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HomeMy WebLinkAbout200-175MEMORANDUM State of Alaska Insp Num: mitLOL210212104840 Alaska Oil and Gas Conservation Commission Rel Insp Num: DATE: Wednesday, April 7, 2021 TO: Jim Rper �2� SUBJECT: Mechanical Integrity Tests P.I. Supervisor I�Tertj vZZ4 EdIA Type lnj N Hilcorp North Slope, LLC 8525 - E -31A FROM: Lou Laubenstein PRUDHOE BAY UNIT E -31A Petroleum Inspector Ste: Inspector zo017s0 Reviewed By SPT"Test P.1. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT E -31A API Well Number 50-029-22411-01-00 Inspector Name: Lou Laubenstein Permit Number: 200-175-0 Inspection Date: 2/12/2021 Insp Num: mitLOL210212104840 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well EdIA Type lnj N TVD 8525 - Tubing 129 2538' 2382 2293' PTD zo017s0 !Type Test SPT"Test psi 2131 IA 801 836 - 833 - 833 - BBL Pumped: 0.2 BBL Returned: OA 2 0 0 0 Interval OTHER P/F 1 ' Notes' MIT -T For CO 4736 to verify Combo MIT-T/IA test, plug set @ 1112711. Test 43 The screened orifice was removed and a dummy valve was installed to isolate the IA. Wednesday, April 7, 2021 Page 1 of I MEMORANDUM TO: Pim Regg ,qet 1 2G%7i( P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 3, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC E-31 A PRUDHOE BAY UNIT E -31A Sre: Inspector Reviewed By: P.I. Suprv, Comm Well Name PRUDHOE BAY UNIT E-3 ]A API Well Number 50-029-22411-01-00 Permit Number: 200-175-0 Insp Num: mitLOL210212104840 Rel Insp Num: Inspector Name: Lou Laubenstein Inspection Date: 2/12/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min E-31A - Type Inj N- TVD 8525 Tubing 1129 2538 - 2382- 2293, — - zoons0 Type Test SPT Test ps 2131 IA 801 aid FBBL 833 833 mped o.z BBL Returned: OA z 1 ° _L ° ° Interval OTHER P F F Notes: MIT -T For CO #736 to verify Combo MIT-T/IA test, plug set @ 1 1127ft. Test #3 The screened orifice was removed and a dummy valve was installed to isolate the IA. �l Wednesday, March 3, 2021 Page 1 of I MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector Z'IZ,( NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 16, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC E -31A PRUDHOE BAY UNIT F,3 IA Ste: Inspector Reviewed By: P.I. Sup" T �— Comm Well Name PRUDHOE BAY UNIT E-3 IA API Well Number 50-029-22411-01-00 Inspector Name: Lou Laubenstein Permit Number: 200-175-0 Inspection Date: 2/11/2021 IOSp Num: mi[LOL210212103553 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well E -31A 'Type InJ I N #VD 8525 Tubing 1 2201 2518 2384 2304 - 2242 - PTD 2001250 Type Test SPT Test psi 2131.25 IA 1490 1529 1540 1545 - 1548 - BBL Pumped: 0.2 IBBI Returned: OA o 0 0 0 0 Interval OTHER Notes: MIT -T For CO #736 to verify Combo MTC-T/IA test, plug set @ 11127R. Test #1 t�1S�,4s �-0'�4 �Racitlt� Tuesday, February 16, 2021 Page I of 1 MEMORANDUM TO: Jim Regg� P.I. Supervisor77 FROM: Lou Laubenstein Petroleum Inspector zlF�5l7-01-t NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 16, 2021 SUBJECT: Mechanical Integrity Tests Hilemp Nonh Slope, LLC E-31 A PRUDHOE BAY UNIT E-31 A Ste: Inspector Reviewed By: P.I. Supry i Comm Well Name PRUDHOE BAY UNIT E -31A API Well Number SM29-22411-01-00 Inspector Name: Lou Laubenstein Permit Number: 200-175-0 Inspection Date: 2/11/2021 IRsp Num: mi[LOL210212103007 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well E -31A Type IBJ N 'TVD 8525 Tubing 512 - 2509 2357 - 2302 PTD zom7so Type Test sPT Test psi 2131.25 IA 518 2517 - 2410 - 2355 - BBL Pumped: 16.2 - IBBL Returned: 6.1 OA o 0 0 0 Interval IOTHER I IP/F P Notes: Combo MIT-TIIA every 2 -years per CO #736 Skt� 31�-177 ��iiz�1 Tuesday, February 16, 2021 Paee I of I MEMORANDUM TO- Jim Regg P.I. Supervisor i FROM: Lou Laubenstein Petroleum Inspector qz'�7 Z�)Z4 NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 16, 2021 SUBJECT: Mechanical Integrity Tests Hdcorp North Slope, LLC E-31 A PRUDHOE BAY UNIT E -31A Ste: Inspector Reviewed By: P.I. Sup" Comm Well Name PRUDHOE BAY UNIT E-3 IA API Well Number 50-029-22411-01"0 Inspector Name: Lou Laubenstein Permit Number: 200-175-0 Inspection Date: 2/11/2021 InSp Num: mitLOL210212104442 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well E -31A Type Inj N TVD 5525 Tubing 2242 2530 - 2414 2343 2285 PTD 1 2001750 - Type Test I SP1' Test psi 213115 IA 1548 1556 1557 - 1560 - 1563 BBL Pumped: I IBBL Returned: 01 OA 0 0 0 0 0 Interval OTHER P/F I Notes: MIT -T For CO#773��6��to�verify test, plug set @ 11127R. Test #2 /Combo .+IMff-TM Tuesday, February 16, 2021 Page I of I MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 16, 2021 SUBJECT: Mechanical Integrity Tests Hilcom North Slope, LLC E -31A PRUDHOE BAY UNIT E -31A Src: Inspector Reviewed By: P.I. Sup" _ Comm Well Name PRUDHOE BAY UNIT E -31A API Well Number 50-029-22411-0"0 Inspector Name: Lou Laubenstein Permit Number: 200-175-0 Inspection Date: 2/12/2021 Insp Num: mhl.ol.210212105329 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well E -31A Type Inj I N 'ITVD 1 8525 1 Tubing 2293 2540 2426- 2359 2307 _ PTD 2001950 Type Test SPT Test psi 2131.25 IA 833 840 841 844 - 848 ' BBL Pumped: BBL Returned: 0.2 OA o 0 0 0 0 Interval OTHER p/p I 1 ✓ Notes: MITT For CO 4736 to verify Combo MIT-T/IA test, plug set Q 11127fi. Test #4 The screened orifice was removed and a dummy valve was installed to isolate the IA. Tuesday, February 16, 2021 Page I of I Originated: Schlumhepp PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: AO GCC r ATT N: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 2 001 ` 5 f' TRANSMITTALDATE y- •• TRANSMITTAL# SERVICE ORDER SERVICE COLOR WELL NAME API # # FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED PRINTS CDs 50-029-22411-01 PRUDHOE BAY 51-123-22557-02 1141- BAY nsmittal Signature return via courier or sign/scan and email a copy i A Transmittal Receipt signature confirms that a package (box envelope, etc.) has been received and the contents of the v package have been verified to match the media noted above. The Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Schlumberger and BP point. Schlumberger -Private Auditor - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS _�.. v riJ FEB 2 8 2019 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ OperatiA [ Ic❑ s Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: IA Cement Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit [o Drill Number. 200-175 3. Address: P.O. Box 190612 Anchorage, AK 99519-6612 Slratigraphic ❑ Service ❑ 1 6. API Number. 50-029-22411-01-00 7. Property Designation (Lease Number): ADL 028304 8. Well Name and Number: PBU E 31A 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 15572 feet Plugs measured 12510, 14190 feet true vertical 6798 feet Junk measured 12516 feet Effective Depth: measured 12510 feet Packer measured 11104 feet true vertical 8848 feet Packer true vertical 8525 feet Casing: Length: Size: MD: TVD: Buret: Collapse: Structure Conductor 80 20" 30-110 30-110 1490 470 Surface 3883 13-3/8" 30-3912 30-3527 4930 2270 Intermediate 10638 9-5/8" 26-10664 26-8349 6870 4760 Liner 887 7" 10444 - 11331 8253-8613 7240 5410 Liner 4426 4-1/2" 11146 - 15572 8542-8798 8430 7500 Perforation Depth: Measured depth: 12050 - 15360 feet True vertical depth: 8843-8791 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.611 L-80 24-11161 24-8547 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 11104 8525 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Sting Into Cement Retainer at 11042'. Circulate 253 bbls 15.8ppg Class G Cement into IA. Unsting w/ 1 bbl left in Coil. Estimated TOC in IA - 5942'. Bottom cement depth - 11104'. Wait on compressive strength. Mill Cement Retainer and cement down to 11060'. Mill CBP at 11062' & push to TD of 12516'. Intervals treated (measured): 5942'-11104' Treatment descriptions including volumes used and final pressure: 253 bbls Class G Cement pumped into IA. Final Pressures = OA = 0 psi, IA = 162 psi, TBG = 930 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 501 32964 16 0 1562 Subsequent to operation: No Test Available 162 930 14. Attachments: (e eine per 20 nnc 25.070,25.071,&25.2e0) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Strattgraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ 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: 318-177 MAR 0 6 2019 Authorized Name: Hibbert, , Michael Contact Name: Hibbert, Michael Authorized Title: Well lnterventio sEngineer Contac Email: Michael. Hibbert(QBP.com Authorized Signature: Date: Z u I Contact Phone: +1 907 564 4351 Form 10-404 Revised 04/2017 /� YY//�6J y,//1,/17 Submit Original Only Daily Report of Well Operations PBU E -31A ACTIVITYDATF CI IRAMAPV ***WELL S/I ON ARRIVAL*** (Cement Squeeze) CURRENTLY RIH TO PULL P -PRONG FROM PXN-PLUG @ 11,148' MD 7/14/2018 ***CONT. ON 07/15/2018 WSR*** ***CONT. FROM 07/14/2018 WSR*** (Cement Squeeze) RAN 3.77" WRP DRIFT TO 11,130' SLM PULLED 4-1/2" PXN PLUG @ 11,148' MD 7/15/2018 ***JOB COMPLETE, WELL LEFT S/I*** ***JOB STARTED ON 28 -JULY -2018*** (SLB ELINE SET CBP) WELL SHUT IN ON ARRIVAL. INITIAL TWO = 160/225/0. RU. PT. RUN 1: RIH W/WFT 4.5" CBP. SET CBP AT 11065' ME. CCL TO MID ELEMENT: 8.4'. CCL STOP DEPTH= 11056.6'. 7/28/2018 ***JOB CONTINUED ON 29 -JULY -2018*** ***JOB CONTINUED FROM 28 -JULY -2018*** (SLB ELINE TUBING PUNCH AND CEMT RET SET) CONTINUE POOH AFTER SETTING CBP. RUN 2: PUNCH TUBING AT 11050'- 11055', 4 SPF, 0 DEG PHASED. CCL TO TOP SHOT= 5.6'. CCL STOP DEPTH = 11044.4' LRS PERFORM PASSING CMIT-TxIA TO 2500 PSI. RUN 3: RIH AND SET HES SVC CEMENT RETAINER ME AT 11040'. TOP OF RETAINER 11039'. CCL TO MID ELEMENT = 7.9', CCL STOP DEPTH = 11032.1'. LOG CORRELATED TO TUBING TALLY DATED 12 -MAY -2002. RDMO. NOTIFY PAD OP ON DEPARTURE AND HANDOVER RAP. WELL SHUT IN ON DEPARTURE. FINAL T/I/O = 515/38/0. 7/29/2018 ***JOB COMPLETE ON 29 -JULY -2018*** CTU#8 1.75" CT. Job Scope: Cement IA MU & RIH w/ HES Cement Retainer Stinger BHA w/ 2 knuckle joints. Park above Cmt Retainer & circulate btms up to get gassy fluids out of system. Tag retainer at 11026' ctm. Unable to sting into retainer trying various methods. Pooh. Re -run stinger w/ 1 knuckle joint and same results, unable to sting into retainer. Pooh. Trim 150' of pipe & re -head. Add an additional 10' of spacer pipe between the 2 stabilizers and re -run stinger bha w/ no knuckles. Tag Cmt Retainer at 11027'. Try various methods to get stung in. Was able to bobble past 11027' down to 11042' and sting into retainer. Appears the BHA was catching on GLM#1. PT backside to 750psi and confirm Coil is isolated. Circulate 160 bbis of diesel into IA. 9/3/2018 ***Continue Job on 9/4/18 WSR*** CTU#8 1.75" CT. Job Scope: Cement IA Continue circulating diesel into IA. Total of 340 bbis of diesel pumped into IA. Circulate 253 bbis 15.8ppg Class G Cement into IA. Unsting w/ 1 bbl left in Coil. Pooh pumping pipe displacement. Estimated TOC in IA - 5942'. Bottom cement depth - 11104'. Wait on compressive strength. 9/4/2018 ***Job Continued on 9/5/18 WSR*** CTU#8 1.75" CT. Job Scope: Cement IA RIH w/ WFT 2-7/8" Milling BHA w/ 3.70" Junk Mill. Tag at 7457' (Cement Stringers). Mill down to 7800'. Pump btms up. Drytag at 10947'. Mill Cement down to a hard stall at 11044' (Cmt Retainer). Mill Cement Retainer and cement down to 11060'. Pump btms up. Mill CBP at 11062'& push to TD of 12516'. POH & FP well. RDMO 9/5/2018 ***Complete*** ***WELL S/I ON ARRIVAL***(Cement Squeeze) RAN 3.70" CENT W/ 2.5" SAMPLE BAILER TO DEVIATION @ 11,618' SLM (multiple tight spots, while pooh hang up and get stuck, able to work free, see log for details) LRS LOADED 120 bbls CRUDE WHILE STUCK LRS FLUSHED W/ 150 bbls CRUDE 9/17/2018 ***WELLS/[ ON DEPARTURE*** Daily Report of Well Operations PBU E-31A CTU#8 1.75" CT Job Scope: Mill Cement Sheath MIRU CTU. MU & RIH w/ Baker 3.80" milling bha. Load well with 1% slick KCI and engage mill/motor at 6500'. RIH at 20 fpm while pumping at 2.0 bpm. See minimal motor work at - 6560' and 6850'. 1/20/2019 ***Continued on 1/21/2019 WSR*** CTU#8 1.75" CT Job Scope: Mill Cement Sheath Resume RIH with Baker milling BHA, pumping at 2.0 bpm and RIH at 25 fpm. Minimal motor work while RIH. Dry tag XN nipple at 11,146' otmd. Make 2 passes from above XN to 10,800'. RIH and dry drift from 10,800' to XN (11,146' ctmd). POOH. Freeze protect well with 60/40. RDMOL. 1/21/2019 ***Job Complete*** ****WELL S/I UPON ARRIVAL**** (Cement squeeze) R/U SLICKLINE UNIT SWCP #4522 TO SET TTP 1/29/2019 ****CONT JOB ON 1/30/19**** ****CONT. JOB FROM 1/29/19**** (Cement squeeze) DRIFTED W/ 3.80" G-RING, 4-1/2" BRUSH, 3.50" G-RING TO XN-NIP @ 11,151' SLM 111,148, MD LRS LOADED TBG W/ 220 BBLS CRUDE SET 4-1/2" PXN-PLUG @ 11,149' SLM 111.148' MD LRS ATTEMPTED MIT-T TO 2,420 psi (See LRS log / Plug losing 200psi every 5 mins) PULLED & RE-SET P-PRONG IN PXN PLUG BODY @ 11,148' MD (Metal shavings in packing) LRS ATTEMPTED 2 MIT-T's TO 2,420 psi (See LRS log / Plug losing 200psi every 15 mins) 1/30/2019 ****CONT JOB ON 1/31/19**** ****CONT. JOB FROM 1/30/19**** (Cement squeeze) PULLED 4-1/2" PXN-PLUG FROM 11,148' MD RAN 4-1/2" BRUSH, 3.50" G-RING, BRUSHED FROM 10,900' - 11,150' SLM LRS PUMPED 60 BBLS CRUDE WHILE BRUSHING SET 4-1/2" XX PLUG IN X-NIPPLE @ 11,127' MD. LRS PERFORMED PASSING MIT-IA TO 2420psi. PULLED 4-1/2" XX PLUG FROM X-NIPPLE @ 11,148' MD. SET 4 1/2" X-SEL TEST TOOL IN XN @ 11154' SLM. 1/31/2019 ***CONT ON 2-1-19 WSR*** ***CONT FROM 1-31-19 WSR***(Cement squeeze) SET 4-1/2" X-SELECTIVE TEST TOOL IN XN-NIPPLE & BOTH LOWER X-NIPPLES. LRS ESTABLISHED LLR OF -.05 BPM. SET 4-1/2" X-SELECTIVE TEST TOOL IN X-NIPPLE @ 2163' MD. LRS PERFORMED PASSING PRESSURE TEST ON TBG. SET 4 1/2" XX PLUG IN X-NIPPLE AT 11,127' MD. LRS PERFORMED FAILED CMIT TxIA TO 2420' PSI. 2/1/2019 ***CONT ON 2-2-19 WSR** ***CONT FROM 2-1-19 WSR***(Cement Squeeze) RAN PDS LDL- FOUND SAT STA #5 AT 3559' MD. SET 4 1/2" SS CSUB AT 3660' SLM. PULLED AND RESET RK-DMY GLV IN STA #5 AT 3559' MD. 2/2/2019 ***CONT ON 2-3-19 WSR*** ***CONT FROM 2-2-19 WSR***(Cement Squeeze) LRS PERFORMED PASSING MIT-T TO 2420psi.(state witnessed) LRS PERFORMED PASSING MIT-IA TO 2420psi.(state witnessed 5 MD. SET RK-OGLV(20/64") IN ST#5 @ 3559' MD. PULLED 4-1/2" SLIP STOP CATCHER FROM 3660' SLM.(empty) BEGIN SCMT LOG 2/3/2019 ***CONT ON 2-4-19 WSR*** ***CONT FROM 2/3/19 WSR***(cement squeeze) RAN SLB SCMT LOG FROM 11,115' SLM TO SURFACE.(good data) PULLED 4-1/2" XX PLUG FROM X-NIPPLE @ 11,127' MD. 2/4/2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** 4" CARBON 13-3/8" FMC 6. CLCV = 154.62' °ELEV = 68.T Pte' 11331' 20CON0. 112' c Angle = 97' @ 14024' 91.5#, H40 um MD= iimr ID -19.124" um TVD= 8800'SS 13-3/8' CSG, 68#, L-80 13U1T, D = 12.415' -I 3918' w TOC(09/05/18) -5942' Minimum ID =3.725- @ 11148' 4-1/2" HES XN NIPPLE TO-P-7-—LNR-� 10460' 9-5/8" CSG, 47#, L-80, NSCC, D = 8.681" I-� 10670' R)NCH, 4 SPF (07/29/18) H 11050' - TOP OF 4-12" LNR D = 3.958" PERFORATION S(#rMARY REF LOG SPU RY SUN MA) ON 05/08/02 ANGLEAT TOP FH2F: 83" @ 12050' Note: Refer to Production DB for historical pert data SIZEISPFI NTUWAL OpNSgz SHOT SOZ 2-71W 4 12050 - 12100 O 01/15/04 MWGM 2-12" 4 12190 - 12400 O 0524/02 '4 2-12" 4 12660 - 12860 C 0524/02 DW 2-12' 4 12910-13150 C 0524/02 8427 2-1/2' 4 13220 - 13560 C 0524/02 W 2-12" 4 14350-14530 C 05/24102 7923 2-12" 4 15010 - 15360 C 0524102 0 E -31 A M DOal .2 @ 7 747E .70 11629"" 'HES X NP, D=3.813' MR I FT RA&K nM R ST MD TVD I DEV I TYPE VLV LATCH PORT DOTE 5 3559 3263 41 MWGM SO RK 20 02!03/19 '4 6623 5543 42 MAGM DW RK 0 11/27/06 '3 8427 6889 41 WAGM DMY W - 0 0528!02 7 9852 7923 50 WAGM DMY RK 0 05/26/02 h 11018 8492 67 KBG2 DMY BK 0 05/26!02 STA # 1 THRU 4 = BBiND CEMEWr 10460' 7" BKR TACK SLV, D = 7.50" 1046T9-5/8' X T BKR MOD -H PKR D = 6.19- 8.25"X .19'8.25"X 7" BKR HMC LNR HGR, D = 6.29" 11083' 4-12" HES X NP, D = 3.813" 7" X 4-12" BKR S3 P D = 3 X 5-12' BKR HMC LNR HGP- D = 67- l-la-lrc VYLtCi,u=3.95a' BT 5" X 4-12" XO, D = 3.980" MLLOUr VVNDOW (G31A) 11331'-1134T 12516' FISH: MLLED CMT REr, CMT, & VVFT CBP (09/05/18) ' LNR, 12.6#, L-80 BT -M, . 15577 bpf, D = 3.958' 11.+1:?.1i1111m PRUDHOE BAY LNR WELL: E -31A P9iMT No: `1001750 AR No: 50-029-22411-01 SBC 6, T11 N, R14E, 608' FN. & 501' FEL DATE REV BY CONVENTS DATE RE/ BYCOM5E4T5 12111/93 WISE ONG HORIZ COMPLETION 07/16/18 GJ&J PULL® 412" PXN PLUG (07/15118) 05/28/02 N-2ES SIDETRACK "A" 07/30118NXVWJNC SET CBP, TBG RUCHES, SErGATRE 1023/07 JSRIPJC DRAVVNGOORPECT101% 09/06/18 WJMD CMTlA/IrLLEDCMT&CBP(9/5/18) 05/12/15 PJC URATE PER TALLES 02/07/19 JL/JMD GLV GO 0728115 STFIJMD SET FISH (STUCK KB PATCH)l 0226119 DQfJMD ADDED REF & BF BE//®TT 133!8" GRADE BP Exploration(Alaska) 122&15 /TLH PULL FISWBASET PLUG (11/02/15) 1 Simulation Field May 2018 A 0.tl A � ^ �lr9t en c e ti" eye e1e D c B A A 8 c D D C 9 AI A B C D �I ev B6 e76 � GPMA ® X -Pad P2, NK � PI, NK [FER an D C B A L A B C D I D c a AA 849 Be0 _ B pp [ D ®R, 5 ®RW, U ] Blip 04 I ' ' 11, 03 ® F52 650 NI / 302 D c a A�f L A B c D 7 D c 8 A A B c D //pp 0 Ot :o i s, W ® K,E,4 UI �: : 09, 05 ® 05, 07 ® Ji °'e Ql RO 0 me I o l e A atm jj�� A B c D I FSI/3 CC�i 8 A B C D Ip� 1 E n l P' R �� 02, 15 �06, 18, GNI, NGI I. a &1 890 I G C B A BDN B C D A2 D C B A A B C D 40 V, E e V. NCI ®WGI, AGD1 II,WURDZ 13, MUD LOBS ® 01 ® I SSM B A A B c D I A B c D 536ell PBU lvishak PBU E PBU West End West Sak Performance &47 311 819 Bu " A B C D B 611 �' B16 B 7 531 6sD e1D MEMORANDUM TO: Jim Regg e�q 31(, I( 1 P.I. Supervisor FROM: Matt Herrera Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: February 3, 2019 SUBJECT: Plug Verification - IA Squeeze PBU E -31A BPXA PTD # 2001750; Sundry # 318-177 Section: 6 Depth Btm Township: 11N Range: 14E Meridian: Umiat Drilling Rig: NA 15.8 Rig Elevation: NA Total Depth: 15572 ft MD Lease No.: ADL 028304 0 Operator Rep: Jim Lenzner Suspend: NA P&A: NA Casing/Tubing Data: Casing Removal: Conductor: 20" O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 3912 Feet Csg Cut@ Feet Intermediate: 9 5/8" O.D. Shoe@ 10664 Feet Csg Cut@ Feet Liner: 7" O.D. Shoe@ 11331 Feet Csg Cut@ Feet Liner: 41/2" O.D. Shoe@ 15572 Feet Csg Cut@ Feet Tubing: 4 1/2" O.D. Tail@ 11161 Feet Tbg Cut@ Feet Plugging Data: Test Data: Type Plug Founded on Depth Btm Depth (Top MW Above Venfied Annulus Retainer 11020 5942 ft (est.)" 15.8 N/A 2 2 0 0 0 Initial 15 min 30 min 45 min Result Tubing 268 289 299 2488 IA 2629 2542 2503 ' P OA 2 2 2 0 Initiel tri min 3n min 4F min Result Tubing 2679 - 2553 2509 2488 IA 746 - 758 - 763 766 - P OA 0 0 0 0 Remarks: 254 bbls cement pumped into IA to repair tubing leaks (TBG x IA Communication); cement bottom on packer. Est TOC in IA @ ✓ 5942 MD to cover tubing leaks. MITIA and MITT post IA cement squeeze. Attachments: None rev. 11-28-18 2019-0203_Plug_Verification_IA-Squeeze_PBU_E-31A_mh .71111.11.1 8,or to, • tsfr Iyyyc THE STATE Alaska Oil and Gas �►:"? A OfLASI�eA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Michael Hibbert Well Interventions Engineer SCAM° BP Exploration(Alaska), Inc. P.O Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU E-31 A Permit to Drill Number: 200-175 Sundry Number: 318-177 Dear Mr. Hibbert: 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, L(U ;V__ Hollis S. French Chair DATED this ) day of May,2018. RBDMS re AY 16 2016 • STATE OF ALASKA 1 ALASKA OIL AND GAS CONSERVATION CAD t SSION 071 r/(S APPLICATION FOR SUNDRY APPROVALS (� l� 20 AAC 25.280 APR 2 8 2018 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 - O.e -it '.n u wd Suspend 0 Perforate o Other Stimulate 0 Pull Tubing 0 Chang A<. -e Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other IA Squeeze 0. 