vac 20 min static ressures 14:18 300 vac vac 30 min static ressures, be in RD 15:18 50 vac vac Static pressures, rig down complete, finish paper work, tag well, verif casin valves o en to au es 15:40 Stand b for Ian forward for 2-trans orts kcl & um 15:58 Send transports to freeze protect plumbing, stand by C~ shop for water 'ob 16:15 Notif o erator of well status & results 16:59 End ticket Final 50 -0 -0 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL CH2MHILL LABOR $450 $2,370 EQUIPMENT FLEET $563 $4,763 LITTLE RED $8,824 $16,996 LITTLE RED PLUS 20 PERCENT $1,764 $3,398 ORBIS $1,300 $1,300 WAREHOUSE $2,088 $2,136 SCHLUMBERGER $0 $3,555 SCHLUMBERGER PLUS 10 PERCENT $0 $356 TOTAL FIELD ESTIMATE: $14,989 $34,874 FLUID SUMMARY 30 bbls 60/40 methanol water WELL SERVICE REPORT WELL 09-15A JOB SCOPE SIDETRACK UNIT SWS 2150 DATE 6/2/2007 DAILY WORK CEMENT BOND LOG--SCMT/USIT DAY SUPV BOYLES COST CODE PLUS PBD4P2592-D KEY PERSON SWS-WIBLE NIGHT SUPV LYNCH MIN ID 3.725 " DEPTH 15730 FT TTL SIZE 4.5 DAILY SUMMARY INITIAL T/1/0=0/0/0 FINAL T/I/O=0/0/0 SSV CLOSED ON ARRIVAL. MASTER VALVE CHAINED CLOSED ON ARRIVAL MAX TOOLSTRING LENGTH=67.1'. MAX OD-2.125" CONTINUE FROM 01-JUNE-2007. LOGGED SCMT PASS UP AT 30 FPM FROM 9400'-15650'. TIED INTO SLB USIT LOG DATED 6-MAY-07 USING GAMMA RAY NEAR 9700'. FOUND TOP OF CEMENT AT 9952'. PUSHED DEBRIS DOWN HOLE W/TRACTOR FROM 10900' TO TD. TRACTORED'IN HOLE TO 15650`. LOG JEWELRY PASS FROM 10300' TO 5380' TO CONFIRM TIE-IN WITH USIT DATED 08-APRIL-2007. USIT LOG WAS RUN TO 7500' AND IS BEHIND MULTIPLE STRINGS OF PIPE. TOP OF CEMENT IDENTIFIED AT 9960'. SSV CLOSED ON DEPARTURE. MASTER CLOSED ON DEPARTURE. LOG ENTRIES Init Tb , IA, OA -> 0 0 0 TIME COMMENT 00:01 CONTINUED FROM PREVIOUS DAY 00:10 WEIGHT CHECK AT 14700', 3000 LBS, CONTINUE TRACTORING IN HOLE AT 1500 FPH. 01:16 TRACTORING SLOW FROM 15100'. 01:58 ON BOTTOM, STOP TRACTORING, START LOGGING UP AT 30 FPM. 05:15 DOWN LOGGING, POOH 06:43 OOH, SHUT SWAB, BLEED DOWN, UNSTAB, RIG BACK SCMT AND TRACTOR. 07:13 TOOLS RIGGED DOWN, WAITING TO HEAR IF PE WANTS A BETTER JEWELRY LOG. COLLARS ARE WEAK DUE TO CENTRALIZED TOOLSTRING FOR SCMT. IF PE WANTS BETTER COLLARS, ANOTHER RUN IS NECESSARY. 07:26 RELIEVED CONFIRMATION THAT PE WANTS BETTER JEWELRY LOG, RU, CORRELATION TOOL 08:09 RIH WITH GR/CCL FOR JEWELRY PASS. TOTAL TOOLSTRING LENGTH=20.7'. MAX OD =1 11/16". TOOLSTRING: MH-22, SWIVEL, ERS, 2 X 1 11/16" WEIGHT BARS, UPCT. 09:10 LOG GR/CCL JEWELRY PASS FROM 10300 TO 5380' TO CONFIRM TIE IN TO USIT LOG DATED OS-APRIL- 2007. 10:28 OUT OF HOLE WITH WIRELINE. 11:25 COMPLETE RIG DOWN OF ELINE AND THIRD PARTY CRANE. 11:50 MOBILIZE TO SHOP. F inal Tb , IA, OA -> 0 0 0 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL ORBIS _ $1,000 $1,000 SCHLUMBERGER $157,809 $161,215. VECO $692 $792 TOTAL FIELD ESTIMATE: $159,501 $163,007 FLUID SUMMARY NONE SAFETY NOTES MASTER VALVE CHAINED CLOSED ON ARRIVAL.SSV CLOSED ON ARRIVAL. COMMUNICATION WITH THIRD PARTY CRANE IMPORTANT. WELL SERVICE REPORT WELL JOB SCOPE UNIT WELL SERVICE REPORT WELL 09-15A JOB SCOPE SIDETRACK UNIT SWS 2150 DATE 6/2/2007 DAILY WORK CEMENT BOND LOG--SCMT/USIT DAY SUPV BOYLES COST CODE PLUS PBD4P2592-D KEY PERSON SWS-WIBLE NIGHT SUPV LYNCH MIN ID 3.725 " DEPTH 15730 FT TTL SIZE 4.5 " DAILY SUMMARY INITIAL T/I/0=0/0/0 FINAL T/I/O=0/0/0 SSV CLOSED ON ARRIVAL. MASTER VALVE CHAINED CLOSED ON ARRIVAL. MAX TOOLSTRING LENGTH=67.1'. MAX OD=2.125" CONTINUE FROM 01-JUNE-2007. LOGGED SCMT PASS UP AT 30 FPM FROM 9400'-15650'. TIED INTO SLB USIT LOG DATED 6-MAY-07 USING GAMMA RAY NEAR 9700'. FOUND TOP OF CEMENT AT 9952'. PUSHED DEBRIS DOWN HOLE W/TRACTOR FROM 10900' TO TD. TRACTORED IN HOLE TO 15650'. LOG JEWELRY PASS FROM 10300' TO 5380' TO CONFIRM TIE-IN WITH USIT DATED 08-APRIL-2007. USIT LOG WAS RUN TO 7500' AND IS BEHIND MULTIPLE STRINGS OF PIPE. TOP OF CEMENT IDENTIFIED AT 9960'. SSV CLOSED ON DEPARTURE. MASTER CLOSED ON DEPARTURE. LOG ENTRIES Init Tb , IA, OA -> 0 0 0 TIME COMMENT 00:01 CONTINUED FROM PREVIOUS DAY 00:10 WEIGHT CHECK AT 14700', 3000 LBS, CONTINUE TRACTORING IN HOLE AT 1500 FPH. 01:16 TRACTORING SLOW FROM 15100'. 01:58 ON BOTTOM, STOP TRACTORING, START LOGGING UP AT 30 FPM. 05:15 DOWN LOGGING, POOH 06:43 OOH, SHUT SWAB, BLEED DOWN, UNSTAB, RIG BACK SCMT AND TRACTOR. 07:13 TOOLS RIGGED DOWN, WAITING TO HEAR IF PE WANTS A BETTER JEWELRY LOG. COLLARS ARE WEAK DUE TO CENTRALIZED TOOLSTRING FOR SCMT. IF PE WANTS BETTER COLLARS, ANOTHER RUN IS NECESSARY. 07:26 RELIEVED CONFIRMATION THAT PE WANTS BETTER JEWELRY LOG, RU, CORRELATION TOOL 08:09 RIH WITH GR/CCL FOR JEWELRY PASS. TOTAL TOOLSTRING LENGTH=20.7'. MAX OD =1 11/16". TOOLSTRING: MH-22, SWIVEL, ERS, 2 X 1 11/16" WEIGHT BARS, UPCT. 09:10 LOG GR/CCL JEWELRY PASS FROM 10300 TO 5380' TO CONFIRM TIE IN TO USIT LOG DATED 08-APRIL- 2007. 10:28 OUT OF HOLE WITH WIRELINE. 11:25 COMPLETE RIG DOWN OF ELINE AND THIRD PARTY CRANE. 11:50 MOBILIZE TO SHOP. F inal Tb , IA, OA -> 0 0 0 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL ORBIS $1,000 $1,000 SCHLUMBERGER $157,809 $161,215 VECO $692 $792 TOTAL FIELD ESTIMATE: $159,501 $163,007 FLUID SUMMARY NONE MASTER VALVE CHAINED CLOSED ON ARRIVAL.SSV CLOSED ON ARRIVAL. COMMUNICATION WITH THIRD PARTY CRANE IMPORTANT. 09-15A sIDETRACK SWS 2150 DATE 6/1/2007 DAILY WORK CEMENT BOND LOG--SCMT/USIT DAY SUPV BOYLES COST CODE PLUS PBD4P2592-D KEY PERSON SWS-WIBLE NIGHT SUPV LYNCH MIN ID 3.725 " DEPTH 15730 FT TTL SIZE 4.5 " DAILY SUMMARY INITIAL T/I/0=0/0/0 FINAL T/I/O=0/0/0 SSV CLOSED ON ARRIVAL. MASTER VALVE PADLOCKED CLOSED ON ARRIVAL. FLUID LEVEL IDENTIFIED AT 695' RIH. TRACTOR IN HOLE TO 14700'. """JOB CONTINUED ON 2 JUNE 07"" LOG ENTRIES Init Tb , IA, OA -> 0 0 0 TIME COMMENT 14:15 MOBILIZE TO 09-15A. CONTACT PAD OPERATOR. SPOT EQUIPMENT AND THIRD PARTY CRANE. MEET WITH OPERATOR. MASTER VALVE IS PADLOCKED. 15:00 HOLD PJSM WITH SLB AND THIRD PARTY CRANE OPERATOR. DISCUSS JOB AND CRANE OPERATIONS. 15:15 RIG UP ELINE. OPCHECK DOWNHOLE TRACTORS. 16:27 PRESSURE TEST LUBRICATOR TO 1500 PSI HIGH AND 500 PSI LOW FOR 5 MINUTES. 16:41 RIH WITH PRESS/TEMP/GR/CCUSCMT IN CEMENT MAPPING MODE. TOTAL TOOLSTRING LENGTH=68.7'. MAX OD=2.125". TOOLSTRING: PEH-E, SAH-G SWIVEL,ERS (ELECTRIC DISCONNECT), TTSA (TENSION SUB), TRACTOR CARTRDIGE, 2x 2.125" MAXTRAC TRACTORS, PBMS-T, SLIM CEMENT MAPPING TOOL. 16:58 FLUID LEVEL IDENTIFIED AT 695' RIH. 17:26 PERFORM FREE PIPE CALIBRATION WITH TOOL STATIONARY AT 5300'. 18:03 TAKE UP WEIGHT AND TIE IN FROM 9740' TO 10400'. 18:45 TRACTOR DOWN TO 10550' AND LOG UP PASS OVER TOP OF CEMENT TO 9600'. 20:00 BEGIN TRACTOR DOWN FROM 1045U'. SIT DOWN IN DEBRI$ AT 10900'. FIGHT UP AND DOWN CLEANING TRACTOR FROM 10900' TO 11060'. FIGHT TO GET THROUGH THE AREA BETWEEN 11060' AND` 11090'. SUSPECT DEBRIS DOWNHOLE. BOTTOM SONDE WILL SLIP'AT THIS. DEPTH REPEATEDLY. PULL OF HOLE AND RE-TRACTOR TO THIS DEPTH WITH NO ISSUES. 21:11 BREAK THROUGH AND TRACTOR TO 11160'. SIT DOWN MULTIPLE TIMES AT 11160'. TOOL STOPS WITH SCHMOO AT 11160'. 21:42 PASS THROUGH SCHMOO AT 11160'. CONTINUE DOWNHOLE AT 2000 FPH. 23:14 TAKE UP WEIGHT OF 2900# AT 13700'. BEGIN TO TRACTOR DOWNHOLE AGAIN AT 1700 FPH. 23:59 CONTINUE NEXT DAY F inal Tb , IA, OA -> JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL SCHLUMBERGER $0 $3,406 VECO $0 $100 TOTAL FIELD ESTIMATE: $0 $3,506 FLUID SUMMARY PUMPED 1 BBL OF DIESEL FOR PT. by PERFORATING PROCEDURE .~_ -~. ~~! i~~ ~~~~~~~ Well: 09-15A API #: 50-029-20256-01 Date: 03/24/2008 Prod Engr_P_atti Phillips Office Ph: 564-4578 Home Ph: 346-1755 Cost: _-- ---$60,000_-_ ___ Cell/Pager: ____ _____24.0,3742_________. CC or AFE: PBD09WL15-C IOR: 600 WBL Entries ------------------------------ H2S Level; No Data DS 09 is an H2S site IOR Type Work Desciption Priority/Comments 2 .. ... C lAdperf 1.00...... .. .. _ _ _ ........... . . ... . 3 600 -- C _ _ ,Injectivity_test Aad_stim_ _Inlectivity test post acid stem. _ _ _ _ __________~_____________t______________________________________~_______-----_________----______ Well Objectives and Perforating Notes: Alin ID = 3.725" @ 9950' MD, 4-1 /2" XN Nipple. Angle at Min ID = 50 deg Flax Angle to adperfs = 91 deg @ 15350' MD. Angle at top of current perforations = 90 deg @ 15550' ~jectivity test post adperfs. Pump -10 bbls down backside at max rate @ 2000 psi max pressure. acid stimulation. Infectivity test post acid stim. Attachment: Reference log with proposed perfs annotated at 5"/100'scale Reference Log Tie in Log Add/Subtract _ _ _ _ _ feet Log: MWD/G R_ to the tie-in log to be on Date: 5/6/2007 _ depth with the reference log. Company: Halliburton Depths (from-to) Depths (from-to) Feet SPF Orient, Phasing Zone Ad/Re/Iperf .. 15,350'....-...15,400... ....----._... ................. . 50~.. ._.6..-. .. ...... Random........... ....._..6Q........... . 27P... ...Adperf..... _.15,450' _. -._15,500' _ ___ __ _____ _________ _ __________. - 50'__ ___6___ ._ _ ___ _ ____ Random______ __..___60~______ _________ ___ _ _27P__ ____ _-_Adperf ____ ___ Requested Gun Size: 2-7/8" Charge: 2906 PowerJet_Ome~a HMX Is Drawdown Necessary/Desired/Unnecessary During Perforating Preferred Amount of DrawdowNSuggestions to Achieve Drawdown Last Prod: BOPD BWPD Unnecessary-----......__ ................._........__...........------...... NA Last Tag: 15650' ft MD on 6/2/2007 Est Res. Pres. (~ 8,800 MD is 3251 psi (Estimate from parent" Perforation Summary Summary Dist Well: 09-15A Town: Date: API#: .......... 50-029-20256-01 ....................................... Prod Engr: ........................ Anch Prod Engr P.D.Center PBTD General Comments: ............ ........................................... ....................................... .................................... Depths ........................................... ....................................... Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf O/B/U - O/B/U - O/B/U - O/B/U - O/B/U - O/B/U - O/B/U - O/B/U - O/B/U - • 09-15A GR/MWD log, 5/6/2007 _ .~ _ ~- - .P...~ ~ a~ ~ r ...__ ._ _~.~...~_..~..~--- _, _ --, ~ - __ _. _4 ~ ~ __ _ ~~ . ~ _ s ;. ~ ._ ; { _.,~r.-..,~, .~. ... ,~ __ ~ - - `~ ~ ~ .. _ ~. ~ _ -_ __~ ~_ ~ __ ,~ , > _: _.. .; W -~---~-~- ~ ..~ s ~_ r ,r ~ , x __ - m, _.. ~ .._.. ~ .~ .~.. _,~ ~ ~ ~ ki+;~ ;~r_~3i~ ~ar~jma ~~°-°°_ r~~ ~?t~al G>n~n7~ ~~~ ~ ~~`~~ ~!>~~tro~a~n~tir. VVE-~v~ ~e~ist~~~ty ~-lar~4nti f~r~s~~t~kic,ar~ ""~~.. (~~ R~rtc Qf ~"~~~~ratc~r~ ~ . _~„ ~.. ~. I ~ ~C~ffi7 ~~1~1'~' g E r e ~ ~KfJ~tlf~~~<JCl ~,,~~x"I~JI~~31 IFS, ` ~F~ ~~~Mf ~ ~~~ ~ ~ . ~ t+'~'eYll ~1~~~J/~I _ z ~° ' ~ ;e lti ~ .~ -. r ~~ «t~~-ct= E3 ~y U t v tD, rti 1 t. ';,r'7 ~" 1'r t.F ~F 4J F~ I lf't 1 .3 Yc~ z r d~7 Y L. ~ i .. i i"'~r9 I~~.~r1~1~~~~~" i.tV^~t`7'S'.V~'.~~'°~.3~'+1 i T J: , j ~ c yi y r f ~~ IJ~ J ~ n ,... I ciflil,i~u ._..., _.__. ..~ ._ ,. 'r J 1 a, ~..~, ~~ i~~C}fj},_ 1- f. ~ ~~., l ~ -.3 x ~,L~,I ~tl~rt i,r I~iat,~~ra " ~ - "' - s-~ }~~ _~ i > - ~:I t~ F~I~~L N~ t.:a,r~ ~~ ~ ~a hnlll~r<~ ~ _ €~ril~1~i~~r F ~- ~~ I Ir ~, ?.~ , ~;1 rl_tyitl ~yiFl Fln~f ~ I ~fJ.Qf7 #! r {~^~1 /'~ ~~``** ~ ~ ~ L _.. ~,_ I ~J V ~..JL.7 _ ,. ~~.~w t~,;~a it ~_._, - - iY.rCE~V~.~il ,l i< '~`3~~~.4~I~~ . _ I I''I` C'vf` ~ ~ ~kf ? ~! ll r l t ~~ i~~,. << I S7 a .. - isi ,,ashy I 7ii ~ ~ I :-,,~, ~~° -~ ~ ~ x~~~.~a it ~~<~ a,-r~,a t~~ F€ r-,,, ~ ~ r; ; ~~~~~~ I , i ri li tl '~; , k ._ ~~~ - ~ _: t„~ r ~ ~ I Iii _ ~ ~ ~~ ~ f ~~ 1' r- IC.... i I ~ ,I~ 1 ~ I~ I ti~ I t ~ ~( l i - ... ~ _..... ,. ._. .. , , I ___ ALASSA OIL A1~TD (irA-S COI~TSFRQATIOI~T COrII~i1551O1Q Patti Phillips Pad Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Pool, 09-15A Sundry Number: 308-098 Dear Ms. Phillips: SARAH PALlN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 2nd day of April, 2008 Encl. ~ ~ STATE OF ALASKA ALA A OIL AND GAS CONSERVATION COMMISSION ,~;~ ~ ~' ~. ~Q~ REPORT OF SUNDRY WELL OPERATI . 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Exten r Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory .~' 207-0220 ' 3. Address: P.O. Box 196612 Stratigraphic Service ~ ' 6. API Number: Anchorage, AK 99519-6612 50-029-20256-01-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 48.5 KB PBU 09-15A 8. Property Designation: 10. Field/Pool(s): ADLO-028324 ~ Prudhoe Bay Field/ Prudhoe Bay Pool ` 11. Present Well Condition Summary: Total Depth measured 15820 feet Plugs (measured) None true vertical 8734.7 _ feet Junk (measured) None Effective Depth measured 15731 feet true vertical 8736.17 ~ feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 94# H-40 SURFACE - 100' SURFACE - 100' 1530 520 Surface 2731' 13-3/8" 72# N-80 SURFACE - 2731' SURFACE - 2731' 5380 2670 Production 7479' 9-5/8" 47# N-80/J&L/LSURFACE - 7479' SURFACE - 6890' 6870 4760 Liner 2766' 7" 26# L-80 7304' - 10070' 6750' - 8669' 7240 5410 Liner 5904' 4-1/2" 12.6# L-80 9914' - 15818' 8567' - 8735' 8430 7500 Perforation depth: Measured depth: 15550 - 15650 = _ _ True Vertical depth: 8736.87 - 8736.76 = _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 9922' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BAKER S3 PACKER 9865' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after Droposed work' Copies of Logs and Surveys Run Exploratory Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG {~ GINJ ~' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/ if C.O. empt: 307-357 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 12/31/2007 `~'1 Form 10-404 Revis d 04/2006 u r ~~j ~ ~ ,~ ~~~~ ~~~~ Sub it Original O~nly~ ~ ~~ ~ ~/~'~ 09-15A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE ~ SUMMARY 12/25/2007 CTU #8, Acid Treat; Road unit to DS-09 from P2-32. MIRU CTU #8. Release ~ 'crews from location. Cont' on WSR 12/26/07 ... 12/26/2007 CTU #8 (Mud acid stimulation) continued from 12-25-07. finish rigging up coil unit. load IA with diesel and pressurize to 1000 psi. RIH stop @ 15357 ***job in progress'** . __ . __ 12/26/2007 CTU #8 (Mud acid stimulation) continued from 12-25-07. finish rigging up coil unit. '~,'~ load IA with diesel and pressurize to 1000 psi. RIH stop @ 15357 `' `*`job in progress'** 12/27/2007: CTU#8 Cont` WSR From 12/26/07 Mud Acid stimulation Park coil above perfs '' 15336` Injection rate is .50 bpm @ 2000 psi. pump acid treatment as per ;procedure. perform final infectivity test 2.2 bpm CC 2050 psi.(well freeze protected) ','Bleed IA to zero. Notify DSO of well status. **job complete** FLUIDS PUMPED BBLS 50 3% NH4CL + F103 10 3% NH4CL + F103 + U67 50 12% HCL 110 TOTAL WELL LOG TRANSMITTAL To: State of Alaska December 4, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 09-15A AK-MW-4971247 1 LDWG formatted CD rom with verification listing. API#: 50-029-20256-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: _ - - Signed: UZ~~a~-a22 ~ ls~ L_J ` S' .,I l /~ `~~ ~l~L~ ~"~~f~ in I r ) ~~Ll CO1~T5E8QA ATIp1~T CO~'II IISS,IGp~1~T Patti Phillips Pad Engineer BP Exploration Alaska, Inc. PO BOX 196612 Anchorage, AK 99519-6612 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-15A Sundry Number: 307-357 Dear Ms. Patti Phillips: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of November, 2007 Encl. ~~'oa~ Sincerely. 26 f STATE OF ALASKA ~~5 N~~ Zaal ALASKA OIL AND GAS CONSERVATION COMMISSI Sk8 ~~~ ~ ~~~ COi13. Commis8ion APPLICATION FOR SUNDRY APPROV Anchoraq~ 20 AAC 25.280 ~ Gry~ ~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver ^ Ot ~ Alter casing^ Repair well ^ Plug Perforations^ Stimulate [Time Extension ^ ac~ im Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ ",„_.~- 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmeni^ Exploratory ^ 207-0220 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ 6. API Number: ~ Anchorage, AK 99519-6612 50-029-20256-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 09-15A~ Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028324 ~ 48.5 KB Prudhoe Bay Field / Prudhoe Bay Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15820 ~ 8734.7 15731 - 8736.17 ~ NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 94# H-40 URFACE 100' SURFACE 100' 1530 520 Surface 2731' 13-3/8" 72# N-80 URFACE 2731' SURFACE 2731' 5380 2670 Production 7479' -5/8" 47# N-80/J&L-9 URFACE 7479' SURFACE 6890' 6870 4760 Liner 2766' 7" 26# L-80 7304' 10070' 6750' 8669' 7240 5410 Liner 5904' 4-1/2" 12.6# L-80 9914' 15818' 8567' 8735' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 15550 - 15650 8736.87 - 8736.76 4-1/2" 12.6# L-80 Surface - 9922' Packers and SSSV Type: 7"x4-1/2" Baker S3 Packer Packers and SSSV MD (ft): 9865' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/4/2007 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Patti Phillips Printed Name Patti Phillips Title Pad Engineer Signature "~ ~ ,'~; Phone 564-4578 Date 11/20/2007 ~ COMMISSION USE ONLY Conditi f l N tif i i th t C i i ~ _ S ons o approva : o y omm on so ss a a representat ve may w tness undry Number: Plug Integrity ^ BOP Test ^ Mechanical Inte r't Test ^ Location Clearance ^ Other: 3X~C7 Q9~ r~Zri~M~1M ~dp ~C Subsequent Form Required: y(\ APPROVED BY G /'~ ~ Approved by: M ONER THE COMMISSION Date: 7 Form 10-403 Revised 06/2006 V ~~ p R I G I N A Lsubmit in Duplicate F, ~' To: Jerry Bixby/Clark Olsen GPB Wells Operations Supervisor From: Patti Phillips, DS 09 Engineer Brian Sinosic - SLB Subject: 09-15Ai Mud Acid Stim Cost Code: PBD4P2592-C Capacity Sustainment Date: November 20, 2007 IOR: 800 Est. Cost: 125M Step Type Procedure 1. C CT Mud Acid stimulation, does not require an acid flowback NOTE: This coil wellwork will be charged to the Capital Drilling AFE because we have not been able to inject into the well affer the sidetrack was drilled in May 2007. WELL DATA: Status: Max Deviation: Deviation at top pert Perforation interval BHP: Min. ID: Last TD Tag: Last Downhole Ops: Last H2S: Shut-in WAG Injector 95.6 deg @ 10,689' MD 90 deg @ 15,550' 15,550' - 15,650' 3251 psi @ 8,600' - 12/26/03 3.725" @ 9,909' 06/02/07 Tractored in hole to 15650' 10/04/07 Pulled MCX plug No data If there are any questions please call: Patti Phillips: (W) 564-4578 (C) 240-3742 Jennifer Julian: (W) 564-5663 (C) 240-8037 Brian Sinosic (SLB): (W) 564-4164 (C) 223-8136 (H) 346-1755 (H) 274-0929 09-15Ai Acid Stim 11-14-07.Doc Page 1 of 6 OBJECTIVE: The objective of this procedure is to pump acid on the first 100' of perforations to increase injectivity in this new MIST injector. BACKGROUND INFORMATION: Well 09-15Ai is a new horizontal MIST injector in Zone 2C, above the 25N and the HOT, drilled and completed on 5/8/07 in the 04-09i PWI pattern. The well is a `fish-hook' horizontal MI well drilled around a central PWI injector. The plan is for the well to have 7 sets of 100' of perforated interval, with each set separated by a CIBP. MI will be injected into each set with each `plug-n-perf' MI injection cycle lasting 1-2 years. After the well was completed, 09-15Ai was initially put on water injection on 06/29/07 but would not take any injection. A short injectivity test was performed and the well took only 3/a bbl per minute at 2800 psi. On 10/5/07, a high pressure breakdown was attempted to establish injectivity, but only could inject 1 bpm at 3000 psi. PROCEDURE: Acid Treatment: 1. Trap 1000 psi on the IA. 2. MIRU CT. RIH with a 2" - 2 1/4" jet swirl nozzle with stinger as necessary (Note: Min ID = 3.725" @ 9909'). Pump the following fluid schedule while making multiple passes across the perfs (15,550' - 15,650') if possible. If CT cannot reach the perforations, park above and bullhead. Pump at maximum rate while not exceeding 2000 psi WHP*. See fluid details on the attached fluid summary sheet: 50 bbls 3% NH4C1 + F103 10 bbls 3% NH4C1 + F103 + U067 50 bbls 12% HCI 50 bbls 9:1 Regular Mud Acid 85 bbls 3% NH4CI + F103 * If needed to establish injection, go to 3000 psi WHP. When acid is on the perfs, max WHP should be 2000 psi. • Acid will not be brought back to surface; it will be pumped away. 3. Ensure that the entire overflush volume is pumped away before POOH to avoid stirring up solids. 09-15Ai Acid Stim 11-14-07.Doc Page 2 of 6 . - i ~ 4. POOH and bleed IAP. RDMO. Put well on PWI injection. • Please note the initial and final injectivities on the WSR, and record vitals when each stage hits the perfs. Ensure that all Pressure-Rate-Density (PRD) data, including WHP, are acquired and recorded in 1-s intervals. • Please note the acid titrations and iron ppm on the WSR. CC: Well Files 09-15Ai Acid Stim 11-14-07.Doc Page 3 of 6 • ScflrrrbacpOlfiddSeUa~ r &irnSirrsic ~ ~ 14-C~-t-07 Qierit: BP E~lordirnl~lcskq Ire Well Nary Oyu-lei Eriy riser : Nls, F>r11i F~-i I I i F~ Field Ru~~e Ba/ ServiceDistrid: Ru~~oeBcy Farrdion: 2C FI u d Systems: 1 50 bbls 41 Regina' MudAcid 2 50 bbls 12% HCt 0.2 % A261 Irtikita~ 0.2 % A261 Irtikitcr 0.2 % F103 Sufcda~tl; EZEFLO 0.2 °~ F103 Sufccfa-~ EZEFLO ZL1.0 ~t L058 IrrnStdiliz~r' 20.0 {fit L058 IrrnStcYiliza 0.5 % V~54 NcrrErnJsifyir~P~ 0.5 % VuJ54 Nrn-Ern.Isifyir~P~-~ 0,5 % Vu060 SIL~a~lErnlsirnFfie~a 0.5 % Slu~cr~iErn.IsirnFfie„alta 3 135 bbl s 3% NFI4CI + F 103 4 10 bbl s 3% N H4C1 + F 103 + U067 0.2 °~ F103 Suficcta~, EZEFLO 0.2 °~ F103 S~xfarfa-~ EZEFLO 25J.0 qct J285 Prnr~iun~lcrictti 2~,0 qct J285 Prrrr~ri~rri~icric~ 5,0 % U067 M~.d Sd~tr ~e BHST =155°F, v~lbrrear~drs L-BOt~.kaJQS. Ir~ikitQS ax~rrnanlsifias tobed~igx~iaardr~y. Chem od Req~.i rements: Told Ligi.,i d Load 245 kJds 9 g~ 21 g~ 1523 Ib 84 Ib 21 gj 21 gl 21 g~ A261 Iri-ikita F103 Sufat~ EZEFLO J285 Prrrr~r-i txnck 1 cri c!~ L058 IrcnStcblize 0067 M..h.d Sd~ V~ f~la~Ernlsifyir~P~tr V+,~O Na~rErnlsifyirgPgx~ 09-15Ai Acid Stim 1 1-14-07.Doc Page 4 of 6 WELL SERVICE REPORT WELL 09-15A JOB SCOPE PRESSURE TEST (RES SURV) UNIT LRS 42 DATE 10/5/2007 DAILY WORK ATTEMPT; INJECTIVITY TEST DAY SUPV CULPEPPER COST CODE PLUS PBD09WL15-R KEY PERSON LRS-ROBUSTELLINI NIGHT SUPV BOYLES MIN ID 0" DEPTH OFT TTL SIZE 0" DAILY SUMMARY _ _ _ ~ _ __ T/I/0=200/vac/vac Attempt Step Rate Test -Attempt to establish injectivity down tbg w/30 bbls 60/40 methanol water. Injectivity 1 bpm Q 3000 psi. Step rate test canceled due to low injectivity. Verify casing valves open to gauges, tag well & notif o erator. Final WHP's=50/vac/vac LOG ENTRIES Init-> 200 -0 -0 TIME .._10:00 BPM _______.._____. BBLs __.__________ FLUID ..._____________ TEMP ._._.__________ TBG ..__________ IA .._________ OA __.._..__......._ COMMENTS ._. ~....._~______..______._ _______ _ __ ________~ Start ticket, simmo s w/s-line & DHD, o en uw w/o erator 10:20 PJSM discuss hi h wind hazards 10:40 Be in RU hard line to tree ca ,flan e u to IA 11:30 Finish RU, s of in & RU trans rots, fuel unit 12:10 PJM wICH2MHil{, LRS crews & co re 12:37 BP challen er on location, site/'ob orientation & safet briefin 12:51_ ____ P_T lines to tree cap & IA to 4000 psi 13:03 ~ _____ Good t, ressure up ssv & function test m_ _ 13:10 Line u to um tb 13:17 0.7 sU0 60/40 meth 250 vac vac Start um tb w/60/40 meth-water, walkin u rate 13:19 3 4 350 vac vac 13:20 1 9 2000 vac vac Reduce rate 13:22 0.6 10.5 2100 vac vac Reduce rate 13:23 0.45 11 2175 vac vac Reduce rate 13:27 13:30 13:32 0.45 0.3 0.3 13 14 15 2250 2200 2175 vac vac vac vac vac vac Rate steady, TP slowly climbi, n~....__.__~e___~_,~. _~ Reduce rate, co rep discussing wltown _ _ 13:34 0.75 16 2350 vac vac Increase rate 13:36 1 17 2550 vac vac Increase rate 13:38 1 19 2750 vac vac TP slowl climbin 13:39 1 20 ~ 2775 vac vac Increase rate to 1.3 b m 13:40 1.3 21 2850 vac vac .13:41 13:42 ....._...._________ 13:43 1.3 1 _~...______ 1 22 23.5 __., _._._.. 25 __~. __... .e____ 3000 3000 ~ ___..r 3000 vac vac ~ ___ _ _ vac vac vac _e____ vac Reduce rate to 1 bpm _____________.__..~...._....________ _~...__ _ _..~._ __..~e____.__ TP stead 3000 si C~3 1 b m 13:48 1 30/sd 60/40 meth 3000 vac vac Shutdown 13:49 2800 vac vac Static ressures C~ shutdown 13:58 1000 vac vac 10 min static ressures 14:08 500 vac vac 20 min static ressures 14:18 300 vac vac 30 min static ressures, be in RD 15:18 50 vac vac Static pressures, rig down complete, finish paper work, tag well, verif casin valves o en to au es 15:40 Stand b for Ian forward for 2-trans orts kcl & um 15:58 Send transports to freeze protect plumbing, stand by C~ shop for water 'ob 16:15 Notif o erator of well status & results 16:59 End ticket Final 50 -0 -0 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST _ _ CUMUL_TOTAL _ _ ~ ~ CH2MHILL LABOR $450 $2,370 EQUIPMENT FLEET $563 $4,763 LITTLE RED LITTLE RED PLUS 20 PERCENT -_~_e__ _ _- _ ~ - - __ $8,824 _ _ ~~ $1,764 . $16,996 $3,398 ~~~~ ~ e ______ -- .--- --- -- -°°-_ ORBIS _~~°" $1,300 $1,300 09-15Ai Acid Stim 11-14-07.Doc Page 5 of 6 L WAREHOUSE ~ $2,088 $2,136 SCHLUMBERGER $0 ~ $3,555 SCHLUMBERGER PLUS 10 PERCENT ~ $0 $356 TOTAL FIELD ESTIMATE: $14,989 $34,874 FLUID SUMMARY 30 bbls 60/40 methanol water WELL SERVICE REPORT WELL JOB SCOPE UNIT 09-15A SIDETRACK SWS 2150 DATE DAILY WORK DAY SUPV 6/2/2007 CEMENT BOND LOG--SCMT/USIT BOYLES COST CODE PLUS KEY PERSON NIGHT SUPV PBD4P2592-D SWS-WIBLE LYNCH MIN ID DEPTH TTL SIZE 3.725 " 15730 FT 4.5 " DAILY SUMMARY INITIAL T/I/O=0/0/0 FINAL T/I/0=0/0/0 SSV CLOSED ON ARRIVAL. MASTER VALVE CHAINED CLOSED ON ARRIVAL. MAX TOOLSTRING LENGTH=67.1'. MAX OD=2.125" CONTINUE FROM 01-JUNE-2007. LOGGED SCMT PASS UP AT 30 FPM FROM 9400'-15650'. TIED INTO SLB USIT LOG DATED 6-MAY-07 USING GAMMA RAY NEAR 9700'. FOUND TOP OF CEMENT AT 9952'. PUSHED DEBRIS DOWN HOLE W/TRACTOR FROM 10900' TO TD. TRACTORED IN HOLE TO 15650'. LOG JEWELRY PASS FROM 10300' TO 5380' TO CONFIRM TIE-IN WITH USIT DATED 08-APRIL-2007. USIT LOG WAS RUN TO 7500' AND IS BEHIND MULTIPLE STRINGS OF PIPE. TOP OF CEMENT IDENTIFIED AT 9960'. SSV CLOSED ON DEPARTURE. MASTER CLOSED ON DEPARTURE. LOG ENTRIES Init Tb , IA, OA -> 0 0 0 TIME COMMENT 00:01 CONTINUED FROM PREVIOUS DAY 00:10 WEIGHT CHECK AT 14700', 3000 LBS, CONTINUE TRACTORING IN HOLE AT 1500 FPH. 01:16 TRACTORING SLOW FROM 15100'. 0_1:58 ON BOTTOM, STOP TRACTORING, START LOGGING UP AT 30 FPM. ~~ 05:15 DOWN LOGGING, POOH ~_~_~~ 06:43 OOH, SHUT SWAB, BLEED DOWN, UNSTAB, RIG BACK SCMT AND TRACTOR. 07:13 TOOLS RIGGED DOWN, WAITING TO HEAR IF PE WANTS A BETTER JEWELRY LOG. COLLARS ARE WEAK DUE TO CENTRALIZED TOOLSTRING FOR SCMT. IF PE WANTS BETTER COLLARS, ANOTHER RUN IS NECESSARY. 07:26 RELIEVED CONFIRMATION THAT PE WANTS BETTER JEWELRY LOG, RU, CORRELATION TOOL 08:09 RIH WITH GR/CCL FOR JEWELRY PASS. TOTAL TOOLSTRING LENGTH=20.7'. MAX OD =1 11/16". TOOLSTRING: MH-22, SWIVEL, ERS, 2 X 1 11/16" WEIGHT BARS, UPCT. 09:10 LOG GR/CCL JEWELRY PASS FROM 10300 TO 5380' TO CONFIRM TIE INTO USIT LOG DATED 08-APRIL- __ 2007. _ 10:28 OUT OF HOLE WITH WIRELINE. 11:25 COMPLETE RIG DOWN OF ELINE AND THIRD PARTY CRANE. 11:50 MOBILIZE TO SHOP. F inal Tb , IA, OA -> 0 0 0 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL ______~.._____. __._._____._~__~e_~~_~~_______________ r.____._____. _______________._______________________ ORBIS _ _~~~~_~~~_~_~_®__..__ $1,000 _ $1,000 SCHLUMBERGER $157,809 $161,215 VECO $692 $792 TOTAL FIELD ESTIMATE: $159,501 $163,007 FLUID SUMMARY NONE SAFETY NOTES MASTER VALVE CHAINED CLOSED ON ARRIVAL.SSV CLOSED ON ARRIVAL. COMMUNICATION WITH THIRD PARTY CRANE IMPORTANT. 