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 200-175 - 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0. 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-22411-01-00 • 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes 0 No 0 PBU E-31A 9. Property Designation(Lease Number): 110. Field/Pools: ADL 028304 PRUDHOE BAY.PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: I Effective Depth TVD: MPSP(Psi ) I Plugs(MD): Junk(MD): 15572 . 8798 . 11148 8542 11148,12510,14190 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 30-110 30-110 1490 470 Surface 3883 13-3/8" 30-3912 30-3527 5020 2260 Intermediate 10638 9-5/8" 26-10664 26-8349 6870 4760 Liner 887 7" 10444-11331 8253-8613 7240 5410 Liner 4426 4-1/2" 11146-15572 8542-8798 8430 7500 Perforation Depth MD(ft): I Perforation Depth TVD(ft): I Tubing Size: I Tubing Grade: Tubing MD(ft): 12050-15360 8843-8791 4-1/2"12.6#L-80 L-80 I 24-11161 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 11104/8525 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic II 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 14.Estimated Date for Commencing Operations: May 15,2018 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 ❑ Commission Representative: GINJ 0 OpShutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hibbert,Michael be deviated from without prior written approval. Contact Email: Michael.Hibbert@BP.corn Authorized Name: Hibbert,Michael Contact Phone: +1 907 564 4351 Authorized Title: Well Interventions Engineer Authorized Signature: \ ` Date: /JZ /l7 11 COMMISSION USE—ONLY • Conditions of approval:Notify Commission so that a representative may witness �/ Sundry Number Plug Integrity 0 BOP Test 0 Mechanical Integrity Test Lel Location Clearance 0 31/3,- . Other: pa 5 fD h ,t r 1,4 ,V1 t J ; , � v, c� r- w�L. ds j � ,....41-..,.." dl / I‘'fln •a,) %/Li71 iv' t 'r M' g w F"L Post Initial Injection MIT Req'd? Yes a No 0 C 0 3 Spacing Exception Required? Yes 0 No Ld/ Subsequent Form Required: `o —.4o* APPROVED BYTHE 1 //,O Approved by: LCUICOMMISSIONER COMMISSION Date: 1 f J`I�.� (� '`� V'Ti-- 5/�4/ig � cRIGtNAL RBDMS �1. AY 16 2018 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • by Well: E-31 E-31 IA Cement Job Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Laurie Derrick (907) 564-5952 Estimated Start Date - May 15, 2018 History E-31A was ST in May 2002 and completed in zone 1B/2A. The well produced fulltime until late 2006, when a TIFL failed. A LDL found a leak at 7,560' MD with a 4.9 gpm LLR (920 psi differential). In October 2007, integrity was restored by setting a patch over the leak. In October 2011, the well developed TxIA communication again and was verified by a failing MIT-IA to 3,000 psi (small leak of 2.52 gpm with 1630 psi differential). A LDL performed in April 2012 located a leak at 7,684' MD (below current patch). A caliper confirmed the tubing is very corroded with 60-70% penetrations from 7100-7530'md. Current Status ➢ The well is currently classified as "Not-Operable" by BP due to tubing by inner annulus leak. The well is currently shut-in until the leaks are repaired. The OA has no known integrity related issues. Surface Casing Shoe is at 3,918' MD and 3,530' TVD. The Cretaceous stratigraphy in this well is 1938' MD to 7675' MD (1855' TVD to 6262' TVD). To of G4 is 5406' MD (4570' TVD). The proposed top of cement will be 536' MD below the UG4 top and 1505' TVD below the surface casing shoe. Economics Well E-31A was found to have multiple tubing leaks at 7684' MD & 7560' MD and has been shut-in since 2011. By repairing this well with an IA cement squeeze, it is estimated that an incremental 54 mbo can be produced over the next several years. Without an IA remedial squeeze, the well has no utility in the foreseeable future. (Dow. ;01,:te/ha tuf (efe(vts kook/ ler , Iffor q 440% 4 i Objective 7 c r f-1474 The proposed plan is to place cement into the IA to fix the tubing by inner annulus leak @ 7,560' MD and 7,684' MD. The proposed cement top will be -5,942' MD (5,035' TVD) to cover the tubing leaks. Post-Job Evaluation ➢ MIT-IA and MIT-T to maximum anticipated well-head pressure ➢ SCMT to confirm Top of Cement (TOC) Long-Term Integrity Monitoring ➢ Record WHPs and Injection rate daily 2-year (biennial) MITIAs to maximum anticipated well-head pressure. • Current Schematic", 114=E- 4"CARBON VIEI 1 I-FAD= 13-3/6"FK: E-31A SAFETY NOTES; WIE1.1 AWILE>70 a 1 ion 3A ACTUATOR= KIR MAX BOGLE&16.2 111 11473' OKB_REV--- 64.62' BF Fl FV= 35 25' I] KOP= 11331' 70"cmint r.Tro, / Max AnGle= 97" lit --I iir 14074' ..._________ I I j 2163' I--4 12"1-ES X NIP,ID=3.813' Datum NU= 11857' 915*,F+.40, Colurri TVG.= 8800'SS ID "I9 12C GAS LI-I AONNURI=LS 11 3/8'CSG,MO PirlIOS BUTT 13^,l25 }-{ 3918'• ' ST IAD TVD10EV TYPE VLV LATCH FORT DATE . . 5 3559 3263 41 ROAM, DIAY FOC r 0 11/27106 I 4 6623 5543 42 MPAGIA1 DMA RK r 0 11/27/06 3 6477 6889- 41 AILICIIA MAY RIK r 0 05/26/02 Minimum ID =3.725" @ 1 1 148' 2 9852 1923 50 MI/GM OW RK 0 05/26,0021 4-1/2" HES X N NIPPLE 1 11018 8492 i 67 '(LIG-2 DI& BK 0 05/26/02 TOP 7LNR I10460' 10460' J--r BKR TEBACK SLY,13=7.50' " - I— I 40457' H9-5/8"X 7"BKR 1.400-H n<R,ID=6.19" ...\, ) 10482'j--11.36-Z 7;i1KRI-INIC LNR MGR,ID 9-5/Er CSG,478.L-80,NSOC,ID=&car —I 10670' 1—• Ob. I I I 11063.D-1±14-2"I-ES X NIP,ID-3.113'1 Z' X 4 11104'J-1T"X 4-112'BKR S-3 PKR,13=j.875. I I 1 11127' _-14 1/2"I-IE..&1P ID--.3 813'1 11146' I .B..',.'ii-X r !Km(),,r)..-S 2ricri [TOP OF 4-102-L.NR H iiimr 11148. _14-112'PXN P-U0(1802t1511 = ...1 11148' 4117 FES XN NIP.KJ=3_ns - 3 L 11163' } it,x5.le?804 ZXPLTP,O.4.41/8"1 r-- t 4-1/7 1BG.12,81,L-80 ST-14, - 1161' :=, 1 0152 1391,1).3,9513" 4 144111415 1.12"DKR HIAC LAIR NOR D.4430"1 11181 —14-1/2"AtEG,10'3.938"j 11167" I---i 5'X 4-112"X0 D=3.9110" 1 L/VHIRSTOCK(D5/12#C0__) —f i1fi24' ...........„....___________ _ - i r ILI'4‘203;e,L-Eq I4SCT,.0383 bpi,ID---•8278' --I —11322 --- 7"MI LOUT%WIDOW(E-31A) 11331'- 11343' 1 1 FFRFORATTAI S4 INA RY REF LOG: SPERRY SUN WU ON 05/08/02 1 42540* 14 1,-:,"VirPn cr.-....y.laen4) ANGLE AT TOP PEW 83' fE0 12050' OS Note:Refer to RoductionDBlor historical pert data . IP . \_ _141cifY 1 3 MT RKR CIRP(9/13/1113) SIZE SFF INTERVAL OprdSqz' SHOT SQZ 2-7/8" 4 12050- 12100 C 131/15,04 2-1/7 4 12190- 12400 C I 06/24.432 2 10" 4 12660 12860 C 05/24402 rii"4 -iiI;-1 I:1-67 2-1/2' 4 12910-13150 C 105/24102 .; 2 1/2" 4 13220 13560 C 05/24402 2-1/ ' 4 14150-14530 C 05t24/02 A. /-11/ 4 mu RI- 13.501., IL. UNZ4JUZ .4.1. 4 .4" 4-1/7 L142,12.811,L-80 BT-M, I 15572' . 0152 bpi,ID=3.9sr .. DATE REV BY C01.6134TS DATE REV BYCOMENTS FRUD-ICE BAY UNIT 12111193 N-18E ORM HOW COMPLETION 07/28115 STF/JIA31 SET FISH(STUCK KB PATCH) lAELL: E-31A 05/28/02 04.2E5 SIDETRACK-A" 12/28/15 fit/I ,i FULL F Li YUP/SEI F'LlXi(11/1015) PERIXT ND:' 001750 10r2oar J1+#/PJC SEIKP PA 10-1(1'Jt11/0/) All hb, 50-029-22411-01 10/23/07 JSR/PJC CRAWING CORPECTIONS • — . SEC 6.T11N,R14E,608'RI_&501'Eli 0118/10*JLVV/SV CSG CORRECTION 1 05/12'15 PJC UPDATE FER TA LLESBP Exploration(Alaska) , .. 2 , . • I Post IA Cement Joil0 TREE- 4"CARBON 1/Will-FAD= 13-318-RIC E-31A SAFETY NOTES: W ELL ANGLE>70 a 11629' ACTUATOR= BAKER MAI(DOGL EG.16 2 a 1 14 751"• OKB_ELEV= 64.62 FRF Fl FV= 345 75' KUP= 11331' =CU: OR, d____112._ K Max A wile= 70' T 47"fir 140741 I I 2163 I-14-1,2"I-ES X NIP,la=3.813' I Datum FA)= 11857' 91•50M40. ilium Pi D= B8DCE SS ICI 19.124' GAS LI-I PAM-AILS I 13 3/8"CSG lISP.NT ROS 91/TT.ID- 1:`4 15" f 3916, I ST MD 1VD ON TYPE VLV LATCH PORT DATE 5 3K-9 32631 41 MUM DL!" RK V" 0 11/27lOe -5,942'-TOC in IA 4 6623 5543'.d 42 INGPA DM RK ' 0 11/27,06 3 Minimum ID =3.725" @ 11148' 2 985213427 68891923! 4 501 1443M (W PXRK P. 00 0G5125/26/61a2°2,: 4-112" HES XN NIPPLE 1 11018 8492' 67 '(HG-2 DM B 0 K 05/26/02 TOP 7'LNR10450' ; 10450' I--7'BKR TEBACK SLV•ID=7.50' 1---. U el I 1 1045T 1-.9-5,d8"X 7'BKR 1.100-H PKR n=6 10^ 1 10462' , •8.,!, li ,' riKI4 NM:t hilt 1-1(A.t,0) rh" 9-51Er CSG,47#,1-80,1 ,ID=8.681' H 10670' 110113 -E4-ii.,Ill..X NIP Li m ez 11104- --I_T-X 4-1/2"BKR S-3 MR D=.141/5.• I 1I L11127' " 4 1/2"I ILL;x NIP ID=3 813^ 11146' -,,-1,,,11'x r 11110(1.,.n,s 7517'] TOP OF 4-1frl-NR 1-f 11141' - "/"/"....1 11148' H4-12'FiXN Pi-UG(I UG15)j 11148' -14-1,2-i-Es xt4 Pao,ID- 1 /25' 1 ,,---- -.11 1 5 3. 11'" '1 5 II?El KI-1,211X11.11.I '''1) .1 4°8- 1 4-1/2"TRG.12.01/,L-(30 UT-M, - 11161' k ----,4 11190 r—e-X s 11_7 HIOR WRAC LAIR iriCAR, -4-4310 I 1,0152 bpi,ID r--3 958" ' 11161' ._... . tiler —16-x 4-irr xi),lo=3tri 1•M-1176TOCK(136/12/02.3_1*11127 7*LW,2611,L-Ei0 NSCT, .0383 bp1,113-,-6.276' H -11322 F., 7"MILL.OUTIANDOW(E-31A) 11331'-11343' I RIRFORAT1ON St SAO RY .. „., I 12510' 14 Ir."'`PATZ1)Cr ', ), IC404) REF LOG: SI4TRY SUN MWD ON 05/08/02 - ANGLE AT TOP PERF 83"qi 1205(7 II 4 Ibte:Refer to Ftoduction DB/or historical pert data 00.0 \. I• ! 1.110•0' I—.I 5R1'RKR CalP(9/13,03) • SIZE SPF NTERVAL 'OprOSqz SI-IDT C(17 III • 2-7/8* 4 12050- 12100. C 01/151041 Airf‘ 2-12" 4 121W). 12400 C !05124.102 2 1/2" 4 12660 12860 i C 05024/02 I 1646F1—P6TD 1 _...., 2-1/2' 4 12910-131501 C 05124/02 2 1/2" 4 13220 13560, C 06124/02 2_1,2 4 14150-1455) C 6512442 I AV' 4 1.1%)IU- 113.304) %..... 1.113.1141LM %Imp* 4-1/2"LM 12-8N,1-80 BT-M,.1 15577 .-- 0162 W,0=3.9sr DATE REV BY COL&U4TS GATE REV BY 1 COMFAIENTS FRUCHOE BAY UNT 12/11193 N-18E ORG HOR1Z COUPLETION 07/2.915 STF,J1143',SET FtSH(STUCK KB PATCH) 'AELL. E-31A 05/28/02" N-2B SIDETRACK"A" 12721311,5 Ili! .FILL l-tS1111.3PISt I PLUG(11,02f 15) P134,1(T Pb.t001750 . , 10/2010/ J111-/FIJC. 5E1?CP PA10ii 1 3/11107) All NJ, 50-029-22411-01 10/23107 JSP/PJC CRAWING CCRi- RECT1CNS SEC 6.T11N,R14E,608'FN.&501'FEL ., 03/18/10 JI_WiSV CSG CORRECRON 05/12415 PJC UPDATE FER TALLES BP Exploration(Alaska) • 3 Proposed P&A • 4"CARBON . Mil-FAD= 13 Air FRC E-3 1 A SAFETY MOTU: WELL ANGLE 70 fit 11629'*** ACTUATOR= BAKER MAX 0OGLE6c16.2 il 11476' 0003„ELEV= 6&&Z — Cement Plug#2 Tubing punch rutiKOxPA=noe= 11331' !K,:iii iii ,::::/::i:i!iiiii.....,.:.:: ::...,,::ii]i •Imi 97 0. 14074, 20"mrsrinTon --I ?.-•i:iiiiii:::.., ,k2L: 1 M 216 1500' and circulate cement down Cbrturrits.D= 91 50 11-40' tubing and up IA and 0A. 1185T ' ' Datum TVD- 8scro.Ss u-19 124' 13 1/11°CSC,61141 NT 80,- it'll k) 1 'l',' 14—irsir k GAS LIE I MA MAELS I ., 1 ST hi) -Fyn fly TYIT VLV LATCH FORT DATE ti1011,4 . ! 5 3559 3203 41 #4Y RK 'r 0 11727,06 Cement Plug#1 Pumped 1 4 6623 5543 42 tottiGMI OW RK r 0 11127106' 3 8427 11889V. 41 MIAMI OW RK r 0 0ar26102 Minimum ID =3.725" @ 11148' ,i;...._ 2 9852 7923 50 5,11.1G11/44 OW RK 0 05/261a2 4-1/2" HES XN NIPPLE .:-.:::::::g--'. ":,.. 1 11018 8492 67 KBG-2 0U BK 0 06/26102, TOP 7-LNR - ' 104W : i1464*——frEKR TEBACX SLY. D=7.50 1 1045T I-9-518"X 7 BKRLDO-HR(R,0=6.19" 10467 I' i 8 26*X r ilKRI-64C Ll4R MGR.,KJ 82 ... , g-5Jir CSG,47#,L-80,NSCC,ID=8.681H 10670' : :-- ::::::•• 1110$3* i .HES X NP,104634313. ..... :::-- :::•.:::: 9211n:1111:i1 11104' T'X 4-112"BKR S-3 FKR,ID=1.875" I 11127• H41/2"I Up X NIP.0=3 813' 1 •:•:•::.::::::. .:: -:-:•:•:• ..... ••- -:•:•:•:. 1146 1 ti•'',,fl, x r TARA+ ::::::-: 11148*i 4, 1,, ,IXN r_LX,(11,04,15) TOP Of 4-1/7 LN1i1-1_1114.11" I -.:•:•:•:•:- i L !.INHE j I --. 11148' ,4 1.,2 HES XN RIF,la=1725" •••......° A. 1115t 4 ' 7, 7 Xid 5 r 11/444 2XP LIR -........... . 3-_, --, 117 TBG,12,8N,L-81)1044, 11181. Ili Ill , = " .:...:..:• . De4_430n20003958 4.. 11161' 4 lir AUG.ID=3,957 •:',...:i::::::: --------- 1448T 5'X 4-117 X0,ID=3,96-071 ._ ...., l,541RS rocK105/12/02) isszr r UV&28#,L-80 NWT, .0303 bpf,ID 6.270" —11322 --- ;;::•:::::.,,.. r MI LOUT~OW(E314) 11331 . 11343. PERFORATION&AMA RY ,N "•••, 1 12510* 14 1/,''.Aron(I'-*,Y., REF LOG: SFFRRY SLNMADON05/08/02 \ I ANGLE AT TOP PERF 63°8:0 12050 744941 , , 143te-Refer to Roduction 00.for historical pert dab3 444.4 0..1* \,,.. L 141cifli' —13.59/1"FiKR EiRP/5/13103)ii SIZE SEE RITERVAL I OpniSqz, SHOT SQZ 44444 VA tat 2-7/7 4 12050-12100 C 01/15104 Iry 2-1/7 4 12190-12400 C I 06/24.02 2 112 4 12660 12860 C ±05/24/02 ‘ 15456' 1 ,—FMTTD1 2-1/7" 4 12910-13150 C 05424.102 2 1/2" 4 13220 13560 C 05/24/02 9 2-1,2* 4 14150-14530 C 0544/02 . 444 I-Ill 4 Intl It)- MeV 1-,..' 1.10114JUI 4-1/7 LW„12.86,L-80 ST-141,. —I 15572' • 0152 bpf,0=3,068" _J DATE REV BY COMI/ENTS DATE REV BY i COR#6.11415 [RIO-CE BAY MT 12111193 N-18E °NOHOW COMPLETION 07)281115 STF/JMD7SET FISH CSTUO(KB PATCH) "AaL: E-31A 05/28/02 N-2ES SIDETRACK"A" 12/241/15, ,r1L11 *ALL EIS.VILOSE I HMG(11/02/15) PERNIT No:42001750 10120/07 MIRK; SET KP PA 101(10111/07) Afl tb. 60-029-22411-01 10/23107 JSRPJC ERAANG CORRECTONS -- SEC 6,Ti IN,R14E,608'FAL&5011-EL )3n a i 1 a AWSV 6KG CORRECTION 05/12115 PJC LPUATE PER TA LLE5 BP Exploration(Alaska" 4 • TIO Plot • • 020 120 3.600- _rp 3400 3260 -130 3.000 2300 -160 7p, 2600 2403 40 220 R 2000 -lp ..f----.IA OA 1300 100 s —4—000A � —an ■ Bleed W + Not ♦ under .r Tem Job Notes • The tubing x IA LLR is —0.08 bpm @ 2400 psi - observed on 4/9/12. • BHCT is estimated to be 180 F. • BHST 190 F. • New TOC in the IA will be 5,942' MD and 5,035' TVD. Cement Calculations Volume Cement 254 bbls Total cement to pump 254 bbls Key Parameters Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc (20-100 cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 7 hours Cement thickening time: Mix on the fly Activity Time(hours) Shearing time, quality control, PJSM 0 Cement displacement 5 Cement contamination Safety 1 Minimum required thickening time: 7 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 120 3000 5:00 150 1850 7:00 150 1850 • S Volumes: volume top MD bot MD Size ID bbls/ft. Ft. bbls 4-1/2"tbg to production packer 0 11,104 4-1/2" 12.6# 3.958" 0.0152 11,104 169 9-5/8"47#x 4-1/2" x 9-5/8" annulus 0 10,457' 4-1/2" 12.6# 8.681" .05353 10,457' 560 7"26#x 4-1/2"x 7" annulus 10,457' 11,104' 4-1/2" 12.6# 6.276" .01859 647 12 Summary of Procedure Slickline 1. Pull PXN plug from 11,148' Electric Line 2. Set CBP @ -11,050' 3. Punch tubing @ 11,035' 4. Set cement retainer @ -11,020' Coiled Tubing 5. Place 254 bbls of cement in IA 6. Wait on cement. 7. MIT-IA 8. Mill out cement, retainer, and CBP. Slickline & Fullbore 9. Set PXN plug @ 11,127' 10. MIT-T and MIT-IA 11. SCMT 12. Pull PXN plug 6 ,----- • . III 110 BP EXPLORATION Wellbore Equipment Report Welt E-31 Event REENTER+COMPLETE RTA(B Elev. 60_00(ft) well ID Event Start. 5/5/2002 Ground Elev. 34.20(ft) Feld: PRUDHOE BAY Event EncI KB to GL: 29.80(ft) Spud- 5/12/2002 Wel Type: Muarve Elev. 0.00(ft) Installed' 5128/2002 Top: 0.00(ft) Wellbore 01 TUBING Bottom; 22,320.80(It) ..: , -- Component ,.. Size 1 Jta Length 1 Top Set Weight GradeThreacts :Mn ID,Comments I(0) i ' (ft) 1 (ft) (110/8) ; (m) 1 . • N2ES RT-TS ;. 1_0,000 1 24.19 0.001 0.091. TUBING HANGER 1 4.500 1 074 24,19! 0.00 L-80 NSCT I 3.9581 X-0 TBG PUP JT 1 4.500 1 1.37 24.931 12_60 L-80 NSCT 1 581 T1.1BING JOINTS 4.500 1 41.90 28-.3-i 12.601 1-80 IBT-M 1 3.958• 1 TUBING PUPJOINT 4.500 2 19.171 68.20! 12.60: L-80 NSCT I_3 958, , ... ._. TUBING JOINTS 4.500 50 2,065.461 87.37 12.60! L-80 IBT-M 1 3.9581 X-0 TBG PUP JT 1 4-5001 1 9,82. 2,152.83 1250' L-80 IBT-M -t - NIPPLE 4.5001 1 . 1.141 2,162.65 0.00 9CR NSCT ' 3,810' X-0 TBG PUP JT 4 500 1__I_ 9.821 2,163 79 12.60 L-80 NSCT 3.958 .TUBING JOINTS 4.500 33 1,375.61 2,173,61 12.60 L-80 IBT-M 3.958 i X-0 TBG PUP JT 4.500 1 9,79 3.54922 12.60 L-80 IBT-M 3.958 *GAS LIFT MANDREL 4.500 1 8.59 3,559.01 0.00 SCR NSCT .... X-0 TBG PUP jT 4.500 - 1 9 871 3,567 60 12.60 L-80 1NSCT 3.9581 I1 TUBING JOINTS 4.500! 74 , 3.035_52 3,577.47 12.601 L-80 I IBT-M 3.9581 X-0 TBG PUP JT 4,5001 1 9,83, 8,612.901 12.60' L-80 I IBT-M 3_9581 I , GAS LIFT MANDREL 4.500/ 1 81331 6,622_82; 9.001I 9CR INSCT 3 958 , X-0 T130 PUP JT i 4.500' 1 9.871 6,631.451 12.601 1-60 INSCT 3.958 TUBING JOINTS I. 4.500; 43--r-•1,775.431 8.641 32 12.001 L-80 IBT-M 3 9581 X-0 TEG PUP JT 44.500 1 9.831 8,416.75' 12.60_i_ L-80 I BT-8,1 ; 3_95E11 GAS LIFT MANDREL 4.500 1 8.64 8.426.58 0.001 9CR NSCT 3 958: X-0 TBG PUP JT 4 5001 1 8.97 8,435.22 12.60 L-80 NSCT 3-958; TUBING JOINTS • 4.5001 34 4, 1397.75 8444 19 12 60 L-80 IBT-M 3958 I ' X-0 TBG PUP JT 4 5001 1 i 9.83 9,841.94 12.601 L-80 IBTAI 3.959: GAS LIFT MANDREL 4.500 i 1 1 8.611 9.851.77 0 001 9CR NSCT 3.958'' 1 X-0 TBG PUP JT 45C)& 1 ! 9.86, 986038! 12.501 L-80 NSCT 3958k TUBING JOINTS 4 500 28 :'. 1,138.13i 9,870.241 12.601 L-BO IBT-M 3.9581 X-0 TBG PUP JT 1 4 5001 1 9.82; 11,006.37! 12.601 -80 !IBT-M 3.958I -' L• .1 GAS LIFT MANDREL 1 4.500' 1 6.89! 11,018.191 000' 9CR 1NSCT 3.9581 1X-0 TBG PUP JT ' 4.500 1 9.87 11,025 081 12,60; 1-80 NSCT 3,958 I . TIJBING JOINTS 4.500 I 343.31 J 11,034_95 12.60;; L-80 IBT-M 3.958 X-0 TBG PUP JT 4 500 1 9 841 1i,073,26 12.60! L-80 IBT-M 3.958 NIPPLE 4,500i 1 1.14 11083.101 0.001 9CR NSCT 3.8131 X-0 TBG PUP JT 4 5001 1 9 86 11 084 24_1 12 601 L-80 NSCT -I , • • . X-0 TBG PUP JT 1 4,500[ 1 9.891 11,094_10: 12.60; L-80 LIBT-fvI . 3.958 - ,. PACKER(PERMANENT) ••: 7 000 1 3 8Di 11,103 90 I 25.00 L-80 i NSCT - 3.875 . , TUBING PUPJOINT 1 4.5001 2 19.75; 11,107.7W 12.60 L-60 1NSCT 3 958 .. _ ...i I . NIPPLE *r 4 5001 1 1_151 11,127.45i 0.00 9CR NSCT13.8131 ! ! , TUBING PUPJOINT 1 4.500 2 . 19.761 11.128.60! 12.60 L-80 ;NSC r 3.958 NO-GO NIPPLE ...4.500 I 1.211 11,148.381 0.00 9CR 1NSCT . 