09-15Ai Acid Stim 1 1-14-07.Doc Page 6 of 6 S ~ Page 1 of 1 Preble, Gary B (SAIC) From: Phillips, Patti J Sent: Tuesday, November 20, 2007 12:27 PM To: G ANC PDC Subject: 09-15Ai CT Mud Acid Stim Attachments: 09-15Ai Acid Stim 11-14-07.doc Gary, Here is the pgm for 09-15Ai acid job. Can you please prepare a sundry for me? Let me know what I need to do and when I can send the pgm to the slope. Thanks, Patti 11/20/2007 TREE, ~ FMC GEN 1 WELLHEAD = FMC ACTUATOR=~ _ AXELSON KB. ELEV = 54' _... . BF. ELEV = KOP = 3355' Max Angle = Datum MD = Datum TVD = 8800' SS ~° SAF OT ES: w _' 2279' ~ 9-5/8" 40#,L-80 TCII,(8.835" ID) 2007.54' 4-1/2" X Nipple, ID = 3.813" 2279' HES 9-5/8" ES Cementer 13-3/8" CSG, 72#, N-80, ID = 12.347" ~-i 2731' Minimum ID = 3.725" @ 9909.08' 4-1/2" XN NIPPLE TOC 9500' PERFORATION SUMMARY REF LOG: ANGLEATTOPPERF: 90° ~cr) 15550' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 15550 - 15650 Opn 05/06/07 9-5/8" CSG, 47#, N-80, ID = 8.681" I-i 10040' DATE REV BY COMMENTS 09/08/77 ORIGINAL COMPLETION 10/05/87 LAST WORKOV ER 01/26/07 JEN Proposed sidetrack 05/09/07 MS/DM Sidetrack/Perf NABOBS G 05109107 MGSfPAG DRLG DRAFT CORRECTIC FO Cementers 2400` and 2523' 7304' 7" Hanger /liner top packer 7,479' 9 5/8" Window 9843.95' 4 1/2" X Nipple (3.813" ID) 9864.78' 7" x 4 1/2" Baker S3 Packer 9888.33' 4 1/2" X Nipple (3.813" ID) 9909.08' 4 1/2" XN Nipple (3.725" ID) 9914' 4 1/2" Hanger /liner top packer 9920.17' 4 1/2" WLEG 10070' 7" 26# L-80 (6.276" ID) 4 1/2" 12.6#, L-80 IBT-M, 3.958" ID 15818' PBTD = 15730` ~,. TE REV BY COMMENTS PRUDHOE 8AY UNf1- WELL: 09-15A PERMfI- No: 1770360 API No: 50-029-20256-01 SEC 1, T10N, R15E, 4163.84' FEL & 1134.65' FNL BP Exploration (Alaska) Date 09-20-2007 Transmittal Number:92904 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) have anv questions, Dlease contact llou~las llortch at trie YllC: at Jf)4-4y /s Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 15A ao"~-v9~ `~ ~Stl~l __ I-10A~o~-~3S '~ i5~/$a ___ _ _ _ __ F-09Bao~-~~3 ~ ~5~/1f5 F-42A 2U~ ° US 3 '~ ~ 5~1Kta L-204L1 a(~Co-pcj3 ~'t5~/~~- L-204L2 a oto - Og ~l " ~S~/~~l L-204L3 a(U(o-OAS "t5~1~ L-204L4 8 U(o-p~j f, '~ t 5~! ~} d N-22B c7U(o -!!o / ~ /55/9 / V-205L1 r.7UCo - l?f f' ~ I S~l^7 a V-205L2 aUCo-I `1~c7 z` 153 W-204L1_c?C~(o-159_' t..'S~°i_</ _ W-204L2_av~_-/~O ~'1~~/45 WG1-09_-~'zc ~aL - 1y~6 ~ ~5 ~9~ Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2- l 900 E. Benson Blvd. PO Box 19661.2 Anchorage, AK 995 19-66 1 2 i b' • ~ Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Friday, July 20, 2007 11:21 AM To: Saltmarsh, Arthur C (DOA) Subject: PBU 09-15A / PTD # 207-022 Hi Art, Please reference the following well: Well Name: PBU 09-15A Permit #: 207-022 API #: 50-029-20256-01-00 This welt began Injection on June 29, 2007 as a Produced Water Injector There is no well test data. ~~~~ BFI ~~~. ~' +~ 1DD7 7/26/2007 MEMORANDUM TO: Jim Regg P.I. Supervisor ~Q~~ 7~(~U~ FRONT: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 11, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-15A PRUDHOE BAY UNIT 09-15A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv "/'~ Comm Well Name: PRUDHOE BAY UNIT 09-15A API Well Number: 50-029-20256-01-00 Inspector Name: Chuck Scheve It1Sp Num: mitCS070709165648 Permit Number: 207-022-0 Inspection Date: 2/g/2oo7 ,.~ Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~, o9-ISA ype Inj. ~ W ~I TVD I ass6 TA ~ a6o ~ zszo ~ zaso zaao j zo~o22~ eTest~rTest ~ psi P.T.D, 'TYP 2134 I OA ~ o I o I o ~ o _ _ Interval IrrIrAL p~ P ,/ Tubing ~ _ 1600 1 o I6oo ~ I6oo Notes: Pretest pressures observed and found stable. Wednesday, July 11, 2007 Page 1 of I STATE OF ALASKA ~~ DECEIVED ~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 0 7 2pQ7 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oii & Gas Cons. Commission 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.,05 2oAAC 2s.,,o ^ GINJ ^ WINJ ^ WDSPL ®WAG ^ Other No. of Completions One 1b. Well Class: f1C 01'a~8 ^ Development ^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aba 5/9/2007 12. Permit to Drill Number 207-022 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 4/007 ~~ 13. API Number 50-029-20256-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 5/3/2007/ 14. Welt Name and Number: PBU 09-15A FSL, 150 FWL, SEC. 01, T10N, R15E, UM 994 Top of Productive Horizon: 4529' FSL, 512' FEL, SEC. 02, T10N, R15E, UM 8. KB (ft above MSL): 48.5' Ground (ft MSL): 20' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2436' FSL, 1578' FEL, SEC. 35, T11 N, R15E, UM 9. Plug Back Depth (MD+TVD) 15731 8736 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 718542 y- 5942466 Zone- ASP4 10. Tota! Depth (MD+TVD) 15820 8735 16. Property Designation: ADL 028324 TPI: x- 717775 y- 5945981 Zone- ASP4 Total Depth: x- 716615 y- 5949136 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted informati n er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIR / GR, RES / PWD, DIR / GR /RES / ABI, USIT 1~//~/.dOw ~ s~~1~ ir1D 6~'y~/.S8'Tyd 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD" SETTING DEPTH TVD f jOL~' AMOUNT Wi. PER FT. GRADE ' TOP BOTTOM ° "TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 100' Surf ce 10 ' 32" 258 sx Arcticset II 13-3/8" 72# N-80 Surface 2731' Surface 2731' 17-1/2" 6200 sx AS II 175 sx AS II 9-5/8" 47# N-80 / J&L-95 Surface 7 Surface 6890' 12-1/4" 1000 sx 'G', 300 sx AS II & 787 sx'G' 7" 26# L-80 7304' 10070' 675 ' 86 8-1/2" 176 sx LiteCrete 168 x I s'G' 4-1/2" 12.6# L-80 9914' 15818' 8567' 8735' 6-1/8" 705 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24' TUBING RECORD If Yes, IISt each Interval Open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter 6 spf 4-1/2", 12.6#, L-80 9922' 9865' , MD TVD MD TVD 15550' - 15650' 8737 - 873T 25.' AeID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Ei KIND OF MATERIAL USED Freeze Protect w/ 151 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCf: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULAreo 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical result ~AC,-~5Q.071. .~' ~_t:.:.,. None ~~ JUL ~-~2~~~ . ~ 0r~=--~ ""-.' lF Form 10-407 Revised 02/2007 ~ A ~ONTINUED ON REVERSE SIDE ~~ / ,, 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. CM3 7620' 6998' None CM2 8260' 7490' CM1 9114' 8056' Top HRZ 9764' 8473' Base HRZ 10063' 8664' LCU /Top Zone 4 10103' 8690' 31 P /Top Zone 3 10130' 8708' 27P /Top Zone 2C 10189' 8747' 26P 10291' 8807' Formation at Total Depth (Name): 26P 10291' 8807' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. ~ ~ Signed Terrie Hubble " ) Title Technical Assistant Date Q~ Q PBU 09-15A 207-022 FreparedByNameMumber. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Phil Smith, 564-4897 Permit No. / A royal No. INSTRUCTIONS GeNewu: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: 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. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory infomtation 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: 09-15 Common Name: 09-15 Test Date Test Type Test Depth (TMD) ~ Test Depth (TVD) AMW Surface Pressure ~ Leak Off Pressure (BHP) EMW 4/15/2007 FIT 7,507.0 (ft) 6,913.0 (ft) 9.00 (ppg) 650 (psi) 3,882 (psi) 10.81 (ppg) 4/24/2007 FIT 10,099.0 (ft) 8,674.0 (ft) 8.40 (ppg) 725 (psi) 4,510 (psi) 10.01 (ppg) Printed: 5/10/2007 11:41:04 AM ~ i BP EXPLORATION Page 1 of 19 Operations Summary Report Legal Well Name: 09-15 Common Well Name: 09-15 Event Name: REENTER+COMPLETE Start: 4/6/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/9/2007 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To Hours Task % Code ~ NPT Phase -- -- - - !_ I -i__ _ I_ 4/5/2007 18:00 - 00:00 ~ 6.00 ~ MOB ~ P ~ ~ PRE 4/6/2007 100:00 - 04:00 I 4.001 RIGU I P 04:00 - 04:30 I 0.501 RIGU I P 05:00 - 06:30 0.50 BOPSUR P 06:30 - 07:30 I 1.001 BOPSUR P 07:30 - 08:30 I 1.001 BOPSUR P 08:30 - 09:00 0.50 BOPSU P 09:00 - 09:30 0.50 BOPSU P 09:30 - 11:00 I 1.501 BOPSUR P 11:00 - 11:30 0.50 BOPSU~ P 11:30 - 12:00 0.50 BOPSU P 12:00 - 15:00 I 3.001 BOPSUf~ P 15:00 - 17:00 2.00 BOPSU P 17:00 - 18:00 1.00 BOPSU P 18:00 - 20:00 2.00 BOPSU P 20:00 - 22:30 2.501 BOPSUFt P 22:30 - 00:00 1.50 BOPSU P 4/7/2007 00:00 - 10:00 10.00 BOPSU P 10:00 - 12:00 2.00 BOPSU N 12:00 - 16:30 4.50 BOPSU N 16:30 - 17:30 1.00 BOPSU N Spud Date: 8/10/1977 End: 5/9/2007 Description of Operations Split complexes and move pit complex away from sub. Move sub off well 09-11. Move rig and spot over DS 09-15. Spot cuttings tank and support buildings. Berm rig and Plt areas,complete Pre-Spud check list. Hold Pre-Spud meeting with all personnel. Rig accept 04:00 04/06/2007. Install secondary annulus valve. Rig up circulating hoses for displacing diesel through choke to cuttings tank. PJSM. Rig up DSM lubricator and pull BPV. 0 psi on tubing and annulus. PJSM. Rig up return line to tree. Test secondary kill line to 3500 psi and mud line to 5000 psi. PJSM. Displace Diesel trom tubing 140 GPM @ 330 psi. Switch lines to pump down the tubing,taking returns to cuttings tank. PJSM. Circulate seawater surface to surface,240 GPM ~ 530 psi. Blow down line to cuttings box. Rig down circulating lines. PJSM. Install TWC and test from below to 1000 psi,good test. Blow down kill line and rig down hose. PJSM. Bleed control lines off,nipple down tree & adaptor flange,remove from cellar. Attempt to make up crossover and blanking plug into hanger,no go. Threads damaged,unable to test BOP as blanking plug would not go into hanger. Obtain RKB measurements. Nipple up BOP's. PJSM. Rig up DSM lubricator,pull BPV. PJSM.Rig up Camco spooling unit,make up spear,engage tubing hanger,back out lock down screws. Pick up on hanger,free with 170k pull. Tubing wt. 145k. Lay down hanger & 2 tubing joints. Make up crossovers to test plug. Permission from AOGCC rep Tom Maunder to pull hanger and two joints of tubing prior to installing test plug and testing BOP. Rig up & test BOP's and all related valves to 250 psi low and 4000 psi high. Test Hydril to 250 psi low and 2500 psi high. Test witness waived by AOGCC rep Jeff Jones. Test witnessed by BP rep Blair Neufeld (WSL) and Nabors drilling rep Bruce Simonson. Test BOP's and all related valves to 250 psi low and 4000 psi high. Test Hydril to 250 psi low and 2500 psi high. Test witness waived by AOGCC rep Jeff Jones. Test witnessed by BP rep Blair Neufeld (WSL) and Nabors drilling rep Bruce Simonson. Kill line HCR valve and 3 1/2" x 6" variable rams failed. Drain BOP and blow down all surface lines. PJSM. Change upper rams to 5 1/2" pipe rams. PJSM Change out kiII,HCR. Test upper rams and kill HCR to 250 psi low and 4000 psi high. PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE SFAL PRE SFAL PRE SFAL PRE Printed: 5/10/2007 11:31:20 AM BP EXPLORATION Operations Summary Report Legal Well Name: 09-15 Common Well Name: 09-15 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date ;From - To i Hours Task ~ Code NPT i 4/7/2007 16:30-17:30 1.00 BOPSU~N SFAL 17:30 - 18:00 0.50 BOPSU P 18:00 - 19:00 1.00 PULL P 19:00 - 21:30 2.50 PULL P 21:30 - 00:00 2.50 PULL P 4/8/2007 00:00 - 03:00 3.00 PULL P 03:00 - 09:00 6.00 DHB P 09:00 - 10:00 1.00 DHB P Start: 4/6/2007 Rig Release: 5/9/2007 Rig Number: Page 2 of 19 ~ Spud Date: 8/10/1977 End: 5/9/2007 Phase Description of Operations PRE Test kill hose and flanges to 250 psi low and 4000 psi high. DECOMP Rig down test equipment,pull test plug to rig f-oor. Break and lay down crossovers,clearftoor. DECOMP Rig up 5 1/2" tubing equipment. Rig up Camco control line spooler. DECOMP PJSM. Lay down 5 1/2" tubing from 7600' to 5393'. Rig down spooling unit. Recovered 27 SS bands (31 on record) and SSSV. DECOMP Lay down 5 1/2" tubing from 5393' to 1825' DECOMP Lay down tubing from 1825' to surface. Recovered total of 183' full joints and one 22.11' cut off joint. Rig down tubing handling equipment and clear floor of tools. DECOMP Spot wireline truck and rig up to run wireline logs. DECOMP Run gauge ring, junk basket,CCL, and gamma logs to tubing cut off at 7680'. Tools came back clean,change out tools, 09:00 - 12:00 3.00 DHB P DECOMP Make up and run EZSV to 7524',failed to set. 12:00 - 15:30 3.50 DHB N DFAL DECOMP Pull tools out and trouble shoot. Run back in to set EZSV at 7524'. EZSV set 5' above coupling. 15:30 - 16:30 1.00 DHB P DECOMP Set EZSV at 7524',POOH and make up USIT tool. 16:30 - 00:00 7.50 CLEAN P DECOMP Run USIT log to 7500',iog up to surface. Found different weights of casing,run in hole to 2600' re-log to surface. 4/9/2007 00:00 - 01:30 1.50 CLEAN P DECOMP Log out of hole with USIT. Lay down USIT tool. 01:30 - 03:30 2.00 CLEAN P DECOMP Re-head E-line for string shot. Make up and arm string shot on rig floor. 03:30 - 05:00 1.50 CLEAN P DECOMP Run in hole with string shot to 2400'. Log up from FO collar for correlation. Set string shot off over collar at 1857'. Pull tool out of hole. 05:00 - 05:30 0.50 CLEAN P DECOMP Rig down wireline unit. 05:30 - 06:30 1.00 CLEAN P DECOMP PJSM. Make up Baker casing cutter assembly . 06:30 - 08:00 1.50 CLEAN P DECOMP PJSM. Run in hole from 11' to 1877' picking up pipe from pipe shed. Install blower hose. 08:00 - 09:00 1.00 CLEAN P DECOMP Break circulation,locate and verify collar C~31846'.Pull up 16' to 1830' 09:00 - 09:30 0.50 CLEAN P DECOMP Rig up Little Red Hot Oil to cement manifold and test lines. Rig up circulating lines from annulus to cuttings tank. 09:30 - 11:00 1.50 CLEAN N WAIT DECOMP Wait on orders. 11:00 - 13:00 2.00 CLEAN P DECOMP Run in hole to 2312',break circulation and locate collar at 2289'. Pick up to 2273',open knives and cut casing. 13:00 - 14:00 1.00 CLEAN P DECOMP Close Hydril,circulate down drill pipe and out annulus to cuttings tank. Pressure broke over at 570 psi,verify circulation,20 SPM 250 psi. Open well and open cutters to verify cut. Close Hydril and establish circulation to cuttings tank,4 BPM ~ 950 psi. Blow down circulating lines and rig up head pin. Arctic pack Printed: 5/10/2007 11:31:20 AM ~ ~ BP EXPLORATION Page 3 of 19 ~ Operations Summary Report Legal Well Name: 09-15 Common Well Name: 09-15 Spud Date: 8/10/1977 Event Name: REENTER+COMPLETE Start: 4/6/2007 End: 5/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/9/2007 Rig Name: NABOBS 2ES Rig Number: Date From - To 4/9/2007 13:00 - 14:00 14:00 - 16:00 16:00 - 17:30 Hours I Task ~ Code ~ NPT i 1.00 CLEAN P 2.00 CLEAN P 1.50 CLEAN P Phase Description of Operations DECOMP coming back very thick -vac trucks can't pick fluid up DECOMP Take sample and wait on results of flash point test from PBOC lab to verify supersuckers can take the material on board safely. DECOMP Circulate down pipe with diesel. Close Hydril, circulate 149 bbl. 90 degree diesel up 9 5/8" x 13 3/8" annulus to cuttings tank with Little Red Hot Oil Services at 2 BPM. DECOMP Wait for diesel to soak in 9 5/8" x 13 3/8" annulus. DECOMP Pump remaining 40 bbl. 120 degree diesel, and 40 bbl soap pill. Displace with 290 bbl clean seawater. Blow down surface equipment, remove blower hose. DECOMP PJSM. POH from 2273' to BHA. Service break cutter, clear floor. DECOMP Change upper rams to 9 5/8". DECOMP Pressure test door seals to 4000 psi, good test. Pull test plug, rig down test equipment. DECOMP PJSM. Make up Baker spear assembly. DECOMP Engage spear, back out lock down screws. Pull hanger free with 165k, and casing broke free at 185k. Free up wt. 130k. Pull hanger to floor, rig up false bowl and casing tongs. Break out hanger & spear, lay down. Change out elevators. Close bag and reverse circulate diesel out of casing to cuttings tank. Pull and lay down 9-5/8" casing from cut at 2273'. Recovered 56 full joints, 11 centralizers and cut joint of 25.46'. Break out torque ranged from 12k to 44k. Rig down casing equipment. Clear and clean floor. DECOMP Install wear ring. Pick up washpipe and scraper tools to rig floor. Make up washpipe BHA to 351'. Change out handling equipment. DECOMP RIH to 1284'. Circulate out arctic pac. RIH to 2218'. Install blower hose. DECOMP Wash down to 2289'. Mill up centralizer. Wash down to 2308'. Wash over several times. DECOMP Circulate bottoms up at 230 gpm with 150 psi. Rotate and reciprocate. Up and down weight 80k. Circulate 40 bbls soap pill and 110 degree seawater around at 380 gpm with 350 psi. Large amount of arctic pack circulated out. POH to 1190'. Load pits with 110 degree seawater. Circulate BU at 420 gpm with 320 psi. Rotate and reciprocate. Blow down top drive. DECOMP POH to 351'. Change out handling equipment. POH with collars to 75'. DECOMP PJSM. Break BHA. Clean arctic pack from floor. Lay down scraper, XO's, float sub, junk sub, bumper sub and washpipe assembly. Clear junk subs -empty. Clear and clean floor. DECOMP PJSM. Spot and rig up SWS. Run string shot. Tie in and fire across coupling to be backed off at 2300' ELMD - (2289' DPM). POOH and rig down SWS. DECOMP PJSM. Run drill collars. Pick up and make up backoff tool BHA to 325'. Fill with fresh water. DECOMP RIH to 2560'. Fill every other stand with fresh water. PU single DP and make up pump in sub. Space out across collar at 2289'. Line up test pump. Pressue up to 1300 psi and set bottom anchor. Pressure up again to 1700 psi and shear upper 17:30 - 18:30 1.00 CLEAN P 18:30 - 20:30 2.00 CLEAN P 20:30 - 22:00 1.50 CLEAN P 22:00 - 23:00 1.00 CLEAN P 23:00 - 00:00 1.00 CLEAN P 4/10/2007 00:00 - 02:00 2.00 STCTPL P 02:00 - 13:30 11.50 STCTPL P 13:30 - 16:30 I 3.001 CLEAN I P 16:30 - 18:00 I 1.501 CLEAN I P 18:00 - 19:00 I 1.001 CLEAN I P 19:00 - 23:00 I 4.00 I CLEAN I P 23:00 - 00:00 I 1.001 CLEAN I P 14/11/2007 100:00 - 03:30 I 3.501 CLEAN I P 03:30 - 07:00 ~ 3.50 ~ CLEAN ~ P 07:00 - 09:30 I 2.501 FISH I P 09:30 - 12:30 I 3.00 I FISH I P Printed: 5/10/2007 11:31:20 AM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: - Date ~ From - To 4/11/2007 09:30 - 12:30 12:30 - 13:30 13:30 - 15:30 15:30 - 16:00 16:00 - 17:00 17:00 - 18:30 4/12/2007 09-15 09-15 REENTER+COMPLETE NABOBS ALASKA DRILLING NABOBS 2ES Hours Task ~ Code ~ NPT t ~ I 3.00 ~ FISH I P 1.00 FISH P 2.00 FISH P 0.50 I FISH I P 1.00 FISH P 1.50 FISH P 18:30 - 18:30 24.00 FISH P 18:30 - 20:30 2.00 FISH P 20:30 - 23:00 2.50 CASE P 23:00 - 00:00 1.00 CASE P 00:00 - 07:30 7.50 CASE P 07:30 - 08:30 1.00 (CASE ( P 08:30 - 10:00 1.50 CASE P 10:00 - 12:00 2.00 CASE P 12:00 - 12:30 0.50 CASE P 12:30 - 13:30 1.00 CASE P 13:30 - 14:30 ( 1.00 (CASE ~ P 14:30 - 15:15 I 0.751 CASE I P 15:15 - 16:00 I 0.751 CASE I P 16:00 - 21:30 I 5.501 BOPSUFi P Start: 4/6/2007 Rig Release: 5/9/2007 Rig Number: Page 4 of 19 Spud Date: 8/10/1977 End: 5/9/2007 Phase j Description of Operations DECOMP anchor. Casing connection broke at 2000 psi. Approximately 20k ft/Ibs. Cycle back off tool a total of 6 turns. Rig down test hose. Release from casing stump. DECOMP POOH to 320'. Change out handling equipment. DECOMP Service break back off tool and lay down. Rack back drill collars. Clear and clean floor. DECOMP Make up 9-5/8" spear assembly. RIH to 21'. Change out handling equipment. DECOMP RIH to 2260'. DECOMP Wash down to top offish at 2273' at 122 gpm with 60 psi. Engage fish to 2281'. Turn off pumps. Turn pipe 10 times to the left and pick up fish. DECOMP POOH to 21'. DECOMP Release from 9-5/8" casing stump. Stump measured 14.97'. Break and lay down bumper sub and spear. Clear and clean floor. DECOMP Pick up and install long bales. Rig up 9-5/8" casing equipment. DECOMP PJSM. Make up screw in sub assembly. DECOMP Run 56 jts 9-5/8" 40# L-80 TC-II casing tieback to stub at 2289'. Had near miss when picking up 2nd joint of casing, with joint falling approximately 12 to 18 inches back onto skate due to side door elevators coming unlatched. See remarks. Space out with pup jt to keep coupling away from wellhead area. MU XO to top drive. DECOMP Tag stub with screw in sub. Engage same and rotate to make up SIS to stub. MU to 10 klbs torque and work torque down to SIS. Made up a total of 16 turns. Pull test to 175 klbs over up weight - OK. Pressure test casing to 2000 psi for 5 min - OK. DECOMP LD XO from top drive. RU cement head and lines. DECOMP PU 100 klbs over string weight. Pressure up and shear open ES cementer at 2500 psi. Circulate 110 deg seawater around wellbore until 85 deg returns. DECOMP PJSM w/ cementers & crew. DECOMP RU cementers. Hook up feed lines from rig & test same. Air up & prime up. DECOMP Pump 2 bbls water. Test lines to 4000 psi. Pump 3 bbls water followed by 164 bbls (790 sx) Class G cement at 15.8 ppg. 6.3 bpm G 1400 psi -start. 3.9 bpm ~ 450 psi -end. DECOMP Release closing plug and kick out with 5 bbls water. Displace with seawater at 8 bpm ~ 850 psi. Caught cement at 80 bbls away - 1050 psi ~ 8 bpm. SD pumping, close annular and open line from wellhead direct to cuttings tank at 120 bbls away. Continue displacement and saw cement returns to surface at 145 bbls away. Slow displacement to 2.5 bpm C~ 1000 psi. Bump plug at 179 bbls away -got back 34 bbls slurry to surface. Pressure up to 2500 psi and close ES cementer - OK. CIP at 1500 hrs. Release pressure and RD line from cement head. Open valve on head and verify cementer closed. DECOMP Flush ROPE with seawater with retarder to cuttings tank. Flush lines and mud manifold. Rig down cement head. Pick up weight on 9-5/8" casing at 200k. DECOMP Nipple down BOP stack. Split stack and casing spool and lift off. Install 9-5/8" emergency slips slack off and set with 100k. Printed: 5/10/2007 11:31:20 AM BP EXPLORATION Page 5 of 19 Operations Summary Report Legal Well Name: 09-15 Common Well Name: 09-15 Spud Date: 8/10/1977 Event Name: REENTER+COMPLETE Start: 4/6/2007 End: 5/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/9/2007 Rig Name: NABOBS 2ES Rig Number: Date I From - To Hours Task Code ~ NPT 4/12/2007 16:00 - 21:30 5.50 BOPSUf~ P 4/13/2007 00:00 - 02:00 2.00 80PSUR P 02:00 - 05:00 3.00 BOPSUF{ P 05:00 - 07:00 ~ 2.00 BOPSUp P 07:00 - 08:00 1.00 CLEAN I P 08:00 - 10:30 2.50 CLEAN P 10:30 - 11:00 0.50 CLEAN P 11:00 - 15:00 4.00 CLEAN P 15:00 -.15:30 I 0.501 CLEAN I P 15:30 - 17:30 I 2.001 CLEAN I P 17:30 - 18:00 0.50 CLEAN P 18:00 - 22:00 4.00 CLEAN P 22:00 - 23:00 I 1.001 CLEAN I P 23:00 - 00:00 I 1.001 CLEAN I P 4/14/2007 00:00 - 03:30 3.50 CLEAN P 03:30 - 06:30 3.00 CLEAN P 06:30 - 08:00 1.50 STWHIP P 08:00-12:30 4.50 STWHIP P 12:30 - 17:00 4.50 STWHIP P 17:00 - 18:00 1.00 STWHIP P ~1n 1tt:UU- 09~~SA Phase ~ Description of Operations DECOMP Cut 9-5/8" casing with Wach's cutter. Lay down cut joint of 31.51'. Nipple down tubing spool. Stand back stack. Remove. old tubing spool and bring in new tubing spool. DECOMP Install 9-5/8" packoff and new tubing spool. DECOMP PJSM. Install tubing spool and test packoff to 2400 psi for 15 minutes. Test OK. DECOMP PJSM. Nipple up BOP stack. Change out top rams from 9-5/8" to 3-1/2" x 6" variables. DECOMP PJSM. Make up test joint. Install test plug and test rams, doors and flange to 250 psi low, 4000 psi high as per AOGCC. Test witness waived by Chuck Scheve with AOGCC. Install wear ring and lay down test joint. DECOMP PJSM. Pick up tools to rig floor. DECOMP PJSM. Make up BHA to 43'. RIH with drill collars form derrick to 318'. Pick up heavy weight and RIH to 964'. Change handling equipment. DECOMP RIH to 2177'. Up and down weight 95k. DECOMP Install blower hose. Wash down to cement at 2207'. Drill cement to 2250' at 400 gpm with 540 psi. RPM 50 with 5-7k WOB. Drill cement to ES Cementer at 2278'. Drill up ES cementer to 2285'. Torque at 4-7k with 50 rpm, WOB 5-10k. DECOMP Circulate BU. Test upper casing to 3000 psi for 5 minutes. Test OK. DECOMP Drill baffle plate and plug at 2286'. Ream to 2302' work through several times. Circulate BU. Remove blower hose. Install air slips. Blow down top drive. DECOMP PJSM. RIH from derrick to 3204'. DECOMP PJSM. Pick up 4" DP and RIH to EZSV. Tag EZSV at 7501'. Down weight 150k, up weight 180k, RT 165k. Rotate and stack 30k down on bottom. DECOMP Pump hi-vis sweep surface to surface at 490 gpm with 1805 psi. DECOMP Line up and test casing to 4000 psi for 30 minutes and record on chart. Test OK. DECOMP PJSM. Bleed off and blow down top drive. POOH to 964'. DECOMP PJSM. Rack back HWDP and drill collars. Break bit. Break and lay down BHA. Clear and clean floor. WEXIT PJSM. Pick up whipstock BHA. WEXIT PJSM. Make up MWD and upper mill to 89'. Orient toolface. Upload MWD. Make up top drive and surface test MWD. Pump at 400 gpm with 410 psi. Test OK. Pick up whipstock slide. Make up bullnose. Line up and install shear bolt. Pick up and RIH with remaining BHA to 992'. Pick up and RIH with HWDP to 1046. Change out elevators. Install air slips. WEXIT RIH with whipstock assembly to 7480'. WEXIT Make up top drive. Break circulation and orient to 80 degrees left. Down weight 145k, up weight 187k. Install blower hose. Make up last stand and tag at 7502'. Set anchor with 20k down. Confirm with 10k overpull. Slack off and shear lug with 30k down. Pick up and confirm free. Torque 7k at 70 rpm. RT weight 170k. Pump at 400 gpm with 1500 psi. WEXIT Pump 40 bbl hi-vis spacer o lowed by 9.0 ppg L ND mud at 500 gpm with 1200 psi. Pump mud surface to surface. Shut Printed: 5/10/2007 11:31:20 AM ~ ~ BP EXPLORATION Page 6 of 19 ~ Operations Summary Report Legal Well Name: 09-15 Common Well Name: 09-15 Spud Date: 8/10/1977 Event Name: REENTER+COMPLETE Start: 4/6/2007 End: 5/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/9/2007 Rig Name: NABOBS 2ES Rig Number: Date From - To 4/14/2007 18:00 - 20:00 Hours Task ' Code ~ NPT ( Phase -- ~ Description of Operations 20:00 - 00:00 4/15/2007 100:00 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 07:30 07:30 - 08:30 08:30 - 11:00 11:00 - 15:30 15:30 - 16:30 16:30 - 20:00 20:00 - 23:00 23:00 - 00:00 4/16/2007 00:00 - 01:00 01:00 - 03:30 03:30 - 12:00 12:00 - 16:30 16:30 - 18:30 2.00 STWHIP P WEXIT 4.00 STWHIP P WEXIT 2.00 STWHIP P WEXIT 1.00 STWHIP P WEXIT 1.00 STWHIP P WEXIT 3.50 STWHIP P WEXIT 1.00 STWHIP P WEXIT 2.50 STWHIP P WEXIT 4.50 STWHIP P WEXIT 1.00 STWHIP P WEXIT 3.50 STWHIP P WEXIT 3.00 STWHIP P WEXIT 1.00 STWHIP P WEXIT 1.00 STWHIP P WEXIT 2.50 DRILL N SFAL INT1 8.50 DRILL P INT1 4.50 DRILL P INT1 2.00 DRILL N DPRB INT1 down. Clean shakers and troughs. Change out screens. SPR's both pumps, 30/300, 45/350. Mill window from top at 7479' to 7492'. Torque 6-9k at 100 rpm. Pump at 400 gpm with 1140 psi. WOB 3-7k. Continue to mill 8-1/2" window. Top of window at 7479', bottom of window at 7496'. Mill 20' of new formation from middle of window to 7507'. Ream through window several times. Pull through window without rotation. Window looks good with no hang ups. Torque 6-9k at 100 rpm. WOB 3-5k. Pump at 400 gpm with 1148 psi. Up weight 170k, down weight 155k, RT 165k. Pump hi-vis sweep surface to surface until clean. Mud weight in and out 9.0 ppg. Pull one stand into window and prepare to pertorm FIT. Recovered 160 Ibs of metal PJSM. Perform FIT to 10.8 ppg EMW. Blow down top drive and kill line. PJSM. Slip and cut drilling line. Change out spool PJSM. Service top drive, drawworks and crown. Make up top drive. Establish circulation. Pump dry job. Blow down top drive. POOH to 1022'. Change out handling equipment. POOH with HWDP to 377'. Clear and clean floor. PJSM. Lay down drill collars and bumper sub. Break and service float. Flush MWD tools with fresh water. Break and lay down mill, and joint of HWDP. Clear and clean floor. Starting mill 1/8" under gauge, string mill full gauge. Pick up test joint. Pull wear ring. Make up flushing tool and flush out BOP stack. Function rams and hydril. Blow down choke and kill lines. Install wear ring. Lay down tool. PJSM. Pick up motor. Make up bit, float sub and MW D tool then scribe. Make up TM collar with probe. Upload MWD. Pick up Flex DC's. Pick up and RIH with HWDP. Make up XO and 1st stand to 820'. Surface test MWD. Pick up and RIH with 4" DP singles to 3624'. Fill pipe and test MWD. RIH to 6332' and fill pipe. PJSM. RIH to 7452'. Make up top drive. Install blower hose. Orient tool at 70 degrees left. Pump at 450 gpm with 1535 psi. SPR's #1 30/280, 45/350, #2 30/280, 45/340. Mud weight in and out 9.0 ppg. Reboot MWD computers. Troubleshoot and bring on line. Slide through window with no problem. Drill ahead to 7887'. Pump at 480 gpm with 2150 psi on bottom, 1890 psi off bottom. Torque 6-7k on bottom, 4-5k off bottom at 50 rpm. WOB 5-10k. Up weight 165k, down 140k, RT 155k. Drill ahead to 8105' MD, 7368' TVD. Up weight 170k, down 145k, RT 160. Torque on bottom 5-7k, off bottom 4-5k at 50 rpm. WOB 4-10k. Pump at 500 gpm with 2330 psi on bottom, 2150 psi off bottom. Trouble shoot MWD survey problems. Rack back 1 stand. Cycle pumps. Stagger pump speed. Increase flow rate. Clean suction screens and check pulsation dampners. Pre-Charge. All Good. Discovered steady decrease in pump pressure. Printed: 5/10/2007 11:31:20 AM BP EXPLORATION Page 7 of 19 Operations Summary Report 'Legal Well Name: 09-15 Common Well Name: 09-15 Spud Date: 8/10h 977 Event Name: REENTER+COMPLETE Start: 4/6/2007 End: 5/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/9/2007 Rig Name: NABOBS 2ES Rig Number: Date From - To j Hours Task Code NPT Phase ~ Description of Operations 4/16/2007 16:30 - 18:30 ~ 2.00 DRILL N DPRB INT1 ~ Check surface equipment. Treat mud for aeration. Cycle 18:30 - 19:30 I 1.001 DRILL I N I DPRB I INT1 19:30 - 20:30 I 1.001 DRILL I N I DPRB I INT1 20:30 - 22:30 I 2.001 DRILL I N I DPRB I INT1 22:30 - 00:00 I 1.501 DRILL I N I DPRB I INT1 14/17/2007 100:00 - 01:30 I 1.501 DRILL I N I DPRB I INT1 01:30 - 12:00 I 10.501 DRILL 1 P 12:00 - 00:00 I 12.001 DRILL I P 14/18/2007 100:00 - 08:00 I 8.001 DRILL I P 08:00 - 12:00 I 4.001 DRILL I P 12:00 - 14:30 2.50 DRILL P 14:30 - 15:30 1.00 DRILL P 15:30 - 18:00 I 2.501 DRILL I P INT1 INT1 INT1 INT1 INT1 INT1 INT1 pumps again. Loss of 700 psi. Suspect washout in DP, or tools downhole. Blow down top drive. PJSM. POOH to 7452' wet and pull inside window. Remove blower hose. Clean floor. Install air slips. Pick up and rig up Geo-Pilot manifold on rig floor while DP not blocking access. Continue to POOH wet. Found washout in DP 2' above pin end on stand 40. Change out joint. Make up top drive and pressure test. Pressure within limits of earlier pressures recorded at 3700' during pipe fill and MWD check. RIH to 7358'. Pull air slips. Make up top drive. Orient to 80 degrees left. Install blower hose. PJSM. MU top drive. Check pressures inside window - OK. RIH from 7538' to 7826' with no problems. Make up top drive. Wash down last 2 stands to 8105'. Up weight 170k, down weight 140k. Pump at 480 gpm with 1985 psi. SPR's both pumps, 30/350, 45/410. Directionally drill from 8105' to 8664' MD. 502 gpm, 2298 psi off btm, 2510 psi on btm PU Wt. - 175k, SO - 150k, RT - 160k Torque off btm - 5k, Torque on btm - 7 k WOB 15k. RPM - 70 CECD = 9.52 ppg, AECD = 9.65 ppg. From 00:00 - 12:00, AST - 3.38 hr, ART - 1.74 hr, ADT - 5.12 hr. Directionally drill from 8664' to 9220' MD. 510 gpm, 2550 psi off btm, 2750 psi on btm PU Wt. - 185k, SO - 145k, RT - 167k Torque off btm - 5k, Torque on btm - 7k WOB 15k. RPM - 80 CECD = 9.53 ppg, AECD = 9.72 ppg. From 12:00 - 00:00, AST - .98 hr, ART - 8.50 hr, ADT - 9.48 hr. Directionally drill from 9220' to 9500' MD. 510 gpm, 2560 psi off btm, 2780 psi on btm PU Wt. - 185k, SO - 145k, RT - 167k Torque off btm - 5-6k, Torque on btm - 7-9k WOB 15k. RPM - 80 CECD = 9.53 ppg, AECD = 9.72 ppg. From 00:00 - 08:00, AST - 3.31 hr, ART - 4.62 hr, ADT - 7.93 hr. Pump 30 bbt High-vis sweep followed by blending 270 bbls of 16.0 ppg spike fluid with black product raising mud weight to 11.0 ppg in the active system. Circulate until consistent mud properties around. Final circulating pressure with new mud wt. 3286 psi ~ 490 gpm. Mud Wt in and out 11.0 ppg. Shut down and monitor well, Static. Obtain SPR's MP #1) C~ 30 spm = 450 psi, @ 45 spm = 540 psi. MP #2) ~ 30 spm =440 psi, ~ 45 spm = 540 psi. POH with no problems to 7510' MAD Pass from 7510' to 7300' ~ 300 fph for correlation tie in logs as per geology. Pump dry job, install air slips and POH from 7300' to 822' Printed: 5/10/2007 71:31:20 AM BP EXPLORATION Page 8 of 19 Operations Summary Report Legal Well Name: 09-15 Common Well Name: 09-15 Spud Date: 8/10/1977 Event Name: REENTER+COMPLETE Start: 4/6/2007 End: 5/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/9/2007 Rig Name: NABOBS 2ES Rig Number: i Date From - To ~ Hours Task ~ Code NPT Phase Description of Operations 4/18/2007 18:00 - 19:00 1.00 DRILL P INT1 PJSM, Stand back HWDP, Jars, & Flex DC's 19:00 - 20:00 1.00 DRILL P INT1 Down-load MWD 20:00 - 21:30 1.50 DRILL P INT1 Flush BHA with water, blow down top drive, Break and lay down MW D tools, Motor, & bit. Clean and clear rig floor of vendors tools. 21:30 - 00:00 2.50 DRILL P INT1 PJSM, Pick up directional BHA #3 toots to rig floor. Load MWD probe in TM collar & MU Security FSF2565 bit, to Geo-Pilot, remove reference housing clamp. 4/19/2007 00:00 - 02:00 2.00 DRILL P INT1 MU BHA #3 consisting of, Bit /Geo-Pilot TL 150 / TM / NM GP DM FDC/ Smart STB / RES-GR-PW D /Smart STB / HCIM / TM / NM Float Sub, 02:00 - 03:00 1.00 DRILL P INTi Up-Load MWD Tool 03:00 - 03:30 0.50 DRILL P INTi Shallow test MWD C~ 77', with 450 gpm 768 psi 03:30 - 04:00 0.50 DRILL P INT1 Cont' RIH with remaining Flex DC's, HWDP to 834' MU Centurion Circ Sub and ball catcher on top of Jar. 04:00 - 04:30 0.50 DRILL P INT1 RIH w/BHA #3 on 4" drill pipe to 3,730' 04:30 - 06:00 1.50 DRILL P INT1 PJSM, MU top drive and fill pipe, Test Geo-Span to 3000 psi. Good test. Pump at 483 gpm 1772 psi. and rotate at 5 - 10 - 20 - 60 RPM to break in bearings. Test Down-Link on Geo-Pilot. Tools working properly. Break out top drive and blow down all equipment. 06:00 - 07:00 1.00 DRILL P INTi RIH to 7485', MU Top drive and break circulation with 402 gpm 1951 psi. 07:00 - 08:00 1.00 DRILL P INT1 Circulate and condition mud, Check shot servey, Break out and blow down top drive, install blower hose on same. 08:00 - 09:30 1.50 DRILL P INT1 RIH from 7485' to 9418'. No problems on trip in open hole section. MU Top drive and wash to bottom C~ 9500' w/ 451 gpm 2854 psi, 60 rpm, Torque 6k 09:30 - 12:00 2.50 DRILL P INT1 Directionally drill from 9500' to 9606' MD. 500 gpm, 3291 psi off btm, 3421 psi on btm PU Wt. - 190k, SO - 140k, RT - 162k Torque off btm - 5-6k, Torque on btm - 8-12k WOB 15k. RPM - 100 SPR's @ 9509' MD MP#1) 30 SPM - 400 psi. 45 SPM - 500 psi. MP#2) 30 SPM - 410 psi. 45 SPM - 490 psi. CECD = 11.63 ppg, AECD = 11.74 ppg. ART - 1.97 hr 12:00 - 15:15 3.25 DRILL P INT1 Directionally drill from 9606' to 9792' MD. 500 gpm, 3450 psi on btm PU Wt. - 198k, SO - 145k, RT - 170k Torque off btm - 5-6k, Torque on btm - 8-12k WOB 15k. RPM - 120 CECD = 11.64 ppg, AECD = 11.74 ppg. ART - 2.91 hr 15:15 - 16:00 0.75 DRILL N DFAL INT1 Investigate loss in pump pressure. Loss 1100 psi. in 20 min. Check rigs surface equipment &Geo-Span manifold. All surface equipment checked out good. Suspect washout in DP, or BHA. Blow down top drive. Bottoms up achieved during trouble shoot. Mud weight in and out 11.0 ppg. 16:00 - 18:00 2.00 DRILL N DFAL INT1 POH from 9792' to 7460' wet looking for washout. Encountered 30k over-pull at 9350', wiped clean, no other Printed: 5/10/2007 11:31:20 AM s BP EXPLORATION Operations Summary Report Page 9 of 19 ~ Legal Well Name: 09-15 Common Well Name: 09-15 Spud Date: 8/10/1977 Event Name: REENTER+COMPLETE Start: 4/6/2007 End: 5/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/9/2007 Rig Name: NABOBS 2ES Rig Number: Date I From - To Hours Task Code NPT Phase Description of Operations 4/19/2007 16:00 - 18:00 2.00 DRILL N DFAL INT1 problems in open hole section. Monitor well, Blow down top drive, remove blower hose, and install air slips. 18:00 - 19:30 I 1.501 DRILL I N I DFAL I INT1 19:30 - 21:30 I 2.001 DRILL I N I DFAL I INT1 21:30 - 22:00 I 0.501 DRILL I N I DFAL 1 INT1 22:00 - 22:30 0.50 DRILL N DFAL INT1 22:30 - 00:00 1.50 DRILL P INT1 4/20/2007 100:00 - 06:00 I 6.001 DRILL I P I I INT1 06:00 - 07:30 1.50 DRILL P INT1 07:30 - 08:15 0.75 DRILL P INT1 08:15 - 09:00 0.75 DRILL P INT1 09:00 - 10:00 1.00 DRILL P INT1 10:00 - 12:00 2.00 DRILL P INT1 12:00 - 12:30 0.50 DRILL P INT1 12:30 - 15:30 3.00 DRILL P INT1 15:30 - 17:30 2.00 DRILL P INT1 17:30 - 19:00 1.50 DRILL P INT1 19:00 - 20:00 1.00 DRILL P INT1 20:00 - 20:30 0.50 DRILL P INT1 20:30 - 21:30 I 1.001 DRILL I P I I INT1 21:30 - 22:30 1.00 DRILL ~ P INT1 22:30 - 23:00 0.50 BOPSU P LNR1 Cont' POH to 6408' where washout was found in the friction weld area below the box end tooljoint. LD and replaced joint of drill pipe. MU top drive and pressure test drill string @ 400 gpm 1900 psi, compared to pressures taken at 7465' on trip in. Good test. Blow down top drive. RIH from 6408' to 9330', held up @ 9330' Encountered 20k excess down wt at 8785' to 8815' worked through without problem. MU top drive, establish circulation and ream from 9290' to 9380' x2. Kill pumps and rotary and run through dry, no problems. Continue RIH from 9380' to 9700', MU top drive and wash last stand to bottom @ 9792' Directionally drill from 9792' to 9868' MD. 500 gpm, 3650 psi on btm PU Wt. - 195k, SO - 140k, RT - 165k Torque off btm - 5-6k, Torque on btm - 7-12k WOB 15k. RPM - 120 CECD = 11.55 ppg, AECD = 11.57 ppg. ART - 1.36 hr Directionally drill from 9868' to TD @ 10079` MD. 475 gpm, 3310 psi on btm PU Wt. - 195k, SO - 147k, RT - 166k Torque off btm - 7-8k, Torque on btm - 7-12k WOB 15k. RPM - 120 CECD = 11.44 ppg, AECD = 11.58 ppg. ART-4.64 hr Pump 40 bbl High-Vis Sweep around surface to surface ~ 500 gpm 3399 psi, Rotary 120 rpm until hole cleaned up. CECD = 11.44 ppg, AECD = 11.58 ppg. Mud wt. in and out 11.0 ppg POH Short trip from 10079' up to 8700'. No problems RIH from 8700' to 10079'. No problems, no fill on bottom. Pump 40 bbl High-Vis Sweep around surface to surface @ 500 gpm 3400 psi, Rotary 120 rpm until hole cleaned up. CECD = 11.44 ppg, AECD = 11.55 ppg. Mud wt. in and out 11.0 ppg. POH from 10079' up to 7465'. No problems Monitor well at the window, static. Pump dry job, blow down top drive, remove blower hose, install air slips. Cont' POH to 2600' PJSM, POH LD 57 jts. drill pipe 1x1 PJSM, LD 5" HWDP, NM Flex DC's, & Drlg Jar. Down-Load MWD MU top dirve and flush Geo-Pilot /MWD assembly with 20 bbls water, Break out and blow down top drive. LD MWD &Geo-Pilot, Bit. One missing and one broken roller on Geo-Pilot reference housing. Clean and clear rig floor of vendors tools. Drain BOP stack, pull wear bushing & install test plug Printed: 5/10/2007 11:31:20 AM BP EXPLORATION Page 10 of 19 Operations Summary Report Legal Well Name: 0 9-15 Common W ell Name: 0 9-15 Spud Date: 8/10/1977 Event Nam e: REENTE R+COM PLET E Start : 4/6/2007 End: 5/9/2007 Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 5/9/2007 Rig Name: NABOBS 2ES Rig Number: Date From - To ~ Hours Task Code NPT Phase ~ Description of Operations 4/20/2007 23:00 - 00:00 1.00 BOPSU P LNR1 Change out top set of rams to 7" 4/21/2007 00:00 - 01:30 1.50 BOPSU P LNR1 Cont' Change out top set of rams to 7" 01:30 - 02:30 1.00 BOPSU P LNRi PJSM, RU & test BOP bonnets to 250 psi low 3500 psi high. RD test equipment, Install wear bushing. Blow down equipment. Test Witnessed by Matt Turcotte (NAD), Chris Clemens (WSL) 02:30 - 03:00 0.50 CASE P LNR1 RU 7" casing equipment. 03:00 - 07:30 4.50 CASE P LNR1 PJSM, MU 7" Shoe Track, Baker-l_oc first 3 joints to insert landing collar. Fill pipe and check floats, floats held. Run total of 67 jts. 26# L-80 BTC-M 7" liner filling every joint on the fly, MU to position 8400 fUlbs, Install Centralizer floating as follows, 1 per jt 1-2, 2 per jt 3-14 1 per jt 15-62 1 per jt 65-66 07:30 - 08:00 0.50 CASE P LNR1 Change out elevators, PU & MU Baker 7" x 9-5/8" HMC Liner Hanger & ZXP Liner Top Packer, RIH w/ same on 1 std. 4" DP. 08:00 - 09:00 1.00 CASE P LNR1 MU top drive & circulate 1.5 Liner volume ~ 126 gpm, 220 psi. Liner Wt's. Up 90k, Dn. 80k Blow down top drive. 09:00 - 10:30 1.50 CASE P LNR1 PJSM, RIH with 7" liner on 4" DP filling every 10 stds ran from 2875' to 4929' @ 90 FPM max running speed. 10:30 - 11:00 0.50 CASE N RREP LNR1 Repair failed hydraulic hose on iron roughneck. 11:00 - 13:00 2.00 CASE P LNR1 RIH from 2875' to 8.5" window 7449' ~ 90 FPM max running speed. 13:00 - 14:00 1.00 CASE P LNR1 MU Top Drive and establish circulation , 171 gpm, 581 psi, increase rate up to 220 gpm, 599 psi, Circulate 1.5 Liner / DP volume. String Wt. Up 170k, Dn 130k, Blow down top drive. 14:00 - 15:00 1.00 CASE P LNR1 RIH from 7449' to 10059' ~ 60 FPM max filling pipe on the fly. No problems running through open hole section. 15:00 - 15:30 0.50 CASE P LNR1 PU liner cement head, circulating lines, made up on single DP, MU same to string and RIH & tag bottom ~ 10079', No fill on bottom. 15:30 - 21:00 5.50 CASE P LNR1 Establish circulation and stage pumps as follows, 1 bpm, 445 psi / 2 bpm, 539 psi / 3 bpm, 650 psi / 4 bpm, 787 psi / 5 bpm, 943 psi. Circulate and condition mud for cement. No losses while running or circulating liner through out job. PJSM, with rig crew, Schlumberger Cementers, Veco truck drivers. Spot cement trucks and RU same. Start Batch Mix cement 19:15 hrs. 21:00 - 23:00 2.00 CEMT P LNR1 Switch over to Dowell and pump 5 bbl H2O through Tee, Test lines to 4500 psi. Flush H2O out of lines w/ 11.6 ppg Mud Push I I, Pump 40 bbl's Mud push @ 4.5 bpm, followed by 71 bbl's 12.4 ppg LiteCRETE GASBLOK Lead, Switch and pump 35 bbls 15.73 ppg Class G GASBLOK Tail @ 4.5 bpm, Drop and kick out wiper plug w! 5 bbls H2O. Switch over to rig and displace cement C~3 5 bpm, slowed pumps to 3 bpm to latch up plug w/ 1132 stks, increase rate to 5 bpm slowing to 3 bpm to bump. Bumped plug w/ 170 bbls mud away 2929 stks. (CIP ~ Printed: 5/10/2007 11:31:20 AM s ~ BP EXPLORATION Page 11 of 19 ~ Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date i __ Name: 0 ell Name: 0 e: Name: From - To ' 9-15 9-15 REENTE NABOB NABOB Hours R+COM S ALASK S 2ES Task j i PLET A DRI Code i E LLING NPT Start I Rig Rig Phase ~ Spud Date: 8/10/1977 : 4/6/2007 End: 5/9/2007 Release: 5/9/2007 Number: Description of Operations 4/21/2007 21:00 - 23:00 2.00 CEMT P LNR1 22:50 Hrs.) Increase pressure to 3500 psi to set HCM liner hanger, SO to 95K, hanger set, bleed off pressure and check floats, Held. confirm hanger set w/o pressure. PU to netural wt. and rotate 20 turns to the right to release f/ hanger. Pressure up to 1000 psi and PU to release seals ramping pumps up to 400 gmp 2090 psi. and circulate 40 bbls up hole. reduce pumps to 3 bpm and SO w/ rotating dog sub @ 20 rpm and set liner top packer, positive indication w/ 75k do continue do to 50k, repeat xi . Full returns through out job. 23:00 - 00:00 1.00 CEMT P LNR1 PU 14' ramping pumps up to 500 gpm 3000 psi and circulate mud push & approximately 25 bbls excess cement out of the hole while reciprocating pipe. 4/22/2007 00:00 - 01:00 1.00 CEMT P LNR1 Monitor well, Static. Break and LD cement head and single DP. Blow down all lines. 01:00 - 02:00 1.00 CEMT P LNR1 Slip & Cut 136' of Drilling Line. 02:00 - 02:30 0.50 CEMT P LNR1 Pump dry job & blow down top drive. 02:30 - 05:30 3.00 CEMT P LNR1 POH, & LD C2 Running Tool. 05:30 - 06:00 0.50 BOPSU P LNR1 MU Running tool and pull wear bushing. Mu and install test plug. 06:00 - 07:00 1.00 BOPSU P LNR1 PJSM, Change out top set of rams to 3-1/2" x 6" VBR's 07:00 - 08:00 1.00 BOPSU P LNR1 PJSM, Change out lower well control valve on top drive to 4-1/2" IF, C/O grabber die blocks and stabbing guide to 5". 08:00 - 09:00 1.00 BOPSU P LNR1 PJSM, & RU BOP test equipment. 09:00 - 16:30 7.50 BOPSU P LNR1 Test BOP and all associated 4" & 5" equipment to 250 psi low / 4000 psi High, 2500 Psi annular Test, Perform accumulator Test, as per BP, Nabors, & AOGCC policies. Witness of test waived by Lou Grimaldi (AOGCC Inspector), Test witness by Bill Decker (WSL), Cleve Coyne (NAD), Toby Bordelon (NAD) 16:30 - 17:00 0.50 BOPSU P LNRi RD test equipment, Install wear bushing, Blow down equipment. Clear rig floor. 17:00 - 17:30 0.50 CEMT P LNR1 PJSM, PU 5" mule shoe and 5" slip segments to rig floor. 17:30 - 23:30 6.00 CEMT P LNR1 PJSM, MU 5" mule shoe and RIH picking up 189 jts. 5" drill pipe 1x1 to 5945'. Pipe heavily scaled, rabbit sticking in pipe. 23:30 - 00:00 0.50 CEMT P LNR1 MU Top Drive and circulate 357 bbls to clean residual scale out of drill pipe, 500 gpm 1098 psi. Mud weight in and out of hole 11.0 ppg. 4/23/2007 00:00 - 03:00 3.00 CEMT P LNR1 POH standing back 63 stds 5" DP. 03:00 - 04:30 1.50 DRILL P PROD1 PJSM, PU BHA #4 tools to the rig floor. 04:30 - 07:30 3.00 DRILL P PROD1 MU Directional BHA #4 as follows, Hughes 6-1/8" MX-18HDX / 4-3/4" BHM / MN Flt Sub / NM Stb / DM / RLL / TM / 3x NM Flex DC's / 3 x 3.5" HW DP /Jar / 2 x 3.5" HWDP /Ball Catcher / Centurion Circ Sub / XO / 07:30 - 08:00 0.50 DRILL P PROD1 MU Top drive and shallow test MWD at 474', 250 gpm, 1440 psi. Blow down top drive and C/O handling equipment to 4" 08:00 - 11:30 3.50 DRILL P PROD1 PJSM, RIH from 474' to 7938' Fill pipe C~? 3180', 250 gpm, 1680 psi. Fill pipe @ 5982', 250 gpm, 2000 psi. 11:30 - 12:00 0.50 DRILL P PROD1 PJSM, C/O handling equipment to 5", and RIH from 7938' to 8032' 12:00 - 15:30 3.50 DRILL P PROD1 PJSM, Perform D1 Kick while tripping & D6 Stripping Drill. Strip in the hole 3 stands allowing crewmembers to work the choke. Printed: 5/10/2007 11:31:20 AM i ~ BP EXPLORATION Page 12 of 19 Operations Summary Report Legal Well Name: 09-15 Common Well Name: 09-15 Spud Date: 8/10/1977 Event Name: REENTER+COMPLETE Start: 4/6/2007 End: 5/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/9/2007 Rig Name: NABOBS 2ES Rig Number: Date ;From - To Hours I Task I Code I NPT I Phase 4/23/2007 12:00 - 15:30 3.501 DRILL P PROD1 15:30 - 16:30 1.00 DRILL P PROD1 16:30 - 17:30 1.00 DRILL P PROD1 17:30 - 18:30 1.00 BOPSU P PROD1 18:30 - 21:30 I 3.001 DRILL I P I I PROD1 21:30 - 00:00 2.501 DRILL P PROD1 4/24/2007 ~ 00:00 - 02:30 ~ 2.50 (DRILL ~ P ~ ~ PROD1 02:30 - 03:00 0.501 DRILL P PROD1 03:00 - 04:30 1.50 DRILL P PROD1 04:30 - 05:00 0.50 DRILL P PROD1 05:00 - 12:00 I 7.001 DRILL I P I I PROD1 12:00 - 00:00 I 12.001 DRILL I P I I PROD1 4/25/2007 100:00 - 04:00 I 4.001 DRILL I P I I PROD1 04:00 - 05:30 1.50 DRILL P PROD1 05:30 - 08:00 2.50 DRILL P PROD1 08:00 - 08:30 I 0.501 DRILL I P I I PROD1 Description of Operations Bleed off pressure, open well, POH 3 stds, LD IBOP & Floor safety valve, blow down choke manifold. RIH from 8032' to 9918' MU Top Drive, Install blower hose, CBU C~ 255 gpm, 2295 psi PJSM, RU and test 7" Liner x 9-5/8" casing to 4000 psi for 30 min and record on chart. Bleed off pressure and blow down kill line. Wash ~ 100 gpm, 735 psi, from 9918' to tag TOC ~ 9976' increase rate to 250 gpm, 2190 psi and drill cement & Flt equipment from 9976' to 10057', 10' above shoe w/ 40 RPM, 7500 ft/Ibs TO, 12k WOB, LC ~ 9986' FC @ 10027' PJSM, Pump 50 bbl H2O followed by 45 bbl High-Vis sweep & chase w/ 575 bbls 8.4 ppg Flo-Pro SF mud at 269 gpm, 2232 psi, 50 rpm, rotate and recipricate pipe. Up Wt 180k, Dn Wt 160k, Rt Wt 170k. Obtain SPR's & Drill cement from 10057' to shoe ~ 10070' and clean out rat hole to 10079' 260 gpm, 1500 psi, 40 RPM, TO 3-4k off btm, 4-5k on btm, WOB 5k Slight packing off at 10074' wash and ream area to clean up. Samples show Slitstone Shale SPR's MP #1&#2) 30 SPM, 530 psi, ~ 45 SPM, 640 psi at 10057' MD Drill New Hole from 10079' to 10099' 260 gpm, 1500 psi off btm, 1600 psi on btm, 40 RPM, TO 3-4k off btm, 4-5k on btm, WOB 12k CBU @ 260 gpm, 1520 psi, 40 rpm PJSM & perform FIT to 10.0 EMW @ 8674' TVD Test MW 8.4 ppg, Surface test pressure 721 psi Drill from 10099' to 10328' 270. gpm, 1650 psi off bottom and 1800 psi on bottom. 12k WOB, 60 RPM, TO 4-5k off bottoma & 5-7k on bottom. Drill 6 1/8" hole from 10,328' to 10,481'. Up wt. 190k,down wt. 155k,rotating wt. 175k. 270 GPM,1670 psi off bottom and 1800 psi on bottom. RPM 20,off bottom torque 4k & on bottom 5k. Mud wt in and out 8.4ppg, running water at 4/5 BPH. Drill 6 1/8" production hole from 10,481' to 10,563'. Up wt. 190k,down wt. 155k,rotating wt. 175k. 270 GPM,1670 psi off bottom and 1800 psi on bottom. RPM 20,off bottom torque 4k & on bottom 5k. Mud wt in and out 8.4ppg, running water at 4/5 BPH. ROP slowed to 7 FPH while rotating. Circulate bottoms up. PJSM. POOH 10,563' to 7938'.Monitor well,pump dry job,remove blower hose,and blow down top drive at 10,013'. PJSM. Change out handling equipment from 5" to 4". Drop ball to open circulating sub,pump ball down at 128 GPM C~ 675 psi. Circ sub opened at 2000 psi. Pump dry job,blow down top drive. Printed: 5/10/2007 11:31:20 AM • BP EXPLORATION Page 13 of 19 Operations Summary Report ',Legal Well Name: 09-15 'Common Well Name: 09-15 Spud Date: 8/10/1977 Event Name: REENTER+COMPLETE Start: 4/6/2007 End: 5/9/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/9/2007 Rig Name: NABORS 2ES Rig Number: Date ;From - To Hours Task Code ; NPT Phase Description of Operations 4/25/2007 08:30 - 12:00 3.50 DRILL P PROD1 PJSM. POOH from 7938' to 380',close circ sub at 475'. 12:00 - 13:30 1.50 DRILL P PRODi PJSM. Change out handling equipment. Break out circ sub,retrieve 2 balls. Rack back HWDP and flex collars. 13:30 - 14:00 0.50 DRILL P PROD1 Make up top drive and flush BHA with fresh water. 14:00 - 14:30 0.50 DRILL P PROD1 PJSM. Break out bit and plug into MWD. 14:30 - 15:00 0.50 DRILL P PROD1 PJSM. Download MWD and clean rig floor. i 15:00 - 15:30 0.50 DRILL P PROD1 Lay down MWD and mud motor,pick up new MWD. 15:30 - 16:00 0.50 DRILL P PROD1 PJSM.Pick up 5" mud motor and make up PDC bit. 16:00 - 17:00 1.00 DRILL P PROD1 Make up BHA,scribe motor bend to MWD. 17:00 - 18:00 1.00 DRILL P PROD1 Upload MWD tool. 18:00 - 19:00 1.00 DRILL P PROD1 Pick up flex collars and HWDP,change out handling equipment. 19:00 - 19:30 0.50 DRILL P PROD1 Shallow pulse test MWD,279 GPM ~ 1007 psi. Blow down top drive. 19:30 - 00:00 4.50 DRILL P PROD1 Run in hole from 473' to 10,013' fill pipe and test MW D every 30 stds. 4/26/2007 00:00 - 01:00 1.00 DRILL P PROD1 Run in hole from 10,013 to 10,563'. 01:00 - 12:00 11.00 DRILL P PROD1 Drill 6 1/8" production hole from 10,563' to 10,924'. Up wt. 185k,down wt. 155k,rotating wt. 175k. 290 GPM, 1840psi off bottom and 2080 psi on bottom. RPM 50,off bottom torque 4k & on bottom 5-7k. Mud wt in 8 5.ppg and out 8.6ppg, running water at 10 BPH. Running mud cleaner and centrifuge to control drilled solids. 12:00 - 00:00 12.00 DRILL P PROD1 Drill 6 1/8" production hole from 10,924' to 11,473'. Up wt. 185k,down wt. 155k,rotating wt. 175k. 290 GPM, 2033 psi off bottom and 2210 psi on bottom. RPM 50,off bottom torque 4-5k & on bottom 5-7k. Mud wt in 8 7.ppg and out 8.7 ppg, running water at 10 BPH. Running mud cleaner and centrifuge to control drilled solids. Had Swaco rep to rig to adjust cetrifuge to assit in weight control and 5 out of 8 shaker screeens changed from 250 to 325. 4/27/2007 00:00 - 12:00 12.00 DRILL P PROD1 Drill 6 1/8" production hole from 11,473' to 12,228'. Up wt. 190k,down wt. 155k,rotating wt. 175k. 290 GPM, 1979 psi off bottom and 2225 psi on bottom. RPM 80,off bottom torque 6k & on bottom 7k. Mud wt in 8 7.ppg and out 8.7 ppg, running water at 10 BPH. Running mud cleaner and centrifuge to control drilled solids. 12:00 - 00:00 12.00 DRILL P PROD1 Drill 6 1/8" production hole from 12,228' to 12,764'. Up wt. 205k,down wt. 140k,rotating wt. 175k. 310 GPM, 2210 psi off bottom and 2400 psi on bottom. RPM 80,off bottom torque 8-9 k & on bottom 9-10 k. Mud wt in 8 7.ppg and out 8.7 ppg, running water at 10 BPH. Running mud cleaner and centrifuge to control drilled solids. MI solids control van added to the sytem at 19:OOhrs. ~i4/28/2007 00:00 - 12:00 12.00 DRILL P PROD1 Drill 6 1/8" production hole from 12,764' to 13,088'. Up wt. 205k,down wt. 140k,rotating wt. 175k. 310 GPM, 2250 psi off bottom and 2425 psi on bottom. RPM 80,off bottom torque 8-9 k & on bottom 9-10 k. Mud wt in 8 7.ppg and out 8.7 ppg, running water at 10 BPH. Running mud cleaner, centrifuge and MI solidis control unit to Printed: 5/10/2007 11:31:20 AM BP EXPLORATION Page 14 of 19 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 0 ell Name: 0 e: Name: From - To 9-15 9-15 REENTE NABOBS NABOBS Hours R+COM ALASK 2ES Task ~ PLET A DRI Code E LLING NPT Start I Rig Rig Phase Spud Date:. 8/10/1977 : 4/6/2007 End: 5/9/2007 Release: 5/9/2007 Number: Description of Operations 4/28!2007 00:00 - 12:00 12.00 DRILL P PROD1 control drilled solids. 12:00 - 00:00 12.00 DRILL P PROD1 Drill 6 1/8" production hole from 13,088' to 13,520'. Up wt. 205k,down wt. 140k,rotating wt. 180k. 310 GPM, 2200 psi off bottom and 2440 psi on bottom. RPM 80,off bottom torque 8 k & on bottom 9 k. Mud wt in 8 6+.ppg and out 8.7 ppg, running water at 10 BPH. Running mud cleaner, centrifuge and MI solidis control unit to control drilled solids. Van processing 1.5 bbls/min. Lubricants increased to 3%. 4/29/2007 00:00 - 12:00 12.00 DRILL P PROD1 Drill 6 1/8" production hole from 13,520' to 13,837. ', Up wt. 210k,down wt. 140k,rotating wt. 180k. 310 GPM, 2250 psi off bottom and 2440 psi on bottom. i RPM 80,off bottom torque 8 k & on bottom 9 k. Mud wt in 8 7.ppg and out 8.7+ ppg, running water at 10 BPH. Running mud cleaner, centrifuge and MI solidis control unit to control drilled solids. Van processing 1.5 bbls/min. Lubricants running at 3%. 12:00 - 14:00 2.00 DRILL P PROD1 Drill 6 1/8" production hole from 13,837' to 13,876'. Up wt. 205k,down wt. 140k,rotating wt. 180k. 310 GPM, 2250 psi off bottom and 2470 psi on bottom. RPM 80,off bottom torque 8 k & on bottom 9 k. Mud wt in 8 6.ppg and out 8.7 ppg, running water at 10 BPH. Running mud cleaner, centrifuge and MI solidis control unit to control drilled solids. Van processing 1.5 bbls/min. Lubricants running at 3%. 14:00 - 16:00 2.00 DRILL P PROD1 PJSM. Circulate Hi-Vis sweep surface to surface. Monitor well. 16:00 - 18:30 2.50 DRILL P PROD1 PJSM. POOH pumping from 13,876' to 12,085',61 GPM @ 420 psi. 18:30 - 20:00 1.50 DRILL P PROD1 POOH from 12,085' to 10,013'. Hole in good condition and took correct amount of displacement. 20:00 - 21:30 1.50 DRILL P PROD1 PJSM. Drop ball and pump down at 2 BPM. Open circ sub at 1950 psi and pump Hi-Vis surface to surface,504 GPM Co3 1360 psi. Monitor well,pump dry job,blow down top drive. 21:30 - 23:00 1.50 DRILL P PROD1 POOH from 10,013' to 7938'. 23:00 - 00:00 1.00 DRILL P PROD1 PJSM. Cut and slip 95' of drilling line. 4/30/2007 00:00 - 01:00 1.00 DRILL P PROD1 Service Top drive 01:00 - 01:30 0.50 DRILL P PROD1 Drop ball and close circulation sub with 2000 psi. Verify closed with MW D detection. Blow down top drive. 01:30 - 04:00 2.50 DRILL P PROD1 Run in hole from 7936' to 10,360' picking up 4" pipe from pipe shed. Change out handling equipment. 04:00 - 05:30 1.50 DRILL P PROD1 Run in hole from 10,360' to 13,786'. Wash last 100' to bottom. Hole in good condition well gave back correct amount of displacement. 