3 725 TIJ 8 ING PUPJOINT 1 4 500 1 ; ; 9.861 I1,149591 12.60' L-80 'NSCT ! 3 958; f wlieLINE.OCJIDE I 4.500, 1 1.351 14159.451 0.00 9CR •NSCT ; 3955 . .. Comments- Remarks- WELL WAS TREATED W/CORROSION INHIBITOR ON ANNULUS F/11180 TO 2200'AND FREEZE PROTECTED WI 151 BBLS OF DIESEL F/2200'BACK TO SURFACE ON TUBING AND ANNULUS RPV IS SHEARED IN GLM AT 3559' RETRIEVED BALL/ROD FROM RHC PLUG INSTALLED IN XN NIPPLE AT 11148' ., ... ., Proloci 5.2tatta la an AM Page 1 of 1 7 M • Roby, David S (DOA) From: Ohms, Danielle H <Danielle.Ohms@bp.com> Sent: Wednesday, May 02, 2018 2:52 PM To: Roby, David S (DOA); Loepp, Victoria T(DOA); Davies, Stephen F (DOA) Cc: Derrick, Laurie R; Hibbert, Michael Subject: FW: Sundry application for PBU E-31A (PTD 200-175) Dave, Following up on our short conversation yesterday regarding the E-31A Sundry Application. The 54 MBO referenced is incremental oil recovered by repairing and returning that well to service. With our facilities at gas handling limits,the e are a number of operable wells that are shut-in and only brought online when room in the system is available. While we believe that after repairing E-31A it will be a competitive well for a portion of the year, because of the gas rate tha will be produced along with the oil, it would back a less competitive online well out of the system. Thus the 54 MBO i• our estimate of incremental (or net)oil that will be brought into the system over the next several years. If you need additional information related to E-31A's estimated incremental production please let us know. Thanks. Danielle Ohms AK PE Discipline Lead BP Exploration (Alaska) Inc. (907) 564-5759 office (907) 440-9082 cell ohmsdh@bp.corn From: Hibbert, Michael Sent: Monday,April 30, 2018 2:21 PM To: Derrick, Laurie R<Laurie.Derrick@bp.com> Cc:Worthington,Aras J<Aras.Worthington@bp.com>;Ohms, Danielle H<Danielle.Ohms@bp.com> Subject: FW:Sundry application for PBU E-31A(PTD 200-175) Hi Laurie, Can you please respond to this request for clarification form the AOGCC about the remaining value of E-31?When you reply please also copy all three AOGCC staff included below. Thanks, Michael Hibbert BP Alaska—Intervention&Integrity Engineer Email: Michael.Hibbert@bp.com From: Roby, David S(DOA)<dave.roby@alaska.gov> Sent: Monday,April 30,2018 1:10 PM To: Hibbert, Michael<Michael.Hibbert@BP.com> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Davies,Stephen F(DOA)< ve.davies@alaska.gov> Subject:Sundry application for PBU E-31A(PTD 200-175) 1 • Michael, In reviewing the referenced sundry application i notice that the anticipated remaining reserves for the well are given as 54 MBO and the expected life is several yea.:. In looking at the production data for this well, over the last several years of its productive life it appears that the well was cycled due to high GOR and during the production cycle the well was only online.on average,for about half the lays in a month. During these production cycles the well would still produce a significant amount of oil. The well ceased more or lease continuous production in November 2006, and was shut in for 10 months before the well was put back on production for about 180 days over the next year. During this time the well produced over 100 MBO. After this production period the well was shut in for about 5 months before being returned to production for a period of 9 months. During this time the well produced nearly 60 MBO over 130 online days. The well was shut in for about a year after this before being put online for its last production period which lasted for about a year. During this time the well produced about 80 MBO and was online for about 170 days. Based on the past production performance for the well and an expected life of several years I'd expect the well to be able to recover much more than 54 MBO if it was returned to service. Conversely, if the reserves are 54 MBO I'd expect the well to recover that in under a year and not over a period of several years. There are several reasons I can think of as to why the reserves now would be lower than what would be predicted based on the previous production performance (for example it's possible, maybe even likely,that in the 7+years since this well last produced the area has been swept by gas and or water so there'd be less oil in the area and the well would be even less competitive than before due to increased GOR or water cut) but I was wondering if you could provide any insight into where the 54 MB reserve figure came from? Thanks in advance, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas vrrservation Commission tAOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/•r "r vileaed 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 i sending it to you,contact Dave Roby at(907)793-1232 or _ave.robyalaska.gov. 2 • • l xco Thousand Cubic Feet of Gas ("MCF") per Month X m ...(--..1 N M O or Gas-Oil Ratio N 0 0 co v o 0 0 0 0 O O O O O N O O O O a w Ln ,11111 % f it lo�oe ?I& a N r .1 I Lrl r, 0 o 0 c _ . o u? 1 a NI ........ m O M ° al W ° v U o I E stoe o Z L Opt u p 0 a HI Q J w CO 0 I I D W w a f�6 .. .z I'll 41- • ° ° `."� a 2 .4‘ �� I • �. I N n OC o d = I0. d >: c 'I •• I • otos Q a .r . L •`'1`10---. I �Pff V O . -1HIM Z = O u4 4 11_ 11 11!11 1 YCe -- CO 41 V ° 4 I 1 I . _.;. ° ° 7.041 QI I ° ° N iIiii8 M M 1 4 4 _ I ■.. I soon Z 'y 4 44 t-'-'171--.---12........• 1 `Pr 0 1 4 4 --4 � ` ' • ett _a 8 : °°. �--.— 0 CC o c44 CO p O J a } " ti CL a W CL 0 CO iuuI , , , 0OoO gluol/1l aad aaIeM to slaaae8 ,io i uoim Jad l!O Jo slaaae8 ~ ,,--;. Image oject Well History File Cover P"'..;.Ie XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ ()O-17Swell History File Identifier Organizing (dOIl,~) 0 Two-Sided 1111/11111111111111 RESCAN o Rescan Needed 11/1/111111111/1111 0 Color items: 0 Grayscale items: 0 Poor Quality Originals: 0 Other: DIGITAL DATA ~ Diskettes, No. ~ OVERSIZED (Scannable) o Maps: o Other, Norrype o Other items scannable by large scanner OVERSIZED (Non-Scannable) NOTES: o Logs of various kinds BY: ~yA 0~ Other DA" ~~~ , BY: (~ DA"1fi/*~ V11P III 1111111111111111 ~ 16 = TOTAL PAGES I Do ~ Project Proofing BY: -3- x 30 = f!-I2- + D"'7ß IOlf~ B Scanning Preparation Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: IfJó NO PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: BY: ¡jJ~ DATE: ¿/z-/o I Stage 2 I-Y~O IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: DATE: ISI (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) ,~ III 1111111/111 11111 ReScanned fìnl.fividual pJg~ 1(,IW:ì.11 Mlòf1tínf1} _~c']f1nillg ¡;OmpIBlòd) III 1/11111111111111 RESCANNED B'< BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /s/ General Notes or Comments about this file: SCANNED JUL 1 9 2004 Quality Checked (dont'! '_ 111111111111/1111/1 , 1211 OI02Rev3NOTScanned. wpd OPERABLE: Producer E -31A (PTD #01750) Tubing Integrity Restored • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] /`b t Sent: Thursday, January 06, 2011 2:54 PM c To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 Operators; AK, OPS Prod Controllers; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Engel, Harry R; Ramsay, Gavin Cc: King, Whitney; AK, D &C Well Integrity Coordinator Subject: OPERABLE: Producer E -31A (PTD #2001750) Tubing Integrity Restored All, Producer E -31A (PTD #2001750) passed an MITIA on 1/06/2011 verifying that tubing integrity has been restored. The well has been reclassifie a3 s gable and may be placed on production when convenient for operations. Please be careful when placing the well on production as the IA is fluid packed. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator ri Office (907) 659 -5102 O' J Cell (907) 752 -0754 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Monday, December 27, 2010 8:49 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Facility OTL; AK, OPS GC1 Field 0 &M TL; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 Operators; AK, OPS Prod Controllers; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; 'Maunder, Thomas E (DOA)'; Cismoski, Doug A; Engel, Harry R; AK, RES GPB West Wells Opt Engr; 'Regg, James B (WAY; 'Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>' Cc: AK, D &C Well Integrity Coordinator; Janowski, Carrie; Ramsay, Gavin Subject: UNDER EVALUATION: Producer E -31A (PTD #2001750) Sustained Casing Pressure on the IA All, Producer E -31A (PTD #2001750) has been confirmed to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA equal to SSV /2160/0 psi on 12/24/10. The well has been reclassified as Under Evaluation for further diagnostics. The plan forward is as follows: 1. Pumping: MIT -IA to 3000 psi, LLR if fails 2. E -line: Leak Detect Log pending MITIA results A TIO plot and wellbore schematic have been included for reference. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 1/6/2011 UNDER EVALUATION: Producer E (PTD #2001750) Sustained Casing 1ssure on the IA Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] "1 J Ito Sent: Monday, December 27, 2010 8:49 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Facility OTL; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 Operators; AK, OPS Prod Controllers; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Maunder, Thomas E (DOA); Cismoski, Doug A; Engel, Harry R; AK, RES GPB West Wells Opt Engr; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D &C Well Integrity Coordinator; Janowski, Carrie; Ramsay, Gavin Subject: UNDER EVALUATION: Producer E -31A (PTD #2001750) Sustained Casing Pressure on the IA Attachments: E -31A TIO Plot 12- 27- 10.doc; E- 31A.pdf All, Producer E -31A (PTD #2001750) has been confirmed to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA equal to SSV /2160/0 psi on 12/24/10. The well has been reclassified as Under Evaluation for further diagnostics. The plan forward is as follows: 1. Pumping: MIT -IA to 3000 psi, LLR if fails 2. E -line: Leak Detect Log pending MITIA results A TIO plot and wellbore schematic have been included for reference. «E -31A TIO Plot 12- 27- 10.doc» «E- 31A.pdf» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 ViAlirrfIDDEIL , Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 12/28/2010 PBU E -31A PTD 2001750 12/27/2010 TIO Pressures Plot Welt E -31 4,000 - _ • 3.000 - -►- Tbg C i00 - —E- IA -416- OA OOA -+- 0004 On 1,000 - rimasessomi 7.7 • 07/03/10 08/03/10 09/03/10 10104/10 11/04/10 12/05/10 TREE= 4" CARBON WELLHEAD = 13-3/8" FMC III SAFETY N.: ACTUATOR = BAKER' E -3 1 A KB. ELEV = 58.7'' BF. ELEV = 35.25' KOP = 11331' I 1 I Max Angle = 97@ 14024' 1 2163' 1-14-1/2" HES X NIP, ID = 3.813" I Datum MD = 11857' 120" CONDUCTOR 1 110' Datum TVD = 8800' SS 1 13-3/8" CSG, 68#, NT-80S BUTT, ID = 12.415" H 3925' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 14-1/2" BKR KB PATCH, D = 2.45" (10/11/07) H 7551' - 7581' 5 3559 3263 41 MMGM DMY RK ' 0 11/27/06 0 iii 4 6623 5543 42 MMGM DMY RK r 0 11/27/06 ,•, Minimum ID = 2.45" @ 7551' lin 3 8427 6889 41 MMGM DMY RK 0 05/26/02 2 9852 7923 50 MMGM DMY RK 0 05/26/02 4-1/2" BAKER KB PATCH 1 11018 8492 67 KBG-2 DMY BK 0 05/26/02 'TOP 7" LNR1-1 10450' 10450' J-17" BKR TIEBACK SLV, D = 7.50" I 10457' H9-5/8" X 7" BKR MOD-H PKR, ID = 6.19" I 10462' 1-18.25" X 7" BKR HMC LNR HGR, ID = 6.28" 1 1 9-5/8" CSG, 47#, L-80, NSCC, ID = 8.681" H 10670' E-A I 11083' 1-14-112" HES X NIP, ID = 3.813" 1 I 11104' 1-17" X 4-1/2" BKR S-3 PKR, ID = 3.875" 1 Fl■ II 11127' I-14-1/2" HES X NIP, ID = 3.813" 11146' H 4-1/2" TBG, 12.6#, L-80 IBT-M, —I 11161' 7' LINER TIEBACK, ID = 5.250" 1 .0152 bpf, ID = 3.958" 11148' 1-14-1/2" HES XN NIP, ID = 3.725" 1 'WHIPSTOCK (05/12/02) H 11322' 1 !--7 11153' H 7" X 5-1/2" BKR ZXP LTP, ID = 4.408" 1 PERFORATION SUMMARY Llri REF LOG: SPERRY SUN MWD ON 05/08/02 1 A . 1 7" X 5-1/2" BKR HMC LNR HGR, ID = 4.430" ANGLE AT TOP PERE: 82"@ 12050' 11161' H4-1/2" WLEG, ID = 3.958" 1 Note: Refer to Production DB for historical perf data 1116T 1—I 5" X 4-1/2" XO, ID = 3.980" 1 SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 12050 - 12100 0 01/15/04 2-1/2" 4 12190 - 12400 0 05/24/02 2-1/2" 4 12660 - 12860 C 05/24/02 7" MILLOUT WINDOW (E-31A) 11331' - 11343' 2-1/2" 4 12910 - 13150 C 05/24/02 2-1/2" 4 13220 - 13560 C 05/24/02 2-1/2" 4 14350 - 14530 C 05/24/02 1 12510' 1-14-112" WFRD GIBP (05/16/04) I 2-1/2" 4 15010 - 15360 C 05/24/02 WAN ■ * AN 1 14190' H3.593" BKR CIBP (5/13/03) 1 .4 - - kr!: 1 7" LNR, 26#, L-80 NSCT, .0383 bpf, ID = 6.276" H 12694' 7.- -01 + ks *N \ 16486' -I PBTD I 14-1/2" SLTD LNR, 12.6#, .0152 bpf, ID = 3.958" 1-1_13393 14 Atr 4.- .,..- . 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" H 15572' DATE REV BY COMMENTS DATE REV BY COMMENTS I PRUDHOE BAY UNIT 12/11/93 D-9 ORIG HORIZ COMPLETION 12/05/06 GJF/TLH XXN PLUG SET & GLV C/O (11/27) WELL: E-31A 05/28/02 N2ES SIDETRACK "A" , 10/04/07 GJF/TLH PLUG PULLED PERMIT No: t001750 05/13/03 JGIWKK SET BKR CIBP 10/20/07 JMF/PJC SET KP PATCH (10/11/07) API No: 50-029-22411-01 01/15/04 KCF/KK A DPERF 10/23/07 JSRJPJC DRAWING CORRECTIONS SEC 6, T11N, R14E, 608' FNL & 501' FEL 02/02/04 CMO/TLP REF LOG/DATUM MD/TVD 03/18/10 JLW/SV CSG CORRECTION 05/16/04 SRB/KAK SET WFRD CIBP BP Exploration (Alaska) ~S~' STATE OF ALASKA ~ ~' ~ ~ ~a~7 /~ ~~~`? ALAS A OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL 0~-1~Ai~ID~ns. Corrunission 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other 0 PATCH TUBING - Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program [] Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 200-1750 - 3. Address: P,O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-22411-01-00 7. KB Elevation (ft): 9. Well Name and Number: 58.7 KB ~ PBU E-31 A ' 8. Property Designation: 10. Field/Pool(s): ADLO-028304 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 15572 ' feet Plugs (measured) 12510 14190 true vertical 8797.72 ~ feet Junk (measured) None Effective Depth measured 12510 feet true vertical 8848 feet ~t~ ~iy~~,,~yyr (~C'", ~~~ ~ 200? l~ ib~~ ~~6~ ~ Casing Length Size MD TVD Burst Collapse Conductor 80 20"91.5# H-40 28 - 108 28 - 108 1490 470 Production 10638 9-5/8" 47# L-80 26 - 10664 26 - 8349.13 6870 4760 Liner 22 7" 26# L-80 11146 - 11168 8541.52 - 8549.96 7240 5410 Liner 4404 4-1/2" 12.6# L-80 11168 - 15572 8549.96 - 8797.72 8430 7500 Surface 3892 13-3/8" 68# L-80 27 - 3919 27 - 3533 4930 2270 Liner 886 7"26# NT-80 10446 - 11331 8524 - 8613 5410 7240 Perforation depth: Measured depth: O 12050 - 12100 O 12190 - 12400 C 12660 - 12860 C 12910 - 13150 C 13220 - 13560 C 14350- 14530 C 15010 - 15360 True Vertical depth: 8843 - 8848 8850 - 8850 8849 - 8849 8849 - 8846 8846 - 8847 8791 - 8780 8776 - 8791 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 24 - 11158 0 0 - Packers and SSSV (type and measured depth) 4-1/2" Baker S-3 Perm Packer 11103 7"X4-1/2" ZXP LNR TOP PACKER 11160 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~w r~ nn 't- ~~~_ ()('" ~ ~ ~~U~ti~~~ 1. ~Ctc ACS ~c ' W `" 1 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 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: NIA Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature ,, . ~ Phone 564-4944 /,~L~ ~~~ Date 10/12!2007 UKIVIIVf~L • E-31A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY -- ---- ------ - ACTIVITYDATE'~ SUMMARY 10/10/2007 "'"`WELL SHUT-IN ON ARRIVAL"*" INITIAL T/I/O: 250/150/75. SET BAKER "KB" PATCH FROM 7551' - 7581' TO COVER LEAK AT 7569'. PATCH DIMENSIONS: 30' ELEMENT TO ELEMENT, MIN ID = 2.45". "`**JOB INCOMPLETE. CONTINUED ON 11-OCT-2007 AWGRS*'* 10/10/2007 "*"CONTINUED FROM PREVIOUS DAY"' INITIAL T/I/O: 2501150175. SET BAKER "KB" PATCH AT 7551 - 7581" TO COVER LEAK AT 7569'. PATCH DIMEN t NS: 30' ELEMENT TO ELEMENT, MIN ID = 2.45". POSITIVE INDICATION OF PATCH SET SEEN ON SURFACE. WELL LEFT SHUT IN. FINAL T/ I/ O = 300/ 150/ 80 `*"JOB COMPLETE**" 10!11/2007 T/I/0= 260/170/40. Temp= SI. Bleed IAP to CLP, IA FL, pre-MIT-IA (restore tbg integrity). No AIL line on well. IA FL C 246' (13 bbls). FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE I""' STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSIOt--J" REPORT OF SUNDRY WELL OPERATIØN~'7 2004 ~ 1. Operations Performed: . ~!f!I<a Oil & Gig C~. Comm\~s!O!1 Abandon 0 RepairWeliD PluQ PerforationslK) Stlmula . ~her Alter CasingD Pull TubingO Perforate New Pool 0 ~% ",'!:{'r :., ,r. WaiverD Time E'&enS¡o',,[j' Change Approved Program D Operation Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 200-1750 Development 00 ExploratoryD 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-22411-01-00 7. KB Elevation (ft): 9. Well Name and Number: 58.70 E-31A 8. Property Designation: 10. Field/Pool{s): ADL-o028304 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 15572 feet true vertical 8797.7 feet Plugs (measured) 12510,14190 Effective Depth measured 12510 feet Junk (measured) None true vertical 8848.2 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 28 - 108 28.0 - 108.0 1490 470 Liner 885 7" 26# NT-80 10446 - 11331 8253.9 - 8612.7 5410 7240 Liner 22 7" 26# LoSO 11146 - 11168 8541.5 - 8550.0 7240 5410 Liner 4404 4-1/2" 12.6# LoSO 11168 15572 8550.0 - 8797.7 8430 7500 Production 10638 9-5/8" 47# LoSO 26 10664 26.0 - 8349.1 6870 4760 Surface 3892 13-3/8" 68# L-80 27 3919 27.0 - 3532.5 4930 2270 Perforation deDth: Measured depth: 12050 - 12100, 12190 - 12400 True vertical depth: 8843.01 - 8847.97, 8849.81 - 8849.2 Tubing ( size, grade, and measured depth): 4-112" 12.6# LoSO @ 24 - 11158 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer @ 11103 4-1/2" Baker ZXP Packer @ 11153 . 12. Stimulation or cement squeeze summary: 0'7 ,~~k Intervals treated (measured): -- BfL Jut Treatment descriptions including volumes used and final pressure: 13 ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Me! Water-Bbl Casing Pressure TubinQ Pressure Prior to well operation: 1125 46.8 2 1200 1516 Subsequent to operation: 3121 5.4 3 1220 768 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development[! ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Oil 00 GasD WAGD GINJD WINJD WDSPLD Daily Report of Well Operations - X Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or NIA if C.O. Exempt: Contact Garry Catron NIA Printed Name Garry Catron Title Production Technical Assistant Signature BI"-.4. (' .