05:30 - 12:00 6.50 DRILL P PRODi Break circulation and drill ahead sliding in 6 1/8" hole. Drill 6 1/8" production hole from 13,876' to 14,076'. Up wt. 200k,down wt. 145k,rotating wt. 175k. 275 GPM, 1900 psi off bottom and 2250 psi on bottom. RPM 80,off bottom torque 8 k & on bottom 9 k. Printed: 5/10/2007 11:31:20 AM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: 09-15 Common Well Name: 09-15 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date ~ From - To :Hours Task ~ Code NP~ Start: 4/6/2007 Rig Release: 5/9/2007 Rig Number: Phase 4/30/2007 ~ 05:30 - 12:00 ~ 6.50 DRILL ~ P ~ PROD1 12:00 - 00:00 I 12.001 DRILL I P I I PROD1 5/1/2007 100:00 - 06:30 6.501 DRILL P PROD1 06:30 - 08:00 1.50 DRILL N DFAL PROD1 08:00 - 09:30 1.50 DRILL N DFAL PROD1 09:30 - 13:00 I 3.501 DRILL I N I DFAL I PROD1 13:00 - 14:30 ~ 1.501 DRILL N DFAL ~ PROD1 14:30 - 18:00 3.50 DRILL N DFAL PROD1 18:00 - 19:00 1.00 DRILL N DFAL PROD1 19:00 - 20:00 1.00 DRILL N DFAL PROD1 20:00 - 22:30 2.50 DRILL N DFAL PROD1 22:30 - 23:00 I 0.501 DRILL I N I DFAL I PROD1 23:00 - 00:00 1.00 DRILL N DFAL PRODi 5/2/2007 00:00 - 03:30 3.50 DRILL N DFAL PROD1 03:30 - 04:30 1.00 DRILL N DFAL PROD1 04:30 - 08:00 3.50 DRILL N DFAL PROD1 08:00 - 10:30 ( 2.501 DRILL I N I DFAL I PROD1 10:30 - 00:00 I 13.501 DRILL I P I I PROD1 Page 15 of 19 ~ Spud Date: 8/10h 977 End: 5/9/2007 Description of Operations Mud wt in 8 6.ppg and out 8.7 ppg, running water at 10 BPH. Running mud cleaner, centrifuge and MI solidis control unit to control drilled solids. Van processing 3 bbls/min. Lubricants running at 3%. Drill 6 1/8" production hole from 13,078' to 14,480'. Up wt. 210k,down wt. 135k,rotating wt. 175k. 282 GPM, 1930 psi off bottom and 2150 psi on bottom. RPM 80,off bottom torque 8 k & on bottom 9 k. Mud wt in 8 6.ppg and out 8.6 ppg, running water at 10 BPH. Running mud cleaner, centrifuge and MI solidis control unit to control drilled solids. Van processing 3 bbls/min. Lubricants running at 4%. Drill 6 1/8" production hole from 14,480" to 14,850'. Up wt. 210k,down wt. 130k,rotating wt. 175k. 310 GPM, 2250 psi off bottom and 2470 psi on bottom. RPM 80,off bottom torque 8 k & on bottom 10 k. Mud wt in 8 6.ppg and out 8.6+ppg, running water at 10 BPH. Running mud cleaner, centrifuge and MI solidis control unit to control drilled solids. Van processing 4 bbls/min with a cut of .05 ppg Lubricants running at 4%. Trouble shoot MWD,pump water pill, work pipe. Circulate water out of hole 305 GPM ~ 2240 psi. Monitor well. PJSM. POOH for MWD,14,850' to 9986'. Pump out from 14,850' to 14,440',60 GPM ~ 400 psi. Change out handling equipment from 5" to 4" at 10,361'. PJSM. Drop circ sub ball and open circulating sub with 2050 psi. Circulate bottoms up,510, 1450 psi. Monitor well,pump dry job. PJSM. POOH from 9986' to 1407'. PJSM. Lay down drill pipe from 1407' to 473'. Break circulation,drop ball & close circulating sub. PJSM.Handle BHA,Iay down collars, MWD tools, and motor. Download MWD PJSM. Lay down MWD tools off floor. Pick up new MWD tools to floor. PJSM. Make up BHA to 67'. Make up BHA from 67' to 94',orient and upload MWD. Pick up 2 drill collars and shallow pulse test MWD,300 GPM ~ 1020 psi. PJSM. with all personnel on installing radioactive sources. Install sources and add drill collar. Change out handling equipment. Pick up 4" drill pipe from pipe shed. Run in hole with pipe from derrick,1417' to 10,371'. Fill hole C~ 3650',6921',and 9996'. Change out handling equipment. Run in hole from 10,371' to 14,706',wash down from 14,706' to bottom at 14,850',300 GPM C~ 2400 psi. Drill 6 1/8" production hole from 14,850' to 15,556'. Up wt. 215k,down wt. 120k,rotating wt. 180k. 300 GPM, 2260 psi off bottom and 2460 psi on bottom. Printed: 5/10/2007 11:31:20 AM BP EXPLORATION Operations Summary Report Legal Well Name: 09-15 Common Well Name: 09-15 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING ~ Rig Name: NABOBS 2ES i Date ~ From - To I Hours ' Task Code NPT -- 5/2/2007 ~ 10:30 - 00:00 ~ 13.50 DRILL P 5/3/2007 100:00 - 04:00 4.00 I DRILL P 04:00 - 05:00 I 1.001 DRILL I P 05:00 - 08:30 3.50 DRILL P 08:30 - 14:30 6.00 DRILL C 14:30 - 15:30 I 1.001 DRILL I P 15:30 - 16:00 0.50 DRILL P 16:00 - 16:30 0.50 DRILL P 16:30 - 17:00 0.50 DRILL P 17:00 - 18:00 1.00 DRILL P 18:00 - 19:00 1.00 DRILL P 19:00 - 21:00 2.00 DRILL P 21:00 - 22:30 1.50 DRILL P 22:30 - 00:00 I 1.501 DRILL I P 5/4/2007 100:00 - 04:00 ~ 4.001 DRILL P 04:00 - 07:00 3.00 DRILL. C 07:00 - 08:00 1.00 DRILL P 08:00 - 09:00 1.00 CASE P 09:00 - 09:30 0.50 CASE P 09:30 - 18:00 8.50 CASE P 18:00 - 18:30 I 0.501 CASE I P 18:30 - 19:00 I 0.501 CASE I P 19:00 - 21:30 I 2.501 CASE I P 21:30 - 22:00 I 0.501 CASE I P Start: 4/6/2007 Rig Release: 5/9/2007 Rig Number: Page 16 of 19 ~ Spud Date: 8/10/1977 End: 5/9/2007 Phase Description of Operations PROD1 RPM 80,off bottom torque 8 k & on bottom 10 k. Mud wt in 8 7.ppg and out 8.7 ppg, running water at 10 BPH. Running mud cleaner, centrifuge and MI solidis control unit to control drilled solids. Van processing 3 bbls/min Lubricants running at 4%. PROD1 Drill 6 1/8" production hole from 15,556' to 15,820'. Up wt. 215k,down wt. 120k,rotating wt. 180k. 300 GPM, 2260 psi off bottom and 2460 psi on bottom. RPM 80,off bottom torque 8 k & on bottom 10 k. Mud wt in 8 7.ppg and out 8.7 ppg, running water at 10 BPH. Running mud cleaner, centrifuge and MI solidis control unit to control drilled solids. Van processing 3 bbls/min Lubricants running at 4%. PROD1 Pump Hi-Vis sweep surface to inside 7" casing,328 GPM ~ 2470 psi. PROD1 POH, circulating between MAD pass intervals PROD1 Backream /MAD pass swell packer setting depths,15,348' - 15,348',14,948' - 14,898',14,448' - 14,398',13,848' - 13,048',12,368' - 12,368'. PROD1 2" x 1 1/2" x 1/2" tong die fell out of top drive gripper from 95' above the floor. Secure floor bring top drive to floor and remove remainder of broken die. Inspect remaining dies for damage. PROD1 Circulate cuttings up hole at 10,747',300 GPM @ 1880 psi. PROD1 POOH from 10,747' to 9996',change out handling equipment. PROD1 PJSM. Drop circ sub ball and circulate into place at 83 GPM,590 psi. Open circ sub with 2000 psi. PROD1 Circulate sweep surface to surface,514 GPM,1960 psi. Pump dry job,blow down surface equipment. PROD1 PJSM. Change out saver sub from 4 1/2 IF to HT-40,change out gripper blocks. PROD1 PJSM. POOH from 9996' to 6643'. PROD1 Change out handling equipment,Run in hole with 5" drill pipe from derrick. PROD1 PJSM. POOH from 9753' to 8720',pump dry job. Lay down 99 joints 5" drillpipe. PROD1 POOH from 8720' to BHA @ 390'.Change out handling equipment. PROD1 Lay down BHA. Remove radioactive sources,download MWD. PROD1 Clear and clean floor. RUNPRD PJSM. Bring casing tools to floor,rig up to run 4 1/2" production liner. RUNPRD Service top drive. RUNPRD PJSM. Run 4 1/2" 12.6# BTC-M production liner to 5866'. Average torque 3800 fUlbs. RUNPRD Make up liner hanger.Mix and add PAL mix to hanger,wait for it to set. RUNPRD Make up stand and circulate liner volume,5 BPM X250 psi. Up wt 95k Down wt. 95k. RUNPRD Run in hole from 5908' to 10,024', 1 minute per stand,filling every 10 stands. RUNPRD Circulate 1 1/2 times liner volume,stage rate up to 5 BPM ~ Printed: 5/10/2007 11:31:20 AM BP EXPLORATION Page 17 of 19 Operations Summary Report Legal Well Name: 09-15 Common Well Name: 09-15 Spud Date: 8/10/1977 Event Name: REENTER+COMPLETE Start: 4/6/2007 End: 5/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/9/2007 Rig Name: NABOBS 2ES Rig Number: Date 5/4/2007 From - To Hours Task ~ Code NPT .. __ _- 21:30 - 22:00 ~ 0.50 CASE ~ P 22:00 - 00:00 5/5/2007 00:00 - 01:00 01:00 - 04:30 04:30 - 06:30 06:30 - 08:30 08:30 - 10:30 2.001 CASE I P 1.001 CASE I P 3.501 CEMT I P 2.001 CEMT P 2.OOiCEMT IP 2.001 CEMT I P Phase ~ Description of Operations RUNPRD 540 psi. Up wt 155k down wt. 135k 2 BPM =350psi 3 BPM = 400 psi 4 BPM = 460 psi RUNPRD Run in hole from 10,024' to 13,843',filling every 10 stands. 11,051' = 165k up / 125k down 11,983' = 170k up / 120k down 12,912' = 175k up / 120k down 13,843' = 180k up / 130k down RUNPRD Run in hole with 4 1/2" production liner from 13,843' to 15,801',fill pipe every 10 stands. 14,310' = 195k up wt. / 120k down wt. 14,776' = 200k up wt. / 120k down wt. 15,801' = 200k up wt. / 115k down wt. RUNPRD Make up cement head & single,break circulation at 1 BPM / 800 psi. Stage up pump slowly tag bottom at 15,820'. 3 BPM = 1000 psi 4 BPM = 1200 psi Circulate 2 x open hole volume @ 4 BPM. PJSM with all personnel. Start Batch mixing cement,continue to circulate and reciprocate at 185k up,115k down. Able to increase rate to 4.6 BPM at 1200 psi. RUNPRD Pressure test lines to 4500 psi. Pump 14.3 bbl. Mudpush II with dye. Hydraulic line on Knife valve for mixing mud push failed, only 14.3 bbl of 40 planned mud push pumped. Pump 147.2 bbl. 15.8 class G cement with GasBlok maximum rate of 5 BPM. Wash lines to floor with 6 bbls Perf Pill Drop plug and displace with 105 bbl. pert pill follwed by 83 bbl 8.5 ppg Flo Pro mud C~ 5 bpm. Continue to reciprocated pipe until 45 bbls cement rounded corner, SO wt dropped to 60k. parked liner on depth for remainder of displacement. Slow pumps to 3.5 BPM to latch up, plug sheared at 2800 psi. and set hanger, ~ 180 bbls away slow to 2 BPM @ 1500 psi. & Bump with 2400 psi. Slack off 60k and verify hanger set, pressure up to 4000 psi to release from hanger. Bleed pressure,check floats. Held Pick up 200k, hanger not released, slack off, pressure to 4500 psi, bled down to 1000 psi. Pick up to confirm free,up wt. 180k. bled down to 0 psi. Weight set packer with 15 RPM 4k torque, slack off to 115k, positive indication packer set, repeat x3. RUNPRD Swap to rig pumps pressure up to 1000 psi and PU 27' to clear seals. Circulate bottoms up ~ 500 gpm, 35 bbls cement back to surface. Break and lay down cement head and make up top drive. RUNPRD Pump weighted spacer & displace to seawater,500 GPM C~3 2500 psi. Flush and blow down cement manifold and top drive. Printed: 5/10/2007 11:31:20 AM BP EXPLORATION Page 18 of 19 Operations Summary Report Legal Well Name: 09-15 Common Well Name: 09-15 Spud Date: 8/10/1977 Event Name: REENTER+COMPLETE Start: 4/6/2007 End: 5/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/9/2007 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours i Task Code I NPT 5/5/2007 ~ 10:30 - 11:30 1.00 CEMT ~ P 11:30 - 12:30 1.00 CEMT P 12:30 - 13:00 0.50 CEMT P 13:00 - 15:30 2.50 CEMT P 15:30 - 16:30 I 1.001 CEMT I P 16:30 - 18:30 I 2.001 CEMT I P 18:30 - 19:30 I 1.001 CEMT I P 19:30 - 21:00 I 1.50 I EVAL I P 21:00 - 00:00 I 3.00 EVAL I P 5/6/2007 00:00 - 01:00 1.00 EVAL P 01:00 - 02:00 1.00 EVAL P 02:00 - 03:00 1.00 BOPSU P 03:00 - 09:00 6.00 BOPSU P 09:00 - 10:00 ~ 1.00 (BOPSUp P 10:00 - 11:00 1.00 PERFO P 11:00 - 12:00 1.00 PERFO P 12:00 - 18:00 I 6.001 PERFOBI P 18:00 - 22:30 4.501 PERFOB P 22:30 - 23:30 I 1.001 PERFOBI P 23:30 - 00:00 I 0.501 PERFOBI P 5/7/2007 100:00 - 09:00 I 9.001 PERFOBI P 09:00 - 16:00 I 7.001 PERFOBI P 16:00 - 17:30 I 1.501 PERFOBI P Phase Description of Operations RUNPRD PJSM. Cut and slip 110' of drilling line. Inspect traction motor brushes and lubricate Elmago splines. RUNPRD Service top drive and drawworks. RUNPRD Pump dry job,blow down surface equipment. RUNPRD POOH from 9886' to 2893' Fluid wt in and out 8.5 ppg. RUNPRD Change out handling equipment,run in hole with 5" pipe from 2893' to 5722'. RUNPRD POOH laying down 5" pipe from 5722' to 2893',change out handling equipment. RUNPRD POOH from 2893' to surface, lay down liner hanger running tool. RUNPRD Spot E-line unit,PJSM with all personnel,Rlg up and make up USIT tools. RUNPRD Run in hole with USIT and log up from 9880' TO 7100'. POOH with logging tools. RUNPRD POOH with logging tools,rig down E-line unit. RUNPRD Test casing to 4000 psi,chart and hold for 30 minutes. RUNPRD Pick up 4" test joint,pull wear ring & install test plug. RUNPRD Test BOP and related valves to 250 psi low and 4000 psi high. Test Annular to 250 psi low and 2500 psi high. Test witness waived by AOGCC rep Bob Noble Test witnessed by BP rep Blair Neufeld (WSL) & Chris Clemens (WSL) RUNPRD Break and lay down 2 7/8" test joint. Pick up 4" test joint and pull test plug,install wear ring,blow down surface lines. OTHCMP PJSM. Pick up and rig up gun and PAC handling equipment. OTHCMP Make up guns and firing head & disconnect to 143'. Change out handling equipment. OTHCMP Run in hole picking up 2 7/8" PAC from pipe shed to 5951',change out handling equipment. OTHCMP Run in hole with 4" pipe from derrick to 15,680' Run in and tag up landing collar at 15,728'. Pick up and shoot guns at 15,650'- 15,550' OTHCMP Fill pipe,break circulation.Open up through annulus and drill string,close pipe rams. PJSM with all personnel. Run pressure sequence as per Schlumberger rep,bleed off pressure,open pipe rams. Guns fired,good indication on surface.Rack back two stands,moniter well, losses Obbl. OTHCMP Pump dry job,blow down surface equipment. Lay down drill pipe from 15,470' to 15,189' Wt of fluid in hole 8.5 ppg in and out. OTHCMP Lay down drill pipe from 15,189' to 5955',run in 5 stands out of derrick,lay down. Break out crossovers and make up PAC drill pipe safety valve. Hole took correct displacement. OTHCMP PJSM. Change out handling equipment,rig up power tongs & backups. Lay down PAC drill pipe from 5955' to 148'. Hole took correct displacement. OTHCMP PJSM with all personnel,lay down perforating guns from148'. Printed: 5/10/2007 11:31:20 AM • • BP EXPLORATION Page 19 of 19 Operations Summary Report Legal Well Name: 09-15 Common Well Name: 09-15 Spud Date: 8/10/1977 Event Name: REENTER+COMPLETE Start: 4/6/2007 End: 5/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/9/2007 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours ~ Task Code NPT Phase Description of Operations 5n/2oo7 5/8/2007 5/9/2007 16:00 - 17:30 1.50 PERFO P OTHCMP 17:30 - 19:00 1.50 BUNCO RUNCMP 19:00 - 20:00 1.00 BUNCO P RUNCMP 20:00 - 00:00 4.00 BUNCO RUNCMP 00:00 - 11:00 I 11.001 RUNCON'~ I I RUNCMP 11:00 - 15:00 I 4.001 RUNCON~P I I RUNCMP 15:00 - 17:30 I 2.501 RUNCON9P I I RUNCMP 17:30 - 20:30 I 3.001 RUNCONIP I I RUNCMP 20:30 - 21:30 I 1.001 RUNCOMP I I RUNCMP 21:30 - 22:30 1.00 RUNCO~ RUNCMP 22:30 - 00:00 1.50 BUNCO P RUNCMP 00:00 - 02:00 2.00 BUNCO P RUNCMP 02:00 - 03:00 1.00 RUNC01~1P RUNCMP 03:00 - 04:30 1.50 BUNCO WP RUNCMP All shots fired,rig down handling equipment,clearand clean floor. Pick up, and rig up torque turn equipment. PJSM with all personnel,make up paker and tailpipe assembly. Make up and run 4 1/2",12.6#,L-80, TC11 tubing. Optimum torque 3850 fUlbs. No losses while running. Make up and run 4 1/2",12.6#,L-80, TCII tubing. Optimum torque 3850 fUlbs. Did not tag liner top. Pick up 2 extra joints, run in and tag. Lay down 3 joints. Make up space out pups of 9.77', 9.76' and 5.76' and joint #241. Drain stack. Change out elevators. Pick up and make up landing joint. Make up hanger and land. Run in lock down screws. No losses while running. PJSM. Rig up circulating lines to annulus and lower mud cross. Reverse circulate 180 bbls clean seawater at 126 gpm with 140 psi. Follow with 410 bbls clean seawater with corrosion inhibitor. Rig up LRS. PJSM. Test lines to 4500 psi. Reverse circulate 151 bbls of 50 degree diesel at 84 gpm with 550 psi. U-tube annulus and tubing. Install landing joint. Drop 1-7/8" ball and rod. Break and LD landing joint. Test tubing to 4000 psi for 30 minutes. Bleed off to 1500 psi. Test annulus to 4000 psi for 30 minutes. Both tests ok. Bleed off annulus and tubing. Test witness waived by Bob Noble with AOGCC. Dry rod TWC. Test from above to 1000 psi with LRS. Suck back lines and rig down LRS. Blow down surface equipment. Nipple down BOPE. Nipple up adapter flange. PJSM. Jack up rig. Open cellar doors and bring in tree. Nipple up tree. Fill tree with diesel and test to 5000 psi. Test OK. Pick up DSM lubricator. Pull TWC. Intall BPV. Lay down lubricator. Remove secondary annular valve. Install flanges, plugs, needle valves and gauges. Secure well and cellar for rig move. Release rig at 04:30 hrs on 05/09/2007 for move to F-44A. Printed: 5/10/2007 11:31:20 AM Halliburton Company ~ Survey Report C'omhan}~: BP AmoCO Date: 5%19`2007 'lime 04:03:53 Page: 1 Field: Prudhoe Bay Co-ordinutc(NGJ Itcfcrcncc: We ll: 09-15, True N orth Site: PB DS 09 Vertical ~'I'~'Ul KcFer ence: 20'GL+28.5RK.B 48 .5 ~~~ell: 09-15 SccLion (VSi Kcfcrcncc: User (O.OON.O.OOE, 345.53Azi) ~i 1~elfpath: 09-15A Survey Calculation Method: Min imum Curvature Db: Oracie j Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 09-15 Slot Name: 15 09-15 Well Position: +N/-S 1517,73 ft Northing: 5942466.30 ft Latitude: 70 14 43.377 N +E/-W 1366.98 ft Easting : 718541.52 ft Longitude: 148 14 4.352 W Position Uncertainty: 0.00 ft Wellpath: 09-15A Drilled From: 09-15 500292025601 Tie-on Depth: 7446.50 ft Current Datum: 20'GL +28.5RKB Height 48.50 ft Above System Datum: Mean Sea Level Magnetic Data: 4/12/2007 Declination: 24.18 deg Field Strength: 57676 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28 .50 0.00 0.00 345.53 Survey Program for Definitive Wellpath Date: 5/19/2007 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 795.50 7446.50 1 : Camera based mag multi sho CB-MAG-MS Camera based mag multi shot 7479.00 15778.00 09-15A IIFR+MS+Sag (7479.00-15 MWD+IFR+MS MWD +IFR + Multi Station Survey MD Lul ,1zim TVD Svs TVD N/5 E/W MapN MapE 'Pool ft deg deG ft ft ft ft ft ft 28.50 0.00 0.00 28.50 -20.00 0.00 0.00 5942466.30 718541.52 TIE LINE 795.50 0.50 136.00 795.49 746.99 -2.41 2.32 5942463.96 718543.91 CB-MAG-MS 1174.50 1.25 93.00 1174.45 1125.95 -3.81 7.60 5942462.71 718549.23 CB-MAG-MS 1759.50 0.25 83.00 1759.39 1710.89 -3.99 15.24 5942462.75 718556.87 CB-MAG-MS 2709.50 0.50 230.00 2709.38 2660.88 -6.40 14.12 5942460.31 718555.82 CB-MAG-MS 2790.50 1.00 143.00 2790.37 2741.87 -7.20 14.28 5942459.52 718556.00 CB-MAG-MS 2883.50 1.00 153.00 2883.36 2834.86 -8.57 15.13 5942458.18 718556.89 CB-MAG-MS 2976.50 1.00 131.00 2976.35 2927.85 -9.82 16.12 5942456.95 718557.91 CB-MAG-MS 3069.50 1.75 29.00 3069.33 3020.83 -9.11 17.42 5942457.70 718559.19 CB-MAG-MS 3162.50 3.75 4.00 3162.22 3113.72 -4.84 18.32 5942462.00 718559.97 CB-MAG-MS 3256.50 5.75 3.00 3255.89 3207.39 2.93 18.78 5942469.78 718560.20 CB-MAG-MS 3349.50 8.00 2.00 3348.22 3299.72 14.06 19.25 5942480.91 718560.35 CB-MAG-MS 3442.50 11.25 1.00 3439.90 3391.40 29.60 19.63 5942496.45 718560.28 CB-MAG-MS 3535.50 14.00 1.00 3530.64 3482.14 49.92 19.99 5942516.78 718560.05 CB-MAG-MS 3628.50 17.00 3.00 3620.25 3571.75 74.75 20.89 5942541.62 718560.24 CB-MAG-MS 3721.50 19.00 6.00 3708.69 3660.19 103.39 23.19 5942570.31 718561.70 CB-MAG-MS 3814.50 20.25 7.00 3796.29 3747.79 134.42 26.73 5942601.43 718564.34 CB-MAG-MS 3907.50 22.00 9.00 3883.04 3834.54 167.60 31.42 5942634.73 718568.06 CB-MAG-MS 4000.50 23.00 9.00 3968.96 3920.46 202.75 36.99 5942670.03 718572.61 CB-MAG-MS 4094.50 24.50 10.00 4054.99 4006.49 240.09 43.24 5942707.53 718577.78 CB-MAG-MS 4187.50 26.00 11.00 4139.11 4090.61 279.09 50.48 5942746.72 718583.89 CB-MAG-MS 4280.50 27.50 12.00 4222.15 4173.65 320.10 58.84 5942787.96 718591.05 CB-MAG-MS 4373.50 28.00 12.00 4304.45 4255.95 362.46 67.84 5942830.56 718598.82 CB-MAG-MS 4466.50 28.50 13.00 4386.38 4337.88 405.43 77.37 5942873.79 718607.10 CB-MAG-MS 4559.50 28.50 13.00 4468.11 4419.61 448.67 87.35 5942917.29 718615.82 CB-MAG-MS 4652.50 29.00 13.00 4549.64 4501.14 492.25 97.42 5942961.15 718624.62 CB-MAG-MS 4745.50 29.00 14.00 4630.98 4582,48 536.09 107.94 5943005.28 718633.86 CB-MAG-MS 4839.50 29.25 14.00 4713.10 4664.60 580.49 119.01 5943049.97 718643.64 CB-MAG-MS 4932.50 30.00 15.00 4793.94 4745,44 624.99 130.52 5943094.79 718653.86 CB-MAG-MS Halliburton Company Survey Report Company: BP Amoco Field: Prudhoe Bay Site: PB DS 09 «~cll: 09-15 11'cllpath: 09-15A hurcev VTR Incl ft deg zim deg VD ft ys TVD ft llate: 5/19/2007 Time: 04:03:53 Page: 2 Co-ordinaie~N~) Reference: Well: 09 15, True North j Vertic:ll ~'I~"Dl Reference: 20'GL+28.5RKB 48.5 Section (l~Si Kcfcrence: User (O.OON,O.OOE,345.53Azi} Sur~c}~ Calculation'~Iethod: tvtinirnurn Curvature Db: OraCle N/S r:/~V MapN iVlapE Tool ft ft ft ft 5025.50 31.00 15.00 4874.07 4825.57 670.58 142.74 5943140.71 718664.75 CB-MAG-MS 5118.50 31.00 15.00 4953.79 4905.29 716.85 155.14 5943187.32 718675.80 CB-MAG-MS 5211.50 31.00 15.00 5033.50 4985.00 763.12 167.53 5943233.92 718686.85 CB-MAG-MS 5304.50 32.00 16.00 5112.80 5064.30 809.94 180.52 5943281.10 718698.47 CB-MAG-MS 5397.50 32.50 16.00 5191.45 5142.95 857.64 194.20 5943329.17 718710.76 CB-MAG-MS 5490.50 32.50 16.00 5269.89 5221.39 905.68 207.98 5943377.58 718723.14 CB-MAG-MS 5584.50 33.00 16.00 5348.94 5300.44 954.56 221.99 5943426.85 718735.73 CB-MAG-MS 5677.50 32.50 16.00 5427.16 5378.66 1002.92 235.86 5943475.59 718748.19 CB-MAG-MS 5770.50 32.25 16.00 5505.70 5457.20 1050.79 249.59 5943523.83 718760.52 CB-MAG-MS 5863.50 34.00 18.00 5583.59 5535.09 1099.37 264.46 5943572.83 718773.98 CB-MAG-MS 5956.50 34.00 18.00 5660.69 5612.19 1148.83 280.53 5943622.73 718788.61 CB-MAG-MS 6049.50 35.00 19.00 5737.33 5688.83 1198.78 297.25 5943673.14 718803.87 CB-MAG-MS 6142.50 35.00 20.00 5813.52 5765.02 1249.06 315.06 5943723.92 718820.21 CB-MAG-MS 6235.50 35.25 19.00 5889.58 5841.08 1299.50 332.92 5943774.85 718836.60 CB-MAG-MS 6328.50 36.00 20.00 5965.18 5916.68 1350.56 351.00 5943826.41 718853.20 CB-MAG-MS 6422.50 36.50 20.00 6040.98 5992.48 1402.79 370.01 5943879.17 718870.69 CB-MAG-MS 6515.50 36.50 19.00 6115.74 6067.24 1454.94 388.48 5943931.82 718887.63 CB-MAG-MS 6608.50 36.25 19.00 6190.62 6142.12 1507.09 406.44 5943984.47 718904.07 CB-MAG-MS 6701.50 36.25 19.00 6265.62 6217.12 1559.08 424.34 5944036.96 718920.45 CB-MAG-MS 6794.50 36.25 18.00. 6340.62 6292.12 1611.23 441.79 5944089.59 718936.38 CB-MAG-MS 6887.50 36.25 17.00 6415.62 6367.12 1663.68 458.32 5944142.49 718951.39 CB-MAG-MS 6980.50 36.25 17.00 6490.62 6442.12 1716.27 474.40 5944195.52 718965.94 CB-MAG-MS 7073.50 37.00 16.00 6565.26 6516.76 1769.46 490.16 5944249.15 718980.14 CB-MAG-MS 7167.50 36.00 15.00 6640.82 6592.32 1823.34 505.10 5944303.43 718993.52 CB-MAG-MS 7260.50 37.00 15.00 6715.58 6667.08 1876.77 519.42 5944357.26 719006.28 CB-MAG-MS 7353.50 37.00 15.00 6789.85 6741.35 1930.83 533.91 5944411.71 719019.19 CB-MAG-MS 7446.50 37.00 15.00 6864.12 6815.62 1984.89 548.39 5944466.17 719032.10 CB-MAG-MS 7479.00 37.00 15.00 6890.08 6841.58 2003.79 553.45 5944485.20 719036.61 MWD+IFR+MS 7559.66 40.45 9.22 6953.02 6904.52 2053.09 563.93 5944534.79 719045.66 MWD+IFR+MS 7603.87 41.56 6.35 6986.38 6937.88 2081.82 567.85 5944563.62 719048.74 MWD+IFR+MS 7696.81 42.61 0.02 7055.39 7006.89 2143.95 571.28 5944625.82 719050.36 MWD+IFR+MS 7789.96 39.53 353.86 7125.64 7077.14 2205.00 568.11 5944686.75 719045.43 MWD+IFR+MS 7882.58 39.71 347.60 7197.01 7148.51 2263.23 558.61 5944744.67 719034.24 MWD+IFR+MS 7975.03 39.71 338.66 7268.19 7219.69 2319.63 541.50 5944800.55 719015.51 MWD+IFR+MS 8069.11 39.39 332.17 7340.76 7292.26 2374.04 516.62 5944854.22 718989.06 MWD+IFR+MS 8160.65 38.51 325.18 7411.99 7363.49 2423.15 486.77 5944902.43 718957.80 MWD+IFR+MS 8253.97 38.72 321.33 7484.91 7436.41 2469.79 451.94 5944948.05 718921.63 MWD+IFR+MS 8347.65 40.50 315.73 7557.11 7508.61 2514.47 412.38 5944991.56 718880.80 MWD+IFR+MS 8441.05 43.06 314.25 7626.75 7578.25 2558.45 368.36 5945034.23 718835.53 MWD+IFR+MS 8534.17 45.64 315.64 7693.33 7644.83 2604.44 322.31 5945078.87 718788.16 MWD+IFR+MS 8627.09 48.90 314.88 7756.38 7707.88 2652.90 274.26 5945125.92 718738.73 MWD+IFR+MS 8720.34 52.48 313.67 7815.44 7766.94 2703.25 222.60 5945174.74 .718685.63 MWD+IFR+MS 8813.08 51.56 313.76 7872.51 7824.01 2753.76 169.77 5945223.70 718631.36 MWD+IFR+MS 8906.93 52.89 313.28 7930.00 7881.50 2804.84 115.97 5945273.20 718576.11 MWD+IFR+MS 8999.69 52.69 313.24 7986.10 7937.60 2855.47 62.17 5945322.24 718520.87 MWD+IFR+MS 9092.03 52.08 312.45 8042.46 7993.96 2905.21 8.55 5945370.41 718465.82 MWD+IFR+MS 9181.87 51.08 312.41 8098.29 8049.79 2952.70 -43.41 5945416.37 718412.52 MWD+IFR+MS 9276.88 50.43 310.43 8158.40 8109.90 3001.38 -98.57 5945463.42 718355.96 MWD+IFR+MS 9369.55 50.21 311.84 8217.57 8169.07 3048.29 -152.29 5945508.76 718300.91 MWD+IFR+MS 9461.01 48.65 312.29 8277.05 8228.55 3094.84 -203.87 5945553.78 718248.01 MWD+IFR+MS 9506.33 48.94 312.38 8306.90 8258.40 3117.80 -229.07 5945576.00 718222.15 MWD+IFR+MS 9573.23 49.38 312.51 8350.65 8302.15 3151.96 -266.42 5945609.06 718183.83 MWD+iFR+MS Halliburton Company S Survey Report Company: BP Amoco Field: Prudhoe Bay Site: PB DS 09 Nell: 09-15 ~Vellpath: 09-15A 5urvev MD Intl ft deg zim deg '1D ft ysTl~ll ft Uate: 5/19/2007 'time: 04:03:53 .Page: 3 Co-ordinate(NE)Reference: Well: 09-15. True North vertical (TVDI Rcferener. 20'GL+28.5RKB 4r~,.5 Scctiou (VS) Reference: User (O.OON.O.OOE,345.53Azi) Sur~ev Calc~tation Method: Minimum Curvature Db: Oracle N/S E/W Map1 MapE "Cool ft ft ft ft 9666.69 50.37 314.58 8410.89 8362.39 3201.19 -318,21 5945656.77 718130.64 MWD+IFR+MS 9760.19 51.02 315.74 8470.12 8421.62 3252.49 -369.22 5945706.57 718078.17 MWD+IFR+MS 9852.29 51.54 317.10 8527.73 8479.23 3304.55 -418.75 5945757.16 718027.15 MWD+IFR+MS 9947.82 49.60 314.63 8588.40 8539.90 3357.51 -470.10 5945808.61 717974.28 MWD+IFR+MS 10034.15 48.64 311.69 8644.91 8596.41 3402.16 -517.70 5945851.86 717925.41 MWD+IFR+MS 10128.15 48.49 310.48 8707.12 8658.62 3448.47 -570.81 5945896.61 717870.98 MWD+IFR+MS 10154.44 48.27 310.80 8724.58 8676.08 3461.27 -585.73 5945908.97 717855.70 MWD+IFR+MS 10249.55 54.61 314.19 8783.85 8735.35 3511.54 -640.46 5945957.64 717799.54 MWD+IFR+MS 10278.79 56.86 314.90 8800.31 8751.81 3528.49 -657.68 5945974.08 717781.84 MWD+IFR+MS 10310.96 61.08 314.38 8816.89 8768.39 3547.86 -677.29 5945992.86 717761.67 MWD+IFR+MS 10343.82 66.97 315.86 8831.27 8782.77 3568.79 -698.12 5946013.18 717740.25 MWD+IFR+MS 10374.79 71.11 315.93 8842.35 8793.85 3589.55 -718.24 5946033.35 717719.53 MWD+IFR+MS 10405.99 75.32 316.56 8851.36 8802.86 3611.12 -738.89 5946054.31 717698.26 MWD+IFR+MS 10437.18 80.30 316.59 8857.94 8809.44 3633.25 -759.84 5946075.83 717676.68 MWD+IFR+MS 10468.06 84.80 316.52 8861.94 8813.44 3655.48 -780.89 5946097.43 717655.00 MWD+IFR+MS 10499.24 89.51 316.07 8863.49 8814.99 3677.99 -802.40 5946119.31 717632.84 MWD+IFR+MS 10529.36 93.39 315.73 8862.73 8814.23 3699.60 -823.35 5946140.31 717611.28 MWD+IFR+MS 10578.18 93.56 315.51 8859.77 8811.27 3734.43 -857.44 5946174.13 717576.20 MWD+IFR+MS 10625.12 94.95 313.36 8856.29 8807.79 3767.20 -890.86 5946205.92 .717541.84 MWD+IFR+MS 10656.61 95.45 313.16 8853.43 8804.93 3788.69 -913.70 5946226.74 717518.39 MWD+IFR+MS 10688.77 95.60 313.34 8850.34 8801.84 3810.63 -937.01 5946247.98 717494.45 MWD+IFR+MS 10720.32 93.29 313.23 8847.89 8799.39 3832.19 -959.91 5946268.87 717470.94 MWD+IFR+MS 10751.39 93.98 312.42 8845.92 8797.42 3853.27 -982.65 5946289.28 717447.60 MWD+IFR+MS 10785.16 93.55 312.08 8843.70 8795.20 3875.93 -1007.59 5946311.20 717422.01 MWD+IFR+MS 10814.39 93.00 312.91 8842.04 8793.54 3895.64 -1029.11 5946330.28 717399.93 MWD+IFR+MS 10845.27 92.75 312.28 8840.49 8791.99 3916.51 -1051.81 5946350.49 717376.63 MWD+IFR+MS 10876.17 93.25 310.78 8838.87 8790.37 3936.97 -1074.91 5946370.27 717352.95 MWD+IFR+MS 10907.55 93.42 311.05 8837.04 8788.54 3957.49 -1098.59 5946390.09 717328.70 MWD+IFR+MS 10998.57 92.87 311.20 8832.05 8783.55 4017.26 -1167.04 5946447.85 717258.53 MWD+IFR+MS 11049.14 92.69 310.82 8829.60 8781.10 4050.41 -1205.16 5946479.87 717219.48 MWD+IFR+MS 11093.28 92.19 310.78 8827.72 8779.22 4079.22 -1238.54 5946507.71 717185.27 MWD+IFR+MS 11125.69 91.83 309.15 8826.58 8778.08 4100.03 -1263.37 5946527.78 7i 7159.86 MWD+IFR+MS 11157.47 93.31 308.82 8825.16 8776.66 4120.00 -1288.04 5946547.03 717134.61 MWD+IFR+MS 11189.22 92.99 306.04 8823.41 8774.91 4139.27 -1313.22 5946565.56 717108.89 MWD+IFR+MS 11220.51 92.86 303.60 8821.81 8773.31 4157.11 -1338.87 5946582.65 717082.74 MWD+IFR+MS 11251.18 91.76 305.98 8820.58 8772.08 4174.59 -1364.03 5946599.39 717057.08 MWD+IFR+MS 11282.29 91.08 303.78 8819.81 8771.31 4192.38 -1389.55 5946616.43 717031.06 MWD+IFR+MS 11314.70 90.96 301.20 8819.23 8770.73 4209.78 -1416.88 5946633.03 717003.24 MWD+IFR+MS 11346.12 90.59 298.83 8818.80 8770.30 4225.49 -1444.08 5946647.95 716975.59 MWD+IFR+MS 11377.24 90.28 295.71 8818.57 8770.07 4239.75 -1471.73 5946661.40 716947.54 MWD+IFR+MS 11408.19 90.52 292.86 8818.35 8769.85 4252.48 -1499.94 5946673.30 716918.97 MWD+IFR+MS 11440.49 90.28 288.82 8818.13 8769.63 4263.97 -1530.12 5946683.91 716888.47 MWD+IFR+MS 11472.41 90.71 284.58 8817.85 8769.35 4273.14 -1560.69 5946692.19 716857.66 MWD+IFR+MS 11504.07 91.88 280.48 8817.14 8768.64 4280.00 -1591.58 5946698.16 716826.58 MWD+IFR+MS 11534.77 92.44 276.82 8815.98 8767.48 4284.62 -1621.90 5946701.89 716796.14 MWD+IFR+MS 11565.81 91.58 275.08 8814.89 8766.39 4287.83 -1652.76 5946704.21 716765.21 MWD+IFR+MS 11610.03 92.50 274.96 8813.31 8764.81 4291.70 -1696.78 5946706.80 716721.09 MWD+IFR+MS 11660.76 91.44 274.20 8811.57 8763.07 4295.75 -1747.31 5946709.38 716670.46 MWD+IFR+MS 11704.98 90.76 273.20 8810.72 8762.22 4298.60 -1791.43 5946710.95 716626.28 MWD+IFR+MS 11753.24 90.09 272.87 8810.36 8761.86 4301.15 -1839.62 5946712.11 716578.04 MWD+IFR+MS 11848.32 89.84 274.91 8810.42 8761.92 4307.60 -1934.48 5946715.80 716483.04 MWD+IFR+MS 11898.85 89.20 275.73 8810.85 8762.35 4312.29 -1984.79 5946719.03 716432.62 MWD+IFR+MS 11943.66 88.86 275.98 8811.60 8763.10 4316.86 -2029.36 5946722.30 716387.94 MWD+IFR+MS Halliburton Company Survey Report ~ Company: BP Amoco Field: PrudhoeBay Site: PB DS 09 «`cll: 09-15 Welipath: 09-15A Date: 5/19/2007 'l'ime: 04:03:53 Page: 4 Co-ordinate(TH'1Reference: Well: 09 15. True NoRh ~'crtical (TVl)) Kefcrence: 20'GL+28.5RKB 48.5 Section(VS)ReFcrence: User (O.OON.O.OOE345.53Azi) Survey Calculation Method: Minimum Curvature Db: OraCle Survev - MD Incl 4zim TVD Sys TVD N/S FJW - MapN ~lupE Tool i ft deg deg ft ft ft ft ft ft 11992.38 90.03 274.97 8812.08 8763.58 4321.51 -2077.85 5946725.54 716339.33 MWD+IFR+MS 12036.94 89.78 276.72 8812.15 8763.65 4326.05 -2122.18 5946728.79 716294.89 MWD+IFR+MS 12130.85 89.72 278.06 8812.56 8764.06 4338.12 -2215.31 5946738.17 716201.46 MWD+IFR+MS 12179.31 89.60 278.40 8812.85 8764.35 4345.06 -2263.27 5946743.71 716153.32 MWD+IFR+MS 12225.92 89.10 276.69 8813.38 8764.88 4351.18 -2309.47 5946748.49 716106.96 MWD+IFR+MS 12271.83 91.21 277.95 8813.25 8764.75 4357.03 -2355.00 5946753.01 716061.28 MWD+IFR+MS 12320.14 90.65 278.19 8812.47 8763.97 4363.81 -2402.83 5946758.40 716013.28 MWD+IFR+MS 12352.00 90.28 279.14 8812.21 8763.71 4368.61 -2434.32 5946762.29 715981.66 MWD+IFR+MS 12382.78 91.14 280.65 8811.83 8763.33 4373.90 -2464.64 5946766.70 715951.20 MWD+IFR+MS 12414.23 91.32 279.96 8811.15 8762.65 4379.52 -2495.57 5946771.42 715920.12 MWD+IFR+MS 12445.08 91.07 280.26 8810.51 8762.01 4384.94 -2525.94 5946775.95 715889.61 MWD+IFR+MS 12476.30 91.01 280.97 8809.94 8761.44 4390.69 -2556.62 5946780.81 715858.78 MWD+IFR+MS 12507.79 91.02 282.81 8809.38 8760.88 4397.17 -2587.43 5946786.40 715827.80 MWD+IFR+MS 12539.45 90.95 285.37 8808.84 8760.34 