-h-:. - Phone 564-4657 Date 7/6/04 Form 10-404 Revised 4/2004 ,--..... ~ E-31 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/16/04 SET CIBP @ 12510' FLUIDS PUMPED BBLS 48 1 % KCL 85 50/50 Methonal 133 TOTAL Page 1 ,--..... ~ SAFElY NOTES: TREE = 4"5MCARBON WELLHE'AD = 13-3/8" 5M FMC ACnJA TOR = BAKER KB. B.BI = 58.7' BF. B.EV - 35.25' KOP= 11331' Max Anole = 97 @. 14024' Datum MD = N/A DatumlVD= 8800' 55 13-3/8" COO, 68#, L-80,ID = 12.415" Minimum ID = 3.725" @ 11148' 4-112" HES XN NIPPLE 10450' 9-5/8" COO, 47#, NSCc. ID = 8.681" 4-1/2"lBG, 12.6#, L-80 0.0152 bpf, ID= 3.958" PERFORATION SUMMð.RY REF LOG: SPERRY SlJ'.J MND ON 05/08102 ANGLEATTOPPERF: 84@ 12050' I\bte: Refer to A"oduetion DB for historical perf data SIZE SA"" INTERVAL Opn/Sqz DATE 2-718" 4 12050-12100 0 01/15/04 2-1/2" 4 12190 - 12400 0 OS/24/02 2-1/2" 4 12660 - 12B60 C OS/24/02 2-1/2" 4 12910-13150 C OS/24/02 2-1/2" 4 13220 - 13560 C OS/24/02 2-1/2" 4 14350 - 14530 C OS/24/02 2-112" 4 15010- 15360 C OS/24/02 7" LNR, 26#, NT-BO, .0383 bpf, ID = 6276" 12694' 4-1/2" SL TD LNR, 12.6#, .0152 bpf, ID = 3.958" 13393' E-31 A 2162' 4-1/2" HES X NIP, ID = 3.B13" ST MD TVD 5 3559 2790 4 6622 5192 38426 6606 2 9851 7724 1 1101B 8688 GAS LIFT Mð.NDRB.S ŒV TYPE VLV LATCH 21 MM3M DOME RK 39 MM3M SO RK 50 MM3M DMY RK 59 MM3M DMY RK 66 KBG-2 DMY BK PORT [)II. TE 16 06/07/02 20 06/07/02 05126/02 05126/02 05126/02 11083' 11103' 4-1/2"HESXNIP, ID= 3.B13" 11127' 11148' 11159' 11160' 7" X 4-1/Z' ZXP LNRTOP PKR,ID =4.4OB" 7"WlNDOW11331-11343 I 11322' HTOPOFWHIPSTOCK I 4-1/Z' WFRDCIBP (05/16/04) 4-1IZ' LNR, 12.6#, L-BO, ,0152 bpf, ID = 3.958" DATE REVBY COMMENTS [)II. TE RBI BY COMMENTS 12/11/93 MOO ORIG HORIZ COMPLETION 01/15/04 KCF/KK A DÆRF OS/28/02 DCRiKK RIG SIDETRACK 02,Q2/O4 CMOIlLP REF LOG/[)II.lUM MD'TVD 06/07/02 RUtih ÆRF& GLV UPDATE 05/16/04 SRBlKAK SETWFRDCIBP 11/16/02 GC/KAK GLM DEPTH CORRB::llON 05/13/03 JGfvVKK SET BKR CIBP 07/12/03 CMOITLP KB B.EV A liON CORRB::llON FRU[)- QE BA Y Ut\IT WB.L: E-31A F£RMITNo: 2001750 API No: 50-029-22411-01 SEC 6, T11 N, R14E. 6OB' FNL & 501' FEL BP Exploration (Alaska) ~l J~ DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 .s;1~ I vI ~ ).~ ^ Permit to Dri 2001750 Well Name/No. PRUDHOE BAY UNIT E-31A Operator BP EXPLORATION (ALASKA) INC API ~o. 50-029-22411-01-00 MD 15572 TVD 8798 ,. Completion Date 512712002 Completion Status i-Oil Current Status i-Oil UIC N - - REQUIRED INFORMATION Mud Log No Samples No Directional Survey No -".' - ,- DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint Well Log Information: Electr ) Digital Dataset Log Log Run Interval OHI MedlFrmt Number Name Scale Media No Start Stop CH Received Comments - - 25 Blu 1 12010 15424 Case 8/30/2002 C c..t't445 1 11310 15391 Case 11/29/2002 25 Blu 1 11320 15417 Case 11/29/2002 25 Blu 1 12010 15424 Case 5/1312003 D "'1"'1"504 1 11298 15540 Case 2/5/2003 D 1 11324 15572 Open 7/2/2002 1 11298 15540 Case 2/5/2003 25 Blu 1 11320 15417 Case 11/29/2002 CNT / PTS 25 Blu 1 11320 15417 Case 11/29/2002 1 11324 15572 Open 7/2/2002 1 11324 15572 Open 7/2/2002 MWD --".~ 25 Blu 1 12010 15424 Case 8/30/2002 ) - 25 Blu 1 12010 15424 Case 8/30/2002 D 1 11324 15572 Open 7/2/2002 MWD -~ 25 Blu 1 11320 15417 Case 11/29/2002 t.> u..p 1/ ~ ' , 25 Blu 1 12010 15424 Case 8/30/2002 /J '-Afl1/~4 D CAse 11993 1,2,4 11331 15572 Open 6/2/2003 ED C Pdf 11993 25 Final 11355 15572 Open 6/2/2003 MWD-ROP, DGR-MD ¡/ ED C Pdf 11993 25 Final 11355 8797 Open 6/2/2003 MWD-DGR-TVD ED C Pdf 11993 25 Final 11355 15572 Open 6/212003 MWD-DGR, CTN-MD ED C Pdf 1993 25 Final 11355 8797 Open 6/2/2003 MWD-DGR, CTN- TVD D las i.Ã1383 11717 2233 Case 1/29/2004 ) ) DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Dri 2001750 Well Name/No. PRUDHOE BAY UNIT E-31A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22411-01-00 MD 15572 rvD 8798 Completion Date 5/27/2002 Completion Status 1-01L Current Status 1-01L UIC N Well Cores/Samples Information Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORM@N G/N Well Cored? Y N Daily History Received? Chips Received? ~ Formation Tops 0N Analysis ..::t..J..N- Received? - Comments: - Compliance Reviewed By: Date: " ,-..... .~ -:~ ALASKA OIL AND ~:AST~g~S~L::A~ON COMMISSION F< t:(~E:; 'VE REPORT OF SUNDRY WELL OPERATION¡S.2 [) 20U ."-.... "- cr 1. Operations Performed: Abandon 0 Alter CasingD Change Approved programD 2. Operator SuspendD RepairWellD Pull TubingD Operation ShutdownD Plug PerforationsŒ Perforate New PoolD 4. Current Well Class: ¡'_ '.Mo:,. ~_ 'ð'. /'ì," ::. }i " .'1', t" Perforate 0 ,,<, '" 'waiv,e;g Stimulate 0 Time Exten5i~n(J Re-enter Suspended Well 0 5. Permit to Drill Number: 200-1750 Ô\h'èfÊ] Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Development Œ] ExploratoryD 58.70 8. Property Designation: ADL-0028304 11. Present Well Condition Summary: StratigraphicD ServiceD 9. Well Name and Number: E-31A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 6. API Number 50-029-22411-01-00 Total Depth measured 15572 feet true vertical 8797.7 feet Effective Depth measured 14190 feet true vertical 8801.2 feet Plugs (measured) Junk (measured) 14190 None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 28 108 28.0 - 108.0 1490 470 Liner 885 7" 26# NT-80 10446 - 11331 8253.9 - 8612.7 5410 7240 Liner 22 7" 26# L-80 11146 - 11168 8541.5 - 8550.0 7240 5410 Liner 4404 4-1/2" 12.6# L-80 11168 - 15572 8550.0 - 8797.7 8430 7500 Production 10638 9-5/8" 47# L-80 26 - 10664 26.0 - 8349.1 6870 4760 Surface 3892 13-3/8" 68# L-80 27 - 3919 27.0 - 3532.5 4930 2270 Perforation depth: Measured depth: 12190 -12400,12660 -12860,12910 -13150,13220 -13560 True vertical depth: 8849.81 - 8849.2,8849.09 - 8848.88,8848.51 - 8845.71, 8845.73 - 8847.25 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 24 11158 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer @ 11103 @ 11153 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubing Pressure 1343 1446 Prior to well operation: Subsequent to operation: 1176 980 49 46.3 29 22 1660 1600 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Contact Printed Name Garry Catron Garry Catron 16. Well Status after proposed work: Operational Shutdown 0 OilŒ] GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Copies of Logs and Surveys run _ Daily Report of Well Operations, X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Production Technical Assistant Signature c Phone 564-4657 Date Form 10-404 Revised 12/2003 ....ØfL 3/23/04 '-q. .~ ~ E·31A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/12/03 MIRU CTU # 9. Kill well with 2% KCL. Make 3.66in drift run to14250. No problems. POH. MU CIBP. Rekill well with KCL. 05/13/03 Set CIBP @ 14190' FLUIDS PUMPED BBLS 113 Methonal 75 2% KCL 480 Gallons N2 200 KCL 868 TOTAL Page 1 ~ ^ .-""".. . 1RÈE= WELLHEAD = AClUA TOR = KB. B..BI = BF. B..EV = KOP= MaxAn Ie = Datum WD = Datum lVD= 4"5MCARBON 13-3/8" 5M FWC BAKffi 58.7' 35.25' 11331' 14024' N/A 8800' SS E-31A SAÆTYNOTES: 2162' -14-1/2" HES X NIp, ID=3.813" I GAS LIFT Iv1ANI:RB..S ST MD TVD ŒV TYPE VLV LATCH PORT D<\1E 5 3559 2790 21 MMGM OOI'vE RK 16 06107/02 4 6622 5192 39 MMGM SO RK 20 06107102 Minimum ID = 3.725" @ 11148' 3 8426 6606 50 MMGM DMY RK 05126/02 2 9851 7724 59 MMGM DMY RK 05126102 4-112" HES XN NIPPLE 1 11018 8688 66 KBG-2 DMY BK 05126/02 13-3/8" CSG, 68#, L-80.ID = 12.415" 9-5/8" CSG. 47#, NSCC, ID= 8.681" 11083' - 4-1/2"HESXNIP.ID=3.813" I 11103' -I7"X4-1/2"BKRS-3PKR.ID=3,875" I 11127' - 4-112"HESXNIP.ID=3,813" I 11148' ~4-1/2"HESXNNP.ID=3.725" I 4-1/2" lBG. 12,6#. L-80 0.0152 bpf. ID - 3.958" PERFORATION SUMIv1A RY REF LOG: SPffiRY SU\ MND ON 05/06102 ANGLE A TTOP PffiF: 84 @ 12050' tlbte: Refer to A"oduction DB for historical perf data SIZE SA" INTffiVAL Opn/Sqz DATE 2-7/8" 4 12050-12100 0 01115/04 2-1/2" 4 12190-12400 0 OS/24102 2-1/2" 4 12660 - 12860 0 OS/24102 2-1/2" 4 12910 - 13150 0 OS/24/02 2-1/2" 4 13220 - 13560 0 OS/24/02 2-1/2" 4 14350 - 14530 C OS/24/02 2-1/2" 4 150 1 0 - 15360 C OS/24/02 -14-1/2" WLEG I - 7" X 4-112" ZXP LNRTOP PKR.ID =4.408" 7" WlNOOW 11331 - 11343 11322' HTOP OF WHIPSTOCK I -13.593" BKRCIBP(5I13/03) I 7" LNR, 26#. NT-80. .0383 bpf, ID = 6.276" 4-1/2" SL 10 LNR.12.6#. .0152 bpf.ID= 3.958" 13393' 4-1/2" LI\R, 12.6#. L-80. .0152 bpf. ID= 3.958" DATE 12/11/93 OS/28/02 06/07/02 11/16/02 05/13/03 07/12/03 REV BY COMI'vENrS M DO ORIG HORIZ COMPLETION DCRlKK RIG SIDETRACK RUtlh ÆRF & GL V UFÐA TE GC/KAK GLM DEPfH CORREC1l0N JGM'KK SETBKRCIBP Qv10/TLP KB B..EV A 1l0N CORREC1l0N D<\ TE RBI BY COMMENTS 01/15104 KCF/KK ADÆRF 02102/04 Ctv10llLP REF LOOID<\ lUM MD'TVD FRUa-JOE BA Y Ut\DT WB..L: E-31A ÆRI'v1rr No: 2001750 API No: 50-029-22411-01 -. ·SEC6. ï11N. R14E. 608'FNL& 501'FEL 8P Exploration (Alaska) ___ _ _____________ __________~CANNEDJULJ 9 Înn4 - ..-, ".. --' -' '. "....., STATE OF AlASKA~ F< ALASKA Oil AND GAS CONSERVATION COMMISSION \AAR!2 F; 7nn REPORT OF SUNDRY WELL OPERATIO'NS U"" ~ ~ ~ ' 1. Operations Performed: -cc ,; " Abandon 0 Suspend 0 Operation Shutdown D Perforate ŒI WaivEir B< OtherD Alter Casing 0 Repair Well 0 Plug PerforationsD Stimulate 0 Time ExtensionD Change Approved Program D Pull TubingD Perforate New Pool 0 Re-enter Suspended WellO 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 200-1750 Development Œ] ExploratoryD 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-22411-01-00 7. KB Elevation (ft): 9. Well Name and Number: 58.70 E-31A 8. Property Designation: 10. Field/Pool(s): ADL-0028304 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 15572 feet true vertical 8797.7 feet Plugs (measured) 14190 Effective Depth measured 14190 feet Junk (measured) None true vertical 8801.2 feet Casing Length Size MD TVD Bùrst Collapse Conductor 80 20" 91.5# H-40 28 - 108 28.0 - 108.0 1490 470 Liner 885 7" 26# NT-80 10446 - 11331 8253.9 - 8612.7 5410 7240 Liner 22 7" 26# L-80 11146 - 11168 8541.5 - 8550.0 7240 5410 Liner 4404 4-1/2" 12.6# L-80 11168 - 15572 8550.0 - 8797.7 8430 7500 Production 10638 9-5/8" 47# L-80 26 - 10664 26.0 - 8349.1 6870 4760 Surface 3892 13-3/8" 68# L-80 27 - 3919 27.0 - 3532.5 4930 2270 Perforation depth: Measured depth: 12050 - 12100, 12190 -12400,12660 -12860,12910 -13150,13220 -13560 True vertical depth: 8843.01 - 8847.97, 8849.81 - 8849.2,8849.09 - 8848.88,8848.51 - 8845.71,8845.73 - 8847.25 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 24 - 11158 Packers & SSSV (type & measured depth): 4-1/2" Baker 5-3 Perm Packer @ 11103 4-1/2" Baker ZXP Packer @ 11153 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil·Bbl Gas-Mcf Water-Bbl Casinq Pressure Tubing Pressure Prior to well operation: 873 49.8 27 1300 1327 Subsequent to operation: 3078 28.5 75 1275 1357 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ Service 0 Copies of Logs and Surveys run _ 16. Well Status after proposed work: Operational Shutdown 0 Oil 00 GasD WAGD GINJD WINJD WDSPLD Daily Report of Well Operations, X Prepared by Garry Catron (907) 564-4657. 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: Contact Garry Catron N/A Printed Name Garry Catron Title Production Technical Assistant Signature .13,,, "'A~..If C.~ .h-:::. __ _ I " I ... rh~nel 564-4657 Date 3/23/04 A WlSv. Form 10-404 Revised 12/2003 UK\\.J\\'JJ-\L ....Bfl , ".-., ~ .~-." .,-,'::! E-31A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 01/08/04 DRIFT TUBING WI 27/8" DUMMY GUN I TEL I SB TO 11980' SLM, STOPPED DUE TO DEVIATION (S. BAILER EMPTY) 01/14/04 CTU #8: PERFORM WEEKLY BOP TEST. MU PDS MEMORY LOGGING STRING W/3" OD JSN. KNOCK DOWN WHP AND RIH TO 1382'. HAVING TROUBLE WIPACK OFFS HOLDING. POOH REPLACE PACKOFFS AND RIH TO 12200' CTMD. LOG UP TO 11000' (JEWELRY LOG), FLAGGED PIPE AT 12075' CTMD. POOH ***CONTINUED ON 1/15/04 WSR*** 01/15/04 Perforate 12050'-12100' 4 SPF FLUIDS PUMPED BBLS 238 60/40 Methonal 340 1 % KCL 578 TOTAL ., Page 1 SCANNED JUL 1 9 2004 .~ ids C!\ 1< WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7"'Street Suite # 700 Anchorage, Alaska 99501 RE: Distribution - Final Print(s) ~ 8CO-- l 1-0 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1389 Stafford, TX 77497 WELL loG TyPE DATE Open Hole Res. Eva!. CH E-31 A 1-14-2004 Mech. CH Caliper Survey Signed: ~~'--~ ~,_Cì ~ Ä~~ Print Name: DIGITAL OR CD-ROM 1 BP Exploration (Alaska). Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) 1 1 1 1 1 J d-30'--~ Date: RECEIV(D Ji~N 2 9 2004 AJaska Oil & Gas Cons. CornmiI1ton Anchorage Phone:(281) 565-9085 Fax:(281) 565-1369 PRoACTivE DiAGNOSTic SERVicES, INC., PO Box 1 }69 STAffoRd TX 77477 Website: www,memo"" . E-mail: pds@memOIylog.com ~~~f\'" ~b REPORT OR CoLOR .~ ~ dCG~- } IS 1l993 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 ~chorage,Alaska 99501 May 20, 2003 RE: MWD Formation Evaluation Logs: E-31A, AK-MW-22075 E-31A: Digital Log Images 50-029-22411-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ~ehorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-l 900 E. Benson Blvd. ~ehorage, Alaska 99508 Date: Signed~ \. \-~ i't~~~ RECEIVED JUN 0 2 2003 AJa:;ka ¿~ G~iS CDmm¡~k.'fI ß,i\tl1""';'i'n . ~'~';"""'U'-' 'K't:, ~ YV\ ~ ¿ Scblumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well . E-02A Î1 í-/:J Î r øtU (lAd E-31A :J.,rn-I í 5 \J"~' M-29Ar~t)Q-Oq'1 F-04A d. Œ- rOO H-21 I ?' fLy-a] D.S.1-32A I ~ (¡,~ I J 0.5. 5-06A 1 r.¡~ f 0.5. 7-29B ò,cB-':;¡S<1 D.S. 15-38A àð3-0 I~ 0.5. 15-48AdD~~OO '3 Job# Log Description Date MEMORY PROD PROFILE MEMORY PROD PROFILE PDC & TEMPERATURE 23097 MCNL 23074 RST-SIGMA 23083 MCNUBORAX 23056 RST-SIGMA 23096 MCNL 23089 LINER TOP TIE-IN MGRlCCL 23098 MCNL 03/15/03 08/08/02 04/15/03 03/02/03 01/30/03 02/02103 01/23/03 02/15/03 02/10103 02/19/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd, Anchorage, Alaska 99508 Date Delivered: R' ÇC- r- !\ 11= 0 . ;¡...... t:~!J J- MAY 1 3 2.00~ Ala~a a¡ & Gas Cons. Ccmm_n And1~ Blueline NO. 2772 Company: 05/08/03 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Reœ;'~ ) ) & (kp-J <- Schlumbepgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well E-02A I '1'1 ... í ~2 E-31A . ~~ð-Jjj; "1 M-29A ,;¡.~- ð F-04A d:-'2- ~ J H-21 t ~fL..'. ï I D.S. 1-32A:10 ~ - i g'J; D.S. 5-06A I ~s -a. m D.S.7-29B I - ~7. D.S.15-38A , ~ . \iJlf D.S. 15-48A I <t5"--- :)ðJ5 Job# Log Description MEMORY PROD PROFILE MEMORY PROD PROFILE PDC & TEMPERATURE 23097 MCNL 23074 RST-SIGMA 23083 MCNUBORAX 23056 RST-SIGMA 23096 MCNL 23089 LINER TOP TIE-IN MGRlCCL 23098 MCNL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~......,.!f"""('""J. ..'~.' ~. \¡~.-'D' . K~=V~ã'~ :C r..~ !\ V 1 -; "nO3 IVI!-\ t v Lv , i~ii35ka CU & Gas Cc~ìS. C{)rnm~4Iion AJichcmge Date 03/15/03 08/08/02 04/15/03 03/02103 01/30/03 02/02103 01/23/03 02115103 02/10/03 02/19/03 Blueline 05/08/03 NO. 2772 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints ) CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ) Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 :=,,~~ :a-.., ,.-."" aoo-/75 1150<-/ WELL LOG TRANSMTITAL To: State of Alaska Alaska Oil and Gas Conservation Comm, Attn. : Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska February 04, 2003 RE: MWD Formation Evaluation Logs E-31A, AK-MW-22075 1 LDWG formatted Disc with verification listing. API#: 50-029-22411-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LEITER TO THE AITENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: s&- ¿~ RECEIVED FEB 05 2003 AIa8ka Oit &. Gøs Cons. Commiseion Andmge Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage,AK 99503-5711 ATTN: Beth Well J-10B ~Q.~.~, MPI-02 ( I.fO-Oq¡ 0.5.1-12 I ~ï-ð.5R' H-23A 540RS 0.5.11-33 I 4-0'10 H-08 ~7 7~oa. ~ E-31A ~{)~J it:) H-20 I Ö...OO"1 N-15 I -079 C-31A ~5 ~oo(P ~~~1/~~~~7 A I W. -g~ NO. 2567 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date Blueline Sepia Prints 10/25/02 i 2 10/16/02 ! 2 09/02/02 1 10/12/02 1 09/13/02 1 10115102 1 08/08/02 1 10/09102 1 11/13/02 1 07113102 1 08122/02 11/02/02 Job# Log Description 22494 US IT 22495 US IT 22460 R5T 22488 MCNL 22441 R5T 22479 RST 22409 MCNL 22478 R5T 22507 RST 22335 MCNL 22418 PERF/JEWELRY (PDC) 22504 RST PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: CD 1 1 1 1 1 1 1 1 1 1 RECEiVED Schlumberger GeoOuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Belil NOV 29 2002 R",;,,' ~ ~f'" J Alaska ¡,);~ & Gas COliS. Commission Anchorage 11/26/02 ) ) ( ( Scblun1~epgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well W-20 J )('zf- 0 Y fø E-31A a....OO-/7 c:; N-11B J'tq-Io~ PSI-06 . ~g. .. ~.àoa.-/I.Ir;;; BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: NO. 2365 Company: 08/28/02 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Job# Color Date Blueline Sepia Prints 08/12/02 1 08/08/02 1 08106102 1 08/21/02 1 Log Description 22388 RST-SIGMA MPROD PROFILE MPROD PROFILE SBHP SURVEY RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Received ~ AUG Rð 2002 Alaska 011 & Gas Cons. Commission Anch0l896 CD ~.j 6 , . .~ ~, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 08/08/02, KBE, Loc. & TVO's I 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. L::~~~~,f ~~I! ~~~~~~~. 06, T11 N, R14E, UM J,.,' C~'~~~:':l ~ì~~ At top of productive interval ~ 7 "r 1" \""'~'~: '~~'EWL,SEC.08,T11N,R'4E,UM i.:_~~ .~ 10. WeUNumber 3352' SNL, 5139' EWL, SEC. 08, T11N, R14E, UM ~"A"':::;~ 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 58.7' ADL 028304 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 116. No. of Completions 5/14/2002 5/21/2002 5/27/2002 N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set I 21. Thickness of Permafrost 15572 8798 FT 15485 8796 FT II Yes 0 No (Nipple) 2163' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, ABI, NEU, DEN 23. CASING SIZE 20" 13-3/8" 9-5/8" 7" WT. PER FT. 91.56# 68# 47# 26# 12.6# GRADE H-40 L-80 L-80 L-80 L-80 4-1/2" Classification of Service Well 7. Permit Number 200-175 8. API Number 50-029-22411-01 9. Unit or Lease Name Prudhoe Bay Unit E-31 A CASING, liNER AND CEMENTING RECORD SETTING DEPTH HOLE Top BoTTOM SIZE CEMENTING RECORD 32' 110' 30" ¡280 cu ft Arcticset (Approx.) 36' 3918' 16" ¡2909 cu ft Permafrost, 432 cu ft 'G' 32' 10670' 12-1/4" 1900 cu ft Class 'G' 10450' 11331' 8-1/2" 480 cu ft Class 'G' 11146' 15572' 6-1/8" 612cuftClass'G' 25. SIZE 4-1/2", 12.6#, L-80 MD TVD 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 4 spf MD TVD 12190' - 12400' 8850' - 8849' 12660' - 12860' 8849' - 8849' 12910' - 13150' 8848' - 8846' 13220' - 13560' 8846' - 8847' 14350' - 14530' 8791'- 8791' 15010' - 15360' 8776' - 8791' AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 11161' PACKER SET (MD) 11104' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 152 Bbls of Diesel 27. Date First Production June 14, 2002 Date of Test Hours Tested 7/5/2002 4 Flow Tubing Casing Pressure Press. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR TEST PERIOD CALCULATED 24-HoUR RATE OIL-BBl 1,557 OIL-Bel WATER-BBl 24 WATER-BBL CHOKE SIZE I GAS-Oil RATIO 59.6° 27,178 Oil GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology. porosity, fractures. apparent dips and presence of oil, gas or water. Submit core chips. r'< No core samples were taken. Form 10-407 Rev. 07-01.80 GAs-McF 42,308 GAs-McF ED p\UG 0 ~ 2002 Alaska OJ! & Gas Cons. Gommissiof! Anchorac!f' U R , G I ~J j~ L R B D M S B F l ßHG I 9 200Submit In Duplicate (j ç , ,,~ ~ .1 29. Marker Name Geologic Marker& Measured Depth 30. Formation Tests True Vertical Depth Include interval tested. pressure data. all fluids recovered and gravity, GOR, and time of each phase. 25P 11443' 8654' 24P 11518' 8681' 22P 11673' 8735' 21P 11791' 8774' Zone 18 11880' 8804' Zone 1A 11979' 8831' Zone 1A 13960' 8822' r' r r. , \.,.l ;.' *~ ... \¥' L "" t. " ro, C' <¡OD'? 1 \ 'J' , ¡ !I ./' L ", AtaS\Œ on 8: \Jas (;üns. Comm\S5\O\ Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ tÍÁAiR J ~ R;{ieJ Title Technical Assistant E-31A 200-175 Well Number Permit No. I Approval No. Date 08-6f3'" () ~ Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection. air injection. salt water disposal, water supply tor injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. IrEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB. etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07.01.80 ~~/18/200~~:31 FAX 907 564~0 bp ~ ~.- ~ I4J 002 STATE OF ALASKA ALASKA OIL AND 'GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well II Oil [J Gas 0 Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-175 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22411-01 4. Location of well at surface I" ~';J,';';'r*.~i ,",: '\l:,,"\i~~; 9. Unit or Lease Name 608' SNl, 501' WEl, SEC. 06, T11N, R14E, UM ; 1~...,.;I'¡{i. -----', "1, Prudhoe Bay Unit At top of productive interval; r I ~ /)"2£'~ ~ ¡ 1788' SNL, 2352' EWL, SEC. 08 ~. R14E, UM '~~.?'J!, 10. Well Number ~~~~36' EWL. SEC,a T11N. R14E. UM i ~~I ,." f,~ E-31A .. " '; ., - ~-,. ¡¡ ":""",, 11. Field and Pool 5. Elevation In feet (indicate KB, DF, etc.) ~6' Lease DeSIgnation an Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 60.2' ADL 028304 12. Date Spudded 113. Date T.D. Reached 14. Date Comp., Susp.. or Aband. 115. Water depth, if offshore 116. No. of Completions 5/14/2002 5/21/2002 512712002 N/A MSL One 17. Total Depth (MD+ lVD) 118. Plug Back Depth (MD+ TVD) 119. Directional Survey 120. Depth where SSSV setl21. Thickness of Permafrost 15572 8801 FT 15485 8799 FT II Yes [J No (Nipple) 2163' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, ABI, NEU, DEN 23. CASING SIZE 20" 13-318" 9-5/8" 7" 4-1/2" Revised: 07/18/02 Classification of Service Well 'NT. PER FT. 91.56# 68# 47# 26# 12.6# GRADE H-40 L-80 L-SO L-80 L-80 CASING. liNER AND QoMENTING RECORD - SETTING DEPTH HoLE Top Bo".OM SIZE CEMENTING RECORD 32' 110' 30. ,280 cu ft Arcticset (Approx.) 36' 39181 16" ~909 cu ft Permafrost, 432 cu ft 'G' 32' 10610' 12-1/4" 1900cuftClass'G' 10450' 11331' 8-1/2" 480 cu ft Class 'G' 11146' 15572' 6.1/8" 612 cu ft Class 'G' AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 4 spf MD TVD 12190' - 12400' 8853' - 8853' 12660'.12860' 8853' - 8852' 12910'.13150' 8852'.8849' 13220(.13560' 8849'.8851' 14350'.14530' 8795' - 8784' 15010' -15360' 8780' - 8795' 25. SIZE 4-1/2". 12.6#. L-BO TUBING RECORD DEPTH SET (MD) 11161' PACKER SET (MD) 11104' MD TVD 26. ACID, FRACTURE. CEMENT SQUEEZE. ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 152 Bbls of Diesel 27. Date First Production June 14, 2002 Date of Test Hours Tested 7/5/2002 4 Flow Tubing Casing Pressure Press. PRODUCTION TEST Method of Operation (FloWing, gas 11ft. etc.) FloWing PRODUCTION FoR TEST PERIOD CALCULATED 24-HOUR RATE OIL-BeL 1,557 OIL-BeL GAS-McF 42,308 GA$-MCF WATER-BBL 24 WATER-BBL CHOKE SIZE GAS-DIL RATIO 59.6° 27,178 OIL GRAVITY-API (CORR) 28. CoRE DATA Brief description of lithology, porosity, fractures. apparent dips and presence of oil, gas or water. SUbmit core chips. No core samrlles were taken. Form 10-407 Rev. 07-01-80 Submit In Duplicate QBOMS 8FL JUL I 8 2002 _~/18/2002 13: 32 FAX 907 564~0 ! ",,' , bp ~ I@ 003 29. Marl<er Name Geologic Markers Measured Depth' 30. Formation Tests Include Interval tested, pressure data, all fluids recovered and gravity, GaR, and time of each phase. True Vertical Depth 25P 11443' 8657' 24P 11518' , 86841 22P 11673' 8738' 21P 11791' 8718' Zone 18 11880' 8808' Zone 1A 11979' 8635' ZOne 1A 13960' 8825' 31, List of Atta(:hments: Summary of Daily Drilling Reports, Surveys 32. I hereby (:ertify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~. ~ Title Technical Assistant E-31 A 200-175 Well Number Permit No.1 Approval No. Date 07"/PyO~ Prepared By NamelNumber: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form Is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1; Classification of Service Wells: Gas Injection, water injection, steam injection, air Injection, salt water disposal, water supply for injection, observation. injection for in-situ combustion. ITeM 5: Indicatl3 which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this wallis completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported In item 27. Submit a separate fOrm fOr each additional interval to be separately produced. showing the data pertinent to such interval. ' ITEM 21; Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing toot. . ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible. Water Injection, Gas Injection. Shut.ln, Other-explain. ITeM 28: If no ()Ores taken, Indicate 'none'. Form 10-407 Rev. 07-01-80 ~ ...... ...... ('1)('1) I I LULU Qj E .. ro ( ) z E ro c: Z 0 - E ro E 0>0 .30 Õ) a. ð a a 0 ~ Iii ð co ~ '<t ~ ~ Iii .e, ~ ~ Õ) a. .e, a '<t ex:> g a a N CD- co g ~ ~ ('"") ('"") ~ ~ I- ü: N a a ~ ('"") ~ 10 ~ ~ :õ « ~ ~ ;: '" a a ~ ~ "' ;; Q) ë it ! ¡--.. .~ " Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-31 E-31 REENTER+COMPLETE NABORS NABORS 2ES Start: 5/5/2002 Rig Release: 5/27/2002 Rig Number: Spud Date: 5/12/2002 End: . 5/512002 03:00 - 07:30 4.50 RIGU P PRE RIG DOWN FLOOR. BLOW DOWN STEAM AND WATER LINES. BRIDLE UP. RIG DOWN PITS AND MOVE OFF WELL P1-18A 07:30 - 08:30 1.00 RIGU P PRE WAIT ON SECURITY TO MOVE RIG. INSUFFICIENT SECURITY PERSONNEL AVAILABLE DUE TO OTHER RIG MOVES AND FIELD ACTIVITY. 08:30 - 15:00 6.50 RIGU P PRE MOVE RIG TO E-31A. 15:00 -18:30 3.50 RIGU P PRE SPOT RIG, PITS, CAMP AND SHOP. 18:30 - 00:00 5.50 RIGU P PRE RAISE DERRICK. RIG UP FLOOR AND PITS. TAKE ON SEA WATER. SET CUTTINGS BOX. 5/6/2002 00:00 - 02:00 2.00 RIGU P PRE RIG UP TOP DRIVE. REMOVE BRIDLE LINES FROM BLOCKS. TAKE ON SEA WATER. ACCEPT RIG AT 02:00 HRS 5/6/02 02:00 - 03:30 1.50 RIGU P PRE PULL BACK PRESSURE VALVE WITH DRILL SITE MAINTAINENCE LUBRICATOR. 0 PSI ON TUBING AND ANNULUS. 03:30 - 04:30 1.00 RIGU P PRE INSTALL SECOND VALVE ON ANNULUS. RIG UP LINES TO CIRCULATE. TEST LINES TO 3000 PSI. 04:30 - 05:00 0.50 RIGU P PRE PRESPUD MEETING WITH CREW. 05:00 - 09:00 4.00 RIGU P PRE DISPLACE WEll WITH SEA WATER AND RECOVER 250 BBl FREEZE PROTECT. PUMP 30 BBl BARACLEAN SWEEP. 09:00 - 10:00 1.00 RIGU P PRE INSTALL TWO WAY CHECK. RIG UP LINES AND TEST FROM BELOW TO 1000 PSI. OK. 10:00 - 12:00 2.00 WHSUR P DECOMP NIPPLE DOWN TREE. 12:00 - 18:30 6.50 BOPSURP DECOMP NIPPLE UP BOP. TEST BOP AND RELATED VALVES TO 250 PSI LOW AND 3500 PSI HIGH. NOTE: TEST WITNESS WAIVED BY CHUCK SHEEVE OF AOGCC 18:30 - 20:00 1.50 BOPSURP DECOMP PULL TWO WAY CHECK VALVE WITH LUBRICATOR. 20:00 - 21 :00 1.00 WHSUR P DECOMP BACK OUT LOCK DOWN SCREWS. PULL TUBING HANGER TO RIG FLOOR. PIPE PULLED TO 10,000 OVER STRING WEIGHT AND CAME FREE. MONITOR WELL, STATIC. 21 :00 - 22:00 1.00 PULL P DECOMP RIG UP 3 1/2" TUBING EQUIPMENT. RIG UP CONTROL LINE SPOOLER. 22:00 - 00:00 2.00 PULL P DECOMP POH AND LAY DOWN 3 1/2" 9.2# NSCT TUBING. PIN END THREADS CORRODED THROUGHOUT STRING. 5/7/2002 00:00 - 01 :00 1.00 PULL P DECOMP POH AND LAY DOWN 31/2" 9.2# NSCT TUBING TO 6630'. PIN END THREADS CORRODED THROUGHOUT STRING. 01:00 - 01:30 0.50 PULL P DECOMP RIG DOWN CONTROL LINE SPOOLER. 01 :30 - 07:00 5.50 PULL P DECOMP POH AND LAY DOWN 3 1/2" 9.2# NSCT TUBING TO SURFACE. RECOVERED 268 JTS. PIN END THREADS CORRODED THROUGHOUT STRING. 07:00 - 08:00 1.00 PULL P DECOMP RIG DOWN TUBING HANDLING EQUIPMENT. 08:00 - 09:00 1.00 PULL P DECOMP TEST LOWER BOP PIPE RAMS TO 250 PSI LOW, 3500 PSI HIGH. 09:00 - 10:00 1.00 PULL P DECOMP SLIP AND CUT DRILLING LINE 118'. 10:00 - 10:30 0.50 PULL P DECOMP SERVICE TOP DRIVE. 10:30 -11:00 0.50 PULL P DECOMP INSTALL WEAR BUSHING. 11:00-17:30 6.50 PULL P DECOMP RIH WITH FISHING BHA. GUIDE, HOLLOW MILL CONTAINER, OVERSHOT AND BUMPER SUB. PICK UP 5" DRILL PIPE TO 7715'. Printed: 5/28/2002 11 :21 :09 AM r-\ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-31 E-31 REENTER+COMPLETE NABORS NABORS 2ES Start: 5/5/2002 Rig Release: 5/27/2002 Rig Number: Spud Date: 5/12/2002 End: 5/712002 17:30 -18:00 0.50 PULL P DECOMP TEST CASING TO 3000 PSI. OK. 18:00 - 19:30 1.50 PULL P DECOMP RIH WITH FISHING BHA. PICK UP 5" DRILL PIPE TO TOP OF FISH AT 5889'. 19:30-21:00 1.50 PULL P DECOMP MILL TOP OF FISH. ENGAGE FISH AND APPLY 25K OVERPULL. 21 :00 - 22:00 1.00 PULL P DECOMP PJSM WITH RIG CREW AND SCHLUMBERGER E-LiNE CREW. RIG UP E-LiNE TOOLS. 22:00 - 23:30 1.50 PULL P DECOMP RUN IN WITH SCHLUMBERGER 2.68" JET CUTTER. HELD UP AT TOP OF FISH AT 8589'. UNABLE TO PASS AFTER SEVERAL ATTEMPTS. POH JET CUTTER. 23:30 - 00:00 0.50 PULL P DECOMP RIG DOWN SCHLUMBERGER E-LiNE AND TOOLS. 5/8/2002 00:00 - 00:30 0.50 PULL P DECOMP RIG DOWN SCHLUMBERGER E-LiNE AND TOOLS. 00:30 - 01 :30 1.00 FISH P DECOMP WORK LEFT HAND TORQUE INTO STRING AND PEFORM BLIND BACK OFF IN 3 1/2" TUBING. 01 :30 - 05:00 3.50 FISH P DECOMP POH WITH OVERSHOT. 05:00 - 05:30 0.50 FISH P DECOMP RIG UP TUBING HANDLING EQUIPMENT. 05:30 - 07:00 1.50 FISH P DECOMP POH. LAY DOWN 106.17' OF 31/2" FISH (3 JTS AND CUT OFF) AND OVERSHOT. 07:00 - 08:00 1.00 FISH P DECOMP RIG DOWN TUBING HANDLING EQUIPMENT. 08:00 - 11 :30 3.50 FISH P DECOMP MAKE UP OVERSHOT AND RIH TO 8690'. 11:30-12:00 0.50 FISH P DECOMP SPOT LUBE PILL IN DRILL PIPE 12:00 - 12:30 0.50 FISH P DECOMP WORK OVERSHOT OVER FISH AND ENGAGE SAME AT 8695'. 12:30 - 13:30 1.00 FISH P DECOMP PJSM WITH RIG AND SCHLUMBERGER CREWS. RIG UP SCHLUMBERGER E-LiNE TOOLS. 13:30 - 17:00 3.50 FISH P DECOMP RUN SCHLUMBERGER 2.68" JET CUTTER. WORK E-LiNE TOOLS TO 11537'. CUT 31/2" TUBING AT 11513'. POH WITH E-LiNE. 17:00 - 19:00 2.00 FISH P DECOMP WORK PIPE. ATTEMPT TO FREE TUBING. MAX PULL 335K. PIPED MOVED UP l' AND STOPPED. NO CIRCULATION. PIPE STUCK. 19:00 -19:30 0.50 FISH P DECOMP SERVICE TOP DRIVE 19:30 - 20:30 1.00 FISH P DECOMP SLIP AND CUT DRILLING LINE. 20:30 - 23:00 2.50 FISH N WAIT DECOMP WAIT ON SCHLUMBERGER FREE POINT INDICATOR TOOLS AND SIDE ENTRY SUB. 23:00 - 00:00 1.00 FISH DECOMP RIG UP FREE POINT INDICATOR TOOL AND SIDE ENTRY SUB. 5/9/2002 00:00 - 03:00 3.00 FISH P DECOMP RUN SCHLUMBERGER FREE POINT INDICATOR. CHECK TOOL FUNCTION AT 2000'. RIH TO 11500'. TOOL FAILED. POH AND CHANGE OUT TOOLS. 03:00 - 07:00 4.00 FISH P DECOMP RIH WITH FREE POINT INDICATOR TO 11500'. SEVERAL READINGS FROM 11500' TO 11050'. PIPE STUCK AT 11495'. AT 11450' 84% STRETCH, AT 11050' 90% STRETCH. POH. LAY DOWN TOOLS. 07:00 - 07:30 0.50 FISH P DECOMP PJSM WITH RIG AND SCHLUMBERGER CREWS ON HANDLING OF JET CUTTER. 07:30 - 10:00 2.50 FISH P DECOMP RIH WITH 2.68" JET CUTTER. CUT 31/2" TUBING AT 11450'. POHAND LAY DOWN TOOLS. JET CUTTER FIRED. 10:00 - 12:00 2.00 FISH P DECOMP WORK PIPE UP TO 80% OF YIELD. CIRCULATE AT 336 GPM WITH 2500 PSI. NO PIPE MOVEMENT. 12:00 - 15:00 3.00 FISH P DECOMP PJSM WITH ALL HANDS ON HANDLING OF JET CUTTER. RIH WITH 2.68" JET CUTTER. CUT 31/2" TUBING AT Printed: 5/28/2002 11 :21 :09 AM ~, ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-31 E-31 REENTER+COMPLETE NABORS NABORS 2ES Start: 5/5/2002 Rig Release: 5/27/2002 Rig Number: Spud Date: 5/12/2002 End: 5/912002 12:00 - 15:00 3.00 FISH P DECOMP 11355'. POHANDLAYDOWNTOOLS. CUTTER FIRED. 15:00 - 16:30 1.50 FISH P DECOMP WORK PIPE UP TO 80% OF YIELD. CIRCULATE AT 336 GPM WITH 540 PSI. NO PIPE MOVEMENT. 16:30 - 17:30 1.00 FISH N WAIT DECOMP WAIT ON SCHLUMBERGER JET CUTTER. 17:30 - 20:00 2.50 FISH P DECOMP PJSM WITH ALL HANDS ON HANDLING OF JET CUTTER. RIH WITH 2.68" JET CUTTER. CUT 3 1/2" TUBING AT 11001'. POHANDLAYDOWNTOOLS. CUTTER FIRED. 20:00 - 21 :00 1.00 FISH P DECOMP WORK PIPE UP TO 80% OF YIELD. CIRCULATE AT 336 GPM WITH 750 PSI. NO PIPE MOVEMENT. 21 :00 - 23:30 2.50 FISH P DECOMP PJSM WITH ALL HANDS ON HANDLING OF STRING SHOT AND CHEMICAL CUTTER. RIH WITH 3 STRAND STRING SHOT. FIRE BETWEEN 10332' AND 10342'. POH AN DLAY DOWN TOOLS. 23:30 - 00:00 0.50 FISH P DECOMP PICK UP CHEMICAL CUTTER AND ASSOCIATED TOOLS. 5/10/2002 00:00 - 05:00 5.00 FISH P DECOMP RIH WITH CHEMICAL CUTTER TO 10340'. CUT TUBING. GOOD INDICATIONS ON SURFACE. POH CUTTER AND TOOLS. 05:00 - 06:00 1.00 FISH P DECOMP PICK UP PIPE. TUBING FREE. RIG DOWN SCHUMBERGER. 06:00 - 09:00 3.00 FISH P DECOMP POH 5" DRILL PIPE TO 3 1/2" FISH. 09:00 - 09:30 0.50 FISH P DECOMP RIG UP 3 1/2" HANDLING EQUIPMENT. 09:30 - 11 :30 2.00 FISH P DECOMP POH AND LAY DOWN 3 1/2" TUBING. RECOVERED 50 JTS, GAS LIFT MANDREL, X NIPPLE AND CUT OFF. TOP OF FISH AT 10340' 11:30-12:00 0.50 FISH P DECOMP RIG DOWN TUBING HANDLING EQUIPMENT. 12:00 -13:30 1.50 FISH P DECOMP MAKE UP OVER SHOT AND FISHING BHA. 13:30 - 17:00 3.50 FISH P DECOMP RIH. PICK UP 45 JT 5" DRILL PIPE AND RIH TO 10338' 17:00 - 18:00 1.00 FISH P DECOMP ENGAGE FISH AT 10338'. JAR ON FISH. TUBING CAME FREE. STRING WEIGHT INCREASE BY 10K. 18:00-21:30 3.50 FISH P DECOMP POH WITH 5" DRILL PIPE TO 3 1/2" TUBING FISH. 21 :30 - 22:30 1.00 FISH P DECOMP LAY DOWN FISHING BHA. 22:30 - 23:00 0.50 FISH P DECOMP RIG UP 3 1/2" HANDLING EQUIPMENT. 23:00 - 00:00 1.00 FISH P DECOMP POH. LAY DOWN 3 1/2" TUBING. 5/11/2002 00:00 - 00:30 0.50 FISH P DECOMP RIG DOWN 3 1/2" HANDLING EQUIPMENT. 00:30 - 01 :30 1.00 FISH P DECOMP LAY DOWN FISHING TOOLS. RECOVERED 32 JTS AND TWO CUT PIECES OF 31/2"TUBING, 1011.72'. TOP OF 3 1/2" TUBING FISH AT 11349'. NOTE: NO CUT AT 11001', PARTIAL CUT AT 11349' 01 :30 - 03:30 2.00 STWHIP P PROD1 MAKE UP 61/8" MILLING BHA. 03:30 - 07:00 3.50 STWHIP P PROD1 RIH TO 11137' 07:00 - 08:00 1.00 STWHIP P PROD1 SLIP AND CUT 79' DRILLING LINE. TEST CASING TO 3000 PSI FOR 10 MINUTES. OK. 08:00 - 08:30 0.50 STWHIP P PROD1 SREVICE TOP DRIVE. 08:30 - 09:00 0.50 STWHIP P PROD1 RIH TO TOP OF 31/2" FISH AT 11350'. DRILL PIPE MESUREMENT. 09:00 - 11 :30 2.50 STWHIP P PROD1 DISLACE WELL TO QUICKDRILn MILLING FLUID. OBTAIN MILLING PARAMETERS. 11 :30 - 15:00 3.50 STWHIP P PROD1 POH TO MILLING BHA. 15:00 -17:00 2.00 STWHIP P PROD1 POH MILLING BHA AND STAND BACK SAME. 17:00 - 19:00 2.00 STWHIP P PROD1 PICK UP AND ORIENT MWD. LOAD AND SURFACE TEST MWD. 19:00 - 19:30 0.50 STWHIP P PROD1 PICK UP WHIPSTOCK AND PIN SAME. 19:30 - 20:30 1.00 STWHIP P PROD1 RIH TO 1417' WITH BHA AND 4" DRILL PIPE. Printed: 5/28/2002 11 :21 :09 AM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-31 E-31 REENTER+COMPLETE NABORS NABORS 2ES Start: 5/5/2002 Rig Release: 5/27/2002 Rig Number: Spud Date: 5/12/2002 End: 5/11/2002 20:30 - 00:00 3.50 STWHIP P PROD1 RIH TO 7520' WITH 5" DRILL PIPE. 5/12/2002 00:00 - 03:00 3.00 STWHIP P PROD1 RIH WITH WHIPSTOCK AND MILLING BHA. PASS THROUGH 7" LINER TOP WITH NO PROBLEMS. RIH TO 11290'. 03:00 - 04:00 1.00 STWHIP P PROD1 ORIENT WHIPSTOCK 80 DEG RIGHT OF HIGH SIDE. TAG UP ON TOP OF FISH AT 11350'. SET ANCHOR AND SHEAR OFF MILL. 04:00 - 19:30 15.50 STWHIP P PROD1 MILL WINDOW IN 7" CASING. TOP OF WINDOW AT 11331'. MILL TO 11349'. NO PROGRESS. TOP 61/8" MILL NOT COMPLEATEL Y THROUGH THE WINDOW. 19:30 - 00:00 4.50 STWHIP P PROD1 POH TO CHANGE MILL. 5/13/2002 00:00 - 01 :00 1.00 STWHIP P PROD1 POH WITH MILLS TO BHA. 01 :00 - 03:30 2.50 STWHIP P PROD1 STAND BACK BHA. CHANGE OUT MILL. STARTER MILL INGAUGE AND 60% WORN. 03:30 - 04:00 0.50 STWHIP P PROD1 CLEAR RIG FLOOR. 04:00 - 05:00 1.00 STWHIP P PROD1 PULL WEAR BUSHING. INSTALL TEST PLUG. 05:00 - 07:00 2.00 STWHIP P PROD1 TEST BOP. 250 PSI LOW AND 3500 PSI HIGH. NOTE: WITNESS OF TEST WAIVED BY JOHN CRISP OF AOGCC. 07:00 - 08:00 1.00 STWHIP P PROD1 PULL TEST PLUG AND LAY DOWN TEST JOINT. INSTALL WEAR BUSHING. 08:00 - 09:00 1.00 STWHIP P PROD1 MAKE UP NEW STARTER MILL AND RIH WITH BHA. 09:00 - 13:30 4.50 STWHIP P PROD1 RIH TO 11331' TOP OF 7"WINDOW. 13:30 - 16:00 2.50 STWHIP P PROD1 MILL 7" WINDOW TO 11355'. WORK MILL THROUGH WINDOW SEVERAL TIMES. 16:00 - 16:30 0.50 STWHIP P PROD1 PERFORM FIT TO 10 PPG EMW. 720 PSI SURFACE PRESSURE. 16:30 -18:00 1.50 STWHIP P PROD1 CIRCULATE BOTTOMS UP. RECIPROCATE AND ROTATE PIPE. 18:00 - 22:30 4.50 STWHIP P PROD1 POH WITH MILLS TO BHA. 22:30 - 00:00 1.50 STWHIP P PROD1 LAY DOWN MILLING BHA. 5/14/2002 00:00 - 01 :00 1.00 DRILL P PROD1 CLEAR RIG FOOR 01 :00 - 03:00 2.00 DRILL P PROD1 PUlMU BUILD SECTION BHA. SURFACE TEST MWD - OK. LOAD RA SOURCES. 03:00 - 05:00 2.00 DRILL P PROD1 PU 60 JTS OF 4" DP, 1X1 FROM THE SHED. 05:00 - 07:30 2.50 DRILL P PROD1 RIH WI 5" DP TO 10,360'. FILL PIPE AND TEST MWD AT 2,566' AND 6,932'. 07:30 - 09:00 1.50 DRILL P PROD1 CUT AND SLIP 101' OF DL. SERVICE TD. 09:00 - 09:30 0.50 DRILL P PROD1 RIH TO 10,913'. UWT = 220K, DWT = 160K. 09:30 - 10:00 0.50 DRILL P PROD1 LOG AND CORRELATE DEPTHS FROM 10,913' -10,953'. 10:00 - 11 :00 1.00 DRILL P PROD1 ORIENT TF TO 80 DEG RHS. PASS THRU WINDOW WIO PROBLEMS. 11:00 - 00:00 13.00 DRILL P PROD1 DRILL 6-1/8" HOLE WITH 1.5 DEG MOTOR. DAILY ART = 5 HR, DAILY AST = 4.81 HR. 5/15/2002 00:00 - 17:30 17.50 DRILL P PROD1 DRILL 6-1/8" HOLE WITH 1.5 DEG MOTOR. ART = 7.67 HR, DAILY AST = 4.91 HR. 17:30 - 20:00 2.50 DRILL P PROD1 PUMP HI-VIS SWEEP WHILE ROTATING AT 60 RPM, WITH A FLOWRATE OF 275 GPM. 20:00 - 00:00 4.00 DRILL P PROD1 POOH 5 STDS, FLOWCHECK, PUMP SLUG. POOH WI 5" DP. 5/16/2002 00:00 - 03:00 3.00 DRILL P PROD1 CONTINUE TO POOH TO BHA. 03:00 - 04:30 1.50 DRILL P PROD1 LD BHA. REMOVE RA SOURCE FROM LWD. 04:30 - 05:00 0.50 DRILL P PROD1 CLEAR RIG FLOOR. Printed: 5/28/2002 11 :21 :09 AM ,~ ,~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-31 E-31 REENTER+COMPLETE NABORS NABORS 2ES Start: 5/5/2002 Rig Release: 5/27/2002 Rig Number: Spud Date: 5/12/2002 End: 5/16/2002 05:00 - 07:00 2.00 DRILL P PROD1 PU PDC BIT AND BHA SHALLOW TEST MWD - OKAY. 07:00 - 08:00 1.00 DRILL P PROD1 RIH AND PU 4" DP NEEDED TO TO THE WELL AT 15,654', 08:00 - 09:00 1.00 DRILL N SFAL PROD1 REPAIR PIPE SKATE. CHANGE OUT TOP DRIVE HANDLER PIN LOCK VALVE. 09:00 - 15:30 6,50 DRILL P PROD1 CONTINUE TO RIH TO 11,246'. FILLING PIPE. 15:30 - 16:00 0.50 DRILL P PROD1 ORIENT TOOLFACE TO 85R. 16:00 - 17:00 1.00 DRILL P PROD1 SHUT DOWN PUMPS. RIH TO 11,332' (TOW = 11,331 '), SET DOWN WITH 15K. PU TO 11,281', REORIENT TO 75R, SHUT DOWN PUMPS, RIH TO 11,332' AND SET DOWN 20K LB. 17:00 - 18:00 1.00 DRILL N DPRB PROD1 FLOW CHECK WELLBORE, PUMP SLUG, BLOW DOWN TOP DRIVE. 18:00 - 00:00 6.00 DRILL N DPRB PROD1 POOH TO 1,420'. 5/17/2002 00:00 - 01 :00 1.00 DRILL N DPRB PROD1 CONTINUE POOH TO BHA LD A TOTAL OF 90 JTS OF 4" DP. 01 :00 - 02:00 1.00 DRILL N DRPB PROD1 LD DRILLING BHA CHECK MWD ORIENTATION, AND GUAGE BIT - ALL OKAY. 02:00 - 02:30 0.50 DRILL N DRPB PROD1 CLEAR RIG FLOOR. 02:30 - 03:30 1.00 DRILL N DRPB PROD1 PU 5-5/8" PILOT MILL AND 6.15" STRING MILL. 03:30 - 08:00 4.50 DRILL N DRPB PROD1 RIHTO11,331'. 08:00 - 09:30 1.50 DRILL N DRPB PROD1 SHUT OFF PUMPS, CONTINUE RIH, SET DOWN 5-10K LBS AT 11,339' (UPPER STRING MILL AT TOP OF WINDOW). PU AND CIRC AT 300 GPM. WORK PIPE DOWN AND STACKED OUT AGAIN W/5-10K. STOP, PU, START ROTATING AT 70 RPM, REAM THRU WINDOW. CONTINUE REAMING THRU WINDOW, INCREASING TO 120 RPM. TURN OFF PUMPS, PU AND SLIDE THRU WINDOW OKAY. 09:30 - 10:00 0.50 DRILL N DRPB PROD1 FLOWCHECK, PUMP SLUG. 10:00 - 14:30 4.50 DRILL N DRPB PROD1 POOH TO 3,250'. 14:30 - 15:00 0.50 DRILL N DRPB PROD1 SERVICE TO. 15:00 - 16:00 1.00 DRILL N DRPB PROD1 CONTINUE POOH TO BHA 16:00 - 17:00 1.00 DRILL N DRPB PROD1 LD BHA ALL MILLS WERE IN GAUGE. 17:00 - 18:00 1.00 DRILL N DRPB PROD1 CLEAR RIG FLOOR. CLEAN. 18:00 - 20:00 2.00 DRILL N DRPB PROD1 PU DRILLING BHA. SHALLOW TEST MWD - OKAY. 20:00 - 23:30 3.50 DRILL N DRPB PROD1 RIH WI 4" DP (PU 90 JTS). 23:30 - 00:00 0.50 DRILL N DRPB PROD1 CHANGE OUT AIR SLIPS AND CONTINUE RIH WI 5" DP, TO 7,213'. 5/18/2002 00:00 - 02:00 2.00 DRILL N DRPB PROD1 RIH TO 11,200. 02:00 - 02:30 0.50 DRILL P PROD1 ORIENT TOOLFACE TO 80R, AND SLIDE THRU WINDOW WITHOUT PROBLEMS. 02:30 - 03:00 0.50 DRILL P PROD1 CONTINUE RIH TO 11,702' AND CHECKSHOT SURVEY. CONTINUE RIH TO 12,238'. 03:00 - 12:00 9.00 DRILL P PROD1 ROTATE AND SLIDE DRILL WITH 1.5 DEG BEND MTR. AST= 1.9 HR, ART = 2.4 HR. WOB=5K, PRESS = 1,620 PSI, TORQUE = 9/10 FT-LB, UWT=235K, DWT=165K, ROT=185K. 12:00 - 00:00 12.00 DRILL P PROD1 ROTATE AND SLIDE DRILL WITH 1.5 DEG BEND MTR. AST= 5.1 HR, ART = 2.5 HR. WOB = 2-3K, PRESS = 1,970 PSI, TORQUE = 10/11 FT-LB, UWT=225K, DWT=155K, ROT = 185K. NOT GETTING GOOD WEIGHT TRANSFER TO BIT, HAVING TROUBLE SLIDING. INCREASE LUBRICANTS AND DRILL INTO CLEANER SANDSTONE. 5119/2002 00:00 - 12:00 12.00 DRILL P PROD1 ROTATE AND SLIDE DRILL WITH 1.5 DEG BEND MTR. Printed: 5/28/2002 11 :21 :09 AM ,,-...., ...-., Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-31 E-31 REENTER+COMPLETE NABORS NABORS 2ES Start: 5/5/2002 Rig Release: 5/27/2002 Rig Number: Spud Date: 5/12/2002 End: 5/19/2002 00:00 -12:00 12.00 DRILL P PROD1 AST=5.3 HR, ART = 3.0 HR. UWT=227K, DWT=148K, ROT=188K. WOB=2/5, TORQUE OFF=10K FT-LB, TORQUE ON = 12/13K FT-LB. 12:00 - 00:00 12.00 DRILL P PROD1 ROTATE AND SLIDE DRILL WITH 1.5 DEG BEND MTR. AST=5.3 HR, ART = 2.5 HR. UWT=225K, DWT=150K, ROT=190K. WOB=2/5K, TORQUE OFF = 10K FT-LB, TORQUE ON = 11/12K FT-LB. 5/20/2002 00:00 - 12:00 12.00 DRILL P PROD1 ROTATE AND SLIDE DRILL WITH 1.5 DEG BEND MTR. AST=4.1 HR, ART = 4.3 HR. UWT=225K, DWT=155K, ROT=192K. WOB=5, TORQUE OFF=10K FT-LB, TORQUE ON= 11 K FT-LB. 12:00 - 00:00 12.00 DRILL P PROD1 ROTATE AND SLIDE DRILL WITH 1.5 DEG BEND MTR. AST=2.5 HR, ART = 5.0 HR. UWT=230K, DWT=150K, ROT=150K. WOB=2/4K, TORQUE OFF=10K FT-LB, TORQUE ON=11K FT-LB. 5/21/2002 00:00 - 12:00 12.00 DRILL P PROD1 ROTATE AND SLIDE DRILL WITH 1.5 DEG BEND MTR. AST=4.4 HR, ART = 2.7 HR. UWT=235K, DWT=150K, ROT=193K. TORQUE OFF=10K, TORQUE ON=11 K FT-LB. 12:00 - 18:00 6.00 DRILL P PROD1 ROTATE AND SLIDE DRILL WITH 1.5 DEG BEND MTR. AST=O HR, ART=6.1 HR, TQ=1 0/11 K - OFF/ON. 18:00 - 20:00 2.00 DRILL P PROD1 CIRCULATE SWEEP AT 8 BPM AND 1,840 PSI. FLOWCHECK. 20:00 - 22:30 2.50 DRILL P PROD1 POOH TO INSIDE 7" CSG, ABOVE WINDOW. NO EXCESS DRAG ON TRIP. 22:30 - 23:00 0.50 DRILL P PROD1 FLOWCHECK WELL, CLEAN RIG. 23:00 - 00:00 1.00 DRILL P PROD1 CUT AND SLIP 88' OF DRILL LINE. 5/22/2002 00:00 - 01 :00 1.00 DRILL P PROD1 SERVICE TD. INSTALL SAFETY CABLES ON TOP DRIVE LINK TILT CYLINDERS. 01 :00 - 02:30 1.50 DRILL P PROD1 RIH THRU WINDOW-OKAY. CONTINUE TO RIH WI PDC BIT TO TO-OKAY. 02:30 - 06:00 3.50 DRILL P PROD1 CIRCULATE SWEEP, SPOT LINER RUNNING PILL, PUMP SLUG, FLOWCHECK-OKAY. 06:00 - 09:30 3.50 DRILL P PROD1 POOH THRU WINDOW (WET)TO 11,229' LAYING DOWN 141 JTS OF 5" DP. (NO PROBLEMS). 09:30 - 15:00 5.50 DRILL P PROD1 POOH TO BHA. 15:00 -17:30 2.50 DRILL P PROD1 DOWNLOAD DATA, LD BHA. 17:30 -18:00 0.50 DRILL P PROD1 CLEAN AND CLEAR RIG FLOOR. 18:00 -18:30 0.50 CASE P PROD1 RU CASING EQUIPMENT. 18:30 - 19:00 0.50 CASE P PROD1 PU/MU AND THREAD LOCK SHOE JOINTS.CHECK FLOATS-OKAY. 19:00 - 00:00 5.00 CASE P PROD1 RUN 97 OF 108 JOINTS OF 4-1/2" 12.6 LB/FT, IBT-M CASING WITH CENTRALIZERS ON JTS # 1, 3-102. 5/23/2002 00:00 - 00:30 0.50 CASE P PROD1 MAKE UP LINER HANGER AND LINER TOP PKR. 00:30 - 01 :30 1.00 CASE P PROD1 LD CASING EQUIPMENT. CLEAR RIG FLOOR. 01 :30 - 02:30 1.00 CASE P PROD1 MAKE UP TOP DRIVE AND CIRCULATE LINER. 02:30 - 05:30 3.00 CASE P PROD1 RIH TO 11,242'. 05:30 - 06:00 0.50 CASE P PROD1 CIRCULATE PIPE VOLUME. 06:00 - 08:30 2.50 CASE P PROD1 PASS THRU WINDOW - OKAY. RIH TO TD. 08:30 - 09:00 0.50 CASE P PROD1 RU ROTATING CMT HEAD. 09:00 - 12:30 3.50 CASE P PROD1 CIRC AND CONDITION AT 6 BPM AND 1,050 PSI WHILE Printed: 5/28/2002 11:21:09AM ~ ....-.., Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-31 E-31 REENTER+COMPLETE NABORS NABORS 2ES Start: 5/5/2002 Rig Release: 5/27/2002 Rig Number: Spud Date: 5/12/2002 End: 5/23/2002 09:00 - 12:30 3.50 CASE P PROD1 MOVING PIPE. UWT=220K, DWT=155K. HOLD PJSM AND BATCH MIX CEMENT. 12:30 - 14:30 2.00 CASE P PROD1 PUMP 5 BBL OF WATER AND TEST LINES TO 4,000 PSI-OKAY. PUMP 30 BBL OF 9.6 PG ALPHA SPACER AT 4-4.5 BPM, PUMP 109 BBL (512SX) OF 15.6 PPG LATEX "G" CEMENT AT 5 BPM. DROP DART AND DISPLACE WITH 90 BBL OF PERF PILL FOLLOWED BY SEAWATER, AT 5-8 BPM. BUMP PLUG AT CALCULATED DISPLACEMENT VOLUME, PRESSURE UP TO 3,500 PSI AND SET HANGER. BLED PRESSURE AND CHECK FLOATS - OKAY. 14:30 - 15:00 0.50 CASE P PROD1 RELEASE FROM HANGER AND SET HANGER PACKER WITH 65K DOWN AND ROTATION. 15:00 - 15:30 0.50 CASE P PROD1 CIRCULATE EXCESS CEMENT FROM WELL AT 14 BPM AND 2,375 PSI. HAD RETURNS OF ALPHA SPACER AND A TRACE OF CEMENT. 15:30 - 18:00 2.50 CASE P PROD1 DISPLACE WELL TO CLEAN SEAWATER AT 7-1/2 BPM AND 1,175 PSI. 18:00 - 18:30 0.50 CASE P PROD1 LD CMT HEAD. 18:30 - 21:00 2.50 CASE P PROD1 FLOWCHECK, PUMP SLUG, POOH WITH 5" DP TO 5,597'. TEST CHOKE MANIFOLD TO 3,500 PSI- OKAY. 21 :00 - 22:30 1.50 CASE P PROD1 CUT AND SLIP 82' OF DRILL LINE. SERVICE TOP DRIVE. 22:30 - 00:00 1.50 CASE P PROD1 CONTINUE TO POOH WITH 4" DP TO 3,730'. 5/24/2002 00:00 - 01 :30 1.50 CASE P PROD1 POOH, LD LINER RUNNING TOOL. 01 :30 - 02:00 0.50 CASE P PROD1 CLEAR RIG FLOOR. 02:00 - 05:30 3.50 CASE P PROD1 PULL WEAR BUSHING AND SET TEST PLUG. TEST UPPER PIPE RAMS, AND HYD CHOKE TO 250 PSI LOW AND 3,500 PSI HIGH, FOR 5/5 MIN. TEST ANNULAR AND MANUAL KILL AND CHOKE TO 250 PSI LOW AND 3500 PSI HIGH, FOR5/5MIN. TESTTD, (2)TIW VALVES, DART VALVE TO 250/3,500 PSI FOR 5/5 MIN. TEST BLIND RAMS, HYD KILL AND CHOKE VALVES TO 250/3,500 PSI FOR 5/5 MIN. WITNESSING OF TEST WAIVED BY CHUCK SCHEVE OF THE AOGCC. 05:30 - 06:30 1.00 CASE P PROD1 RU AND PRESSURE TEST 4-1/2" LINER X 7" LINER X 9-5/8" CASING TO 3,000 PSI, FOR 30 MIN - OKAY. 06:30 - 11 :30 5.00 PERF P COMP PJSM, 2-1/2" HES DPC PERFORATING GUNS, W/11 GM MILLENIUM CHGS, 60 DEG PHASING AT 4 SPF. OVERALL GUN LENGTH = 3,170'. (1,520' LOADED AND 1,650' BLANK) 11:30-12:30 1.00 PERF P COMP MU FIRING HEAD, RIG UP HANDLING EQUIPMENT. 12:30 - 14:30 2.00 PERF P COMP PU 1X1 AND RIH WI 40 JTS OF 2-3/8" HT-SLH90 DP. 14:30 - 19:00 4.50 PERF P COMP RIH AND TAG UP ON LANDING COLLAR AT 15,485'. PU TO 15,360' TO SPACE OUT ON DEPTH. 19:00 - 19:30 0.50 PERF P COMP PJSM FOR PERORATING AND POOH. RU SOUND SENSORS. UWT=215K, DWT=165K. 19:30 - 20:00 0.50 PERF P COMP CLOSE ANNULAR BOP, PRESSURE UP ON DP TO 2,550 PSI, RELEASE PRESSURE. PERFORATE AT 4 SPF: 15,010-360',14,350-530',13,220-560',12,910-13,150', 12,660-860',12,190-400'. - 20:00 - 21 :30 1.50 PERF P COMP POOH (UWT=217K) TO 12,123' STANDING BACK 5" DP. LOST 47 BBLS. 21 :30 - 22:00 0.50 PERF P COMP FLOWCHECK. HOLE TAKING FLUID AT 8 BBUHR. PUMP SLUG. 22:00 - 00:00 2.00 PERF P COMP POOH LAYING DOWN DP AND FILLING HOLE. LOSSES Printed: 5/28/2002 11 :21 :09 AM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-31 E-31 REENTER+COMPLETE NABORS NABORS 2ES Start: 5/5/2002 Rig Release: 5/27/2002 Rig Number: Spud Date: 5/12/2002 End: 5/24/2002 22:00 - 00:00 2.00 PERF P COMP DECREASED TO 4 BBUHR. 5/25/2002 00:00 - 04:30 4.50 PERF P COMP LD 4" AND 2-3/8" DRILLPIPE. 04:30 - 05:00 0.50 PERF P COMP PJSM FOR LAYING DOWN PERF GUNS. CHANGE OUT HANDLING TOOLS. 05:00 - 06:00 1.00 PERF P COMP LAY DOWN PERF GUNS. 06:00 - 06:30 0.50 PERF N COMP REPAIR HYDRAULIC LINE LEAK ON SKATE. 06:30 - 10:00 3.50 PERF P COMP CONTINUE TO LAY DOWN PERF GUNS. ALL SHOTS FIRED. A TOTAL OF 61 BBLS OF PILUSEAWATER WAS LOST ON TRIP OUT OF HOLE. 10:00 -10:30 0.50 RUNCOrvP COMP CLEAR RIG FLOOR OF PERF HANDLING EQUIPMENT. CLEAN FLOOR. 10:30 - 14:00 3.50 RUNCOrvP COMP LAY DOWN 111 JOINTS OF 5" DRILLPIPE. 14:00 - 14:30 0.50 RUNCOrvP COMP PULL WEAR BUSHING. 14:30 - 15:00 0.50 RUNCOrvP COMP RU TUBING HANDLING EQUIPMENT. 15:00 - 15:30 0.50 RUNCOrvP COMP PJSM FOR RUNNING COMPLETION ASSEMBLY. 15:30 - 00:00 8.50 RUNCOrvP COMP RIH WITH 4-1/2",12.6 LB/FT, L-80, IBT-M TUBING, PLUS COMPLETION EQUIPMENT. RAN 240 OF 264 JTS WI AVG MAKE-UP TORQUE OF 4,200 FT-LB. 5/26/2002 00:00 - 01 :30 1.50 RUNCOrvP COMP FINISH RUNNING 4-1/2", L-80, 12.6 LB/FT, IBT-M TUBING. UWT=145K, DWT=111 K. RUN WLEG INTO TIE-BACK RECEPTACLE. 01 :30 - 02:30 1.00 RUNCOrvP COMP PU, LD JT #265, ADD 9.85' + 9.32' SPACE OUT PUPS. 02:30 - 03:30 1.00 RUNCOrvP COMP MAKE UP TBG HANGER, RIH AND LAND TBG. RUN IN LOCK DOWN SCREWS AND TORQUE TIGHTEN. 03:30 - 07:00 3.50 RUNCOrvP COMP CIRC CORROSION INHIBITOR INTO 9-5/8" X 4-1/2" ANNULUS AT 3 BPM AND 200 PSI. 07:00 - 07:30 0.50 RUNCOrvP COMP DROP 1-7/8" BALL AND ROD. 07:30 - 08:00 0.50 RUNCOrvP COMP ATTEMPT TO TEST TBG T/3,500 PSI. BALL WOULD NOT SEAT. ATTEMPT TO SEAT BALL BY PUMPING. WOULD NOT TEST. 08:00 - 08:30 0.50 RUNCOWN DPRB COMP SCREW LANDING JT INTO HANGER, BACK OUT LDS, PULL HANGER TO FLOOR, CHANGE OUT HANGER SEAL. 08:30 - 09:00 0.50 RUNCOWN DPRB COMP PUT 180 DEG TURN IN PIPE, SHAKE PIPE TO FREE UP BALL AND ROD. 09:00 - 09:30 0.50 RUNCOWN DPRB COMP LAND HANGER, RUN IN LDS, AND TORQUE TIGHTEN. 09:30 - 10:00 0.50 RUNCOWN DPRB COMP ATTEMPT TO TEST TBG - NO TEST. 10:00 - 11 :00 1.00 RUNCOWN DPRB COMP PJSM WITH SLlCKLINE UNIT PERSONNEL. LD LANDING JT. 11 :00 - 12:00 1.00 RUNCOWN DPRB COMP PUIRU LUBRICATOR. RU SLlCKLINE EQUIPMENT. 12:00 - 19:00 7.00 RUNCOWN DPRB COMP RIH AND LATCH ONTO BALL AND ROD. SEAT BALL, AND PRESSURE UP - NO TEST. POOH. LD LUBRICATOR AND PU LANDING JT AND SLlCKLINE XOs. RIH, LATCH ON TO BALL AND ROD AND RESEA T. 19:00 - 20:00 1.00 RUNCOrvP COMP PRESSURE TBG TO 3,500 PSI, SET S-3 PERMANENT PKR, AND TEST TBG FOR 30 MIN -OKAY. 20:00 - 21 :00 1.00 RUNCOrvP COMP BLED TBG PRESSURE TO 1,500 PSI. PRESSURE 9-5/8" X 7" CSG ANNULUS PLUS PERMANENT PKR TO 3,000 PSI. TEST FOR 30 MIN - OKAY. 21 :00 - 22:00 1.00 RUNCOIItP COMP BLED CSG AND TBG PRESSURE TO ZERO. POOH, RETRIEVED BALL AND ROD, LD TOOL STRING, RD SLlCKLINE EQUIPMENT. 22:00 - 22:30 0.50 RUNCOtvP COMP RD LUBRICATOR AND LANDING JT. CLOSE BLIND RAMS, PRESSURE UP ANNULUS AND SHEAR RP VALVE AT 2,000 Printed: 5/28/2002 11:21:09AM ~ ,~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-31 E-31 REENTER+COMPLETE NABORS NABORS 2ES Start: 5/5/2002 Rig Release: 5/27/2002 Rig Number: Spud Date: 5/12/2002 End: 5/26/2002 22:00 - 22:30 0.50 RUNCOrvP 22:30 - 23:00 0.50 RUNCOrvP 23:00 - 00:00 1.00 RUNCOrvP 5/27/2002 00:00 - 01 :30 1.50 RUNCOrvP 01 :30 - 02:30 1.00 RUNCOrvP 02:30 - 03:30 1.00 RUNCOrvP 03:30 - 04:30 1.00 RUNCOrvP 04:30 - 07:30 3.00 RUNCOrvP 07:30 - 08:00 0.50 RUNCOrvP 08:00 - 09:00 1.00 RUNCOrvP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP PSI. INSTALL TWC AND TEST FROM BELOW. - OKAY. ND BOPE. ND BOPE AND ADAPTOR FLANGE. NU TREE. PRESSURE TEST TBG HANGER AND TREE TO 5,000 PSI-OKAY. PJSM, RU LUBRICATOR, PULL TWC, RD LUBRICATOR. PJSM, RU HOT OIL SEVICES, PUMP 152 BBL OF DIESEL AT 3 BPM AND 550 PSI DOWN THE 9-5/8" X 4-1/2" ANNULUS. U-TUBE FREEZE PROTECT. SET AND TEST BPV. RD HOT OIL SERVICES. SECURE WELL AND CELLAR. REMOVE SECONDARY ANNULAR VALVE. RELEASE RIG AT 0900 HOURS - 5/27/2002. Printed: 5/28/2002 11 :21 :09 AM ~, "............ c;;(OQ- /7 5 28-Jun-O2 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITVE Re: Distribution of Survey Data for Well E - 31A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,324.57' MD Window / Kickoff Survey 11,331.00' MD Projected Survey: 15,572.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED Attachment(s) JUL 2 2002 Alaska Oil & Gas Cons. Commission Anchorage DEFINITIVE "- North Slope Alaska BPXA PBU_WOA E Pad, Slot E-31 E-31A Job No. AKZZ22075, Surveyed: 21 May, 2002 ) SUR VEY RfIflOR T 27 June, 2902 Your Ref: API 500202241101 Surface Coordinates: 5976455.20 N, 664455.63 E (70020' 31.1168" N, 148039'54.9867" W) Kelly Bushing: 58. 70ft above Mean Sea Level ) -.-. ...... .. .y-- M-, OrdLL.ING Sh....V" s- A Halliburton Company Survey Ref: svy11220 Sperry-Sun DrillllJg<Services I) Survey Report forE.31A Your Ref: API 500292241101 Job No. AKZZ22075, Surveyed: 21 May, 2002 BPXA North Slope Alaska PBU - WOA E Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11324.57 67.230 147.940 8551.57 8610.27 5969.59 S 2735.19 E 5970541.05 N 667321.12 E 6450.64 Tie On Point ') AK-6 BP IFR-AK '-- 11331.00 67.530 147.740 8554.04 8612.74 5974.62 S 2738.35 E 5970542.09 N 667324.38 E 5.480 6456.57 Window Point } 11412.83 68.910 151.840 8584.42 8643.12 6040.27 S 2176.56 E 5910411.29 N 667364.03 E 4.949 6532.22 11441.33 69.380 153.760 8594.56 8653.26 6063.96 S 2188.74 E 5910453.88 N 667376.72 E 6.508 6558.58 11475.17 68.860 159.600 8606.63 8665.33 6092.91 S 2801.25 E 5970425.14 N 667389.86 E 16.196 6589.48 I' 11535.32 69.510 169.110 8628.05 8686.75 6147.04 S 2816.38 E 5970311.42 N 667406.18 E 14.816 6642.32 11566.10 69.320 172.800 8638.88 8697.58 6175.49 S 2820.91 E 5910343.08 N 667411.33 E 11.240 6668.14 11597.25 69.530 173.150 8649.82 8708.52 6204.43 S 2824.48 E 5970314.22 N 667415.53 E 1.249 6693.80 11629.03 70.030 173.120 8660.81 8719.51 6234.04 S 2828.04 E 5910284.69 N 667419.74 E 1.576 6720.00 11660.41 69.910 173.330 8671.56 8730.26 6263.32 S 2831.52 E 5970255.50 N 667423.86 E 0.736 6745.88 11690.56 69.590 172.970 8681.99 8740.69 6291.40 S 2834.89 E 5970221.50 N 667427.85 E 1.543 6770.73 11722.82 70.840 168.040 8692.92 8751.62 6321.33 S 2839.90 E 5970191.69 N 667433.52 E 14.892 6798.03 11753.07 70.640 165.710 8702.90 8761.60 6349.14 S 2846.39 E 5910110.03 N 667440.61 E 7.301 6824.45 11783.78 70.360 165.920 8713.15 8771.85 6377.20 S 2853.48 E 5910142.13 N 667448.32 E 1.117 6851.44 11817.01 70.290 165.420 8724.34 8783.04 6407.52 S 2861.23 E 5970111.99 N 667456.72 E 1.432 6880.64 11877.64 69.970 164.820 8744.94 8803.64 6462.63 S 2815.87 E 5970051.21 N 667472.57 E 1.070 6934.05 11910.11 71.990 165.940 8755.52 8814.22 6492.33 S 2883.61 E 5910021.69 N 667480.97 E 7.024 6962.75 11940.17 75.330 167.060 8763.98 8822.68 6520.38 S 2890.34 E 5969999.80 N 667488.31 E 11.672 6989.51 ) 11971.50 77.850 167.770 8771.25 8829.95 6550.12 S 2896.98 E 5969910.21 N 667495.60 E 8.340 7017.60 12002.92 80.610 166.860 8777.12 8835.82 6580.23 S 2903.76 E 5969940.26 N 667503.04 E 9.233 7046.07 12037.08 81.290 166.570 8782.49 8841.19 6613.06 S 2911.51 E 5969901.60 N 667511.51 E 2.160 7077.33 12069.34 84.270 165.100 8786.54 8845.24 6644.08 S 2919.35 E 5969816.15 N 667520.02 E 10.284 7107.16 12099.34 85.510 164.590 8789.22 8847.92 6672.93 S 2927.16 E 5969848.09 N 667528.46 E 4.467 7135.19 12132.17 88.220 162.680 8791.01 8849.71 6704.37 S 2936.39 E 5969816.85 N 667538.39 E 10.094 7166.18 12164.47 90.680 160.130 8791.32 8850.02 6734.98 S 2946.69 E 5969186.48 N 667549.35 E 10.969 7197.09 12192.31 90.250 158.100 8791.10 8849.80 6760.99 S 2956.61 E 5969160.69 N 667559.84 E 7.453 7224.04 12237.77 89.820 157.980 8791.07 8849.77 6803.15 S 2913.61 E 5969118.92 N 667517.77 E 0.982 7268.26 12331.21 90.250 159.290 8791.01 8849.71 6890.17 S 3001.65 E 5969632.67 N 667613.71 E 1.476 7358.91 12425.57 90.740 159.150 8790.20 8848.90 6978.39 S 3041.13E 5969545.20 N 667649.11 E 0.540 7450.22 12519.25 90120 156.610 8789.49 8848.19 7065.16 S 3076.40 E 5969459.22 N 667686.27 E 2.791 7541.39 27 June, 2002 - 10:34 Page2of5 DrillQuesf 2.00.08.005 Sperry-Sun Drilling Services' (f) Survey Repon fo,.S-41A Your Ref: AP/~1101 Job No. AKZZ22075, Surveyø: 21 May, 2002 BPXA North Slope Alaska PBU_WOA E Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment eft) (ft) eft) eft) eft) (ft) (ft) (o/100ft) 12614.10 89.320 155.820 8789.96 8848.66 7151.95 S 3114.65 E 5969373.29 N 667726.42 E 1.185 7634.30 ) 12707.25 89.880 153.660 8790.61 8849.31 7236.19 S 3154.40 E 5969289.95 N 667768.01 E 2.395 7725.99 -- 12801.08 90.250 151.140 8790.50 8849.20 7319.33 S 3197.87 E 5969207.78 N 667813.29 E 2.714 7818.94 12894.43 90.430 146.370 8789.95 8848.65 7399.12 S 3246.27 E 5969129.07 N 667863.43 E 5.113 7912.02 12988.79 91.040 141.540 8788.73 8847.43 7475.39 S 3301.77 E 5969054.04 N 667920.59 E 5.159 8006.34 13082.80 90.550 135.620 8787.43 8846.13 7545.84 S 3363.94 E 5968984.97 N 667984.28 E 6.318 8099.78 13177.16 90.000 131.070 8786.98 8845.68 7610.59 S 3432.54 E 5968921.74 N 668054.29 E 4.857 8192.29 13272.21 89.690 127.750 8787.23 8845.93 7670.93 S 3505.97 E 5968863.03 N 668129.02 E 3.508 8284.00 13367.42 89.510 122.890 8787.90 8846.60 7725.96 S 3583.63 E 5968809.72 N 668207.87 E 5.108 8373.84 13462.25 89.750 121.990 8788.51 8847.21 