4404.88 -2618.13 5946793.21 715796.89 MWD+IFR+MS 12571.07 91.14 287.29 8808.26 8759.76 4413.77 -2648.47 5946801.22 715766.31 MWD+IFR+MS 12601.98 92.43 289.61 8807.30 8758.80 4423.54 -2677.77 5946810.14 715736.73 MWD+IFR+MS 12633.03 93.42 293.55 8805.72 8757.22 4434.95 -2706.60 5946820.70 715707.59 MWD+IFR+MS 12664.69 92.99 295.31 8803.95 8755.45 4448.02 -2735.38 5946832.93 715678.44 MWD+IFR+MS 12696.98 92.19 298.19 8802.49 8753.99 4462.54 -2764.18 5946846.61 715649.23 MWD+IFR+MS 12728.43 91.99 299.82 8801.34 8752.84 4477.78 -2791.67 5946861.04 715621.32 MWD+IFR+MS 12759.73 91.13 301.83 8800.49 8751.99 4493.81 -2818.53 5946876.29 715594.00 MWD+IFR+MS 12791.24 91.26 303.99 8799.83 8751.33 4510.92 -2844.98 5946892.63 715567.07 MWD+IFR+MS 12822.73 89.78 307.63 8799.54 8751.04 4529.34 -2870.51 5946910.30 715541.01 MWD+IFR+MS 12855.29 88.42 310.07 8800.06 8751.56 4549.76 -2895.86 5946929.98 715515.08 MWD+IFR+MS 12885.01 89.22 313.39 8800.67 8752.17 4569.54 -2918.03 5946949.10 715492.35 MWD+IFR+MS 12920.64 90.21 317.01 8800.84 8752.34 4594.82 -2943.14 5946973.64 715466.53 MWD+IFR+MS 12952.13 90.40 318.26 8800.68 8752.18 4618.08 -2964.35 5946996.28 715444.64 MWD+IFR+MS 12980.68 90.33 321.50 8800.49 8751.99 4639.91 -2982.75 5947017.56 715425.62 MWD+IFR+MS 13015.02 90.15 323.38 8800.35 8751.85 4667.13 -3003.68 5947044.16 715403.91 MWD+IFR+MS 13046.79 90.83 325.66 8800.08 8751.58 4693.00 -3022.12 5947069.48 715384.73 MWD+IFR+MS 13075.56 92.31 327.59 8799.29 8750.79 4717.01 -3037.94 5947093.03 715368.22 MWD+IFR+MS 13108.09 92.43 330.43 8797.95 8749.45 4744.87 -3054.67 5947120.39 715350.69 MWD+IFR+MS 13140.04 92.56 333.16 8796.55 8748.05 4773.00 -3069.76 5947148.07 715334.80 MWD+IFR+MS 13168.77 91.88 336.20 8795.44 8746.94 4798.95 -3082.03 5947173.65 715321.77 MWD+IFR+MS 13200.32 92.37 339.17 8794.27 8745.77 4828.11 -3094.00 5947202.45 715308.96 MWD+IFR+MS 13232.19 92.25 342.82 8792.99 8744.49 4858.22 -3104.37 5947232.24 715297.73 MWD+IFR+MS 13262.48 91.76 345.94 8791.93 8743.43 4887.37 -3112.52 5947261.14 715288.74 MWD+IFR+MS 13307.67 91.82 347.83 8790.51 8742.01 4931.35 -3122.77 5947304.81 715277.22 MWD+IFR+MS 13357.34 91.51 347.61 8789.07 8740.57 4979.87 -3133.33 5947352.99 715265.26 MWD+IFR+MS 13388.57 91.38 348.35 8788.28 8739.78 5010.40 -3139.83 5947383.32 715257.87 MWD+IFR+MS 13420.63 91.20 349.64 8787.56 8739.06 5041.86 -3145.95 5947414.59 715250.84 MWD+IFR+MS 13451.52 91.02 350.08 8786.96 8738.46 5072.27 -3151.39 5947444.82 715244.53 MWD+IFR+MS 13502.10 90.79 349.92 8786.16 8737.66 5122.07 -3160.17 5947494.35 715234.31 MWD+IFR+MS 13545.84 90.52 349.89 8785.66 8737.16 5165.13 -3167.83 5947537.17 715225.39 MWD+IFR+MS 13576.04 91.20 352.34 8785.21 8736.71 5194.96 -3172.50 5947566.85 715219.87 MWD+IFR+MS 13609.26 91.38 354.48 8784.46 8735.96 5227.95 -3176.31 5947599.72 715215.10 MWD+IFR+MS 13640.66 91.13 356.23 8783.78 8735.28 5259.24 -3178.85 5947630.92 715211.65 MWD+IFR+MS 13669.64 90.33 357.01 8783.41 8734.91 5288.17 -3180.56 5947659.78 715209.11 MWD+IFR+MS 13701.72 90.02 358.93 8783.31 8734.81 5320.23 -3181.70 5947691.79 715207.04 MWD+IFR+MS 13733.17 90.70 1.76 8783.11 8734.61 5351.67 -3181.51 5947723.23 715206.32 MWD+IFR+MS 13768.43 91.38 4.93 8782.47 8733.97 5386.86 -3179.45 5947758.46 715207.35 MWD+IFR+MS 13800.24 92.25 7.48 8781.46 8732.96 5418.47 -3176.01 5947790.15 715209.87 MWD+IFR+MS Halliburton Company Survey Report Company: BP Amoco Date: 5/19/2007 Time: 04:03:53 Page: 5 Field: Pr udhoe Bay Co-ordinate(l\~~;i Ite fcreuce: Well: 09-15. True N orth Site: PB DS 09 Vertical (TVlli Kcfc rcnec: 20 'GL+28.5RK13 48 .5 Well: 09 -15 Section <<'SI Rcfereu ce: Us er (O.OON,O.OOE 345.53Azi) ~Vellpath: 09- i 5A Survey Calculation Method: Mli nirnum Curvature Db: Orade ~ Survev - _ MD Intl __ Azim -- TVD - Sys T~1"D ti:S E/W MapN ~~1:~pE Tonl ft deg deg ft ft ft ft ft ft 13833.81 93.18 8.83 8779.87 8731.37 5451.66 -3171.26 5947823.46 715213.66 MWD+IFR+MS 13864.07 92.25 9.08 8778.44 8729.94 5481.51 -3166.55 5947853.44 715217.50 MWD+IFR+MS 13895.71 92.56 10.45 8777.11 8728.61 5512.67 -3161.19 5947884.74 715221.96 MWD+IFR+MS 13930.60 93.01 12.63 8775.42 8726.92 5546.81 -3154.22 5947919.07 715227.93 MWD+IFR+MS 13961.39 93.42 14.62 8773.69 8725.19 5576.69 -3146.98 5947949.14 715234.31 MWD+IFR+MS 13989.63 93.61 16.69 8771.96 8723.46 5603.82 -3139.37 5947976.48 715241.12 MWD+IFR+MS 14024.49 93.23 20.58 8769.88 8721.38 5636.79 -3128.26 5948009.76 715251.28 MWD+IFR+MS 14053.38 92.37 22.78 8768.47 8719.97 5663.60 -3117.60 5948036.87 715261.15 MWD+IFR+MS 14085.07 92.01 24.36 8767.25 8718.75 5692.63 -3104.94 5948066.24 715272.97 MWD+IFR+MS 14118.45 91.94 27.67 8766.10 8717.60 5722.60 -3090.31 5948096.63 715286.72 MWD+IFR+MS 14148.60 91.36 29.53 8765.24 8716.74 5749.06 -3075.88 5948123.50 715300.37 MWD+IFR+MS 14178.27 90.76 31.44 8764.69 8716.19 5774.63 -3060.83 5948149.48 715314.68 MWD+IFR+MS 14212.32 90.15 34.17 8764.42 8715.92 5803.24 -3042.39 5948178.62 715332.28 MWD+IFR+MS 14243.46 90.76 35.86 8764.17 8715.67 5828.74 -3024.52 5948204.63 715349.40 MWD+IFR+MS 14272.10 90.08 37.33 8763.96 8715.46 5851.74 -3007.45 5948228.11 715365.80 MWD+IFR+MS 14306.68 91.01 39.86 8763.63 8715.13 5878.76 -2985.88 5948255.74 715386.57 MWD+IFR+MS 14338.55 91.01 42.29 8763.07 8714.57 5902.78 -2964.94 5948280.36 715406.80 MWD+IFR+MS 14366.04 91.13 44.92 8762.55 8714.05 5922.68 -2945.99 5948300.80 715425.17 MWD+IFR+MS 14400.65 91.75 47.94 8761.69 8713.19 5946.52 -2920.92 5948325.36 715449.53 MWD+IFR+MS 14431.96 92.06 50.18 8760.64 8712.14 5967.03 -2897.29 5948346.54 715472.56 MWD+IFR+MS 14461.05 92.12 52.37 8759.58 8711.08 5985.21 -2874.61 5948365.37 715494.71 MWD+IFR+MS 14491.29 90.89 53.01 8758.79 8710.29 6003.54 -2850.56 5948384.38 715518.21 MWD+IFR+MS 14522.58 90.77 53.96 8758.34 8709.84 6022.15 -2825.42 5948403.72 715542.80 MWD+IFR+MS 14554.27 90.46 53.90 8758.00 8709.50 6040.81 -2799.81 5948423.11 715567.86 MWD+IFR+MS 14598.23 91.70 55.95 8757.17 8708.67 6066.06 -2763.84 5948449.40 715603.08 MWD+IFR+MS 14648.97 91.38 56.92 8755.80 8707.30 6094.11 -2721.57 5948478.65 715644.51 MWD+IFR+MS 14693.65 90.89 56.36 8754.92 8706.42 6118.67 -2684.26 5948504.29 715681.09 MWD+IFR+MS 14742.70 90.28 55.59 8754.42 8705.92 6146.12 -2643.61 5948532.90 715720.93 MWD+IFR+MS 14788.63 90.22 55.94 8754.22 8705.72 6171.96 -2605.64 5948559.83 715758.13 MWD+IFR+MS 14848.71 91.23 56.77 8753.46 8704.96 6205.24 -2555.63 5948594.54 715807.15 MWD+IFR+MS 14900.45 91.82 59.32 8752.08 8703.58 6232.61 -2511.75 5948623.17 715850.22 MWD+IFR+MS 14944.58 92.02 58.86 8750.60 8702.10 6255.27 -2473.91 5948646.92 715887.38 MWD+IFR+MS 14993.53 91.90 58.25 8748.93 8700.43 6280.79 -2432,17 5948673.64 715928.36 MWD+IFR+MS 15040.10 91.96 58.74 8747.36 8698.86 6305.11 -2392.49 5948699.10 715967.32 MWD+IFR+MS 15088.81 91.95 57.94 8745.70 8697.20 6330.66 -2351.06 5948725.84 716008.00 MWD+IFR+MS 15135.59 92.20 58.33 8744.00 8695.50 6355.34 -2311.35 5948751.66 716046.97 MWD+IFR+MS 15183.72 92.39 58.17 8742.08 8693.58 6380.65 -2270.46 5948778.14 716087.11 MWD+IFR+MS 15230.05 91.95 58.12 8740.32 8691.82 6405.08 -2231.13 5948803.70 716125.71 MWD+IFR+MS 15275.67 91.58 58.22 8738.92 8690.42 6429.13 -2192.39 5948828.86 716163.73 MWD+IFR+MS 15324.55 91.21 57.09 8737.73 8689.23 6455.27 -2151.11 5948856.19 716204.24 MWD+IFR+MS 15368.46 91.20 56.99 8736.80 8688.30 6479.16 -2114.27 5948881.13 716240.36 MWD+IFR+MS 15419.61 89.73 57.96 8736.39 8687.89 6506.66 -2071.15 5948909.87 716282.67 MWD+IFR+MS 15464.83 89.73 57.69 8736.60 8688.10 6530.74 -2032.88 5948935.05 716320.23 MWD+IFR+MS 15513.49 89.82 57.44 8736.79 8688.29 6556.84 -1991.81 5948962.33 716360.52 MWD+IFR+MS 15558.93 89.95 57.95 8736.88 8688.38 6581.12 -1953.40 5948987.71 716398.20 MWD+IFR+MS 15607.89 90.10 56.75 8736.86 8688.36 6607.53 -1912.18 5949015.31 716438.64 MWD+IFR+MS 15652.84 90.19 56.98 8736.75 8688.25 6632.10 -1874.54 5949040.96 716475.55 MWD+IFR+MS 15701.30 90.48 57.10 8736.46 8687.96 6658.47 -1833.88 5949068.49 716515.43 MWD+IFR+MS 15748.04 90.76 56.98 8735.96 8687.46 6683.90 -1794.66 5949095.04 716553.89 MWD+IFR+MS 15778.00 91.07 56.85 8735.48 8686.98 6700.25 -1769.56 5949112.12 716578.50 MWD+IFR+MS 15820.00 91.07 56.85 8734.70 8686.20 6723.21 -1734.41 5949136.09 716612.98 PROJECTED to TD ~ rcrr -, nw~, vnv ~ WELLHEAD = FMC = AXELSON ', KB. ELEV = 54' BF. ELEV = KOP = 3355' Max Angle = Datum MD = Datum TV D = 8800' SS • ~~~ ~ ~ - 13-318" CSG, 72#, N-80, ID = 12.347" I-{ 2731' SAFETY NOTES: 2279' -19-5/8" 40#,L-80 TCII,(8.835" ID) 2007.54' 4-1/2" X Nipple, ID = 3.813" 227g' HES 9-5/8" ES Cementer FO Cementers 2400` and 2523' 7304' 7" Hanger /liner top packer Minimum ID = 3.725" @ 9909.08 4-112" XN NIPPLE 7,479' 9 5/8" Windaw~ 9843.95' 4 1/2" X Nipple (3.813" ID) TOC 9500' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 90° ~ 15550' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 15550 - 15650 Oon 05/06/07 9-518" CSG, 47#, N-80, ID = 8.681" I-{ 10040' PBTD = 15730` DATE REV BY COMMENTS DATE REV BY COMMENTS 09/08!77 ORIGINAL COMPLETION 10(05/87 LAST WORKOVER 01/26/07 JEN Proposed sidetrack 05/09/07 MS/DM SidetracklPerf NABOBS 2ES 05109/07 MGStPAG DRLG DRAFT CORRECTIONS 9864.78' 7" x 4 1/2" Baker S3 Packer 9888.33' 4 1/2" X Nipple (3.813" ID) 9909.08' 4 1/2" XN Nipple (3.725" ID) 9914' 4 112" Hanger /liner top packer 9920.17' 4 112" WLEG 10070' 7" 26# L-80 (6.276" ID) i 4 1(2" 12:6#, L-80 IBT-M, 3.958" ID 15818' PRUDHOE BAY UNff WELL: 09-15A PERMIT No: 1770360 API No: 50-029-20256-01 SEC 1, T10N, R15E, 4163.84' FEL & 1134.65' FNI ~~~~ ~~ i?~.C?3A.3~ICAL INTEGRITY R :PORT _?~~D ~'.__ ~ ~I1~'~~ OPER ~ FIELD ~~ ~~~~E ~y _ 1 =..G ~:~..I._..I. ~/S_ ~ ~ i.~LL NUMBER ~~ ~~~,~ I~ ~~ LL DAT~_ T•D : '1.5~5~~?~.. ~5~3~ TVZ) ; PBTD : 1~~~, MD ~s`~3 ~ TVD '1.ti ~ ~- ~.s~ : `1' ~ Shoe : t~`1l~ ~m `~' ~ 'rv~ ; Te~~ : '13~~1 ~ ~ "15 ~ - _ ~~D e .: ~i <j , i Shoe : ~ ~~ '~D ~3 ~ '?' SIP, ~ = C P . ~~_'.~ ~SS6 1 ~'i D -~o;~v ~~~~ Packer ~C.~~'~ TVD; Set at ~~~ ole S~ce ~6`I~- and ~o~~~ Perks i~~S~ to ~StP~~' X513'1 ~~~ 5s'13 h ~C'r'~?~=C~.r INTEGRITY - P?_RT #? r_nr:ulus Press Test: -? (;~15 nin ~0 mi.n Cormrents : -~v~:~.c ~ ~Q. ~S~t-J ~C~ _~~~~T~ r ~~~`~~ ~ cow ~~~®~ ~'CHANICr~ INTEGRITY' -PART # Z ~~~~ Cement voli~es s ~~t. Diner r~b~~~ ; ~ ~~~~~`5 ; DV `~ R . Cwt JoI to cover oers C..~~cv~C~~-C~ ~~c~~~CO'~~i~~ ~, ::eoretical TOC ~~ p~..~~C.~ ~~~~~'' Cement Bond Log (Yes or No) ~~S In AOGCC File CBL Evaluation, gone above perfs ~~~r- `~~ °~~sO~ca~ ~~~~a~ € Production Log: Type Evaluation CON~:>:LJS ~ Ot1S Part iI: .-~ `~ i~ ~ ar ~ i L : \ \ .-ice ~ S \ `~lJ \~L'~. 06/15/07 ~' ~, ,-; Schlumberger Alaska Data 8< Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~v~--oaa Wnll Inh 8 1 nn nncrr: nf:nn NO. 4304 Company: State of Alaska Alaska Oii 8 Gas Cons Comm Attn: Christine Mahnkem 333 West 7th Ave, Suites 100 Anchorage, AK 99501 Field: Prudhoe Bay n~~., c~ r..~... rn P1-16 11637331 WARMBACKS &SBHPS 05104/07 1 P1-14 11637332 WARMBACKS &SBHPS 05105/07 1 01-05 11626486 USIT (CEMENT) 05/13/07 1 01-05 11626486 USIT (CORROSION) 05/13/07 1 MPH-14 11638633 INCLINOMETER-DIRECTION LOG 05113/07 1 MPS-01A 1159454 MDT 05/28/07 1 11-18 11626097 USIT 05/26107 1 09-15A 11629015 SCMT 06/01/07 1 12-12A 11695061 CEMENT IMAGE & BOND LOG 05/28/07 1 03-36A 11629014 SCMT 05/31/07 1 S-401 11626492 SCMT 06/11/07 1 r LGr~JG MVn1YV rvLCIJVC RCliCll~ 1 6T Jllll`IINV Nn1U RC I URIVIIVU VIVt liVY7 tAliF1 I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 _ 900 E. Benson Blvd ~`.~ I @ ~` 6-,.;. ~I Anchorage, Alaska 99508 _ _ V j - ~~ ~r ~{°--~ Date Delivered: r.f _ /„ _ :~I n s ~ ~°', Ana,, ~~3iYt~t~l"~t~p"S~ ,'" `' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~_ .. `~~ ~-'' • 22-May-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 09-15A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 7,446.50' MD Window /Kickoff Survey 7,479.00' MD (if applicable) Projected Survey: 15,820.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date Si ned v Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a~~- ~~~ we1109-15A: 8-3/4" FIT Subject:-well 09-ISA: 8-3/4" FIT From: "Allen, Kenneth W" <Ke~meth.Allen@bp.com> Date: Mon, I6 Apr 2007 10:29:02 -0800 ~-~~ _ ~ ~_~_ To: Thon~~ls ~Iaundcr ~==tom maunder<<i~admin.statc.ak.us=- ('C: "Smith, Phil G (ASRC')" <=-PhiI.G.Smit}1~ci'BP.con~= "E [obbs, Grc<~ S IANC)" ` Gre~.liohbsa,I3P.cum~-~_ "V~SU, AD~V Drl~~ Ri~~ 7 E5" ~~~~`S~'AD~~`DrlLfhi~7~:a'BP.com.~~ Tom, This is a follow up to our conversation Sunday morning (4/15/07). As we discussed, the FIT came in at 10.8 ppg which was lower than we submitted in the 09-15A drilling permit. ran the kick tolerance calculations and we still have infinite kick tolerance with our 9 ppg mud in the hole. The FIT chart did not show a "break down" of the formation, but rather a slow leak off or a slope change in the line once past the 10.8 ppg mark. The pressure was brought up to the permitted FIT pressure and the still no break down of the formation was noted. After our conversation BP plans to drill ahead in this interval as permitted. Thanks for your help and the discussion last weekend. if you have any further questions or need further clarification please give me a call or reply to this a-mail. Ken Allen Operations Drilling Engineer GPB Rotary Mobile: 907.748.3907 Office: 907.564.4366 e-mail: Kenneth.Allen BP.com 1 of 1 4/17/2007 9:38 AM • Page 1 of 2 Maunder, Thomas E (DOA) From: NSU, ADW Drlg Rig 2es [NSUADWDrIgRig2es@bp.com] Sent: Friday, April 06, 2007 4:54 PM To: Thomas Maunder Subject: RE: DS 09-15 Wellhead Blanking Plug Tom, Thanks for the approval. We have been unable to get the blanking plug screwed into the tubing hanger threads so will proceed with pulling the tubing hanger as discussed. The hole is filled with seawater and reservoir pressure in this area is in the range of 7.3 ppg EMW so seawater is kill weight fluid. Jeff Jones agrees with our plan and was the person who suggested that I contact you for approval. Thanks for you help and Happy Easter weekend. Dick Maskell BPX Company Rep Nabors 2ES maskelcr@bp.com Tel: 659-4103 Fax: 659-4177 From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, April 06, 2007 3:21 PM To: NSU, ADW Drlg Rig 2es Cc: Hobbs, Greg S (ANC); Smith, Phil G (ASRC); AOGCC North Slope Office Subject: Re: DS 09-15 Wellhead Blanking Plug Dick, Good to speak with you as well. Your plan is acceptable. In addition to the tested cement plug, there is also fluid in the hole. Sea water is likely sufficient to qualify for KW fluid. You also related that you had discussed this plan with Jeff Jones. Good luck with the operations. Tom Maunder, PE AOGCC NSU, ADW Drlg Rig 2es wrote, On 4/6/2007 2:53 PM: Tom, We're starting the decompletion on the above well and having removed the xmas tree, we notice the threads in the tubing hanger profile are damaged. We are attempting to install the blanking plug in these threads in order to be able to test the BOPE before starting to pull tubing. in the event that we cannot get the blanking plug made up fully, we are seeking permission from the AOGCC to unseat the tubing hanger from the wellhead, pull it to the rig floor and lay it down along with 1 or 2 joints of tubing. We would then install a BOP test plug in the tubing string, land the test plug it in the tubing hanger profile and perform the BOP test against it (as per our telephone conversation of this pm). The well is fully safed out with a downhole cement abandonment plug that 7/10/2007 Page 2 of 2 has been tested to 1500 psi. Your assistance in giving us permission for this contingency plan would be much appreciated -good talking to you this afternoon. Regards Dick Masked BPX Company Rep Nabors 2ES maskelcrC~bp.com TeL• 659-4103 Fax: 659-4177 7/10/2007 SARAk PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-15A BP Exploration (Alaska) Inc. Permit No: 207-022 Surface Location: 994' FSL, 150' FWL, SEC. Ol, T10N, R15E, UM Bottomhole Location: 2438' FSL, 1583' FEL, SEC. 35, T11N, R15E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to redrill the above referenced service 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 anal 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 (909-3607 (pager). ly, Chairman DATED this ~ day of March, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~/A?w01 ALASKA OIL AND GAS CONSERVATION COMMI N ~. PERMIT TO DRILL ~ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is prop,$~ ^ Coalbed Methane LJ G~~rates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 09-15A '~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 15912 TVD 8742 ~ 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 994' FSL 150' FWL SEC 01 T10N R15E UM 7. Property Designation: ADL 028324 ~ Pool , , . , , , Top of Productive Horizon: 5277' FSL, 1469' FEL, SEC. 02, T10N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: March 1, 2007' Total Depth: 2438' FSL, 1583' FEL, SEC. 35, T11 N, R15E, UM ~ 9. Acres in Property: 2560 / 14. Distance to Nearest Property: 17,200' ' 4b. Location of Well (State Base Plane Coordinates): Surface: x-718542 y-5942466 Zone-ASP4 10. KB Elevation Plan (Height above GL): 63,8 feet 15. Distance to Nearest Well Within Pool: 200' 16. Deviated Wells: Kickoff Depth: 7500 feet Maximum Hole An le: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3340 Surface: 2460 18: Casin Pr ram: S cificatio ns To - Settin ' De th -Bo ttom uanti of Cement c f. or sa s Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1 /2" 7" 26# L-80 TC-I I 2768' 7350' 6788' 10118' 8704' 169 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 5944' 9968' 8607' 15912' 8742' 694 sx Class 'G' 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill-and Re-entry Operations) Total Depth MD (ft): 10040 Total Depth TVD (ft): Plugs (measured): 9123 9445 Effective Depth MD (ft): 9445 Effective Depth TVD (ft): 8564 Junk (measured): None Casing Length Size Cement Volume ' MD D Conductor /Structural 100' 20" 258 sx Arcticset II 100' 100' Surface 2731' 13-3/8" 6200 sx Arcticset II 175 sx AS I I 2731' 2731' Intermediate Production 10028' -5/8" 1000 sx Class 'G' 300 sx AS II 1 028' 9112' Liner Perforation Depth MD (ft): 9620' - 9920' Perforation Depth TVD (ft): 8727' - 9010' 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 foregging is true and correct. Contact Phil Smith, 564-4897 Printed Name Greg bbd Title Senior Drilling Engineer Jim Nigh, 564-5220 Prepared By Name/Number: Si nature <_ ~ Phone 564-4191 Date ~?' ~~ ,,,~ Terrie Hubble, 564-4628 .Commission Use Onl Permit To Drill Number: ~~ API Number: 50-029-20256-01-00 Permit A proval See cover letter for Date: ~ • other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed me~th/ane, gas hydrates, or gas contained shales: ,~,/ ~d't9 QS~ ~Q ~r25~ • ~~'~ ~` ~ C~W~~~~d~Samples Req'd: ^ Yes Lt0 No Mud Log Req'd: ^ Yes L+1 No ~~ ~\~~~ ZS Measures: Yes ^ No D ectional Survey Req'd: Yes ^ No 1~~~~~c a ~~,~C~~,o~.c.,`'r~ Gc cccc Other: ~~ ~f 1 i Date ~'~ f~')'' ~ ~ ` APPROVED BY THE COMMISSION COMMISSIONER ~~~~~ V k= ~E~ 1 2 2007 20 AAC 25.005 - Form 10-401 Revised 12/2005 Submit In Duplicate • • Well Name: 09-15A Planned Well Summary Horizontal Well 09-15A Type Sidetrack MIST Object ve Zone 2 In'ector API Number: 50-029-22503-01 Current Status 09-15 Shut-In and P&A Procedures commencing Estimated Start Date: 01-Mar-2007 Time to Com lete: 31.0 Da s Surface Northin Eastin Offsets TRS Location 5,942,466 718,542 993' FSL / 150' FWL 10N, 15E, 01 Northin Eastin TVDss Offsets TRS Target 5,946,701 716,796 -8,762 3' FNL / 3810' FWL 11 N, 15E, 02 Locations 5,947,535 715,145 -8,743 878' FSL / 2185' FWL 11 N, 15E, 35 Bottom Northin Eastin TVDss Offsets TRS Location 5,949,138 716,610 -8,693 2841' FNL / 3697' FWL 11 N, 15E, 35 Planned KOP: 7500'MD / 6858'TVDss Planned TD: 15,912'MD / 8,742' TVDss Ri Nabors 2ES CBE: 31.3' RTE: 63.8' Directional -Sperry P08 KOP: 7500' MD Maximum Hole Angle: ~50° in the 8-1/2" intermediate section (tangent sail angle) ~94° in the 6-1/8" horizontal section Close Approach Wells: DS9-07A passes 200'under the planned DS9-15Ai and 78' inside the allowable deviation ellipse at 11,134' MD. Log-based depth control in the reservoir section provides anti-collision confidence. The well passes minor risk criteria at a 1:200 chance of collision. Surve Pro ram: MWD Standard + IFR /Cassandra / MS Nearest Pro ert Line: 17,200' to the PBU property line Nearest Well within Pool: DS9-07A is 200 vertical feet away from planned well 09-15A at 11,134' ~,, -='''~ planned MD. The wells are separated by Ivishak Zone 2 shale and a 1~~'~'a 9/12/2002 borax log of DS9-07A indicates good cement isolation. DS9-15A ' will provide future FOR support for DS9-07A at its heel approximately 1000 from the closest planned perforation of DS09-15A. Area of Review Anal sis is in ro ress 09-15A Permit to Drill Application Page 1 • Formation Markers 09-15A (Based on SOR) Formation Estimated Formation Tops (TVDss) (TVDbkb) (MDbkb) Estimated Pore Press. ( EMW / Psi) UGl j 5855 5904 6258 WS2 6390 6439 6921 WS1 6610 6659 7195 CM3 6845 6894 7489 CM2 7335 7384 8107 CM1 8015 8064 9123 THRZ 8409 8458 9736 BHRZ 8593 8642 10022 LCU 8655 8704 10118 42N 8655 8704 10118 42P 8665 8714 10134 31N 8670 8719 10143 31P 8680 8729 10158 27N 8722 8771 10224 27P 8722 8771 10224 26N 8770 8819 10319 26P 8770 8819 10319 25N 8787 8836 10365 25P 8793 8842 10381 7.3 / 3340 24N 8808 8857 10432 24P 8827 8876 N/A 23N MHO/HOT 9009 9058 N/A Casinq/Tubinq Program Hole Csg / Wt/Ft Grade Conn Burst Collapse Length Top Bottom Size Tbg (psi) (psi) MD / MD / O.D. TVDrkb TVDrkb 8-'h" 7" 26# L-80 TC-II 7,240 5,410 2768' 7,350' / 10,118' / 6,788' 8,704' 6-1/8" 41h" 12.6# L-80 IBT-M 10,160 10,530 5,944' 9,968' / 15,912' / 8,607' 8,742' Tubing 41h" 12.6# L-80 TC-II 10,160 10,530 9,944' 30' / 30' 9,974,' / 8,611' 09-15A Permit to Drill Application Page 2 • ~ Mud Program Whipstock Millina Mud Properties: LSND Whin Stock Window 9-5/8". 47# Densit PV YP API FL HTHP FL MBT PH 9.0 16-30 30-35 <6.0 N/C N/C 9.0-10 Intermediate Mud Properties: LSND 8-1/2" hole section Depth Interval Density (ppg) PV YP API FL HTHP FL MBT PH 7,500'-9,650' 9.0 - 9.5 14-26 26-30 <6.0 N/C <15 9.0-10 9,650'-10,118' HRZ to LCU 11.0 15-22 26-30 4.0-6.0 <10.0 <15 9.0-10 Production Mud Properties: FLOPRO SF Reservoir Drill-in Fluid I 6-1 /8" hole section De th Interval Densit PV YP LSVR API FI H MBT 10,118'-15,912 8.4 - 8.5 8-12 22-28 >20,000 6.0-8.0 9.0-9.5 < 3 Loaaina Proaram 8-1/2" Intermediate: Sample Catchers - as required by Geology Drilling: Dir/GR at Bit/Res/PWD Open Hole: None Cased Hole: USIT + 9 5/8" USIT 6-1/8" Production: Sample Catchers - as required by Geology Drilling: Dir/GR/Res/ABI Open Hole: None Cased Hole: None Cement Program Casing Size: 7" 26#, L-80 Intermediate Liner Basis: Lead: None Tail: 1,000' of open hole with 40% excess, plus 80' shoe track Tail TOC: 9,118' MD Total Cement Volume: Spacer 40 bbls of Viscosified Spacer weighted to 12.5 ppg (Mud Push II) Lead N/A Tail 34.8 bbls, 195 cuft, 169 sks 15.8 Ib/ al Class G + adds -1.16 cuft/sk Temp BHST =188° F. BHCT ###° F estimated by Schlumberaer Casin Size 4.5" 12.6#, L-80 Production Liner Basis: Lead: None Tail: 5,794' of open hole with 40% excess, 80' shoe track, 150' 4-%z" x 6-1/8" liner lap, and 200' of 7" x 4" DP excess. Tail TOC: 9,918' MD 0200' above Liner Top) Total Cement Volume: Spacer 40 bbls of Viscosified Spacer weighted to 10.0 ppg (Mud Push II) Lead None Tail 144.5 bbls, 812 cuft, 694 sks 15.8 Ib/ al Class G + adds - 1.17 cuft/sk Temp BHST =194° F, BHCT TBD by Schlumberger 09-15A Permit to Drill Application Page 3 r Surface and Anti-Collision Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. At surface 09-51 to the north and 09- 46 to the south are nearest at 30' and 60' away, respectively. Close Approach Shut-in Wells: DS9-07A passes 200'under the planned DS9-15Ai and 78' inside the allowable deviation ellipse at 11,134' MD. Log- based depth control in the reservoir section provides anti-collision confidence. The well passes minor risk criteria at a 1:200 chance of collision. Hydrogen Sulfide DS15 is not designated as an H2S site. Recent H2S data from the pad is as follows: Date of Well Name H2S Level Reading #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Other Relevant H2S Data (H2S alarms from rigs, etc.) 09-51 151 3/20/2003 09-46 130 3/16/2006 04-09 40 3/20/2003 04-31 32 1/14/2006 09-OSA 1361 10/20/2000 DS 9 is an H2S drill site. Follow H2S SOP on the pad and post H2S contingency plan in the doghouse. Faults A single fault of 10-20' throw is expected at 12,075' MD (±150'). Lost circulation is not expected and the wellbore trajectory is planned at near 90° intersection to minimize the fault contract length. 09-15A Permit to Drill Application Page 4 • Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. BOP regular test frequency for 09-15A will be 14 days during drilling phase and 7 days during ~ decompletion and surface casing work. Below is an excerpt from the permit to drill application requesting a variance to the requirements of 20 AAC 25.035 (e)(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285 (f)(2) TUBING WORKOVERS; or, 20 AAC 25.286(e)(1) WORKSTRING SERVICE OPERATIONS "BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, exc t when the routine use of BOP equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this reque t wil of compromise the integrity of the BOP equip nt." 1~a vc~c c t~. ~~ c~ - ~ ~~ Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. ~~I~i" ' " art;'~1 Intermediate Interval Maximum antici ated BHP 3340psi 8800' TVDss (7.3 pp EMW) Maximum surface ressure 2460 psi .10 psi/ft as radient to surface) Kick tolerance Infinite over 10.6 pp FIT assuming 8.5 pp reservoir and 5" drillpipe Planned BOP test pressure Rams test to 4,000 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin Test 4000 psi surface pressure Inte rit Test - 8-1/2" hole 12.5 pp FIT after drillin 20' from middle of window Production Interval Maximum antici ated BHP 3340psi 8800' TVDss (7.3 pp EMW Maximum surface ressure 2460 psi .10 psi/ft as radient to surface Kick tolerance Infinite with a 10.0 pp FIT Planned BOP test pressure Rams test to 4,000 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin /7" Liner Test 4000 si surface pressure Inte rit Test - 6-1/8" hole 10.0 pp FIT after drillin 20' of new hole Planned completion fluids 8.5 pp Seawater / 7.2 pp Diesel No annular injection in this well. ~ Disposal Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class I I wastes to DS-04 for r injection. Haul all Class I waste to Pad 3 for disposal. 09-15A Permit to Drill Application Page 5 • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Ivishak in this fault block is expected to be under-pressured at 7.30 ppg EMW. This pressure is estimated based on offset well pressures. 4000 psi test pressure is in accordance with the RP for injector well casing tests. II. Lost Circulation/Breathing A. DS-9 has little history of significant lost circulation. One fault of 10-20' through is expected at ±12,075' MD, but losses are not anticipated. The lost circulation decision tree should be followed if losses occur. If total losses occur at the fault a gunk squeeze is recommended (procedure will be provided). B. The lower cretaceous unconformity (LCU) has truncated the Kingak, Sag River, Shublik, and much of Zone 4 at the planned 7" casing point. Picking the 7" casing point will be more challenging without the Sag River transition and drilling deep into Zone 4 significantly increases the chance of lost circulation. GR-at-bit will be included in the intermediate BHA to ensure that 8 %2" TD can be picked above the LCU. III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for both the intermediate and production hole sections is infinite with planned mud weights. The FIT will prove up adequate formation strength for expected ECD's. B. Integrity Testing Test Point Test Depth Test EMW (lb/gal) t e 9 5/8" 20-ft minimum from the 9-5/8" FIT 12.5 minimum window window 7" shoe 20-ft minimum from the 7" shoe FIT 10.0 minimum IV. Stuck Pipe A. Significant directional work will be required in the production hole section. Hole cleaning and differential sticking tendency will be of concern. Watch for signs of tight hole and short trip /back ream as required to avoid stuck pipe. VI. Hydrogen Sulfide A. DS-9 is designated as an H2S site; Standard Operating Procedures for H2S precautions should be followed at all times. H2S levels of potentially lethal concentrations have been recorded on this pad. Perform H2S drills regularly and ensure all personnel are properly training and follow the SOP for H2S. VII. Faults A. Little faulting is expected along the planned trajectory. See Section II on lost circulation for more details. VIII. Anti-Collision Issues B. DS9-07A passes 200'under the planned DS9-15Ai and 78' inside the allowable deviation ellipse at 11,134' MD. Log-based depth control in the reservoir section provides anti-collision confidence. The well passes minor risk criteria at a 1:200 chance of collision. CONSULT THE DS 9 DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 09-15A Permit to Drill Application Page 6 • ~ Operations Summary Current Condition: / Fill cleanout to 9979' an 10/1/87 during RWO / Last wireline tag TD at 9692' (over 200' of perfs covered) on 6/10/04 / PXN plug set in tubing tail at 9445; schmoo cleaned from XN prior to setting plug. / Uncemented 13 3/8" x 9 5/8"annulus passes 200D psi pressure test, buf builds pressure over time. Scope Pre-Riq Work: 1. RU slickline and pull the PXN plug from the tailpipe at 9445' MD. 2. Drift the tubing and tag top of fill. 3. Displace the well to clean seawater and fluid pack the IA with diesel. 4. Lay cement abandonment plug from top of fill to 9500' MD. 5. Jet cut the tubing in the middle of a full joint at ±7700' MD. 6. Circulate the tubing and IA to seawater with 2000' TVD of diesel. 7. Pressure test casing and cement plug to 3500 psi. 8. Bleed casing and annulus pressures to zero. 9. Cycle the tubing hanger LDS and test the 9 5!8" mandrel packoff to 5000 psi. 10. Set a BPV and test to 1000 psi from tubing annulus. Remove well house and flow lines. Secure the well. Level the pad as necessary. Riq Operations: 1. MI / RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displace the well to seawater. Set BPV/TWC. 3. Nipple down tree. Nipple up and test BOPE to 4,000psi. Pull BPVlTWC. 4. R/U. Pull 5 ~h" tubing from the cut depth at 7,700' MD and above. 5. RU E-line. RIH w/ 8 ~/z" gauge ring /junk basket to top of tubing stub. 6. RIH with HES EZSV and set the cement retainer as required to avoid cutting casing collar and place top of whipstock at 7500. 7. Run USIT from 7500' to surface to investigate 9 5/8" corrosion and determine TOC between 13 3/8" and 9 5/8" casings. Evaluate for possible cement stringers above TOC. 8. String shot across first 9 5/8" casing collar above TOC. 9. RIH with casing cutter and cut the 9 5/8" casing in the middle of the first full joint above TOC. 10. Circulate arctic pack from the 9 5/8" x 13 3/8" annulus with 150 bbls heated diesel followed by heated seawater. 11. Spear casing at surface. Pull and lay down 2000' of 9 5/8" casing and mandrel hanger packoff. 12. RIH with 13 3/8" casing scraper to top of 9 5/8" stub. Circulate residual arctic pack from the well. POH, LD scraper. 13. RIH with 9 5/8" back off tool. Back off cut stub. 14. RIH 9 5/8" spear and recover cut stub. 15. RU casing handling tools. MU 9 5/8" triple connection sub and ES cementer on 9 5/8" casing. RIH, screw into 9 5/8" casing. Pressure test to 1500 psi. 16. Perform single stage cement job through ES cementer. Bump plug and close ES cementer. 17. Flush and drain BOP. Split stack and install emergency slips. 18. Cut casing with Wach's cutter and install packoff, test same. 19. NU and test BOPs. ~~~ _ o SCE 20. Pressure-test the 9 5/8" casing to 4,000psi for 30 minutes. Record test. 1 21. P/U and RIH with 9 5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock, as desired, and set on bridge plug. Shear off of whip stock. A 22. Displace the well to 9.0 ppg LSND based milling fluid. Completely displace the well prior to beginning 23. Mill window in 9 5/8" casing at ± 7,500' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 24. Pull up into 9 5/8" casing and conduct an FIT to 12.5 ppg EMW. POOH. 09-15A Permit to Drill Application Page 7 1 25. M/U 8'/z" RSS BHA. RIH, kick off and drill the 8 1/2" intermediate section to the top of the HRZ. Weight up to 11.0 ppg prior to entering HRZ. 26. Continue ahead, per directional proposal to base HRZ /Top Zone 4. Circulate well clean, short trip to window. POOH. 27. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. Test to 4000 psi. 28. M/U 6 1/8" Dir/GRlReslABl assembly. RIH to the landing collar. 29. Drill out the liner float equipment and cement to the shoe. 30. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 31. Drill out the 7" shoe plus drill ~20' new formation; pull up into the shoe and conduct an FIT to 10.0 ppg EMW. Drill ahead to horizontal landing point. POOH for bit / BHA change. 32. RIH, drill horizontal section to planned TD, short trip as necessary. 33. Circulate, short trip, spot liner running pill, POOH. 34. Run and cement a 4'/z", 12.6#, L-80 production liner. POOH UD all drill pipe. .-~ 35. Run USIT log from top of 4'/z" liner to top of cement behind 7" drilling liner. 36. RU SLB and RIH w/ 100' 2-7/8" 2906 Powerjet guns set @ 6 SPF. Tag PBTD. 37. Put guns on depth and fire. POOH and verify all shots fired. 38. R/U and run 4 1/2", 12.6#, L-80 completion tubing. Land the tubing RILDS. 39. Set a TWC and test to 1000 psi 40. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. 41. Reverse circulate inhibited seawater followed by 2200' of diesel to the packer depth. Bullhead 2200' of diesel down the tubing. Drop packer setting ball with rod. 42. Set packer and individually test the tubing and annulus to 4,000psi 30 minutes. Record each test. 43. Secure the well. Rig down and move off. Post-Rig Work: 1. Install well house and instrumentation 2. MI / RU slick-line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 3. POP well to test unit until cleaned up. 09-15A Permit to Drill Application Page 8 t TREE _ ~ FMC GEN 1 WELLHEAD= FMC ACTUATOR = AXELSON KB. ELEV - BF. ELEV = KOP = 54` 3355' Max Angle Datum MD = Datum TV D = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" ~~ 2731' Minimum ID = 3.725" @ 9956' 4-1/2" XN NIPPLE TOC 9500' SA OTES: 09-15Ai 2100' 4-1/2" X Nipple, ID = 3.813" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical oerf data 9620 - 9920 tooza 9-5/8" CSG, 47#, N-80, ID = 8.681" -~ 7350` -Top of Liner 7500' 9 5/8" Window 9905' 4 1/2" X Nipple (3.813" ID) 9915' 7" x 4 1!2" Baker S3 Packer 9942' 4 1/2" X Nipple (3.813" ID) 9962' 4 1/2" )QJ Nipple (3.725" ID) 9969' 4 1/2" Hanger /liner top packer 9972' 4 1/2" WLEG 10118' 7" 26# L-80 (6.276" ID) 41IZ' 128#, L~06TF~ 3813' 15~1Z DATE REV BY COMMENTS DATE REV BY COMMENTS 09/08/77 ORIGINAL COMPLETION 10/05/87 LAST WORKOVER 01/26/07 JEN Proposed sidetrack PRUDHOE BAY UNIT WELL: 09-15A PERMIT No: fi1770360 API No: 50-029-20256-01 SEC 1, T10N, R15E, 4163.84' FEL & 1134.65' F BP Exploration (Alaska) ,TREE _ ~ FMC GEN 1 WELLHEAD = ACTUATOR = FMC AXELSON KB. ELEV = 54' BF. ELEV = KOP = 3355' Max Angle = 37 @ 7079' Datum MD = 9755' Datum TV D = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" I~ 2731' Minimum ID = 4.45" @ 9445' 5-112" OTIS XN NIPPLE 5-112" TBG-PC,17#, N-80, .0232 bpf, ID = 4.892" ~ 9457' PERFORATION SUMNtARY REF LOG: BHCS ON 09/02/77 ANGLE AT TOP PERF: 20 @ 9620' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 9620 - 9650 S 09130/87 3-3/8" 6 9620 - 9680 O 07/04/03 2-1/8" 4 9672 - 9692 S 09/30/87 4" 4 9700 - 9736 O 09!21!92 3-3/8" 1/8 9754 - 9762 O 01/11/90 3-3/8" 1/10 9774 - 9784 O 01/11/90 3-318" 1f5 9789 - 9794 O 01/11/90 3-3/8" 4 9812 - 9846 S 09/30/87 3-3/8" 1/2 9854 - 9858 O 01/11/90 4" 4 9874 - 9886 O 10/21/87 4" 4 9892 - 9906 O 10/21/87 3-3/8" 8 9915 - 9920 O 01/11/90 PBTD 10028' r~oZ.B 9-5/8" CSG, 47#, N-80, ID = 8.681" - O ~ _ ~ SAOTES: CRACK IN TBG HGR COUPLING ALL TxIACOMM. *** 5 2196' -15-1/2" CAM BAL-O SSSV NIP, ID = 4.56" 9326' -j5-1/2"BAKERPBRASSY 9341' 9-5/8" X 5-1/2" BAKER SAB PKR 9445' -~ 5-1/2" OTIS XN NIP, ID = 4.45" 9445' S-1/2" PXN PLUG (09/24/05) 9457' ~5-1/2" BAKER SHEAROUT SUB 9458' 5-1/2" TUBING TAIL 9470' ELMD TT LOGGED 10/21!87 DATE REV BY COMMENTS DATE REV BY COMMENTS 09/08/77 ORIGINALCOMPLETION 07/04/03 PWE/TLP ADDPERF 10!05187 LAST WORKOVER 08/29/03 KC/TLH WANER SAFETY NOTE 09/23!01 RN/KAK CORRECTIONS 09/24/05 WTS/TLH PXN PLUG SET 09/02!02 BHC/TP PERF CORRECTIONS 10/02105 EZL/PAG WANER SFTY NOTE DELETED 09/10/02 BHC/TLH PERF CORRECTIONS 02/09/03 ATD/TP WANERSFTY NOTE DELETED PRUDHOE BAY UNfT WELL: 09-15 PERMIT No: €1770360 API No: 50-029-20256-00 SEC 1, T10N, R15E, 4163.84' FEL & 1134,65' FNL BP Exploration {Alaska) • Plan: 09-15A Wp #8 Sperry Drilling Services Proposal Report -Geographic 26 January, 2007 BP Amoco Prudhoe Bay PB DS 09 09-15 -Slot 15 Plan 09-15A Local Coordinate Origin: Centered on Well 09-15 -Slot 15 Viewing Datum: 20'GL+28.5RK6 @ 48.50ft (20'GL+28.5RKB) TVDs to System: N North Reference: True Unit System: API - US Survey Feet HAI_LIBURTON Sperry Drilling Ssrvic®s Project: Prudhoe Bay COMPANY DETAILS: BP Amoco Site: PB DS 09 ~ Calculation Method: Minimum Curvature Well: 09-15 ~ Error system: ISCWSA Scan Method: Trav. Cylinder North Wellbore: Plan 09-15A Ertor Surface: Elliptical Conic Plan: 09-15A Wp #8 Waznmg Method: Rules Based WELLBORE TARGET DETAILS (MAP CO-ORDINATES) Name TVD +N/-S +E/-W Northing Easting Shape 09-15A T6 Rev 1 8741.72 6725.03 -1737.44 5949137.80 716609.90 Point 09-15A T5 Rev 1 8755.52 6440.00 -2148.19 5948841.00 716207.60 Point 09-15A T4 Rev 1 8772.02 5882.06 -2952.25 5948260.00 715420.10 Point 09-15A DD-Poly 8772.02 3745.42 -1171.47 5946176.00 717262.00 Polygon _ 09-15A Geo-Poly 8772.02 5882.06 -2952.25 5948260.00 715420.10 Polygon 09-15A T3 Rev 1 8791.72 5165.52 -3248.66 5947535.20 715144.60 Point 09-15A Fault 8804.83 5512.18 -2272.75 5947910.00 716110.00 Polygon 09-15A Fault 2 8804.83 5713.86 -1189.40 5948143.00 717187.00 Polygon 09-15A T2 Rev 2 8805.52 4490.69 -2875.75 5946871.50 715536.90 Point 09-15A Tt Rev 3 8810.52 4284.04 -1622.06 5946701.30 716796.00 Point by HALLIBURTON ~~ Sperry Drilling Services Start Dir 12°1100' :7500' MD, 6906.85'T/D TF 85L 6600 Start Dir 4°/100' :7520' MD, 6922.8'ND WELL DETAIl.S: 09-15 Ground Level: 20.00 +N/-S +F1-W Northing Eas1iry; latittude Longitude Slot 0.00 0.00 5942466.30 718541.52 70° 14'43.377N 148° 14'4.352 W I S SECTION DETALL.S Sec MD Inc Azi TVD +N/-S +Fi-W Dlxg TFace VSec Target 1 750U.00 37.00 15.00 6906.35 2015.88 556.83 0.00 0.00 1812.51 2 7520.00 37.27 11.05 692'_.80 202264 S59.S5 12.00 -85.00 1823.22 3 8539.99 50.00 313.00 7689.10 2622.59 322.94 4.00 264.14 2458.43 4 10143.82 50.00 313.00 87'_0.02 3450.49 -575.60 0.00 0.00 3494.46 S 10201.38 50.00 313.00 3757.02 3490.57 -607.85 0.00 0.00 3531.65 6 10568.84 94.08 314.24 8367.55 3726.15 -854.37 12.00 L78 3821.41 7 11175.73 94.08 31424 8824.38 4148.43 -1288.06 0.00 0.00 4338.80 8 11545.63 90.00 270.00 8810.52 4284.04 -1622.06 12.00 -94.18 4553.59 09-ISA_TI Rev 3 9 11984.59 90.26 274.67 8810.43 4285.62 -1660.97 12.00 86.80 4564.86 '' 10 12480.68 90.26 274.67 8806.35 4358.54 -2554.08 0.00 0.00 4858.86 11 12834.01 90.00 310.00 8805.52 4490.69 875.75 10.00 90.37 5067.27 09-ISA_T2 Rev 2 12 13056.26 91.36 33219 8802.84 4662.54 -3014.46 10.00 86A0 5268.35 13 13434.75 91.36 332.19 8793.86 4997.20 -3191.02 0.00 0.00 5636.54 14 13613.40 90.00 350.00 3791.72 5165.52 -3248.66 10.00 94.23 5813.92 09-ISA 73 Rev 1 IS 13654.41 92.48 353.22 8790.33 5206.07 -3254.64 10.00 52.32 5854.69 16 13658.08 92.45 353,22 8790.67 5209.71 -3255.08 0.00 0.00 5858.32 17 14433.16 90.00 55.24 8772.02 5882.05 ?952.25 8.00 91.32 6433.54 09-ISA_T4 Rev] l8 14445.47 90.98 55,24 8771.91 5889.07 -'_942.14 8.00 0.00 6437.80 19 15387.37 90.98 55.24 8755.73 6425.97 -2168.41 0.00 0.00 6764.10 20 1541 1.98 90.00 55.24 8755.52 6440.00 =' 148.19 4.00 179.96 6772.62 09-ISA_ TS Rev 1 21 15453.21 91.65 55.24 8754.92 6463.50 -'114.33 4.00 0.00 6786.9U 22 15912.14 91.65 55.24 8741.72 6725.03-1737.44 0.00 0.00 6945.84 09-ISA_T6 Revl REFERENCE INFORMATION Ca-ardiuate (N/EI Referm<e: Wetl 0&15 - Sbt 15, True North y'ertical 171'DI Reference: 20'GL+28.5RKB @ 48.SOft (20'GL*28.5R hleuured DeptL Rrfermce: 20'GL+28.SRKB @48.506 (20'GL+28.SR Calculation hleWod: hfiuimum Curvature CAti1NC DETAILti T\'D hID Name tiise 87U352 IUII8.15 7" 7 InaL7z Is9u.99 a la•• a-la FORMATION TOP DETAILS No.NDPa1h MDPath Formation 1 7383.50 8105.96 CM2 2 8063.50 9122.48 CM7 3 e457.5o s73s.a1 THRZ 4 884150 10021.67 BHRZ i 5 8703.5010118.12 43N 8 87035010118.12 42N 7 8703.5010118.12 LCU 8 8703.50 10118.12 TSHA 9 87035010118.12 44N 10 87035010718.12 42P 11 8703.50 10118.12 45N 12 8703.50 10118.12 45P 13 8703.50 70118.12 44P 14 8703.5010118.12 TSAR 15 8703.50 10118.12 43P • 18 8718.50 10141.48 31N 17 872850 10157.02 31P I 18 8770.50 10222.94 27P 1B 8770.50 10222.94 27N 20 8818.5010313.74 28N 21 8818.50 1D313.74 26P 22 8835.50 10355.52 25N 23 8841.50 10372.87 25P 24 8858.50 10426.36 24N _ _ - - End Dir :13056.26' MD, 8802.84' ND - -J 6900 _-'" ~ 35'ND; - ' - Start Dir 10°/100' :12480 68' MD 8806 Start Dir 10°/100' :13434.75' MD, 8793.86'ND 6900 . , . CM2 End Dir :8539.99' MD, 7689.1' ND CM1,~~ End Dir :11584.59' MD, 8810.43' TND End Dir :13654.41' MD, 8790.83' ND 7200 7200 ,, , T H RZ •, ~ Start Dir 12°1100' :11175.73' MD, 8824.38TVD i ~ ' ,~ ~ i~ Start Dir 8°1100' :13658.08' MD, 8790.67T3/D ~ BHRZ'. ~ 7500 i LCU ~ ~ ~ ~ ' ' 7500 -I ~ TSHA •. ,~ End Dir :10568.84' MD, 8867.55' Nq i ~ r ,~ ' ~ O v 7800 TSAD.~~• ~ '~ I i ~ 45N Start Dir 12°/100' :10201.38' MD, 8757.02'ND i ' ~ / ~ , ~' ~ ~ End Dir :14445.47' MD, 8771.91' ND G 7800 ~ t a 45P ~ `` i ~ I ~ , 44N- ~ ~ ~ / ' ', 0 r 44P ` ~, ~~ ~ ~ , ~ ' 'P,' 'Start Dir 4°/100' :15387.37' MD, 8755.73'ND 8100 -gy _ 8100 a3N ~ ~ ~ ~ ~ ~ , ~, ~ p ~ c~ ~ 43P ~ ` ~ ' i i ~ ~ ~ ` 42N ~' ~ , 8400 7 ~ ~ ~ 1 ~ i r r , 42P. : i~ , ~' End Dir :15453.21' MD, 8754.92' ND D 8400 ~ . ~ ~ ` ~ 7. ~ 1 ~ i r . , _ .--.~~ --'~ ~ 1 ' ~ ~ r , , , 31P--------------- '~ ~' ~ ~„'~ -~ otal p .15912.14M ,8741.72'ND T De th' D 8700 1 -~- ----___-_•_-_.: ~ 27N------'---------•- •---------- i ~ i 1 1 '' ~~ ---- - - - - - - 8700 .aa.... - 26P- "- 25N' 25P' '~.'' 24N ~~._ 45109={5,I 24N~~ Imo. ~.• 25P 25N ~~'' ~', 09-15A_ T1 Rev 3 26N~'26P ~, 09-15A_T2 Rev 2 ; 09-15A _T3 Rev 1 ~~ 09-15A_ T4 Rev 1 4 1 /2" ~,, .. ~ i~a,~ 109-15A_ T6 Rev 1 9000 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 5400 5700 6000 6300 6600 6900 7200 7500 7800 8100 8400 8700 Vertical Section at 345.51° (750 fUin) Project: Prudhoe Bay Sife: PB DS 09 Well: 09-15 Wellbore: Plan 09-15A Plan: 09-15A Wp #8 lHALLIBLIRTON Sperry Drilling Ssrvic~s CASING DETAILS ND MD Name Size 8703.52 10118.15 7" 7 8741.72 15911.99 41/2" 41/2 WELL DEFAILS: 09-15 Ground Level: 20.00 +N/-S +FJ-W Northing Fasting Latinude Longitude Slo[ 0.00 0.00 5942466.30 718541.52 70°I4'43.377N 148°14'4.352W IS COMPANY DETAll.S: BP Amoco Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Me[hod: Rules Based C O 7~ C .C 3 O N 31100 2500 WELLBORE TARGET DETAILS (MAP CO-0RDINATES) Name ND +W-S +E/-W Northing Easting Shape 09-15A T6 Rav 1 8741.72 6725.03 -1737.44 5949137.80 716609.90 Point 09-15A T5 Rev 1 8755.52 6440.00 -2148.19 5948841.00 716207.60 Point 09-15A T4 Rev 1 8772.02 5882.06 -2952.25 5948260.00 715420.10 Point 09-15A DD-Froly 8772.02 3745.42 -1171.47 5946176.00 717262.00 Polygon 09-15A Geo-Poly 8772.02 5882.06 -2952.25 5948260.00 715420.10 Polygon 09-15A T3 Rev 1 8791.72 5165.52 -3248.66 5947535.20 715144.60 Poinl 09-15A Fault 8804.83 5512.18 -2272.75 5947910.00 716110.00 Polygon _ 09-15A Fault 2 8804.83 5713.86 -1189.40 5948143.00 717187.00 Polygon 09-15A T2 Rev 2 8605.52 4490.69 -2875.75 5946871.50 715536.90 Point 09-15A T1 Rev 3 8810.52 4284.04 -1622.06 5946701.30 716796.00 Point REFERENCE INFORMATION ~~' Coordinate IN/E) Retereuce: Well 09-15 - Sbt 15, Trua North I Vertical IND) Reference: 20GL+28.5RKB @ 48.508 (20'GL+26.SRKB) Measured Depth Reference: 20GL+28.SRKB @ 48.508 (20'GL+28.5RKB) 'I CalculaBm Method: hfinimum Curvature ~, SECTION DETAILS II Sec MD Inc Ari ND +W-S +EI-W DLeg TFace VSec Tapel 1 7500.00 37.00 15.00 8908.85 2015.88 558.83 0.00 0.00 1612.51 2 7520.00 37.27 11.05 8922.80 2027.84 558.55 12.00 -85.00 1823.22 3 8539.99 50.00 313.00 7889.10 2822.59 322.94 4.00 284.14 2458.43 4 10143.82 50.00 313.00 8720.02 3460.49 575.80 0.00 0.00 3494.48 5 10201.38 50.00 313.00 8757.02 3490.57 -807.85 0.00 0.00 3531.85 6 10.588.84 94.08 314.24 8887.55 3726.15 -854.37 12.00 1.78 3821.41 7 11175.73 94.08 314.24 8824.38 4148.48 -1288.08 0.00 0.00 4338.80 8 11545.83 90.00 270.00 6810.52 4284.04 -1822.08 12.00 -94.18 4553.58 09-15A_ T7 Rev 3 9 11584.59 90.26 274.87 8810.43 42&5.82 -1880.87 12.00 88.60 4584.86 10 12480.86 90.28 274.87 6808.35 4358.54 -2554.08 0.00 0.00 4858.88 11 12834.01 90.00 310.00 8605.52 4490.89 -2875.75 10.00 90.37 5067.27 09-15A_T2 Rav 2 12 1305826 91.38 332.19 6802.84 488254 -3014.48 10.00 86.40 5268.35 13 13434.75 91.38 332.19 6793.68 4997.20 -3191.02 0.00 0.00 5836.54 14 13613.40 90.00 350.00 8791.72 5185.52 -3248.66 10.00 94.23 5613.82 09-i5A _T3 Rev 1 15 13854.41 82.48 353.22 8790.83 5208.07 -3254.64 10.00 52.32 5854.89 16 13658.08 92.48 353.22 8790.87 5209.71 -3255.08 0.00 0.00 5858.32 _ 17 14433.18 90.00 55.24 6772.02 5882.08 -2952.25 8.00 91.32 6433.54 09-15A T4 Rev 1 18 14445.47 90.98 55.24 6771.91 5889.07 -2942.14 8.00 0.00 8437.80 19 15387.37 90.98 55.24 8755.73 8425,97 -2188.41 0.00 0.00 6764.10 20 15411.98 90.00 55.24 6755.52 8440.00 -2148.19 4.00 179.98 8772.82 09-15A_ TS Rev 1 21 15453.21 91.65 55.24 6754.92 8463.50 -2114.33 4.00 0.00 8786.90 22 15812.14 91.85 55.24 6741.72 8725.03 -1737.44 0.00 0.00 8945.84 09-15A_ TB Rev 1 4 I ~ Total Depth :15912.14' MD, 8741.72' TVD I _ 09-I>-\ l ~ It~~~. i End Dir :15453.21' MD, 8754.92' TVD ---- - - - - - ' - - - - - - - - -Start Dir 4°/ 100' : 15387.37 MD, 8755.73'ND p9-I i:\ is Key i !r ~ End Dir :14445.47 MD, 8771.91' TVD - - - - - - - ,y7- Start Dir 8°/ 100' :13658.08' MD, 8790.67TVD i - 09-I - SA Fault2 _ - -' 09-ISA (im-Poly ~ 09-15A Fault - _ ~ _ - _ _ _ _ - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ End Dir :13654.41' MD, 8790.83' TVD _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Sun Dir 10°(100' :13434.75' MD, 8793.86TVD _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ End Dir :13056.26' MD, 8802.84' TVD _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Start Dir 10°/100' :12480.68' MD, 8806.35'1-VD -~ --- ---~-----------End Dir :11584.59'MD, 8810.43'TVD _ - -Start Dir 12°1100' : 1 1175.73' MD, 8824.38TVD i.. .. GSrJ~. a,,: _. --^~ -- 4 -----------'--Fnd Dir :10568.84'MD, 8867.55'TVD '!09-15:\ TI Rc~ ? - 09-ISA DD-Poly ~ g~ ,. ----- - - - - - Start Dir 12°/100' :10201.38' MD, 8757.02'1"VD 7 ~ ~ti /i~. '~ /s /~ ^~ End Dir :8539.99' MD, 7689.1' TVD 1 _--- Stan Dir 4°/ 100' :7520' MD, 6922.8'ND - - - - - - - Slan Dir 12°/ 100' :7500' MD, 6906.85'1'VD TF 85L 301H1 O C S 0 N ~O 5~ • 7000 -6500 -6000 -5500 -5000 X500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 West(-)/East(+) (1250 Win) Halliburton Company Planning Report -Geographic Database: EDM Sperry Local Co-ordinate Reference: Well 09-15 -Slot 15 Company: BP Amoco TVD Reference: 20'GL+28.5RK6 @ 48.50ft (20'GL+28.5RKB) Project: Prudhoe Bay MD Reference: 20'GL+28.5RK6 @ 48.50ft (20'GL+28.5RK6) Site: PB DS 09 North Reference: True WeA: 09-15 Survey Calcula#ion Method: Minimum Curvature Wellbore: Plan 09-15A Design: 09-15A Wp #8 Project Prudhoe Bay, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well 09-15 - Siot 15, 09-15 Well Position +N/-S 0.00 ft Northing: 5,942,466.30 ft Latitude: 70° 14' 43.377" N +E/-W 0.00 ft Easting: 718,541.52 ft Longitude: 148° 14' 04.352" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 20.OOft Wellbore Plan 09-15A~ Magnetics Model Name Sample Gate Dectlnation Dip Angle Field Strength bggm2008 4/17/2000 27.31 80.82 57,494 Design 09-15A Wp #8 ...;.. Audit Notes: Version: 16 Phase: PLAN Tie On Depth: 7,500.00 Vertical Section: Depth From (TVD) +N/-S +E!-W Direction (ft) (ft) (ft) (°) 0.00 0.00 0.00 345.51 1/26/2007 2:26:46PM Page 2 of 13 COMPASS 2003.11 Build 48 ~ ~ Halliburton Company Planning Report -Geographic Database: .EDM Sperry focal Co-ordinate Reference: Wet! 09-15.-Slot 15 ~' Company: BP Amoco fiVD Reference: 20'GL+28.5RKB @ 48.50ft (20'GL+28.SRKB) Project: Prudhoe Bay MD Reference: 20'GL+28.5RK6 @ 48.50ft (20'GL+28.5RK6) Site: PB DS 09 North Reference: True Well: 09-15 Survey Calculation Method: Minimum Curvature Wellbore: Plan 09-15A Design: 09-15A Wp #8 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth tNJ-S +E/-W Rate Rate Rate TFO (ft) (°) (°) {ft) (ft) (ft) (°I100ft) {°1900ft) (°/'(flilft) (o) 7,500.00 37.00 15.00 6,906.85 2,015.88 556.83 0.00 0.00 0.00 0.00 7,520.00 37.27 11.05 6,922.80 2,027.64 559.55 12.00 1.37 -19.75 -85.00 8,539.99 50.00 313.00 7,689.10 2,622.59 322.94 4.00 1.25 -5.69 264.14 10,143.82 50.00 313.00 8,720.02`• 3,460.49 -575.60 0.00 0.00 0.00 0.00 10,201.38 50.00 313.00 8,757.02 3,490.57 -607.85 0.00 0.00 0.00 0.00 10,568.84 94.08 314.24 8,867.55 3,726.15 -854.37 12.00 12.00 0.34 1.78 11,175.73 94.08 314.24 8,824.38 4,148.48 -1,288.06 0.00 0.00 0.00 0.00 11,545.63 90.00 270.00 8,810.52 4,284.04 -1,622.06 12.00 -1.10 -11.96 -94.18 11,584.59 90.26 274.67 8,810.43 4,285.62 -1,660.97 12.00 0.67 11.98 86.80 12,480.68 90.26 274.67 8,806.35 4,358.54 -2,554.08 0.00 0.00 0.00 0.00 12,834.01 90.00 310.00 8,805.52 4,490.69 -2,875.75 10.00 -0.07 10.00 90.37 13,056.26 91.36 332.19 8,802.84 4,662.54 -3,014.46 10.00 0.61 9.98 86.40 13,434.75 91.36 332.19 8,793.86 4,997.20 -3,191.02 0.00 0.00 0.00 0.00 13,613.40 90.00 350.00 8,791.72 5,165.52 -3,248.66 10.00 -0.76 9.97 94.23 13,654.41 92.48 353.22 8,790.83 5,206.07 -3,254.64 10.00 6.06 7.85 52.32 13,658.08 92.48 353.22 8,790.67 5,209.71 -3,255.08 0.00 0.00 0.00 0.00 14,433.16 90.00 55.24 8,772.02 5,882.06 -2,952.25 8.00 -0.32 8.00 91.32 14,445.47 90.98 55.24 8,771.91 5,889.07 -2,942.14 8.00 8.00 0.00 0.00 15,387.37 90.98 55.24 8,755.73 6,425.97 -2,168.41 0.00 0.00 0.00 0.00 15,411.98 90.00 55.24 8,755.52 6,440.00 -2,148.19 4.00 -4.00 0.00 179.96 15,453.21 91.65 55.24 8,754.92 6,463.50 -2,114.33 4.00 4.00 0.00 0.00 15,912.14 ~ 91.65 55.24 8,741.72 6,725.03 -1,737.44 0.00 0.00 0.00 0.00 1/26/2007 2:26:46PM Page 3 of 13 COMPASS 2003.11 Build 48 Halliburton Company Planning Report -Geographic Database: .EDM Sperry Local Co-ordinate Reference: Well 09-15 -Slot 15 Company: BP Amoco TVD Reference: 20'GL+28.5RK6 @ 48.50k (20'GL+28.5RK6) Project: Prudhoe Bay MD Reference: 20'GL+28.5RK6 @ 48.50ft (20'GL+28.5RK6) Site: PB DS 09 North Reference: True WeH: A9-15 Survey Caicula#ion Method: Minimum Curvature Wellbore: Pian 09-15A Design: 09-15A Wp #8 Planned Survey 09-15A W p #8 Map Map MD Inclination Azimuth TVD SSTYD +N1-S +E1•W Northing East9ng DLSEV Vert 5e'ction {ft) {°} {°} (ft} {ft} {ft} {ft} {~ {ft} (°110pft) (ft} 7,500.00 37.00 15.00 6,906.85 6,858.35 2,015.88 556.83 5,944,497.39 719,039.63 0.00 1,812.51 Start Dir 1 2°I100' :7500' MD, 6906.85'TVD TF 85L 7,520.00 37.27 11.05 6,922.80 6,874.30 2,027.64 559.55 5,944,509.22 719,042.01 12.00 1,823.22 Start Dir 4°1100' :7520' MD, 6922.8'TVD 7,550.02 37.17 9.07 6,946.70 6,898.20 2,045.52 562.72 5,944,527.18 719,044.66 4.00 1,839.73 7,600.02 37.07 5.76 6,986.57 6,938.07 2,075.43 566.61 5,944,557.19 719,047.69 4.00 1,867.72 7,650.02 37.05 2.44 7,026.48 6,977.98 2,105.47 568.77 5,944,587.28 719,048.97 4.00 1,896:27 7,700.02 37.13 359.13 7,066.36 7,017.86 2,135.62 569.18 5,944,617.42 719,048.51 4.00 1,925.35 7,750.02 37.31 355.84 7,106.18 7,057.68 2,165.82 567.85 5,944,647.58 719,046.31 4.00 1,954.93 7,800.02 37.57 352.58 7,145.89 7,097.39 2,196.05 564.78 5,944,677.70 719,042.36 4.00 1,984.97 7,850.02 37.92 349.36 7,185.43 7,136.93 2,226.27 559.97 5,944,707.77 719,036.68 4.00 2,015.43 7,900.02 38.36 346.20 7,224.75 7,176.25 2,256.45 553.43 5,944,737.74 719,029.27 4.00 2,046.28 7,950.02 38.88 343.10 7,263.82 7,215.32 2,286.53 545.17 5,944,767.57 719,020.14 4.00 2,077.47 8,000.02 39.48 340.09 7,302.58 7,254.08 2,316.50 535.20 5,944,797.23 719,009.30 4.00 2,108.98 8,050.02 40.16 337.15 7,340.99 7,292.49 2,346.30 523.52 5,944,826.68 718,996.76 4.00 2,140.76 8,100.02 40.91 334.29 7,378.99 7,330.49 2,375.91 510.15 5,944,855.89 718,982.54 4.00 2,172.77 8,105.98 41.00 333.96 7,383.50 7,335.00 2,379.43 508.45 5,944,859.36 718,980.73 4.01 2,176.61 CM2 8,150.02 41.73 331.53 7,416.55 7,368.05 2,405.29 495.12 5,944,884.82 718,966.66 4.00 2,204.98 8,200.02 42.61 328.85 7,453.61 7,405.11 2,434.41 478.43 5,944,913.44 718,949.14 4.00 2,237.34 8,250.02 43.55 326.27 7,490.14 7,441.64 2,463.22 460.11 5,944,941.71 718,929.99 4.00 2,269.82 8,300.02 44.55 323.78 7,526.08 7,477.58 2,491.69 440.18 5,944,969.59 718,909.24 4.00 2,302.38 8,350.02 45.60 321.37 7,561.39 7,512.89 2,519.80 418.66 5,944,997.06 718,886.92 4.00 2,334.97 8,400.02 46.69 319.05 7,596.03 7,547.53 2,547.49 395.59 5,945,024.07 718,863.05 4.00 2,367.56 8,450.02 47.84 316.82 7,629.96 7,581.46 2,574.75 370.98 5,945,050.60 718,837.67 4.00 2,400.10 8,500.02 49.02 314.67 7,663.14 7,614.64 2,601.54 344.87 5,945,076.62 718,810.79 4.00 2,432.57 8,539.99 50.00 313.00 7,689.10 7,640.60 2,622.59 322.94 5,945,097.02 718,788.26 4.00 2,458.43 End Dir : 8539.99' MD, 7689.1' TVD 8,550.02 50.00 313.00 7,695.54 7,647.04 2,627.82 317.32 5,945,102.10 718,782.50 0.00 2,464.91 8,600,02 50.00 313.00 7,727.68 7,679.18 2,653.95 289.31 5,945,127.39 718,753.74 0.00 2,497.21 8,650.02 50.00 313.00 7,759.82 7,711.32 2,680.07 261.30 5,945,152.69 718,724.98 0.00 2,529.51 8,700.02 50.00 313.00 7,791.96 7,743.46 2,706.19 233.28 5,945,177.99 718,696.23 0.00 2,561.81 8,750.02 50.00 313.00 7,824.10 7,775.60 2,732.31 205.27 5,945,203.29 718,667.47 0.00 2,594.11 8,800.02 50.00 313.00 7,856.24 7,807.74 2,758.44 177.26 5,945,228.58 718,638.71 0.00 2,626.40 8,850.02 50.00 313.00 7,888.38 .7,839.88 2,784.56 149.25 5,945,253.88 718,609.96 0.00 2,658.70 8,900.02 50.00 313.00 7,920.52 7,872.02 2,810.68 121.23 5,945,279.18 718,581.20 0.00 2,691.00 8,950.02 50.00 313.00 7,952.66 7,904.16 2,836.80 93.22 5,945,304.48 718,552.44 0.00 2,723.30 9,000.02 50.00 313.00 7,984.80 7,936.30 2,862.92 65.21 5,945,329.77 718,523.69 0.00 2,755.60 9,050.02 50.00 313.00 8,016.94 7,968.44 2,889.05 37.20 5,945,355.07 718,494.93 0.00 2,787.90 9,100.02 50.00 313.00 8,049.08 8,000.58 2,915.17 9.18 5,945,380.37 718,466.17 0.00 2,820.20 9,122.46 50.00 313.00 8,063.50 8,015.00 2,926.89 -3.39 5,945,391.72 718,453.27 0.00 2,834.69 CM1 9,150.02 50.00 313.00 8,081.21 8,032:71 2,941.29 -18.83 5,945,405.67 718,437.41 0.00 2,852.49 9,200.02 50.00 313.00 8,113.35 8,064.85 2;967.41 -46.84 5,945,430.97 718,408.68 0.00 2,884.79 9,250.02 50:00 313.00 8,145.49 8,096.99 2,993.53 -74.85 5,945,456.26 718,379.90 0.00 2,917.09 9,300.02 50.00 313.00. 