7776.82 S 3663.66 E 5968760.62 N 668289.00 E 0.982 8461.66 13556.18 90.180 121.020 8788.57 8847.27 7825.91 S 3743.74 E 5968713.30 N 668370.14 E 1.130 8548.05 13649.66 92.210 120.170 8786.62 8845.32 7873.47 S 3824.18 E 5968667.51 N 668451.61 E 2.354 8633.41 13742.31 92.960 118.650 8782.44 8841.14 7918.92 S 3904.81 E 5968623.84 N 668533.21 E 1.828 8717.16 13835.35 95.050 118.770 8775.94 8834.64 7963.50 S 3986.20 E 5968581.06 N 668615.57 E 2.250 8800.64 13929.82 96.220 116.810 8766.67 8825.37 8007.33 S 4069.37 E 5968539.06 N 668699.67 E 2.408 8884.54 14023.72 97.030 114.740 8755.83 8814.53 8047.89 S 4153.36 E 5968500.36 N 668784.53 E 2.354 8966.24 14118.00 93.880 112.390 8746.87 8805.57 8085.40 S 4239.37 E 5968464.74 N 668871.34 E 4.162 9046.63 14211.22 92.890 107.200 8741.36 8800.06 8116.90 S 4326.90 E 5968435.17 N 668959.54 E 5.658 9123.01 14306.37 93.940 102.800 8735.69 8794.39 8141.48 S 4418.62 E 5968412.61 N 669051.78 E 4.746 9196.16 ) 14399.66 94.120 100.660 8729.13 8787.83 8160.40 S 4509.73 E 5968395.69 N 669143.28 E 2.296 9264.35 14494.73 93.200 96.150 8723.06 8781.76 8174.26 S 4603.56 E 5968383.89 N 669237.39 E 4.832 9329.99 14588.01 92.090 94.150 8718.76 8777.46 8182.62 S 4696.36 E 5968377.57 N 669330.35 E 2.450 9390.55 14682.96 90.860 89.680 8716.31 8775.01 8185.79 S 4791.20 E 5968376.48 N 669425.24 E 4.881 9448.06 14775.17 90.800 85.980 8714.97 8773.67 8182.30 S 4883.31 E 5968381.99 N 669517.26 E 4.013 9498.57 14868.31 89.020 83.540 8715.12 8773.82 8173.80 S 4976.05 E 5968392.53 N 669609.79 E 3.243 9545.34 14962.93 88.950 80.770 8716.80 8775.50 8160.89 S 5069.76 E 5968407.49 N 669703.19 E 2.928 9589.09 15056.73 89.020 78.390 8718.46 8777.16 8143.92 S 5162.00 E 5968426.47 N 669795.03 E 2.538 9628.68 15150.46 86.860 76.960 8721.83 8780.53 8123.93 S 5253.50 E 5968448.47 N 669886.07 E 2.763 9665.37 15245.86 86.860 76.710 8727.05 8785.75 8102.24 S 5346.25 E 5968472.19 N 669978.33 E 0.262 9701.40 15338.27 87.410 76.050 8731.67 8790.37 8080.50 S 5435.95 E 5968495.89 N 670067.53 E 0.929 9735.63 27 June, 2002 - 10:34 Page30f5 DriliQuest 2.00.08.005 '. ~~~7i.": Sperry-Sun DrillingServittes Survey Report fOrl-31A I; Your Ref: API5tJ( 2m41101 Job No. AKZZ22015, Surveyed: 21 May, 2002 " BPXA North Slope Alaska PBU - WOA E Pad Measured Sub-Sea Vertical Local Coordinates Global CoordInates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 15433.13 87.970 76.260 8735.50 8794.20 8057.82 S 5527.98 E 5968520.58 N 670159.04 E 0.630 9770.44 ) 15524.69 88.830 76.130 8738.05 8796.75 8035.98 S 5616.86 E 5968544.36 N 670247.42 E 0.950 9804.11 15572.00 88.830 76.130 8739.02 8797.72 8024.64 S 5662.78 E 5968556.71 N 670293.08 E 0.000 9821.46 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 144.610° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15572.00ft., The Bottom Hole Displacement is 9821.51ft.. in the Direction of 144.790° (True). Comments \........ Measured Depth (ft) Station Coordinates TVD Northings Eastlngs (ft) (ft) (ft) Comment 11324.57 11331.00 15572.00 8610.27 8612.74 8797.72 5969.59 S 5974.62 S 8024.64 S )' 2735.19 E 2738.35 E 5662.78 E Tie On Point Window Point Projected Survey 27 June. 2002 - 10:34 Page4of5 DrillQuest 2.00.08.005 North Slope Alaska Survey tool program for E-31A -- Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 11324.57 0.00 8610.27 27 June, 2002 - 10:34 To Measured Vertical Depth Depth (ft) (ft) 11324.57 15572.00 Sperry-Sun Drill/"fJ Services Survey Report torE-BfA Your Ref: API5Ot12fU41101 Job No. AKZZ22075, Surveyed: 21 May, 2002 8 BPXA PBU_WOA E Pad Survey Tool Description 8610.27 AK-3 BP _HM - BP High Accuracy Magnetic (E-31) 8797.72 AK-6 BP _IFR-AK (E-31A) Page 5 of 5 DrillQuest 2.00.08.005 ) ) ~ /----", ~C::D-/75 28-Jun-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well E-31A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,324.57' MD Window / Kickoff Survey: 11,331.00' MD Projected Survey: 15,572.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager RECE\VED Attachment(s) !1 I' f") nL' n02 ,,;UL. <.-. .v Alaska Oil & Gas Cons. commisSiOn Ancboœge NorfhSIQl/le ..ka SeKA PBU_WOA Efl¡ ..;~ E-31A'L--- Job No. AKMW22075, SUM"': 21 May, 2002 ') SUR VEY RIJEPO R T 27 June, 2002 Your Ref: API 500292241101 Surface Coordinates: 5976455.20 N, 664455.63 E (70° 20' 31.1168" N, 148039' 54.9867" W) Kelly Bushing: 58. 70ft above Mean Sea Level ) ~r1f'"1y-...., DRILLING SUi!rcVIc:es A Halliburton Company Survey Ref: svy11221 . . Sperry-Sun Drfll~ '!.Services I) Survey Reportlot' ,,' ,'., YourRfíf: APt ~f,i,.f'I ", Job No. AKMW22075, . SufVfJ ld: 21 May, 2002 BPXA North Slope Alaska PBU - WOA E Pad Measured Sub-Sea Vertical Local Coordinates Global CoordInates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 11324.57 67.230 147.940 8551.57 8610.27 5969.59 S 2735.19 E 5970547.05 N 667321.12 E 6450.64 Tie On Point ) MWD Magnetic -.. 11331.00 67.530 147.740 8554.04 8612.74 5974.62 S 2738:35 E 5970542.09 N 667324.38 E 5.480 6456.57 Window Point 11412.83 68.910 150.970 8584.41 8643.11 6039.98 S 2777.07 E 5970477.59 N 667364.53 E 4.035 6532.28 11441.33 69.380 152.640 8594.56 8653.26 6063.46 S 2789.65 E 5970454.40 N 667377.62 E 5.719 6558.70 11475.17 68.860 158.550 8606.63 8665.33 6092.23 S 2802.71 E 5970425.92 N 667391.31 E 16.389 6589.72 11535.32 69.510 169.090 8628.06 8686.76 6146.14 S 2818.34 E 5970372.37 N 667408.11 E 16.412 6642.72 11566.10 69.320 173.010 8638.88 8697.58 6174.59 S 2822.82 E 5970344.02 N 667413.22 E 11.938 6668.51 11597.25 69.530 173.800 8649.83 8708.53 6203.56 S 2826.17 E 5970315.13 N 667417.20 E 2.468 6694.07 11629.03 70.030 174.050 8660.81 8719.51 6233.22 S 2829.33 E 5970285.55 N 667421.01 E 1.738 6720.07 11660.41 69.910 176.070 8671.56 8730.26 6262.59 S 2831.86 E 5970256.24 N 667424.19 E 6.060 6745.48 11690.56 69.590 173.960 8682.00 8740.70 6290.76 S 2834.32 E 5970228.12 N 667427.27 E 6.651 6769.88 11722.82 70.840 169.270 8692.92 8751.62 6320.78 S 2838.75 E 5970198.21 N 667432.35 E 14.217 6796.92 11753.07 70.640 166.790 8702.90 8761.60 6348.72 S 2844.67 E 5970170.41 N 667438.89 E 7.768 6823.12 11783.78 70.360 166.930 8713.16 8771.86 6376.91 S 2851.25 E 5970142.37 N 667446.08 E 1.008 6849.91 11817.01 70.290 166.910 8724.34 8783.04 6407.39 S 2858.34 E 5970112.06 N 667453.83 E 0.218 6878.86 11877.64 69.970 166.070 8744.95 8803.65 6462.83 S 2871.66 E 5970056.92 N 667468.37 E 1.406 6931.77 11910.11 71.990 166.240 8755.53 8814.23 6492.63 S 2879.00 E 5970027.29 N 667476.36 E 6.241 6960.32 11940.17 75.330 167.110 8763.99 8822.69 6520.70 S 2885.65 E 5969999.37 N 667483.62 E 11.453 6987.05 ) 11971.50 77.850 167.720 8771.25 8829.95 6550.44 S 2892.29 E 5969969.78 N 667490.91 E 8.263 7015.14 12002.92 80.610 166.630 8777.12 8835.82 6580.53 S 2899.14 E 5969939.85 N 667498.42 E 9.422 7043.64 12037.08 81.290 166.550 8782.50 8841.20 6613.35 S 2906.96 E 5969907.21 N 667506.96 E 2.004 7074.93 12069.34 84.270 165.810 8786.55 8845.25 6644.42 S 2914.61 E 5969876.31 N 667515.29 E 9.514 7104.68 12099.34 85.510 164.730 8789.22 8847.92 6673.32 S 2922.20 E 5969847.59 N 667523.52 E 5.472 7132.64 12132.17 88.220 163.300 8791.02 8849.72 6704.83 S 2931.23 E 5969816.29 N 667533.23 E 9.330 7163.56 12164.47 90.680 159.760 8791.33 8850.03 6735.45 S 2941.46 E 5969785.89 N 667544.13 E 13.345 7194.45 12192.31 90.250 158.420 8791.10 8849.80 6761.46 S 2951.40 E 5969760.11 N 667554.64 E 5.055 7221.41 12237.77 89.820 159.250 8791.08 8849.78 6803.85 S 2967.81 E 5969718.09 N 667571.98 E 2.056 7265.47 12331.21 90.250 160.310 8791.02 8849.72 6891.53 S 3000.10 E 5969631.14 N 667606.19 E 1.224 7355.65 12425.57 90.740 159.100 8790.20 8848.90 6980.03 S 3032.83 E 5969543.38 N 667640.85 E 1.383 7446.75 12519.25 90.120 156.500 8789.50 8848.20 7066.75 S 3068.22 E 5969457.45 N 667678.13 E 2.853 7537.95 27 June, 2002 - 10:38 Page2of5 DriliQuest 2.00.08.005 .~'".'i' I) "', . Sperry-Sun DrillittgiServices Survey Report for iMWO Your Ref: API_' ¡" 1 Job No. AKMW22075, Sul'Vfiþd: 21 May, 2002 BPXA North Slope Alaska PBU - WOA E Pad Measured Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 12614.10 89.320 154.660 8789.96 8848.66 7153.115 3107.43 E 5969371.97 N 667719.23 E 2.115 7631.06 " ) 12707.25 89.880 151.420 8790.61 8849.31 7236.135 3149.66 E 5969289.91 N 667763.26 E 3.530 7723.19 --- 12801.08 90.250 152.520 8790.51 8849.21 7318.955 3193.75 E 5969208.07 N 667809.16 E 1.237 7816.25 12894.43 90.430 146.650 8789.95 8848.65 7399.42 S 3240.99 E 5969128.66 N 667858.16 E 6.291 7909.20 12988.79 91.040 142.280 8788.74 8847.44 7476.185 3295.81 E 5969053.12 N 667914.65 E 4.676 8003.53 13082.80 90.550 136.360 8787.44 8846.14 7547.435 3357.06 E 5968983.23 N 667977.44 E 6.318 8097.09 13177.16 90.000 132.940 8786.98 8845.68 7613.74 S 3424.18 E 5968918.41 N 668046.00 E 3.671 8190.01 13272.21 89.690 130.970 8787.24 8845.94 7677.28 S 3494.86 E 5968856.43 N 668118.06 E 2.098 8282.75 13367.42 89.510 127.850 8787.91 8846.61 7737.71 S 3568.41 E 5968797.63 N 668192.92 E 3.282 8374.61 13462.25 89.750 130.240 8788.52 8847.22 7797.44 S 3642.05 E 5968739.53 N 668267.85 E 2.533 8465.96 13556.18 90.180 121.020 8788.58 8847.28 7852.10 S 3718.32 E 5968686.55 N 668345.30 E 9.826 8554.68 13649.66 92.210 126.910 8786.62 8845.32 7904.29 S 3795.79 E 5968636.08 N 668423.90 E 6.663 8642.10 13742.31 92.960 120.500 8782.44 8841.14 7955.63 S 3872.75 E 5968586.44 N 668501.96 E 6.959 8728.52 13835.35 95.050 121.010 8775.94 8834.64 8003.08 S 3952.50 E 5968540.74 N 668582.74 E 2.312 8813.39 13929.82 96.220 111.040 8766.64 8825.34 8044.29 S 4036.87 E 5968501.40 N 668667.99 E 10.575 8895.84 14023.72 97.030 112.590 8755.81 8814.51 8078.95 S 4123.46 E 5968468.65 N 668755.32 E 1.853 8974.25 14118.00 93.880 107.820 8746.84 8805.54 8111.34 S 4211.51 E 5968438.20 N 668844.05 E 6.043 9051.64 14211.22 92.890 104.650 8741.34 8800.04 8137.35 S 4300.84 E 5968414.15N 668933.94 E 3.557 9124.59 ) 14306.37 93.940 101.220 8735.67 8794.37 8158.61 S 4393.39 E 5968394.93 N 669026.94 E 3.764 9195.52 14399.66 94.120 103.310 8729.11 8787.81 8178.38 S 4484.32 E 5968377.16 N 669118.28 E 2.243 9264.30 14494.73 93.200 97.920 8723.04 8781.74 8195.84 S 4577.54 E 5968361.74 N 669211.86 E 5.740 9332.52 14588.01 92.090 93.530 8718.73 8777.43 8205.14 S 4670.23 E 5968354.49 N 669304.73 E 4.849 9393.78 14682.96 90.860 90.480 8716.29 8774.99 8208.46 5 4765.08 E 5968353.25 N 669399.63 E 3.463 9451.41 14775.17 90.800 85.360 8714.95 8773.65 8205.11 S 4857.19 E 5968358.61 N 669491.64 E 5.552 9502.03 14868.31 89.020 83.920 8715.10 8773.80 8196.41 5 4949.92 E 5968369.34 N 669584.15 E 2.458 9548.64 14962.93 88.950 81.170 8716.77 8775.47 8184.145 5043.71 E 5968383.67 N 669677.66 E 2.907 9592.96 15056.73 89.020 78.980 8718.44 8777.14 8167.97 S 5136.09 E 5968401.86 N 669769.66 E 2.336 9633.28 15150.46 86.860 77.890 8721.80 8780.50 8149.20 S 5227.85 E 5968422.64 N 669860.99 E 2.581 9671.11 15245.86 86.860 77.770 8727.03 8785.73 8129.12 S 5320.97 E 5968444.76 N 669953.64 E 0.126 9708.67 15338.27 87.410 76.990 8731.65 8790.35 8108.95 S 5411.03 E 5968466.90 N 670043.24 E 1.032 9744.39 27 June, 2002 - 10:38 Page30f5 Dríl1Quest 2.00.08.005 . t'.. .' 8 BPXA North Slope Alaska PBU_WOA E Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastltlgs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 15433.13 87.970 77.620 8735.47 8794.17 8088.12 S 5503.49 E 5968489.75 N 670135.22 E 0.888 9780.96 ì 15524.69 88.830 77.810 8738.03 8796.73 8068.65 S ~ 5592.92 E 5968511.18N 670224.20 E 0.962 9816.87 "-- ~ 8058.66 S J 15572.00 88.830 77.810 8739.00 8797.70 5639.16 E 5968522.18 N 670270.21 E 0.000 9835.51 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 144.610° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15572.00ft., The Bottom Hole Displacement is 9835.76ft.. in the Direction of 145.017° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastlngs (ft) (ft) (ft) Comment 11324.57 11331.00 15572.00 8610.27 8612.74 8797.70 5969.59 S 5974.62 S 8058.66 S 2735.19 E 2738.35 E 5639.16 E Tie On Point Window Point Projected Survey ) 27 June, 2002 - 10:38 Page4of5 DrillQuest 2.00.08.005 !-'.. North Slope Alaska Survey tool program for E-31A MWD --- From Measured Vertical Depth Depth (ft) (ft) 0.00 11324.57 0.00 8610.27 27 June, 2002 - 10:38 To Measured Vertical Depth Depth (ft) (ft) 11324.57 15572.00 I) Sperry-Sun DrilNMServices Survey Report for E-JfÃIfWD Your Ref: API_~1101 Job No. AKMW22075, SufVèIMI: 21 May, 2002 BPXA PBU - WOA E Pad Survey Tool Description 8610.27 AK-3 BP _HM - BP High Accuracy Magnetic (E-31) 8797.70 MWD Magnetic (E-31A MWD) Page50f5 Dril/Quest 2.00.08.005 ) ) j,~ ~ '-, ~~!A~EmF !A~!A~~~fÆ II ALAS IiA 0 IL AND GAS CONSERVATION COMMISSION / TONY KNOWLES, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Robertson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AI( 99519-6612 Re: Prudhoe Bay Unit E-31A BP Exploration (Alaska), Inc. Permit No: 200-175 (REV) Sur Loc: 608' SNL, 501' WEL, Sec. 06, T11N, R14E, UM Btmhole Loc. 3307' SNL, 5136' EWL, Sec. 08, T11N, R14E, UM Dear Mr. Robertson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit E-31A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (~J ~. ~-/ C~; ~chsli Taylor Chair . BY ORDER OF THE COMMISSION DATED this 31st day of January, 2002 jjcÆnclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. \;J6A 'I ;O{Dl-. ~ STATE OF ALASKA,-.., I ALASKA - AND GAS CONSERVATION COMfY; JION ~ I ~J (J? PERMIT TO DRILL _1c- \t~\-()") 20 MC 25.005 Revised: 01115/02; Change BHL 1a. Type of work [] Drill II Redrill 11 b Type of well [] Exploratory [] ßtratigraphic Test II Development Oil [] Re-Entry [] Deepen' [] Service [] Development Gas [¡J'Single Zon~ [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 60.2' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028304 4. Location of well at surface 7. Unit or Property Name 608' SNL, 501' WEL, SEC. 06, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number / 1994' SNL, 2376' EWL, SEC. 08, T11 N, R14E, UM E-31 A At total depth 9. Approximate spud d~1} 3307' SNL, 5136' EWL, SEC. 08, T11 N, R14E, UM .fJ2/JiJf1IO'2~ OIo').. Amount $200,000.00 12. Distance to nearest property line /13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028303, 142' MD E-19AIsS42'awayat 12758'MD 2560 15654' MD /8770' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 MC 25.035 (e) (2)} Kick Off Depth 11500' MD Maximum Hole Angle 96 . Maximum surface 2470 psig, At total depUt (TVD) 8800' /3350 psig 18. Casi~:rogram Specifications T çp Setting DePthBotom Quantitv of Cement Hole CasinQ Weiaht Grade CouDlin<; LenQth MD TVD MD TVD ./ ljnclude staae data) 6-118" 4-112" 12.6# L-aO BTC-M 4304' 11350' 8624' 15654' 8770' 606 ~~~~IVl:u ! 11. Type Bond (See 20 MC 25.025) Number 2S10030263O-277 Casing Structural Conductor Surface Intennediate Production Uner Uner 13394 feet 8831 feet 11773 feet 8749 feet Length Size Plugs (measured) .JAM 3 0 ïO02 Alaska 011 & Gas COns. Commission Anchoraae Abandonment Plug: 45 Bbls Class 'G', TOC at 11773' (07/01) (Tubing cut at 8600') 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Junk (measured) 78' 20" 3882' 13-318" 10638' 9-518" 2244' 7" 820' 4-112" Cemented MD TVD 280 cu ft Arcticset (Approx.) 110' 110' 2909 cu ft PF, 432 cu ft Class 'G' 3918' 3533' 1900 cu ft Class 'G' 10670' 8355' 480 cu ft Class 'G' 10450' -12694' 8259' - 8844' Uncemented Slotted Uner 12575' - 13394' 8841' - 8831' Perforation depth: measured None true vertical None II Filing Fee [] Property Plat 0 BOP Sketch [J Diverter Sketch 1m Drilling Program 1m Drilling Fluid Program [J Time vs Depth Plot 0 Refraction Analysis [J Seabed Report [J 20 MC 25.050 Requirements Contact Engineer NamelNumber. Phil Smith, 564-4897 Prepared By Na~urnber. Terrie Hubble. 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ~:~t~~~t~:~X1< Hydrogen Sulfide Measures lX'Ves 0 No Directional Survey Required §a'Yes 0 No RequiredWorkingPressureforBOPE D2K D3K D4K D5K D10K D15K D3.5KpsiforCTU Other. T€~t. B. 0 r' é -f<J 3500 f?Þ<. ~ ~ ~ Approved By Original Signed ~y Commissioner ~ :~~ion Date f 3 J ð 2- Fonn 10-401 Rev. 12-01-85 CrllhlllY Oeeh8~ R I h I f\f ~ J bm In Triplicate 20. Attachments ~ Permit to Drill- Revision to pe. .t 200-175 ,"-"'" I Well Name: I E-31A Drill and Complete Plan Summary (Revised) I Type of Well (service I producer I injector): 1 Sidetrack Horizontal Producer Surface Location: Estimated Target Location: Sadlerochit Zone 1 Intermediate Target: Bottom Hole Location: x = 664,455.20 608' FNL , 501' FEL X = 667,501.76 1994' FNL , 2903' FEL X = 669,042.15 3503' FNL, 1401' FEL X = 670,295.09 3307' FNL , 143' FEL Y = 5,976,455.63 Sec. 06, T11N, R14E Umiat Y = 5,969,855.81 TVDss 8785 Sec. 08, T11N, R14E Umiat Y = 5,968,381.22 TVDss 8720 Sec. 08, T11 N, R14E Umiat Y = 5,968,604.55 TVDss 8710 Sec. 08, T11N, R14E Umiat / I Rig: I Nabors 2ES I AFE Number: 14P1565 I Estimated Start Date: I 02/05/2002 I 1 MD: 115,654' I 1 Operating days to complete: 120.5 ITVD: 18770' I I RKB: 160.2' I BFIMS: 130.2' I 1 Well Design (conventional, slimhole, etc.): I Horizontal Sidetrack out of 7" liner ,/ I Objective: I Zone 1 (13P /14P), Sadlerochit CasinWTubing Program Hole Size Csg/ WtlFt Grade Conn Length Top Btm Tbg O.D. MDnvD MDnvD 61/8" 4%" 12.6# L-80 BTC-Mod -4304' 11350' /8624' 15,654' /8770' Tubing 4%" 12.6# L-80 BTC-Mod -11,310' GL 11,350'/8620' Directional KOP: 111,500' MD Maximum Hole Angle: -720 In original wellbore at planned KOP -96.10 Through reservoir section of planned sidetrack 1 ~. ,~ Permit to Drill- Revision to pe, ,t 200-175 ~ Close Approach Wells: . Center-center of 676' with P&A'd section of C-18 @ 14,240': Passes minor risk criteria . Center-center of 1155' with P&A'd section of E-14 @ 11,500': Passes minor risk criteria . Center-center of 686' with P&A'd section of E-19 @ 12,350': Passes minor risk criteria . Center-center of 542' with well E-19A @ 12,758'. This well is currently on production at 200-300 BOPD without gas lift. The close approach depth is in the reservoir section the planned 5-32A and adjacent to the production liner below the production packer of E- 19A and therefore is considered minor risk. Standard MWD Surveys from kick-off to TD with IFA/Cassandra. Survey Program: Mud Program WIndow MllliT Mud Properties: Quickdri~N I Whipstock Window in 7" 1 Density (ppg) Viscosity I PV I YP I tauO I MBT I pH I APIFI I 8.4-8.5+ 45 - 60 5-8 25-35 5-8 <3 8.5 - 9.0 N/C Production Mud Properties: Quickdril-N 16 1/8" hole section 1 Density (ppg) I Viscosity I PV YP I tauO I MBT I pH I API FI I 8.4 - 8.5+ 45-60 5-8 20 - 25 5-8 <3 8.5 - 9.0 N/C LogQing Program 6 1/8" Production: Sample Catchers - None Drilling: MWD IGR 1 ABI Real time + NeulDen recorded over entire interval Open Hole: None Cased Hole: None Cement Program I Casing Size 14 W' Production Liner Basis: Lead: None Tail: Based on 82' of 4~" shoe track, 4154' of open hole with 40% excess, 150' of 4~" x 7" liner lap, and 200' oý7" x 4" DP annulus volume. Tail TOC: -11,350' r MD (8624'TVD).