8,177.63 8,129.13 3,019.66 -102.87 5,945,481.56 718,351.14 0.00 2,949.39 1/26/2007 2:28:46PM Page 4 of 13 COMPASS 2003.11 Build 48 ~ f Halliburton Company Planning Report -Geographic Database: .EDM Sperry Local Co-ordinate Reference: Well 09-15 -Slot 15 Company: BP Amoco TYD Reference: 20'GL+28.5RK6 @ 48:50ft (20'GL+28.5RK6) Project: Prudhoe Bay MD Reference: 20'GL+28.512K6 @ 48.50ft (20'GL+28.5RK6) Site: PB DS 09 North Reference: True WeN: 09-15 Survey Calculation Method: Minimum Curvature Wellbore: Plan 09-15A Design: 09-15A Wp #8 Planned Survey 09-15A Wp #8 Map Map MD Inclination Azimuth TVD SSTVD +NI-S +irl.yy Northing fasting DLSEV Yert Section {ft) {°) (°) (fit) {ft) (ft) {ft) (~) (~) (°I1DDft) {ft) 9,350.02 50.00 313.00 8,209.77 8,161.27 3,045.78 -130.88 5,945,506.86 718,322.39 0.00 2,981.69 9,400.02 50.00 313.00 8,241.91 8,193.41 3,071.90 -158.89 5,945,532.16 718,293.63 0.00 3,013.99 9,450.02 50.00 313.00 8,274.05 8,225.55 3,098.02 -186.90 5,945,557.45 718,264.87 0.00 3,046.29 9,500.02 50.00 313.00 8,306.19 8,257.69 3,124.14 -214.92 5,945,582.75 718,236.12 0.00 3,078.59 9,550.02 50.00 313.00 8,338.33 8,289.83 3,150.27 -242.93 5,945,608.05 718,207.36 0.00 3,110.88 9,600.02 50.00 313.00 8,370.47 8,321.97 3,176.39 -270.94 5,945,633.35 718,178.60 0.00 3,143.18 9,650.02 50.00 313.00 8,402.61 8,354.11 3,202.51 -298.95 5,945,658.64 718,149.85 0.00 3,175.48 9,700.02 50.00 313.00 8,434.75 8,386.25 3,228.63 -326.97 5,945,683.94 718,121.09 0.00 3,207.78 9,735.41 50.00 313.00 8,457.50 8,409.00 3,247.13 -346.80 5,945,701.85 718,100.73 0.00 3,230.65 THRZ 9,750.02 50.00 313.00 8,466.89 8,418.39 3,254.76 -354.98 5,945,709.24 718,092.33 0.00 3,240.08 9,800.02 50.00 313.00 8,499.03 8,450.53 3,280.88 -382.99 5,945,734.54 718,063.58 0.00 3,272.38 9,850.02 50.00 313.00 8,531.17 8,482.67 3,307.00 -411.00 5,945,759.83 718,034.82 0.00 3,304.68 9,900.02 50.00 313.00 8,563.31 8,514.81 3,333.12 -439.02 5,945,785.13 718,006.06 0.00 3,336.98 9,950.02 50.00 313.00 8,595.45 8,546.95 3,359.24 -467.03 5,945,810.43 717,977.31 0.00 3,369.27 10,000.02 50.00 313.00 8,627.59 8,579.09 3,385.37 -495.04 5,945,835.73 717,948.55 0.00 3,401.57 10,021.67 50.00 313.00 8,641.50 8,593.00 3,396.68 -507.17 5,945,846.68 717,936.10 0.00 3,415.56 BHRZ 10,050.02 50.00 313.00 8,659.72 8,611.22 3,411.49 -523.05 5,945,861.02 717,919.79 0.00 3,433.87 10,100.02 50.00 313.00 8,691.86 8,643.36 3,437.61 -551.07 5,945,886.32 717,891.03 0.00 3,466.17 10,118.12 50.00 313.00 8,703.50 8,655.00 3,447.07 -561.21 5,945,895.48 717,880.62 0.00 3,477.86 43N - 42N - LCU - TSHA - 44N - 42P - 45N - 45P - 44P -TSAR - 43P - 7" 10,141.46 50.00 313.00 8,718.50 8,670.00 3,459.26 -574.28 5,945,907.29 717,867.20 0.00 3,492.94 31N 10,143.82 50.00 313.00 8,720.02 8,671.52 3,460.49 -575.60 5,945,908.48 717,865.84 0.00 3,494.46 10,150.02 50.00 313.00 8,724.00 8,675.50 3,463.73 -579.08 5,945,911.62 717,862.28 0.00 3,498.47 10,157.02 50.00 313.00 8,728.50 8,680.00 3,467.39 -583.00 5,945,915.16 717,858.25 0.00 3,502.99 31P 10,177.58 50.00 313.00 8,741.72 8,693.22 3,478.13 -594.52 5,945,925.56 717,846.43 0.00 3,516.27 Start Dir 1 2°I100' : 10201.38' MD, 8757.02'TVD 10,222.94 52.59 313.10 8,770.50 8,722.00 3,502.05 -620.15 5,945,948.73 717,820.12 12.00 3,545.84 27P - 27N 10,225.45 52.89 313.11 8,772.02 8,723.52 3,503.41 -621.60 5,945,950.05 717,818.62 12.00 3,547.53 ', 09-15A_DD-Poly - 09-15A Geo-Poly 10,250.02 55.83 313.22 8,786.33 8,737.83 3,517.07 10,284.85 60.01 313.36 8,804.83 8,756.33 3,537.31 09-15A Fault - 09-15A Fault 2 10,300.02 61.83 313.41 8,812.20 8,763.70 3,546.41 -636.17 5,945,963.28 717,803.67 11.99 3,564.40 -657.65 5,945,982.88 717,781.61 12.01 3,589.36 -667.28 5,945,991.70 717,771.72 11.98 3,600.58 1/26/2007 2:26:46PM Page 5 of 13 COMPASS 2003.11 Build 48 Halliburton Company Planning Report -Geographic Database: EDM Sperry Local Co-ordinate Reference: Well 09-15 - Stot 15 Company: BP Amoco ND Ref®rgnce: 20'GL+28.5RK6 @ 48.50ft (20'GL+28.5RKB) Project: Prudhoe Bay MD Reference: 20'GL+28.5RK6 @ 48.50k (20'GL+28.5RK6) Site: PB DS 09 North Reference: True WeA: 09-15 SurveyCaiculation Method: Minimum Curvature Wellbore: Plan 09-15A Design: 09-15A Wp #8 Planned Survey 09-15A Wp #8 Map Map MD Inclination Azimuth ND SSND +N1-S +Ft-W Northing Fasting DLSFV Vett Section (ft) {°) (°) fft) tR1 (ft) (ft) (ft) 4n) (°/1~Qft} tftk 10,313.74 63.48 313.46 8,818.50 8,770.00 3,554.79 -676.13 5,945,999.82 717,762.63 12.02 3,610.91 26N - 26P 10,350.02 67.83 313.59 8,833.45 8,784.95 3,577.55 -700.09 5,946,021.87 717,738.02 11.99 3,638.94 10,355.52 68.49 313.61 8,835.50 8,787.00 3,581.07 -703.79 5,946,025.29 717,734.23 12.05 3,643.27 25N 10,372.67 70.55 313.66 8,841.50 8,793.00 3,592.16 -715.41 5,946,036.03 717,722.28 .12.00 3,656.91 25P 10,400.02 73.83 313.75 8,849.87 8,801.37 3,610.14 -734.23 5,946,053.46 717,702.95 11.99 3,679.04 10,426.36 76.99 313.83 8,856.50 8,808.00 3,627.78 -752.63 5,946,070.56 717,684.05 12.01 3,700.72 24N 10,450.02 79.82 313.90 8,861.25 8,812.75 3,643.84 -769.34 5,946,086.13 717,666.88 11.99 3,720.44 10,500.02 85.82 314.04 8,867.50 8,819.00 3,678.27 -805.03 5,946,119.50 717,630.21 12.00 3,762.70 10,550.02 91.82 314.19 8,868.52 8,820.02 3,713.05 -840.90 5,946,153.23 717,593.35 12.00 3,805.35 10,568.84 94.08 314.24 8,867.55 8,819.05 3,726.15 -854.37 5,946,165.93 717,579.51 12.01 3,821.41 End Dir : 10568.84' MD, 8867.55' TVD 10,600.02 94.08 314.24 8,865.34 8,816.84 3,747.85 -876.65 5,946,186.98 717,556.60 0.00 3,847.99 10,650.02 94.08 314.24 8,861.78 8,813.28 3,782.65 -912.39 5,946,220.72 717,519.88 0.00 3,890.62 10,700.02 94.08 314.24 8,858.22 8,809.72 3,817.44 -948.12 5,946,254.46 717,483.16 0.00 3,933.25 10,750.02 94.08 314.24 8,854.66 8,806.16 3,852.24 -983.85 5,946,288.21 717,446.43 0.00 3,975.87 10,800.02 94.08 314.24 8,851.11 8,802.61 3,887.03 -1,019.58 5,946,321.95 717,409.71 0.00 4,018.50 10,850.02 94.08 314.24 8,847.55 8,799.05 3,921.83 -1,055.31 5,946,355.69 717,372.99 0.00 4,061.12 10,900.02 94.08 314.24 8,843.99 8,795.49 3,956.62 -1,091.04 5,946,389.43 717,336.27 0.00 4,103.75 10,950.02 94.08 314.24 8,840.43 8,791.93 3,991.41 -1,126.77 5,946,423.18 717,299.54 0.00 4,146.38 11,000.02 94.08 314.24 8,836.88 8,788.38 4,026.21 -1,162.50 5,946,456.92 717,262.82 0.00 4,189.00 11,050.02 94.08 314.24 8,833.32 8,784.82 4,061.00 -1,198.23 5,946,490.66 717,226.10 0.00 4,231.63 11,100.02 94.08 314.24 8,829.76 8,781.26 4,095.80 -1,233.96 5,946,524.40 717,189.37 0.00 4,274.26 11,150.02 94.08 314.24 8,826.21 8,777.71 4,130.59 -1,269.69 5,946,558.14 717,152.65 0.00 4,316.88 11,175.73 94.08 314.24 8,824.38 8,775.88 4,148.48 -1,288.06 5,946,575.49 717,133.77 0.00 4,338.80 Start Dir 1 2°1100' :11175.73' MD, 8824.38'TVD 11,200.02 93.86 311.33 8,822.69 8,774.19 4,164.94 -1,305.85 5,946,591.43 717,115.52 11.99 4,359.18 11,250.02 93.38 305.34 8,819.53 8,771.03 4,195.87 -1,344.98 5,946,621.21 717,075.51 12.00 4,398.92 11,300.02 92.87 299.35 8,816.80 8,768.30 4,222.57 -1,387.14 5,946,646.67 717,032.59 12.00 4,435.31 11,350.02 92.32 293.37 8,814.54 8,766.04 4,244.73 -1,431.88 5,946,667.53 716,987.24 12.00 4,467.96 11,400.02 91.75 287.39 8,812.76 8,764.26 4,262.12 -1,478.70 5,946,683.55 716,939.93 12.00 4,496.51 11,450.02 91.16 281.42 8,811.49 8,762.99 4,274.55 -1,527.09 5,946,694.57 716,891.20 12.00 4,520.64 11,500.02 90.56 275.45 8,810.74 8,762.24 4,281.87 -1,576.52 5,946,700.46 716,841.58 12.00 4;540.10 11,545.63 90.00 270.00 8,810.52 8,762.02 4,284.04 -1,622.06 5,946,701.30 716,796:00 12.01 4,553.59 09-15A T1 Rev 3 11,550.02 90.03 270.52 8,810.52 8,762.02 4,284.06 -1,626.45 5,946,701.19 716,791.61 11.94 4,554.71 11,584.59 90.26 274.67 8,810.43 8,761.93 4,285.62 -1,660.97 5,946,701.76 716,757.06 12.01 4,564.86 End Dir : 11584.59' MD, 8810.43' TVD 11,600.02 90.26 274.67 8,810.36 8,761.86 4,286.88 -1,676.35 5,946,702.57 716,741.65 0.00 4,569.92 11,650.02 90.26 274.67 8,810.13 8,761.63 4,290.95 -1,726.19 5,946,705.19 716,691.72 0.00 4,586.33 11,700.02 90.26 274.67 8,809.90 8,761.40 4,295.02 -1,776.02 5,946,707.81 716,641.79 0.00 4,602.73 1/26/2007 2:26:46PM Page 6 of 13 COMPASS 2003.11 Build 48 Halliburton Company Planning Report -Geographic Database: EDM Sperry Local Co-ordinate Reference: Well 09-15 -Slot 15 Company: BP Amoco TVD Reference: 20'GL+28.5RKB @ 48:50ft (20'GL+28.5RKB) Pro}ect: Prudhoe Bay MD Reference: 20'GL+28.5RKB @ 48.50Ft (20'GL+28.5RK6) Site: PB DS 09 North Reference: True Well: 09-15 Survey Calculation Method: Minimum Curvature Wellbore: Plan 09-15A Design: 09-15A Wp #8 Planned Survey 09-15A Wp #8 Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Nortfiing Fasting l)LSE1f Pert Section tftl (') t°) tft) (~) tft) f~) t~) tft) (°tloort) (~t) 11,750.02 90.26 274.67 8,809.68 8,761.18 4,299.09 -1,825.86 5,946,710.43 716,591.86 0.00 4,619.14 11,800.02 90.26 274.67 8,809.45 8,760.95 4,303.15 -1,875.69 5,946,713.05 716,541.93 0.00 4,635.54 11,850.02 90.26 274.67 8,809.22 8,760.72 4,307.22 -1,925.52 5,946,715.67 716,492.01 0.00 4,651.94 11,900.02 90.26 274.67 8,808.99 8,760.49 4,311.29 -1,975.36 5,946,718.30 716,442.08 0.00 4,668.35 11,950.02 90.26 274.67 8,808.76 8,760.26 4,315.36 -2,025.19 5,946,720.92 716,392.15 0.00 4,684.75 12,000.02 90.26 274.67 8,808.54 8,760.04 4,319.43 -2,075.03 5,946,723.54 716,342.22 0.00 4,701.16 12,050.02 90.26 274.67 8,808.31 8,759.81 4,323.50 -2,124.86 5,946,726.16 716,292.29 0.00 4,717.56 12,100.02 90.26 274.67 8,808.08 8,759.58 4,327.56 -2,174.69 5,946,728.78 716,242.36 0.00 4,733.97 12,150.02 90.26 274.67 8,807.85 8,759.35 4,331.63 -2,224.53 5,946,731.40 716,192.44 0.00 4,750.37 12,200.02 90.26 274.67 8,807.63 8,759.13 4,335.70 -2,274.36 5,946,734.02 716,142.51 0.00 4,766.78 12,250.02 90.26 274.67 8,807.40 8,758.90 4,339.77 -2,324.19 5,946,736.65 716,092.58 0.00 4,783.18 12,300.02 90.26 274.67 8,807.17 8,758.67 4,343.84 -2,374.03 5,946,739.27 716,042.65 0.00 4,799.59 12,350.02 90.26 274.67 8,806.94 8,758.44 4,347.91 -2,423.86 5,946,741.89 715,992.72 0.00 4,815.99 12,400.02 90.26 274.67 8,806.72 8,758.22 4,351.97 -2,473.70 5,946,744.51 715,942.79 0.00 4,832.39 12,450.02 90.26 274.67 8,806.49 8,757.99 4,356.04 -2,523.53 5,946,747.13 715,892.86 0.00 4,848.80 12,480.68 90.26 274.67 8,806.35 8,757.85 4,358.54 -2,554.08 5,946,748.74 715,862.26 0.00 4,858.86 Start Dir 1 0°/100' : 12480.68' MD, 8806.35'TVD 12,500.02 90.25 276.60 8,806.26 8,757.76 4,360.44 -2,573.33 5,946,750.08 715,842.96 9.99 4,865.51 12,550.03 90.21 281.60 8,806.06 8,757.56 4,368.34 -2,622.69 5,946,756.55 715,793.40 10.00 4,885.51 12,600.03 90.18 286.60 8,805.89. 8,757.39 4,380.52 -2,671.16 5,946,767.32 715,744.59 10.00 4,909.43 12,650.03 90.14 291.60 8,805.75 8,757.25 4,396.88 -2,718.40 5,946,782.30 715,696.90 10.00 4,937.08 12,700.03 90.10 296.60 8,805.64 8,757.14 4,417.29 -2,764.02 5,946,801.38 715,650.71 10.00 4,968.26 12,750.03 90.07 301.60 8,805.57 8,757.07 4,441.60 -2,807.70 5,946,824.41 715,606.35 10.00 5,002.72 12,800.03 90.03 306.60 8,805.53 8,757.03 4,469.63 -2,849.09 5,946,851.22 715,564.17 10.00 5,040.21 12,834.01 90.00 310.00 8,805.52 8,757.02 4,490.69 -2,875.75 5,946,871.50 715,536.90 10.01 5,067.27 09-15A T2 Rev 2 12,850.03 90.10 311.60 8,805.50 8,757.00 4,501.15 -2,887.88 5,946,881.61 715,524.48 9.98 5,080.43 12,900.03 90.41 316.59 8,805.28 8,756.78 4,535.93 -2,923.78 5,946,915.33 715,487.59 10.00 5,123.08 12,950.03 90.72 321.58 8,804.78 8,756.28 4,573.70 -2,956.51 5,946,952.13 715,453.77 10.00 5,167.84 13,000.03 91.03 326.57 8,804.02 8,755.52 4,614.17 -2,985.83 5,946,991.73 715,423.29 10.00 5,214.36 13,050.03 91.32 331.56 8,802.99 8,754.49 4,657.04 -3,011.52 5,947,033.83 715,396.37 10.00 5,262.29 13,056.26 91.36 332.19 8,802.84 8,754.34 4,662.54 -3,014.46 5,947,039.25 715,393.27 10.05 5,268.35 End Dir : 13056.26' MD, 8802.84' TVD 13,100.03 91.36 332.19 8,801.81 8,753.31 4,701.23 -3,034.88 5,947,077.33 715,371.75 0.00 5,310.92 13,150.03 91.36 332.19 8,800.62 8,752.12 4,745.44 -3,058.20 5,947,120.85 715,347.15 0.00 5,359.56 13,200.03 91.36 332.19 8,799.43 8,750.93 4,789.65 -3,081.52 5,947,164.36 715,322.56 0.00 5,408.20 13,250.03 91.36 332.19 8,798.24 8,749.74 4,833.86 -3,104.85 5,947,207.87 715,297.96 0.00 5,456.84 13,300.03 91.36 332.19 8,797.06 8,748.56 4,878.08 -3,128.17 5,947,251.39 715,273.37 0.00 5,505.48 13,350.03 91.36 332.19 8,795.87 8,747.37 4,922.29 -3,151.49 5,947,294.90 715,248.77 0.00 5,554.12 13,400.03 91.36 332.19 8,794.68 8,746.18 4,966.50 -3,174.82 5,947,338.42 715,224.18 0.00 5,602.76 13,434.75 91.36 332.19 8,793.86 8,745.36 4,997.20 -3,191.02 5,947,368.64 715,207.10 0.00 5,636.54 Start Dir 1 0°/100' : 13434.75' MD, 8793.86'TVD 13,450.03 91.25 333.71 8,793.51 8,745.01 5,010.80 -3,197.96 5,947,382.03 715,199.76 9.98 5,651.45 13,500.03 90.87 338.69 8,792.58 8,744.08 5,056.53 -3,218.13 5,947,427.15 715,178.28 10.00 5,700.76 13,550.03 90.49 343.68 8,791.99 8,743.49 5,103.84 -3,234.24 5,847,473.97 715,160.80 10.00 5,750.60 13,600.03 90.10 348.66 8,791.73 8,743.23 5,152.38 -3,246.19 5,947,522.14 715,147.46 10.00 5,800.58 1/26/2007 2:26:46PM Page 7 of 13 COMPASS 2003.11 Build 48 • Halliburton Company Planning Report -Geographic Database: EDM Sperry Local Co-ordinate Reference: Well 09-15 -Slot 15 Company: BP Amoco ND Reference: 20'GL+28.5RK6 @ 48.50ft (20'GL+28.5RKB) Project: Prudhoe Bay MD Reference: 20'GL+28.5RK6 @ 48.50ft (20'GL+28.5RK6) Site: PB DS 09 North Reference: True Weli: 09-15 Survey Calculation Method: Minimum Curvature Wellbore: Plan 09-15A Design: 09-15A Wp #8 Planned Survey 09-15A Wp #8 Map .Map MD Inclination Azimuth TYD SEND +NI-S +EJ:W Northing Fasting DLSEy Vert Section (ft) (°) (°) fit) (it) (ft) (ft) (ft1 tft) (°J100ft) (ft) 13,613.40 90.00 350.00 8,791.72 8,743.22 5,165.52 -3,248.66 5,947,535.20 715,144.60 10.02 5,813.92 09-15A T3 Rev 1 13,650.03 92.22 352.87 8,791.01 8,742.51 5,201.72 -3,254.11 5,947,571.23 715,138.10 9.91 5,850.34 13,654.41 92.48 353.22 8,790.83 8,742.33 5,206.07 -3,254.64 5,947,575.56 715,137.44 9.91 5,854.69 End Dir : 13654.41' M D, 8790.83' TVD 13,658.08 92.48 353.22 8,790.67 8,742.17 5,209.71 -3,255.08 5,947,579.19 715,136.91 0.00 5,858.32 Start Dir 8°1100' : 13658.08' MD, 8790.67'TVD 13,700.03 92.40 356.58 8,788.88 8,740.38 5,251.45 -3,258.80 5,947,620.80 715,131.97 7.99 5,899.66 13,750.03 92.29 0.58 8,786.83 8,738.33 5,301.38 -3,260.04 5,947,670.67 715,129.29 8.00 5,948.32 13,800.03 92.18 4.58 8,784.88 8,736.38 5,351.28 -3,257.79 5,947,720.61 715,130.09 8.00 5,996.07 13,850.03 92.05 8.58 8,783.04 8,734.54 5,400.91 -3,252.07 5,947,770.38 715,134.37 8.00 6,042.68 13,900.03 91.91 12.58 8,781.31 8,732.81 5,450.02 -3,242.89 5,947,819.74 715,142.12 8.00 6,087.94 13,950.03 91.76 16.58 8,779.71 8,731.21 5,498.37 -3,230.32 5,947,868.44 715,153.29 8.00 6,131.61 14,000.03 91.60 20.58 8,778.25 8,729.75 5,545.74 -3,214.39 5,947,916.24 715,167.83 8.00 6,173.49 14,050.03 91.44 24.57 8,776.92 8,728.42 5,591.88 -3,195.21 5,947,962.92 715,185.67 8.00 6,213.36 14,100.03 91.26 28.57 8,775.75 8,727.25 5,636.58 -3,172.85 5,948,008.24 715,206.72 8.00 6,251.05 14,150.03 91.08 32.57 8,774.72 8,726.22 5,679.61 -3,147.43 5,948,051.99 715,230.88 8.00 6,286.35 14,200.03 90.90 36.57 8,773.85 8,725.35 5,720.77 -3,119.07 5,948,093.95 715,258.03 8.00 6,319.10 14,250.03 90.71 40.56 8,773.15 8,724.65 5,759.85 -3,087.91 5,948,133.92 715,288.05 8.00 6,349.15 14,300.03 90.52 44.56 8,772.61 8,724.11 5,796.67 -3,054.10 5,948,171.70 715,320.77 8.00 6,376.34 14,350.03 90.33 48.55 8,772.24 8,723.74 5,831.04 -3,017.80 5,948,207.11 715,356.05 8.00 6,400.54 14,400.03 90.13 52.55 8,772.04 8,723.54 5,862.80 -2,979.20 5,948,239.97 715,393.72 8.00 6,421.64 14,433.16 90.00 55.24 8,772.02 8,723.52 5,882.06 -2,952.25 5,948,260.00 715,420.10 8.14 6,433.54 09-15A T4 Rev 1 14,445.47 90.98 55.24 8,771.91 8,723.41 5,889.07 -2,942.14 5,948,267.31 715,430.00 8.00 6,437.80 End Dir : 14445.47' MD, 8771.91' TVD 14,450.03 90.98 55.24 8,771.83 8,723.33 5,891.67 -2,938.39 5,948,270.01 715,433.67 0.00 6,439.38 14,500.03 90.98 55.24 8,770.97 8,722.47 5,920.17 -2,897.32 5,948,299.69 715,473.90 0.00 6,456.70 14,550.03 90.98 55.24 8,770.12 8,721.62 5,948.67 -2,856.25 5,948,329.37 715,514.13 0.00 6,474.02 14,600.03 90.98 55.24 8,769.26 8,720.76 5,977.17 -2,815.17 5,948,359.05 715,554.35 0.00 6,491.35 14,650.03 90.98 55.24 8,768.40 8,719.90 6,005.68 -2,774.10 5,948,388.73 715,594.58 0.00 6,508.67 14,700.03 90.98 55.24 8,767.54 8,719.04 6,034.18 -2,733.03 5,948,418.41 715,634.81 0.00 6,525.99 14,750.03 90.98 55.24 8,766.68 8,718.18 6,062.68 -2,691.95 5,948,448.08 715,675.03 0.00 6,543.31 14,800.03 90.98 55.24 8,765.82 8,717.32 6,091.18 -2,650.88 5,948,477.76 715,715.26 0.00 6,560.63 14,850.03 90.98 55.24 8,764.96 8,716.46 6,119.68 -2,609.81 5,948,507.44 715,755.49 0.00 6,577.95 14,900.03 90.98 55.24 8,764.10 8,715.60 6,148.18 -2,568.74 5,948,537.12 715,795.71 0.00 6,595.27 14,950.03 90.98 55.24 8,763.24 8,714.74 6,176.68 -2,527.66 5,948,566.80 715,835.94 0.00 6,612.59 15,000.03 90.98 55.24 8,762.38 8,713.88 6,205.18 -2,486.59 5,948,596.48 715,876.17 0.00 6,629.91 15,050.03 90.98 55.24 8,761.52 8,713.02 6,233.68 -2,445.52 5,948,626.16 715,916.40 0.00 6,647.24 15,100.03 90.98 55.24 8,760.67 8,712.17 6,262.18 -2,404.45 5,948,655.83 715,956.62 0.00 6,664.56 15,150.03 90.98 55.24 8,759.81 8,711.31 6,290.69 -2,363.37 5,948,685.51 715,996.85 0.00 6,681.88 15,200.03 90.98 55.24 8,758.95 8,710.45 6,319.19 -2,322.30 5,948,715.19 716,037.08 0.00 6,699.20. 15,250.03 90.98 55.24 8,758.09 8,709.59 6,347.69 -2,281.23 5,948,744.87 716,077.30 0.00 6,716.52 15,300.03 90.98 55.24 8,757.23 8,708.73 6,376.19 -2,240.16 5,948,774.55 716,117.53 0.00 6,733.84 15,350.03 90.98 55.24 8,756.37 8,707.87 6,404.69 -2,199.08 5,948,804.23 716,157.76 0.00 6,751.16 1/26/2007 2:26:46PM Page 8 of 13 COMPASS 2003.11 Build 48 Halliburton Company Planning Report -Geographic Database: EDM Sperry Local Co-ordinate Reference: Well 09-15 -Slot 15 Company: BP Amoco ND Reference: 20'GL+28.5RK6 @ 48.50ft (20'GL+28.5RK6) Project: Prudhoe Bay MD Reference: 20'GL+28.5RK6 @ 48.50ft (20'GL+28.5RK6) Site: PB DS 09 North Reference: True Well: 09-15 Survey Calculation Method: Minimum Curvature Wellbore: Plan 09-15A Design: 09-15A Wp 1t8 Planned Survey 09-15A Wp #8 Map MD lnctination Azimuth ND SSND +NI-S +FI.W Northing fft) (°) (°) (ft) tft) (ft) (ft) (ft) 15,387.37 90.98 55.24 8,755.73 8,707.23 6,425.97 -2,168.41 5,948,826.39 Start Dir 4°1100' : 15387.37' MD, 8755.73'ND 15,400.03 90.48 55.24 8,755.57 8,707.07 6,433.19 -2,158.01 5,948,833.91 15,411.98 90.00 55.24 8,755.52 8,707.02 6,440.00 -2,148.19 5,948,841.00 09-15A T5 Rev 1 15,450.03 91.52 55.24 8,755.01 8,706.51 6,461.69 -2,116.93 5,948,863.59 15,453.21 91.65 55.24 8,754.92 8,706.42 6,463.50 -2,114.33 5,948,865.47 End Dir :15453.21' M D, 8754.92' ND 15,500.03 91.65 55.24 8,753.58 8,705.08 6,490.19 -2,075.87 5,948,893.26 15,550.03 91.65 55.24 8,752.14 8,703.64 6,518.68 -2,034.81 5,948,922.93 15,600.03 91.65 55.24 8,750.70 8,702.20 6,547.17 -1,993.75 5,948,952.60 15,650.03 91.65 55.24 8,749.26 8,700.76 6,575.67 -1,952.69 5,948,982.27 15,700.03 91.65 55.24 8,747.82 8,699.32 6,604.16 -1,911.62 5,949,011.94 15,750.03 91.65 55.24 8,746.38 8,697.88 6,632.65 -1,870.56 5,949,041.61 15,800.03 91.65 55.24 8,744.94 8,696.44 6,661.14 -1,829.50 5,949,071.28 15,850.03 91.65 55.24 8,743.50 8,695.00 6,689.64 -1,788.44 5,949,100.95 15,900.03 91.65 55.24 8,742.07 8,693.57 6,718.13 -1,747.37 5,949,130.62 15,912.00 91.65 55.24 8,741.72 8,693.22 6,724.95 -1,737.55 5,949,137.72 Total Depth : 15912.14' MD, 8741 .72' ND - 41/2" 15,912.14 91.65 55.24 8,741.72 8,693.22 6,725.03 -1,737.44 5,949,137.80 Map Fasting DLV -Vert Sectioq (ft) (°t100ft} ift) 716,187.80 0.00 6,764.10 716,197.99 3.99 6,768.48 716,207.60 4.01 6,772.62 716,238.21 4.00 6,785.80 716,240.77 4.00 6,786.90 716,278.43 0.00 6,803.12 716,318.65 0.00 6,820.44 716,358.86 0.00 6,837.75 716,399.08 0.00 6,855.07 716,439.30 0.00 6,872.38 716,479.51 0.00 6,889.70 716,519.73 0.00 6,907.01 716,559.95 0.00 6,924.33 716,600.16 0.00 6,941.65 716,609.79 0.00 6,945.79 716,609.90 0.00 6,945.84 1/26/2007 2:26:46PM Page 9 of 13 COMPASS 2003.11 Build 48 • Halliburton Company Planning Report -Geographic Database: EDM Sperry Local Co-ordinate Reference: Well 09-15 -Slot 15 Company: BP Amoco TVD Reference: 20'GL+28.5RK6 @ 48.50k (20'GL+28.5RK6) Project: Prudhoe Bay MD Reference: 20'GL+28.5RK6 @ 48.50fl (20'GL+28.5RKB) Site: PB DS 09 North Reference: True Well: 09-15 Survey Catcutation Method: Minimum Curvature Wetibore: Plan 09-15A Design: 09-15A Wp #8 Geologic Targets Plan 09-15A TVD Target Name +Nl-S +Ei-W Northing >;asting (ft) -Shape ft ft (ft) (ft) 8,804.83 09-15A._Fault2 5,713.86 -1,189.40 5,948,143.00 717,187.00 - Polygon Point 1 0.00 0.00 5,948,143.00 717,187.00 Point 2 -361.58 324.67 5,947,791.00 717,522.00 Point 3 -577.68 324.40 5,947,575.00 717,528.00 Point 4 -723.76 428.21 5,947,432.00 717,636.00 Point 5 -823.34 550.38 5,947,336.00 717,761.00 Point 6 -873.46 656.98 5,947,289.00 717,869.00 Point 7 -954.52 726.66 5,947,210.00 717,941.00 Point 8 -1,212.51 791.21 5,946,954.00 718,013.00 Point 9 -1,363.99 839.84 5,946,804.00 718,066.00 Point 10 -1,626.29 1,018.32 5,946,547.00 718,252.00 Point 11 -1,867.83 1,274.44 5,946,313.00 718,515.00 Point 12 -1,626.29 1,018.32 5,946,547.00 718,252.00 Point 13 -1,363.99 839.84 5,946,804.00 718,066.00 Point 14 -1,212.51 791.21 5,946,954.00 718,013.00 Point 15 -954.52 726.66 5,947,210.00 717,941.00 Point 16 -873.46 656.98 5,947,289.00 717,869.00 Point 17 -823.34 550.38 5,947,336.00 717,761.00 Point 18 -723.76 428.21 5,947,432.00 717,636.00 Point 19 -577.68 324.40 5,947,575.00 717,528.00 Point 20 -361.58 324.67 5,947,791.00 717,522.00 8,791.72 09-15A_T3 Rev 1 5,165.52 -3,248.66 5,947,535.20 715,144.60 - Point 8,772.02 09-15A_Geo-Poly 5,882.06 -2,952.25 5,948,260.00 715,420.10 -Polygon Point 1 -2,195.83 1,752.05 5,946,116.00 717,235.00 Point 2 -1,917.88 1,447.97 5,946,385.00 716,923.00 Point 3 -1,727.77 239.91 5,946,540.00 715,710.00 Point 4 -1,280.60 -310.38 5,946,971.00 715,147.00 Point 5 -435.29 -548.98 5,947,809.00 714,884.00 Point 6 -32.96 -381.23 5,948,216.00 715,040.00 Point 7 429.49 162.43 5,948,694.00 715,570.00 Point 8 952.54 927.95 5,949,239.00 716,320.00 Point 9 1,087.16 1,218.99 5,949,382.00 716,607.00 Point 10 865.02 1,461.67 5,949,167.00 716,856.00 Point 11 105.91 591.25 5,948,383.00 716,008.00 Point 12 -350.62 15.74 5,947,910.00 715,446.00 Point 13 -871.12 24.65 5,947,390.00 715,470.00 Point 14 -1,276.21 366.07 5,946,995.00 715,823.00 Point 15 -1,323.60 1,172.07 5,946,971.00 716,630.00 Point 16 -1,470.84 1,695.05 5,946,839.00 717,157.00 Point 17 -1,854.21 2,150.14 5,946,469.00 717,623.00 Point 18 -2,195.83 1,752.05 5,946,116.00 717,235.00 8,741.72 09-15A_ T6 Rev 1 6,725.03 -1,737.44 5,949,137.80 716,609.90 - Point 8,805.52 09-15A_T2 Rev 2 4,490.69 -2,875.75 5,946,871.50 715,536.90 - Point 8,772.02 09-15A T4 Rev 1 5,882.06 -2,952.25 5,948,260.00 715,420.10 - Point 8,810.52 09-15A_ T1 Rev 3 4,284.04 -1,622.06 5,946,701.30 716,796.00 - Point 1/26/2007 2:26:46PM Page 10 of 13 COMPASS 2003.11 Build 48 Halliburton Company Planning Report -Geographic Database: EDM Sperry 1_ocal Co-ordinate Reference: Well 09-15 -Slot 15 Company: BP Amoco TVD Reference: 20'GL+28.5RK6 @ 48.50ft (20'GL+28.5RK6) .Project: Prudhoe Bay MD Reference: 20'GL+28.5RKB @ 48.50ft (20'GL+28.5RK6) Site: PB DS 09 North Reference: True Well: 09-15 Survey Calculation Method: Minimum Curvature Weilbore: Plan 09-15A Design: 09-15A Wp #8 8,755.52 09-15A_ T5 Rev 1 6,440.00 -2,148.19 5,948,841.00 716,207.60 - Point 8,772.02 09-15A_DD-Poly 3,745.42 -1,171.47 5,946,176.00 717,262.00 - Polygon Point 1 0.00 0.00 5,946,176.00 717,262.00 Point 2 259.52 -289.61 5,946,427.00 716,965.00 Point 3 253.97 -339.80 5,946,420.00 716,915.00 Point 4 278.56 -394.11 5,946,443.00 716,860.00 Point 5 412.17 -723.39 5,946,567.00 716,527.00 Point6 520.35 -1,417.58 5,946,655.00 715,830.00 Point 7 819.39 -1,897.13 5,946,940.00 715,342.00 Point 8 1,183.00 -2,084.67 5,947,298.00 715,144.00 Point 9 1,848.31 -2,153.42 5,947,961.00 715,056.00 Point 10 2,059.41 -2,050.25 5,948,175.00 715,153.00 Point 11 2,291.22 -1,798.41 5,948,414.00 715,398.00 Point 12 3,093.94 -637.59 5,949,250.00 716,535.00 Point 13 2,921.64 -526.53 5,949,081.00 716,651.00 Point 14 2,005.64 -1,610.60 5,948,134.00 715,594.00 Point 15 1,869.32 -1,808.64 5,947,992.00 715,400.00 Point 16 1,727.65 -1,856.77 5,947,849.00 715,356.00 Point 17 1,307.82 -1,834.94 5,947,430.00 715,390.00 Point 18 978.14 -1,644.41 5,947,106.00 715,590.00 Point 19 712.64 -1,389.99 5,946,848.00 715,852.00 Point 20 676.43 -693.71 5,946,832.00 716,549.00 Point 21 651.94 -263.22 5,946,820.00 716,980.00 Point 22 595.80 -155.80 5,946,767.00 717,089.00 Point 23 531.25 -34.61 5,946,706.00 717,212.00 Point 24 268.07 277.90 5,946,452.00 717,532.00 8,804.83 09-15A„_ Fauit 5,512.18 -2,272.75 5,947,910.00 716,110.00 - Polygon Point 1 0.00 0.00 5,947,910.00 716,110.00 Point 2 -130.78 -9.80 5,947,779.00 716,104.00 Point 3 -325.25 -134.49 5,947,581.00 715,985.00 Point 4 -462.72 -120.47 5,947,444.00 716,003.00 Point 5 -604.52 42.49 5,947,307.00 716,170.00 Point 6 -857.99 89.16 5,947,055.00 716,224.00 Point 7 -1,176.09 121.96 5,946,738.00 716,266.00 Point 8 -1,320.22 158.79 5,946,595.00 716,307.00 Point 9 -1,652.67 479.30 5,946,272.00 716,637.00 Point 10 -1,903.69 855.20 5,946,032.00 717,020.00 Point 11 -1,999.67 887.43 5,945,937.00 717,055.00 Point 12 -1,903.69 855.20 5,946,032.00 717,020.00 Point 13 -1,652.67 479.30 5,946,272.00 716,637.00 Point 14 -1,320.22 158.79 5,946,595.00 716,307.00 Point 15 -1,176.09 121.96 5,946,738.00 716,266.00 Point 16 -857.99 89.16 5,947,055.00 716,224.00 Point 17 -604.52 42.49 5,947,307.00 716,170.00 Point 18 -462.72 -120.47 5,947,444.00 716,003.00 Point 19 -325.25 -134.49 5,947,581.00 715,985.00 Point 20 -130.78 -9.80 5,947,779.00 716,104.00 1/26/2007 2:26:46PM Page 11 of 13 COMPASS 2003.11 Build 48 • Halliburton Company Planning Report -Geographic Database: EDM Sperry local Co-ordinate Reference: ___ Well 09-15 -Slot 15 Company: BP Amoco TVD Reference: 20'GL+28.5RK6 @ 48:50ft (20'GL+28.5RK6) Project: Prudhoe Bay MD Reference: 20'GL+28.5RK6 @ 48.50ft (20'GL+28.5RK6) Site: PB DS 09 North Reference: True Well: 09-15 Survey Calculation Method: Minimum Curvature Wellbore: Plan 09-15A Design: 09-15A Wp #8 Prognosed Casing Points Measured Vertical Casing Hole Depth Dept Diameter Diameter t~) {~) (") (") 10,118.15 8,703.52 7 8-112 15,911.99 8,741.72 4-1/2 6-114 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Deter +N!-E +E/-W (ft) (°) t°) {ft) (ft) (ft) Nam® 8,105.98 41.00 333.96 7,383.50 2,379.43 508.45 CM2 9,122.46 50.00 313.00 8,063.50 2,926.89 -3.39 CM1 9,735.41 50.00 313.00 8,457.50 3,247.13 -346.80 THRZ 10,021.67 50.00 313.00 8,641.50 ~ 3,396.68 -507.17 BHRZ 10,118.12 50.00 313.00 8,703.50 3,447.07 -561.21 43N 10,118.12 50.00 313.00 8,703.50 3,447.07 -561.21 42N 10,118.12 50.00 313.00 8,703.50 3,447.07 -561.21 LCU 10,118.12 50.00 313.00 8,703.50 3,447.07 -561.21 TSHA 10,118.12 50.00 313.00 8,703.50 3,447.07 -561.21 44N 10,118.12 50.00 313.00 8,703.50 3,447.07 -561.21 42P 10,118.12 50.00 313.00 8,703.50 3,447.07 -561.21 45N 10,118.12 50.00 313.00 8,703.50 3,447.07 -561.21 45P 10,118.12 50.00 313.00 8,703.50 3,447.07 -561.21 44P 10,118.12 50.00 313.00 8,703.50 3,447.07 -561.21 TSAD 10,118.12 50.00 313.00 8,703.50 3,447.07 -561.21 43P 10,141.46 50.00 313.00 8,718.50 3,459.26 -574.28 31N 10,157.02 50.00 313.00 8,728.50 3,467.39 -583.00 31P 10,222.94 52.59 313.10 8,770.50 3,502.05 -620.15 27P 10,222.94 52.59 313.10 8,770.50 3,502.05 -620.15 27N 10,313.74 63.48 313.46 8,818.50 3,554.79 -676.13 26N 10,313.74 63.48 313.46 8,818.50 3,554.79 -676.13 26P 10,355.52 68.49 313.61 8,835.50 3,581.07 -703.79 25N 10,372.67 70.55 313.66 8,841.50 3,592.16 -715.41 25P 10,426.36 76.99 313.83 8,856.50 3,627.78 -752.63 24N 1/26/2007 2:26:46PM Page 12 of 13 COMPASS 2003.11 Build 48 • Halliburton Company Planning Report -Geographic Database: EDM Speny Local Co-ordinate Reference: We1109-15 -.Slot 15 Company: BP Amoco ND Reference: 20'GL+28.5RKB @ 48.50ft (20'GL+28.5RK6) Project: Prudhoe Bay MD Reference: 20'GL+28.5RKB @ 48.50ft (20'GL+28.5RK6) Site: PB DS 09 North Reference: True Well: 09-15 Survey Calculation Method: Minimum Curvature Wellbore: Plan 09-15A Design: 09-15A Wp #8 Plan Annotations Measured Vertical local Coordinates Depth Depth +N/-S +FJ-W Comment (ft) (ft) (~) (k) 7,500.00 6,906.85 2,015.88 556.83 Start Dir 12°/100' :7500' MD, 6906.85'ND TF 85L 7,520.00 6,922.80 2,027.64 559.55 Start Dir 4°/100' :7520' MD, 6922.8'ND 8,539.99 7,689.10 2,622.59 322.94 End Dir :8539.99' MD, 7689.1' TVD 10,201.38 8,757.02 3,490.56 -607.85 Start Dir 12°/100' :10201.38' MD, 8757.02'ND 10,568.84 8,867.55 3,726.15 -854.37 End Dir :10568.84' MD, 8867.55' ND 11,175.73 8,824.38 4,148.48 -1,288.06 Start Dir 12°/100' :11175.73' MD, 8824.38'ND 11,584.59 8,810.43 4,285.62 -1,660.97 End Dir :11584.59' MD, 8810.43' ND 12,480.68 8,806.35 4,358.54 -2,554.08 Start Dir 10°/100' :12480.68' MD, 8806.35'ND 13,056.26 8,802.84 4,662.53 -3,014.46 End Dir :13056.26' MD, 8802.84' ND 13,434.75 8,793.86 4,997.20 -3,191.02 Start Dir 10°/100' :13434.75' MD, 8793.86'ND 13,654.41 8,790.83 5,206.07 -3,254.64 End Dir :13654.41' MD, 8790.83' ND 13,658.08 8,790.67 5,209.71 -3,255.08 Start Dir 8°/100' :13658.08' MD, 8790.67'TVD 14,445.47 8,771.91 5,889.07 -2,942.14 End Dir :14445.47' MD, 8771.91' TVD 15,387.37 8,755.73 6,425.97 -2,168.41 Start Dir 4°/100' :15387.37' MD, 8755.73'TVD 15,453.21 8,754.92 6,463.51 -2,114.32 End Dir :15453.21' MD, 8754.92' TVD 15,912.00 8,741.72 6,724.95 -1,737.55 Total Depth :15912.14' MD, 8741.72' TVD 1126/2007 2:26:d6PM Page 13 of 13 COMPASS 2003.11 Build 48 °I°~ao66Rl 155 ANTI-COLLISION SETTINGS Interpolation M11ethod:NlD Interval: 25AU llepth Range From: 7500.00 To: 15911.97 Maximum Range: 1788.35 Reference: Plan: 09-15A Wp ik8 i~ / /_ T .~~ / / ~~ i ~~~ I ~T ~ ~ ! l ~_~ ~. ~-rte t- ~_~Y i.~- <-. _ -J. - ~ r - ~~ \ \ ~y ~~~ ~.. \~ ~~~\~' 04-09 53 li I 0 27 ., . • ..:.. `. , 26 1 ~ \ \ \ 26 57 ~ ~ I 5l % ~~ ./ ' y/ ~ . ~A ~~ ;T °!i .: '~ / , ~ - , ~ _105 '\ . 105 / ~' "' 09-07A "' ' Isa 21 MD 11000'-12000 IS>, 5B Iw 1x1 ' .~..gle..e \.'~.m \k ~4 YLpJ ~ ~ vul ~]ssw9 a 19o-I5NSn oo-lwl ~..we ar.+a ~• o..l~ ] a.....9: o.r 99n9wa. o.w WELL DETAILS Name +N/-S +E/-W Northing Easlisle Latilzlde Lolgihak Sbl IP/-IS 1517.7) 1366.95 5942406.;0 7I%541.52 70"14'43.377N 145"14'04.352W IS Travelling Cylinder Azimuth (TFO+AZI) ~deg~ vs Centre to Centre Separation ~ft~ Pr9m ce19Nr -r9 M o zso zw sbu Sao 7w 750 luau IUW 125U 125U ISOU Isa0 nw nw 2uuu 2auu z:w zxw zsbu zsuu 3uw JINNI 10110 40W 50110 SOOO RIIIO 60W 7000 7UW NUW NWI0 90W 90110 - 10000 - 1001 IIWO 2001 12W0 39a I.HNNI 11101 110110 SHIM i~ ~]~I" SURVEY'PRl1GRAM Depth Fm Depth To San~ey/%a0 Tod 7500.00 15911.97 Plaaaed: 09-ISA Wp OS V17 hIWD+IFR+h1S wl;l.lrnsa us,snlLs Plm U't-ISA PveN W605u1h- IIY-IS 1'w ua wU: ]SW.U11 Net. Ullum: 211YiL-2N.$Nra 15SU0 V3WUia (hWiv lhyw YNrmtl Aaple ,w-s •~-w Pwm rvu )1531 O.W 0.011 2NSU Ikd..~-6.. sae NEA"181\ 11FriV I.ti \1D V An rvrl .SI .Y -F..W Olctl M1r« VNn IuB.I I ]SwW ltw ISW 2 ]sN1w l>I] II US 6YU6 tl5 W2Ew tu15 V1 556]2 0 ]]S 559N Itw ~e5w 1812 b] IR2]1] ] tls1Yw ww n]w 1 Iwa ]9 wal n)w nz9w ieiz ]u ]x:w 16u SV -nsw m1w tow ss iN1 stl 5 lotul l6 ww lllw IOSOb e2 11N X'IS]W tlY6]w )NV160 N1)91 t]t615 ~Wb IVW I]tl )5)1]6 ]BII S) II1]S St 91 115151] nOw w2Y ]6 BYluw 11N1tl ~128YU] I2wul ~I6tiW IzW 9118 il1BW 155)SY w-IS:5 rl14v) IISw 1) wm P10] lu I2HU 51 w26 E]1 b] tl81U 11 WN]I 128562 -IbW 9] 115851 ~25w Otl 12W ow Wtlo W ISww Stl 87 11 12wJw w ]IUW 11 INK61U YIN 1)I 19 wnw wUth Nw 6B -28]5)5 i06t 5) -w1116 IUW IUW w]] ~ W SW)ri V9~ISn rl Rnt St6tl i] Il I31U 5Y YIN )1t 19 u u6un ww ]ww Nt9)W rnnm YIY]2u -31HI01 sees sl ~1za66 UW ww u w:] NNN stlu 9s w-ISnnll"vl Is IN51 ZS 9zw Nlu 1~ I165]v2 9z +e lv:z tl]ww naves sew u] ~IZS1w awn azssm law uw sz lz uw sell ]z sastl ]s IN)1llu W 5521 Ie Iwls W w SS ii er)E W ef]I W Sw2 US ~29sz Si stlN1 W ~ri12I] tl W vl )2 6111 s5 w-ISn r1 Bev 1 bIl]tli Iv Isms ss:1 m Islan wm ssa Ntssn nssw 61a v6 .netla a)vw ~nww iw no9W6 6]61w bnte2 wdsn rs Nnl 21 1515]W 9165 55N zz Is9u v] vl es ss zl Y]w 91 tram Ob114 -illl It e]u uz ~Ima 1W uw uw 6]tl6w wls rs w~lsn r6 P.vl • Halliburton Company Anticollision Report Company: BP Amoco Date: 1/26!2007 Tim e: 10:56:19 Page:. 1 Field: Prudhoe Bay Reference Site: PB DS 09 Co-ordlnate(NE) Reference: WeIL' 09-5, True North Reference Well: 09-15 Vertical (TVD) Reference:. 20'GL+28.5RKB 48.5 Reference Wegpath: .Plan 09-15A Db: OraCle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are ><E@I~TiaQells in thisRteddJpal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 7500.00 to 15911.97 ft Scan Method: Trav Cylinder North Maximum Radius: 1788.35 ft Erro r Surface: Ellipse + Casing Survey Program for Detmitive Wellpath Date: 11/27/2006 Validated: No Version: 2 Planned From To Survey Toolcode Tool N ame ft ft 795.50 7500.00 1 : Camera based mag multi sho CB-MAG-MS Camera based mag multi shot 7500.00 15911.9 7 Planned: 09-15A Wp #8 V17 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 10118.13 8703.50 7.000 8.500 7" 15911.96 8741.6 8 4.500 6.250 4 1/2" Summary <---------- Offset Wellpath -- --> Reference .Offset Ctr-Ctr No-Go Allowable Site Well Wegpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB DS 04 04-01 04-01 V1 13950.00 9800.00 818.39 456.75 361.64 Pass: Major Risk PB DS 04 04-04 04-04 V1 Out of range PB DS 04 04-04A 04-04A V1 Out of range PB DS 04 04-09 04-09 V1 15553.71 11300.00 619.08 454.40 164.68 Pass: Major Risk PB DS 04 04-12 04-12 V1 Out of range PB DS 04 04-31 04-31 V1 15471.44 9725.00 808.70 292.13 516.57 Pass: Major Risk PB DS 04 04-43 04-43 V1 9606.33 11875.00 980.19 531.63 448.56 Pass: Major Risk PB DS 04 04-44 04-44 V1 13084.34 10450.00 1549.58 382.90 1166.68 Pass: Major Risk PB DS 04 04-46 04-46 V1 13767.17 10650.00 1335.85 400.32 935.53 Pass: Major Risk PB DS 04 04-48 04-48 V1 Out of range PB DS 09 09-06 09-06 V1 7503.05 8325.00 1735.25 335.27 1399.98 Pass: Major Risk PB DS 09 09-07 09-07 V2 10723.77 9575.00 1136.12 350.20 785.91 Pass: Major Risk PB DS 09 09-07A 09-07A V4 11158.51 10675.00 156.89 23.96 132.93 Pass: Minor 1/200 PB DS 09 09-08 09-08 V1 7502.01 7200.00 1663.39 182.54 1480.85 Pass: Major Risk PB DS 09 09-09 09-09 V1 7500.00 7500.00 1606.56 360.92 1245.65 Pass: Major Risk PB DS 09 09-10 09-10 V1 Out of range PB DS 09 09-11 09-11 V1 Out of range PB DS 09 09-12 09-12 V1 Out of range PB DS 09 09-13 09-13 V1 Out of range PB DS 09 09-14 09-14 V1 Out of range PB DS 09 09-15 09-15 V2 7544.44 7550.00 1.65 349:08 -347.43 FAIL: Major Risk PB D5 09 09-16 09-16 V1 Out of range PB DS 09 09-17 09-17 V1 Out of range PB DS 09 09-18 09-18 V1 Out of range PB DS 09 09-19 09-19 V1 Out of range PB DS 09 09-31C 09-31C V1 12521.69 10943.00 1076.06 294.56 781.49 Pass: Major Risk PB DS 09 09-33 09-33 V1 10869.81 9850.00 666.23 467.38 198.86 Pass: Major Risk PB DS 09 09-34 09-34 V1 Out of range PB DS 09 09-35 09-35 V4 12880.09 10225.00 652.41 256.29 396.12 Pass: Major Risk PB DS 09 09-35 09-35A V7 13319.17 11170.00 527.62 269.69 257.94 Pass: Major Risk PB DS 09 09-36 09-36 V1 7546.72 7750.00 1374.32 141.93 1232.39 Pass: Major Risk PB DS 09 09-36A 09-36A V1 9508.35 9700.00 1010.91 149.76 861.15 Pass: Major Risk PB DS 09 09-366L 09-36BL V1 9453.19 9627.00 .1007.84 145.36 862.48 Pass: Major Risk PB DS 09 09-36C 09-36C V1 9286.89 9375.00 1091.30 134.93 956.36 Pass: Major Risk PB DS 09 09-45 09-45 V1 7506.02 7775.00 1211.83 224.53 987.30 Pass: Major Risk PB DS 09 09-46 09-46 V1 Out of range PB DS 09 09-47 09-47 V1 Out of range PB DS 09 09-48 09-48 V1 Out of range PB DS 09 09-49 09-49 V1 Out of range PB DS 09 09-50 09-50 V1 Out of range PB DS 09 09-51 09-51 V1 Out of range RE: DS9-ISA Area of Review.doc • • Subject: RE: DS9-15A Area of Review.doc From: "Smith, Phil G (ASRC)" ~Phi1.G.Smith~>,bp.com> Date: Fri, 16 Mar 2007 07:54:59 -0800 '~'o: Thomas Maunder <tom ma~in~lcrr~r~,~dnlin_state.ak.us~ Thanks Tam, Yes the schedule looks about the same. Phil From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, March 16, 2007 7:42 AM To: Smith, Phii G (ASRC} Subject: Re: DS9-15A Area of Review.doc Phil, I am working to get 9-15A out. Does the schedule still look like around the 26th? Thanks, Tom Smith, Phil G (ASRC) wrote, On 3/12/2007 7:31 AM: I'd give it two weeks. Thanks Tom. Phil -----Original Message----- From: Thomas Maunder [mailto:tYm mat~nde~~wa.^min.s,ate.ak.~,zs Sent: Friday, March 09, 2007 2:56 PM ', To: Smith, Phil G (ASRC) Subject: Re: DS9-15A Area of Review.doc Thanks Phil. Your comment about information completeness is my experience as well. I do appreciate your gathering the information. When does it look like the rig will head that way? Tom Smith, Phil G (ASRC) wrote, On 3/9/2007 2:38 PM: ', Hi Tom, ', I got the P2-15 proverbial fire beat back enough to get this to you, ': finally. Hope this is what you're looking for. Some info I found was more complete than other. Phil «DS9-15A Area of Review.doc» 1 of 1 3/16/2007 7:59 AM ~J DS9-15A Area of Review • The following fourteen wellbores are within the '/4 mile radius for review in preparation for the DS9-15A MI sidetrack. The primary cement jobs for each of the wellbore and the current well status are provided. 1) DS4-01 -Producer, shut-in. Last test 2/8/05 = 208 BOPD, 0 water a) Ran 9 5/8" casing, cemented 100 sx 50-50 fondu fly-ash through DV @ 2420' MD. Squeezed 450 sacks cement through shoe via RTTS. CBLs 1/3/73 and 1/4/73. Squeezed additional 700 sacks through pert holes at 9600'. Perf'd again 9380' and squeezed additional 200 sacks. PerF'd again 9268' and squeezed additional 100 sacks. b) CBL 3/22/77 post RWO and again 6/21/90. 2) DS4-09i -PWI, Last test 2/11/07 = 12,450 BWPD a) 9 5/8" cemented with 750 sx G + 125 sx PF II b) 7" cemented with 310 sx G 3) DS4-31 -Natural Flowing Producer, Last Test 1/20/07 = 706 BOPD, 4113 bfpd a) Cemented 7" liner 5/18/85 with 300 sx class G @ 16.2 ppg (1.15 yield = 61.5 bbls). Reciprocated pipe during cement job. 4) DS4-46 -Natural Flowing Producer, Last Test 2/5/07 = 190 BOPD, 2645 bfpd a) 7 5/8" cemented with 609 sx Class G 5) DS4-48 - GL Producer, Last test 2/12/07 = 292 BOPD, 480 bfpd a) Cemented 7 5/8" casing with 167 bbls Lead @ 11.0 ppg + 78 bbls tail @ 15.7 ppg. Bumped plug, no mention of problems. 6) DS9-07 Plugged and abandoned a) 9 5/8" casing cemented with 1000 sx 15.8 class G, bumped plug. Pumped 300 sx Arctic-Set between DVs at 2437' and 2312'. 7) DS9-07A - GL Producer, Shut-in. Last test = 11/4/06 600 BOPD, 19,000 bfpd a) Cemented 3 3/16" with 16 bbls 15.6 ppg with coiled tubing 8) DS9-31Ci -PWI, Last test 2/11/07 = 9613 bwpd a) Cemented 2 7/8" liner with 17.5 bbls class G, coiled tubing. 9) DS9-33 -Natural Flowing Producer, Last Test 1/12/07 89 BOPD, 6777 bfpd a) 9 5/8" cemented with 500 sx G + 300 sx CS-1 b) 7" cemented with 250 sx G 10) DS9-35 -Plugged and abandoned a) 7" liner cemented with 300 sx Class G, bumped plug, reciprocated with full returns. 11) DS9-35A -Natural Flowing Producer, Last Test 2/9/07 99 BOPD, 8958 bfpd a) Slotted Liner 12) DS9-36A Plugged and abandoned a) Cemented 7" liner with 300 sx 15.9 pg class G with full returns. Bumped plug 13) DS9-36B Plugged and abandoned a) Attempted sidetrack, ultimately became DS9-36C 14) DS9-36Ci -PWI, Last test 2/11/07 10,866 bwpd a) Cemented 2 7/8" liner with 10 bbls 15.8 ppg, coiled tubing Re: Offsets within I 'a mile of planned MIST~tor 09-I ~A Subject: Re: Offsets within 1/4 mile of planned MIST injector 09-15A From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 07 Feb 2007 14:40:29 -0900 To: "Smith, Phil G (ASRC)" <Phi1.G.Smith@bp.com> Hi Phil, Thanks (I think). Quite a listing as you indicated. The only other comment I can offer on the proximate wells, is the key I look at is the penetration. Where does the wellbore enter the Sadlerochit? If the approach is in zone, then that is not as critical as what comes through the roof. The other considerations is plug backs and "lost holes" that come through the roof. Good luck Phil. Call or message with any questions. Tom Maunder, PE AOGCC Smith, Phil G (ASRC) wrote, On 2/7/2007 1:53 PM: Tom, Looks like all the following are within 1/4 mile. I'll get started reviewing the files if you concur. 4-01, 4-09, 4-31, 4-46, 4-48, 9-07, 9-07A, 9-31 C, 9-33, 9-35, 9-35A, 9-36A, 9-36B, 9-36C Thanks, Phil 1 of 2 2/13/2007 10:45 AM Offsets within I ~ mile of planned MIST inje~)9- I >A Subject: Offsets within 1/4 mile of planned MIST injector 09-15A From: "Smith, Phil G (ASRC)" <PhiLG Smith~bp.com= Date: Wed, 07 Feb 2007 13:53:26 -0900 To: "Tom Maunder (Tom Maunder)" <tom maunder~uadmiastate.ak.us> Tom, Looks like all the following are within t/4 mile. I'll get started reviewing the filesrf you concur. 401, 4-05, 4-31.4-46, 4-48. 9-07 9-07A, 9-31 C, 9-33. 9-35, 9-35A. 9-36A, 9-368. 9-36C r Thanks. Phil A =' W.P ~= rte,,. BP Exploration (Alaska) Inc. 900 Eost Benson Blvd, Anchorage, AK 99519 1 of 1 2/13/2007 10:02 AM Steve Jones: GPB Waterflood, BP Alaskn Office: (907) 564-5831 Cell:(907) 223-2065 Fax:(907) 564-5510 Email: steve.jones@bp.com Alaska Department of Natural Resources Land Administration System Page 1 of 1 i • Case Summary File Type: ADL File Number: 28324 See Township, Range, Section and Acreage? Yes Customer: 000107377 I3P EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSONBL ATTN: LAND MANAGER-ALASKA ANCHORAGE AK 99~ 196612 Case Type: 784 OIL & GAS LF..ASE COMP DNR Unit: 780 011, AND GAS Filc Location: DOU DIV OIL AND GAS Case Status: 35 ISS/APPRV/AC"LV AUTH Status Date: 09/14/1)65 Total Acres: 260.000 Date Initiated: 0/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED ~f1%teridian: U Township: (~11N Range: i~~ l ~l ticction: ?> Section Acreti: ~~-t(~ PYieridiair: 1` Townships: U11'~ Range: UI~I~: Section: ?b Section.Acr:•s:r~-1U Meridian: l ` Township: f}11 V~ Rangc: (11 ~I ticction: 3~ Section Acres: (~d1) Meridian: l Township: UI 1\ Range: (1I>I Section: ib Section _4cres: (~~(~ Leal Deseripti~n OS-28-196.5 * * ~S.-I I,F. NOTICE LEGr1 L DF.SC'RIPTIO~'* Cld-15-f 7~IIN-RISE-Ubf2j,Z6,35,3625620~ II- 3- 7 Erg ~ Case Summary OZ http://vwvw.dnr.state.ak.us/las/Case_Summary~rint.cfm?FileType=ADL&FileNumber=2... 2/12/2007 • • • • TRANSMITTAL LETTER CI~iECKLIST WELL NAME ~°Bl1 09-/Si0 PTD# o?D~- Oa?d? Development / Service Exploratory Stratigraphic Test Non-Conventional Welt Circle 4ppropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-ONS TEXT FOR APPROVAL LETTER WHAT ~ (OPTIONS) APPLIES l ~ MULTI LATERAL ~ The permit is for a new we[Ibore segment of existing i ~ well (IF last two digits in ~ permit No. ,API No. 50- - - i API number are ~ ~ ,' between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE i In accordance with 20 A.4C 25.005(f), a!f records, data and togs ~ !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 EXCEPTION ', ', I ~ The permit is approved subject to full compliance with 20 AAC ~ 2~.0». Approval to perforate and produce /inject is contingent ~ I upon issuance of a conservation order approving a spacing j exception. assumes the ~ i liability of any protest to the spacing exception that may occur. i E DRY D[TCH ~ AI[ dry ditch sample sets submitted to the Commission must be in ' SAMPLE I no greater than 30' sample intervals from below the permafrost or ! from where samples, are first caught and 10' sample intervals ,through target zones. ' ;Please note the following special condition of this permit: Non-Conventional I production or production testing of coal bed methane is not allowed I Well t for (name of well) until after (Companv iYame) has designed and implemented a water well testing program to provide baseline data j on water quality and quantity. (Company Name) must contact the ~ Commission to obtain advance approval of such water well testing ;program. _ i Rev: 12~i06 C:`jody~transmittal_checklist • • 0 rn o_ ~ .N a> ~ O ~ -_ 7 N O Q C O 0 ~ ~ ~ O ~ O o a Q ~ Q) O F- Z m O I o rn ~ M ~ ~ d f6 o Z Z > ~ W d I ~ III ~ _~ C O a } m W O 2 d 0 0 a ~ w J m E Y '' a U ~ W_ a O U U H ~' ~ . W o J ~ d N: ' , ~ ~ ~ •O , ~ ~ - D? Q .. Q v ~~ W (O, N N' - U , - ~ ~ -: ~: i a ~ ~: ~ I ~, m C , ~ a ~ , ~ , ~~ ~ ~: a , >: o a , o. 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I O N M a t!') (O I~ '~ tl0 O O ~ N M rY ~ (D i~ W O O N M d' ~ M h W O N M V t!7 (D h 0p d1 ~ ~ ~ ~ .-- ~ ~ r r r N N N N N N N N N N M M M M M M M M M M -- - - ---- d °o m °o m °o ~ +' N II •''' N ~ N O ~~ I~ p N~ ~ p i N ~ C M I N C G ~ C Q. ~ ~ O Q. N a a Q w a-W-~ ~~ as a~ m ~ °M U N - N a U f6 D rno = C 0 N N O N c ~ ~ o WV a`> U c O C~ O y / O U Well f-iistory File APPENDIX • Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 9-15a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Dec 04 15:35:39 2007 Reel Header Service name .............LISTPE Date . ...................07/12/04 Ori in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................07/12/04 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Prudhoe Bay unit MWD/MAD LOGS WELL NAME: 09-15A API NUMBER: 500292025601 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 04-DEC-07 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: MW0004971247 MW0004971247 MW0004971247 LOGGING ENGINEER: N. WHITE N. WHITE S. POLAK OPERATOR WITNESS: B. DECKER B. DECKER B. DECKER MWD RUN 4 MWD RUN 5 MWD RUN 6 JOB NUMBER: MW0004971247 MW0004971247 MW0004971247 LOGGING ENGINEER: S. POLAK S. POLAK M. BUCKLEY OPERATOR WITNESS: B. DECKER B. DECKER C. CLEMENS SURFACE LOCATION SECTION: 1 TOWNSHIP: lON RANGE: 15E FNL: FSL: 994 FEL: FWL: 150 Page 1 vz ~ ~o~ -tea ~ lS~Sb • 9-15a.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 48.50 GROUND LEVEL: 20.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 7480.0 2ND STRING 6.125 7.000 10070.0 3RD STRING PRODUCTION STRING REMARKS: L 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - (TVD). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 7480'MD AND THE BOTTOM WAS AT 7496'MD IN THE ORIGINAL 9-15 WELLBORE. 4. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR), UTILIZING GEIGER- MUELLER TUBE DETECTORS. MAD SGRC DATA ACQUIRED WHILE POOH AFTER REACHING TD OF RUN 2 WERE MERGED WITH MWD DATA FROM RUN 1. 5. MWD RUNS 2-6 COMPRISED DIRECTIONAL,DGR,AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 2,3 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). RUN 3 ALSO INCLUDED GEOPILOT ROTARY STEERABLE BHA (GP). RUNS 4-6 ALSO INLCUDED AT- BIT INCLINATION (ABI). 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER OPEN- HOLE GAMMA RAY LOG RUN ON 2 SEPTEMBER 1977. THESE DIGITAL DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) VIA E-MAIL ON 16 AUGUST 2007. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THIS SHIFTED DATASET IS THE PDCL. 7. MWD RUNS 1-6 REPRESENT WELL 9-15A WITH API#: 50-029-20256-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15820'MD/8734'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). Page 2 9-15a.tapx SFXE = SMOOTHED FORMATION EXPOSURE TIME. File Header Service name... .......STSLIB.001 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......07/12/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 7261.5 15769.5 FET 7480.0 15776.5 RPX 7480.0 15776.5 RPS 7480.0 15776.5 RPM 7480.0 15776.5 RPD 7480.0 15776.5 oP 7490.0 15830.0 $ BASELINE CURVE FO R SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 7267.0 7252.0 7270.0 7255.0 7281.0 7264.0 7288.0 7271.5 7299.5 7282.5 7304.5 7287.0 7308.0 7292.5 7313.5 7296.0 7315.0 7298.0 7317.0 7301.0 7329.0 7310.0 7332.5 7314.0 7335.0 7316.5 7345.5 7328.0 7353.5 7335.5 7359.5 7341.0 7371.0 7350.5 7378.0 7360.0 7385.0 7365.0 7418.0 7400.0 7424.5 7406.0 7437.0 7420.5 7444.0 7427.5 7447.0 7430.5 7450.0 7432.0 7452.0 7435.0 7457.0 7442.0 7460.0 7444.5 7468.0 7453.0 7475.0 7459.5 Page 3 15835.5 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD REMARKS: 15820.0 9-15a.tapx BIT RUN NO MERGE TOP MERGE BASE 1 7252.0 7504.0 2 7504.0 9499.0 3 9499.0 10079.0 4 10079.0 10563.0 5 10563.0 14850.0 6 14850.0 15820.0 MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loggin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7261.5 15830 11545.8 17138 7261.5 15830 RPD MWD OHMM 1.03 2000 11.8152 16594 7480 15776.5 RPM MWD OHMM 0.99 1835.5 11.173 16594 7480 15776.5 RPS MWD OHMM 1.11 1242.3 6.56657 16594 7480 15776.5 RPX MWD OHMM 1.14 2000 6.67281 16594 7480 15776.5 FET MWD HOUR 0.34 97.65 2.82706 16594 7480 15776.5 GR MWD API 11.62 415.93 68.0689 17017 7261.5 15769.5 ROP MWD FT/H 0.05 790.59 98.0224 16653 7490 15830 First Reading For Entire File..........7261.5 Last Reading For Entire File...........15830 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/04 Maximum Physical Record..65535 File Type ................Lo Page 4 • i 9-15a.tapx Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service sub Level~Name... version Number. ........1.0.0 Date of Generation.......07/12/04 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7252.0 7462.5 ROP 7480.0 7504.0 LOG HEADER DATA DATE LOGGED: 15-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7504.0 TOP LOG INTERVAL (FT): 7480.0 BOTTOM LOG INTERVAL (FT): 7504.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 7480.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 56.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 1200 FLUID LOSS (C3): 9.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .980 64.0 MUD AT MAX CIRCULATING TERMPERATURE: .630 104.0 MUD FILTRATE AT MT: 1.450 64.0 Page 5 ~ r MUD CAKE AT MT: 9-15a.tapx .840 64.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MwD010 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7252 7504 7378 505 7252 7504 GR MwD010 API 28.6 77.95 49.1844 422 7252 7462.5 RoP MwD010 FT/H 0.2 23.33 8.29469 49 7480 7504 First Reading For Entire File..........7252 Last Reading For Entire File...........7504 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/04 Maximum Physical Record..65535 File TyL~e ................L0 Next Fite Name...........STSLIB.003 Physical EOF File Header service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/04 Maximum Physical Record..65535 File Type ................Lo Page 6 • M 9-15a.tapx Previous File Name.......STSLI6.002 comment Record FILE HEADER FILE NUMBER: RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 7463.0 RPX 7470.0 RPM 7470.0 RPD 7470.0 RPS 7470.0 FET 7470.0 ROP 7504.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9458.5 9451.0 9451.0 9451.0 9451.0 9451.0 9499.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): header data for each bit run in separate files. 2 .5000 3 18-APR-07 Incite 72.13 Memory 9499.0 7504.0 9499.0 37.0 52.9 TOOL NUMBER 103770 216787 8.500 7480.0 Lignosulfanate 9.00 56.0 9.4 1200 9.0 .980 64.0 .630 104.0 1.450 64.0 .840 64.0 Page 7 ~ r 9-15a.tapx TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~iny Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MwD020 OHMM 4 1 68 16 5 FET MwD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 7463 9499 8481 4073 7463 9499 RPD MwD020 OHMM 1.03 2000 10.238 3963 7470 9451 RPM MWD020 OHMM 1.11 1243.12 3.72661 3963 7470 9451 RPS MWD020 OHMM l.ll 1242.3 3.07695 3963 7470 9451 RPX MWD020 OHMM 1.14 2000 3.47327 3963 7470 9451 FET MWD020 HOUR 0.43 34.2 1.9242 3963 7470 9451 GR MWD020 API 31.01 288.6 125.574 3992 7463 9458.5 ROP MWD020 FT/H 2.56 790.59 81.2875 3990 7504.5 9499 First Reading For Entire File..........7463 Last Reading For Entire File...........9499 File Trailer Service name... .......sTSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/04 Maximum Physical Record..65535 File TyC~e ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service Sub Level Name... version Number...........1.0.0 Page 8 ~ ~ 9-15a.tapx Date of Generation.......07/12/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 9451.5 10033.5 RPM 9451.5 10033.5 FET 9451.5 10033.5 RPX 9451.5 10033.5 RPS 9451.5 10033.5 GR 9459.0 10041.0 OP 9513.5 10079.0 $ LOG HEADER DATA DATE LOGGED: 20-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10079.0 TOP LOG INTERVAL (FT): 9499.0 BOTTOM LOG INTERVAL (FT): 10079.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 49.4 MAXIMUM ANGLE: 51.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RES IS. 4 216787 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 7480.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 11.00 MUD VISCOSITY (S): 59.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1200 FLUID LOSS (C3): 10.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.710 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .920 136.0 MUD FILTRATE AT MT: 1.580 64.5 MUD CAKE AT MT: 1.790 68.0 NEUTRON TOOL MATRIX: Page 9 MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 9-15a.tapx Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9451.5 10079 9765.25 1256 9451.5 10079 RPD MWD030 OHMM 1.19 8.98 4.68623 1165 9451.5 10033.5 RPM MWD030 OHMM 1.26 8.56 4.50099 1165 9451.5 10033.5 RPS MWD030 OHMM 1.41 8.26 4.33556 1165 9451.5 10033.5 RPX MWD030 OHMM 1.48 8.62 4.33147 1165 9451.5 10033.5 FET MWD030 HOUR 0.58 52.29 4.41407 1165 9451.5 10033.5 GR MWD030 API 87.88 415.93 189.547 1165 9459 10041 ROP MWD030 FT/H 4.14 147.42 61.5353 1132 9513.5 10079 First Reading For Entire File..........9451.5 Last Reading For Entire File...........10079 File Trailer Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Page 10 9-15a.tapx service name... .......STSLIB.005 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 10034.0 10504.5 RPS 10034.0 10504.5 RPD 10034.0 10504.5 RPM 10034.0 10504.5 RPX 10034.0 10504.5 GR 10041.5 10497.5 ROP 10079.5 10563.0 LOG HEADER DATA DATE LOGGED: 25-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10563.0 TOP LOG INTERVAL (FT): 10079.0 BOTTOM LOG INTERVAL (FT): 10563.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 48.3 MAXIMUM ANGLE: 89.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10070.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 59.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 5000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.079 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .680 114.8 MUD FILTRATE AT MT: .880 70.0 MUD CAKE AT MT: 1.110 70.0 Page 11 • NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 9-15a.tapx Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10034 10563 10298.5 1059 10034 10563 RPD MWD040 OHMM 1.89 1894.89 58.4739 942 10034 10504.5 RPM MWD040 OHMM 0.99 1835.5 81.5414 942 10034 10504.5 RPS MWD040 OHMM 2.06 1096.99 11.24 942 10034 10504.5 RPX MWD040 OHMM 1.51 1485.6 11.8765 942 10034 10504.5 FET MWD040 HOUR 0.82 97.65 11.9729 942 10034 10504.5 GR MWD040 API 15.22 225.64 57.7932 913 10041.5 10497.5 ROP MWD040 FT/H 1.96 221.17 43.1389 968 10079.5 10563 First Reading For Entire File..........10034 Last Reading For Entire File...........10563 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/04 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.006 Page 12 9-15a.tapx Physical EOF File Header Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10498.0 14784.0 FET 10505.0 14791.0 RPX 10505.0 14791.0 RPS 10505.0 14791.0 RPM 10505.0 14791.0 RPD 10505.0 14791.0 OP 10563.5 14850.0 $ LOG HEADER DATA DATE LOGGED: O1-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14850.0 TOP LOG INTERVAL (FT): 10563.0 BOTTOM LOG INTERVAL (FT): 14850.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: $8.4 MAXIMUM ANGLE: 95.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10070.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 44.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 5800 FLUID LOSS (C3): 7.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.820 70.0 Page 13 i r 9-15a.tapx MUD AT MAX CIRCULATING TERMPERATURE: .910 147.2 MUD FILTRATE AT MT: 1.750 70.0 MUD CAKE AT MT: 1.910 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~iny Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MwD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MwD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 10498 14850 12674 8705 10498 14850 RPD MWD050 OHMM 1.68 181.7 10.2965 8573 10505 14791 RPM MWD050 OHMM 1.53 78.78 9.53161 8573 10505 14791 RPS MWD050 OHMM 1.63 88.86 8.66311 8573 10505 14791 RPX MWD050 OHMM 1.76 106.33 8.60492 8573 10505 14791 FET MWD050 HOUR 0.34 24.29 2.04746 8573 10505 14791 GR MwD050 API 11.62 144.67 36.7206 8573 10498 14784 ROP MWD050 FT/H 0.05 562.17 111.851 8574 10563.5 14850 First Reading For Entire File..........10498 Last Reading For Entire File...........14850 File Trailer Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/04 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.007 Page 14 9-15a.tapx Physical EOF File Header Service name... .......STSLIB.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 14784.5 RPX 14791.5 RPD 14791.5 FET 14791.5 RPS 14791.5 RPM 14791.5 $OP 14850.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 STOP DEPTH 15759.5 15766.5 15766.5 15766.5 15766.5 15766.5 15820.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): 03-MAY-07 Insite 72.13 Memory 15820.0 14850.0 15820.0 89.7 92.2 TOOL NUMBER 135134 167218 6.125 10070.0 Polymer 8.60 47.0 8.9 9000 Page 15 • 9-15a.tapx FLUID LOSS (C3): 6 7 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .650 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .310 153.5 MUD FILTRATE AT MT: .610 69.0 MUD CAKE AT MT: .750 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 14784.5 15820 15302.3 2072 14784.5 15820 RPD MWD060 OHMM 2.31 6.23 3.4214 1951 14791.5 15766.5 RPM MWD060 OHMM 2.25 7.32 3.5194 1951 14791.5 15766.5 RPS MWD060 OHMM 2.1 7.05 3.51808 1951 14791.5 15766.5 RPX MWD060 OHMM 2.04 7.39 3.56757 1951 14791.5 15766.5 FET MWD060 HOUR 0.44 29.39 2.72319 1951 14791.5 15766.5 GR MWD060 API 12.39 83.73 24.4699 1951 14784.5 15759.5 ROP MWD060 FT/H 0.82 429.94 122.265 1940 14850.5 15820 First Reading For Entire File..........14784.5 Last Reading For Entire File...........15820 File Trailer Service name... .......STSLIB.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/04 Page 16 9-15a.tapx Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLI8.008 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/12/04 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Reel Trailer Service name .............LISTPE Date . ...................07/12/04 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File scientific Technical services Page 17