- Liner top. I Fluid Sequence & Volumes: Pre 5 Bbls Water Flush Spacer Lead Tail 40 bbls Alpha Spacer at 9.8 ppg None / ./' 108 bbl/606 ft3/510 sks of Halliburton 'G' at 15.6 ppg and 1.19 cf/sk, BHST 1900 TT = Batch Mix + 4 to 4.5 hrs 2 ,-, Permit to Drill- Revision to pe. t 200-175 ~ Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- . Maximum anticipated BHP: .,.a350 psi @ 8800' TVDss - Ivishak . Maximum suñace pressure: 2470 psi @ suñace (based on BHP and a full column of gas from TD @ 0.10 psilft) /' 3500 psi 8.6 ppg seawater /7.2 ppg Diesel . Planned BOP test pressure: . Planned completion fluid: Disposal . No annular injection in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Formation Markers Formation Tops (wp25) MD TVDss Comments KINGAK Above casing window T JFITOP KINGAK F " " T JDITOP KINGAK D " " T JAITOP KINGAK A " " SAG RIVER SS WD- TSHU/SHUBLIK " " WD- TElL " " WD-TSADITZ4B " " WD- TCGL " " WD_BCGL " " KICK OFF ZONE: TZ2C 11 ,500' -8607 7.2 ppg EMW expected pore pressure WD-24P 11,530' -8620 " " WD-21P 11,792' -8708 " " WD- TZ1 B 11,898' -8742 " " WD- TDF/13N 12,000' -8767 " " BSAD -8785 Not penetrated TD Criteria: Target polygon (nearby well drainage) 3 ~ Permit to Drlll- Revision to pel ~ 200-175 ,~, Sidetrack and Complete Procedure Summary Ria Operations: 1. MIRU Nabors 2ES. 2. Pull BPV. Circulate out freeze protection an.9;displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull tubing from the cut at 8600' MD. POOH laying down 3*" completion. 5. RIH with dressing mill to the top of the jet cut and dress off the cut stub. 6. RIH with overshot and latch fish at 8600'. 7. RU e-line. Jet cutthe tubing at or below 11,517' MD. RD e-line. / 8. Recover 3 *" tubing from 8600' to 11,517'. ./" 9. Drift the 7" liner with a 6" mill and casing scraper. Pressure test the well to 3500 psi. 10. RIH with 7" Baker whipstock assembly. Orient whipstock as desired and set on cut stub. Mill window in 7" casing at 11,500' MD. POOH. 11. MU 6-1/8" drilling assembly with MWDfTriple Combo + ABI and RIH. Kick-off and drill the 6-1/8" production interval, building at -12°/100' to horizontal, targeting the Zone 1 sands. Drill ahead to an estimated total depth of 15,654' MD. /' 12. Run and c~ent a 4 *",12.6# solid production liner throughout the 6-1/8" wellbore and back into the 7" casing for 150' liner lap. Displace well to seawater above liner top. POOH. /' 13. Test the 4 *" and 9-5/8" casing from the 4 *" landing collar to surface to 3500 psi for 30 minutes. 14. PU Halliburton 2*" perf guns and RIH on DP. Perforate -1700' of Zone 1 in the horizontal section POOH LD DP. . 15. Run 4 *",12.6# L-80 completion tying into the 4 *" liner top. .,,/ 16. Set packer and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 18. Freeze protect the well to -2200' and secure the well. 19. Rig down and move off. Post-Ria Work: 1. MIRU slickline. Pull the ball and rod I RHC plug from 'X' nipple below the production packer and install gas lift valves. Flow back well into portable test separator. 4 ~ Permit to Drlll- Revision to pe. .t 200-175 ~ Job 1: MIRU Hazards and Contingencies » No wells will require shut-in for the rig move to E-31. Adjacent wells E-12 & E-13 are 74' & 36' distance, respectively, from the proposed wellhead. Establish a minimum rig distance of 5' from each of the adjacent wellheads or wellhouses. Discuss the move at a pre-job safety meeting and designate a spotter to ensure that there is no danger of collision. » E Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Relevant H2S data from the pad is as follows: ./ Closest BHL Wells / c-18 6 ppm 12/97 E-19 No recorded H2S Adjacent producers at Suñace: E-12 No recorded H2S E-13 No recorded H2S The maximum recorded level of H2S on the pad was <50 ppm. > Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. Job 2: Decomplete Well Hazards and Contingencies » The perforations and bottom section of this well should be isolated by 2 barriers (the cement plug and the seawater). The plug has been tested to 1000 psi as part of the pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. » After the pre rig work was performed, the sidetrack was re-designed for a deeper kickoff. Therefore a second tubing cut will be required below the new planned KOP at 11,500' with a 2 W supercutter (jet type) after dressing off and latching onto the jet cut at 8600'. Include an open drain sub above the dressing mill / overshot to allow circulating the cutter downhole. Do not run jars. Cutter should be run on rollers. » NORM test all retrieved well head and completion equipment. Job 3: Run Whipstock Hazards and Contingencies » Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which may have settled out. Job 7: Drill 6 1/8" Production Hole Hazards and Contingencies » E-31 and its sidetrack targets lie in the GD area of southem E Pad. The targets are located on a NNW/SSE trending horst block bounded to the east by the midfield graben. The E-31A wellbore path is planned along the middle of this horst block, oriented NNW to SSE. There is a potential for encountering sub-seismic faults «15 ft) from 12110 MD to 12650 MD. Drilling problems are not expected from these small faults. A third fault mayor may not be present in the updip end of the horizontal wellbore at 14,150' MD. There appears to be some shale in the Zone 1 section near the potential fault at the end of the horizontal wellbore, 14150 MD, offering some additional smearing in the gouge zones, and decreasing the odds for large fluid losses. » Several wells in the vicinity and along the wellpath will require attention to close approach issues. See the "Directional" section for details. > Avoid drilling into the base of Sadlerochit while geosteering horizontal section. Communicate with all team members listed on page 1 before changing any plan beyond minor inclination changes in zone 1. If the BSad is drilled, discontinue drilling until discussion has been held with team members regarding plugback or open hole sidetrack. The Kavik shale is too unstable to continue drilling with low mud weight, 5 ~ Permit to Drill- Revision to pel' 200-175 ,-" especially at horizontal. ~ Review the pad data sheet for relevant information on stuck pipe and lost circulation. Job 9: Install 4%" Production Liner Hazards and Contingencies ~ Differential sticking could be a problem. The 8.5 ppg Ouickdril will be -600 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Job 10: DPC Perforate Hazards and Contingencies ~ The well will be perforated overbalanced after running DPC cased hole logs. Ensure all personnel are well-briefed on Halliburton's perforating procedures and that all responsibilities are understood. Essentially personnel only should be present on the rig floor while making up DPC guns. ~ Expect to lose fluid to the formation after perforating. Have ample sea water on location and be prepared with LCM if necessary. Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psiaat 100° F. Job 13: ND/NU/Release Rig Hazards and Contingencies ~ See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. 6 ~, .----". Riasite Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE / ...¡ This Drill Site is not a designated H2S pad. ...¡ Several small faults may be crossed in the horizontal section though none are deemed high risk of losses. Be prepared with LCM and follow the decision tree in the even of lost circulation. ...¡ Drilling too deep and into the Kavik shale underlying the target zone may be the biggest risk in the success of this well. Any steering that results in well path deeper than planned must first be agreed with all appropriate team members. ...¡ There are several close approach wells that pose a minor risk. Watch for MWD indications of magnetic interference between 12,000' and 14,500' MD. ...¡ Watch for trapped pressure between blank sections of perf guns while laying down same. Allow Halliburton to brief the crew on safety precautions. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 2.0 Rigsite Hazards and Contingencies Page I of 1 ",--, TREE = If' 5M CAÆON WB.LHEAD = 13-318" 5M FMC ACIlJ&. TOR = BAKER KB. B.EV = 65.20' BF. B.EV = 35.25' KOP= 1291' Max Ange = 93 @ 13393' DatumMD= 13007' DatumTVD = 8800' SS I 13-318" CSG, 68#, L-80, 10=12.415 H 3925' ~ I MinimLlT1ID = 2.635 @ 12245' I 3-1(2" SWN NIPPLE (TOÞ7"LNRH 10450' r-,. I 9-5/8" CSG, 47#, NSCc. 10= 8.681" H 10670' I- I 3-112"TBG, 9.2#, L.80, 0.0087 bpf, 10= 2.992" H 12256' roÞOF4-112" LNR H 12574' I 7" LNR, 26#. NT -80.0.0383 bpf, ID = 6.276" H 12694' )--- PER=ORA lION SlJ.1M\RY REF LOG: ANGLE A T TOP PERF: Note: Refer Ð Production œ for nstorical perf data SIZE SPF NTERoI AL OpnlSqz DATE SLOTTIÐ LINffi E-31 . - -.! r"--, SA ÆTY NOTES: SIDETRA CK SOiIÐULED 10115 PER 6/5 SCt-EDl1.E 1973' H3-1/2"011S XBDLAN)I~ NP, 10 =2.75" ~ GAS LIFT MAN~B.S ST MD TVD œv TYÆ VLV LATOi VLV 3 4901 4266 42 CAM MAG RK 2 8365 6844 41 CAM MAG RK 1 9305 7547 43 CAM MAG RK Dt\1E -v- --I 8 60 0' . 4-112" SLTDLt-R, 12.6#,0.0152 bpf,lD = 3.953" DA 1E REV BY OOMAENTS 12/11/93 MOO 000 K:>RIZ OOWLETION 02/13101 SJS.OAA CONVERlEDTOCANVAS 03108101 SIS-M> FINAL 07/1<4101 RW1P CORREClIONS 08102/01 D<fTP JET cur lBG HJETCurlBGON07/30AJ1 10183' H3-1/2"SWSNP,ID=2.75" 110. 11773' HCMT RUG, 15.8 PÞG ClASS G COIL - 07/26AJ1 I :& ---t 12191' H7 x3-1/2"BAKERSAB A<R, 10= 3.931" I 12228' H3-1/2"SWS NP,ID=2.75" I 12245' H3-1/2" SWN NP.ID =2.635" 12256' H3-1/2"WlEG,IO=2.992" I 12574' H7 x 4-112 TlWSS PKR WI SOOlP I-EAD,ID=4.000" Dt\ 1E ReI BY OOMAENTS 08l03AJ1 DMTP CEtÆNT PLUG 12580' HPORTIÐJOINT I 12619' H4-112" BLAN< lBG I H 13393' I PRUDK:>EBAY UNrr waL: 6-31 PERMT I'-b: 93-1610 ARNe: 50-029-22411-00 Sec. 6. T11N, R14E BP exploration (Alas ka) waLl.EA~3.S/S" SM FMC ACTUA~ Baker KB. aEV = 6S.2' BF. aEV = 3S.2S KOP= 1291' Max Angle = Datum t.Ð = Datum lVD= -, 13007 S8OO' ss 1 13-3IS" 68#. L-SO 12.41S" Ð I 3925' I~ 4-1/2" 12.6#/ft L-80 BTC-mod Tubing Minimum ID = 3.725" XN nipple PERFORA ilON SlJMMA.RY R8" LOG: ANGLEATTOPÆRF: I Note: Refer to Production DB for historical pert data SIZE SPF MER\( AL OpnlSqz DATE I Jet tubing, 3-112" Top of cement 111,550' 1 11,773' I 7" 26#1ft NT-SO I 12,694' I DA 1E REV BY COMM:NTS 12/11/93 Original CofT1)letion 01/15102 PGS Sidetrack Proposed CofT1)letion ~ SAFETY NOTES: E-31A l J 12200' I X-Nipple. 3.S13" Ð I STA MD lVD DEV TYPE MAN LATCH ~ L GLM4 TBD GLM3 TBD GLM2 TBD GLM1 TBD 4 1/2 x 1 1/2" 4 1/2 x 1 1/2" 4112x 1" 4112x 1" ~ :2 ~ 110,450' I I 1 I 1 1 7" Liner Top 1 9-S/S" 47# NSCC I 1 7" x 4-112" Aa- I 4-112" X 3.S13" Ð 4-112" XN 3.72S" Ð I WLEGlLiner Top I 4-112" Hanger/Pkr I 7" window - ) I ~ r10,670' 111,250' 111,270' 111,315' 11 ,335' 111,350' 1 111,360' I 111,500' 1 1 1 4-1/2" X 3.S13" Ð I 1 I 8 g , \ 5 J '" ~ :$i ...... ~ ,~ F! j 4-1/2" 12.6 #/ft L-80 BTC MD MD '" WellTD 15,654' 8 !') PBTD 15,564' . . - ------- - 1 w ....... Original 4-112" slotted liner PBTD 13,393' MD PRUDHOE BA Y ~rr I AURORA FRD WaL: E-31A PffiMIT No: 93-1610 API No: 50-029-22411-01 Prudhoe Bay Unit C1NA9JÐŒ 11m ò (UMI"ANYIJETAn.s 81'- c_--~ ==: ~~-- F..........., ER_'-C- W_"'- R""- ItEFEItEN<1i INFORMATION C"~.:::W~Ö: tt::; ::"C~ £.II. T... """" _(\'5)-.110<.3110-_' ~.:=.. --= =- c=.. All TVD depths are ssTVD plus 60.2' for RKBE. FORMATION TOP DETAILS No. TVDPa<h MDPalh Fonnation I 8620.20 II 348.35 WI).. TZ2C 2 8750.20 11742.24 WI)..TZIB 3 8800.20 11891.90 WD-TDFI13N 4 8837.20 12021.10 12N 6800- CASINO DETAILS No. TVD 8770.20 MD Name 15654.03 41/2" 7200- 7600- 'C ~ ~ ! ;¡ .t > sooo- l 8400 !lURV¡:Y PROGRAM """"m """" T. """- "!OII.OO I~.~.CM .,.....e-",.,." VI Tool MWl»IFR..... Plan: £,31"1'25 æ-3IlPIan E.3IA' ('...ood By,K<n Alk:n Dat., 10/22/2001 Checked, --...... . Daleo Reviewed, Dat., Size WELL DETAu.s ..... -Hi" . ¡¡.W -.. -.. ...,;""" .......... ."" E.31 n~.71 I9tU' ~97""'-"7 ...m.22 70'20'31.121'" ,"'_.99IW 31 TARa., DETAil.' ..... 1VD -Hi" 'Fl-W -.. -.. "'" E-3IA TA _.2<1 -__'7 """-') ~97I~B) ""17M""" E-3IA TB mo.2<l ."'2" 22..t~ ~970063.62 ""'I$t...... E-3IA Tel "'~.2<I -666'~7 2901.22 ~969m.11 667501.76""" E.3IA m "'~.2<I -n7~." 1143.07 ~96925O.S7 6677 6.92""" E-3IAtE "'~.2<I -""JI :!t4U7 "'61601.06 _n."""" £.3IA TF mo.2<l 4tn.70 """.00 ~961311.22 669042.1~"'" MIA TG "'0.2<1 4111.7~ "'1." S96131235 ...m.l~"'" £.3IAI'd_NEW m~20 ........ 2001.14 '971~ 6. 6 666m21 I'd,... E.3IAm "'0.2<1 -""'" _.o) _.~~ 67029<..09"'" SECTION DETAILS See MD Ine Azi TVD +NI-S +FJ-W DLeg TFace VSec Target I 11500.00 71.98 142.19 8671.14 -6104.50 2827.23 0.00 0.00 6614.02 ) 2 11520.00 72.21 144.70 8677.29 -6119.79 2838.56 12.00 85.00 6633.04 3 11835.41 70.67 184.68 878150 -6400.95 2916.04 12.00 98.83 6907.13 4 11944.23 70.67 184.68 8817.52 -6503.30 2907.66 0.00 0.00 6985.72 5 12109.79 90.00 180.00 8845.20 -6665.57 2901.22 12.00 -13.89 71 14.28 E-3IA TCa 6 12349.77 90.00 156.00 8845.20 -6898.59 2950.75 10.00 -90.00 7332.94 7 12614.82 90.00 156.00 8845.20 -7140.73 3058.55 0.00 0.00 7592.77 8 12774.84 90.00 140.00 8845.20 -7275.99 3143.07 10.00 -90.00 7751.99 E-3IA TD 9 12841.77 89.79 133.31 8845.33 -7324.64 3188.98 10.00 -91.84 7818.24 10 13677.91 89.79 133.31 8848.46 -7898.19 3797.39 0.00 0.00 8638.15 II 13741.47 96.09 132.50 8845.20 -7941.38 3843.87 10.00 -7.30 8700.28 E-3IA TE 12 14088.01 96.10 104.62 8807.68 -8104.45 4143.47 8.00 -88.47 9006.72 13 14312.60 96.10 104.62 8783.82 -8160.80 4359.57 0.00 0.00 9177.80 14 14363.83 92.00 104.62 8780.20 -8173.70 4409.00 8.00 179.95 9216.94 E-3IA TF 15 14576.97 90.90 87.60 8774.77 -8196.28 4620.08 8.00 -93.46 9357.59 16 14861.16 90.90 87.60 8770.32 -8184.38 4903.99 0.00 0.00 9512.29 17 14876.13 90.00 87.60 8770.20 -8183.75 4918.94 6.00 179.92 9520.43 E-3IA TO 18 15135.97 90.00 72.01 8770.20 -8137.90 5173.89 6.00 -90.00 9630.69 19 15654.04 90.00 72.01 8770.20 -7977.89 5666.63 0.00 0.00 9785.57 E-3IA TH 4.500 I' /.. C'" <' -1, ~ ; \ ) <)tart Jir 1;:1100': 11500' WD, 8ð71.1A'TVD End Dir , 15115.97 MD, 8770.2' TVD * E'td,Di-..'.1I835.'.I'MD.8781.5'-VD., - 9t~IDil6l1O0'.14861.16'WU,8170.)¿'TVD \ -- ...- .---- . . ..,., -- --... .. ---&ar-1>ir-1)l~."" M.J. 8U5.2'V'D ~nd DIr , 457f.97' MD, 8774.77' 1VD 3nd Dir , 23490.77' MD, 8145.2 TVD Start '::>;r8/100': 14312.6' MD, 8783.82'TV) -----_...::_~ ----..--. --....--_.....__..¡.._..__._---_Starl~~!~~~~~~~~~~t.I~:!~.~~:'1.~D- . ¡;!1~D1r.-,;,!!oøß~~~~RI...!!&~..M~TV.n.\ -----~--.l \. \. "'1"',41/2" 'NO-TZIB .. ------\.--. ..-----..... . 1. ~ 0 - ~ -- .. WI)..TDfJI3N ...- -.., - - '? - .~ I . - ~, - 0 - 12N . 8 I r -, ,¡~- 1- I..N w, - . ~VV' .0..... .. I~OOO 0 13000 0 14)()0 SlartDirI21.00':1194^.23'MD,!817.<2'TV.O SI..IDi.IClI00'.13G77.91 MD. 8848.46'TVD I Toto Depth: 1~654N'M).87102'TV[) õndDir: 2841.77'MD,8!45.33'TVD Start Dir8'100' 137<;1.47'MD,88452'1VD 8800 9200 6800 7200 7600 8000 8400 Vertical Section at 144.610 [400fllin] ---.....--- 8800 9600 10000 9200 :? è ~ +' I -7000 ~ ! ò -4900- -5600- -6300 -7700 -8400 roMP"NY IJI'T""S BP"..... RF.fERF.NCE INfORMA.T'" r..v=:W~Ö:~ ::.r~E-Jl.1"'- -æ- SIoI-3ICO_Þ.OOEI - ...- ,.,.. ..10 r.. - _cw..n SURVEY "'«)""'-,, I,.,... fm """" T. ...."".. moo.m "6~.'" ",.....H.)I.!'2'VI Tool MWD-lfR-"S Plan: ".)lwp2' cE-WPI.. E.)IA' Oaoed By: Ken ""en Oat., 10/2212001 ("heckecl:_.._.-........--- Date:. r_--¡w.- ~= ~¿;;'-- EmfS.."" fJl_-r- w_""""" """'- Reviewed: -. - .--- --- -... (>ale: on -- CASINO DETAILS WELL DIo"TAILS Nome -N/oS ,fj.W - ""'q '.olio'" ~ Slot Size E.J! )m.11 191'1-" ,.,..".., """22 1O'2G'J1.I21N ""J9'~_99IW " 4.500 TARGET DET"ILS Nome TVD -N/oS -fj.W -~ ""'... S"'" MIATA .....20 ._J7 19033) ""0)2." 666477.44 ""'" E-JiA TB 1030.20 .,..,J) 22IU' """"'.62 666801.'4"'" E.JI"Tr. "',.20 .-J1 290122 '_".0' 661'°1.16"'" E.""ro "'''° .121).99 "4).01 59692)0.81 6671>6.92"'" E-JiA TE "',.20 .",UO )843.81 '968601.06 668412.09"'.. E."An" mo.20 -8m.1O "".00 '...,8122 669042.1""" E-JiA 10 mOlO -8'83.1' 49'0.94 ""'823' ...,)2.1""" E.JlAPaI,...,.NEW 103"° ........ """... ""'>6.<6 ""'1Ill Pal,...,. E.JlArn molo .1977" _.63 ,......-" 6102.......... SECTION DETAILS See MD Inc Azi TVD +N/.S +EI-W DLeg TFace VSec Target I 11500.00 71.98 142.19 8671.14 -6104.50 2827.23 0.00 0.00 6614.02 2 11520.00 72.21 144.70 8677.29 -6119.79 2838.56 12.00 85.00 6633.04 ) 3 11835.41 70.67 184.68 8781.50 -6400.95 2916.04 12.00 98.83 6907.13 4 11944.23 70.67 184.68 8817.52 -6503.30 2907.66 0.00 0.00 6985.72 5 12109.79 90.00 180.00 8845.20 -6665.57 2901.22 12.00 -13.89 7114.28 E-3IA TCa 6 12349.77 90.00 156.00 8845.20 -6898.59 2950.75 10.00 -90.00 7332.94 7 12614.82 90.00 156.00 8845.20 -7140.73 3058.55 0.00 0.00 7592.77 8 12774.84 90.00 140.00 8845.20 -7275.99 3143.07 10.00 -90.00 7751.99 E.3IA TD 9 12841.77 89.79 133.31 8845.33 -7324.64 3188.98 10.00 -91.84 7818.24 10 13677.91 89.79 133.31 8848.46 -7898.19 3797.39 0.00 0.00 8638.15 II 13741.47 96.09 132.50 8845.20 -7941.38 3843.87 10.00 .7.30 8700.28 E.3IA TE 12 14088.01 96.10 104.62 8807.68 -8104.45 4143.47 8.00 -88.47 9006.72 13 14312.60 96.10 104.62 8783.82 -8160.80 4359.57 0.00 0.00 9177.80 14 14363.83 92.00 104.62 8780.20 -8173.70 4409.00 8.00 179.95 9216.94 E.3IA TF 15 14576.97 90.90 87.60 8774.77 -8196.28 4620.08 8.00 -93.46 9357.59 16 14861.16 90.90 87.60 8770.32 -8184.38 4903.99 0.00 0.00 9512.29 17 14876.13 90.00 87.60 8770.20 .8183.75 4918.94 6.00 179.92 9520.43 E-3IA TO 18 15135.97 90.00 72.01 8770.20 -8137.90 5173.89 6.00 -90.00 9630.69 19 15654.04 90.00 72.01 8770.20 -7977.89 5666.63 0.00 0.00 9785.57 E-3IA TH No. TVD 8770.20 MD Name 15654.03 41/2" FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 8620.20 11348.35 WD-1Z2C 2 8750.20 11742.24 WD-TZIB 3 8800.20 11891.90 WD-TDF/13N 4 8837.20 12021.10 12N l'-\ :- ? . ~ ~) . '.. ".-"'" -,. StAI Dir 121100': 11500' MD. 8671.14'TVD , Dir:1I835.4I'MD,8781.5'TVD \. Stott ir 121100': 11944.23' MD. 88 I 7.52'TVD , \, ,,--"Star: Dir I 100': 12109.79' MD, 8845.2'TVD E-} A T~ \ . '\ ~¡.,~ Oir : 1234~T MD, 8845,2' TVD \ \\. '., S~n)irIO/IOO':1 \, . All TVD depths are ssTVD plus 60.2' for RKBE. ) E-31 (E-31) Sta~ DiJ IMOO': 11671.91' M.). 8!48A6--VD 4112" E-3Iwp25 - Starf1)l. &l1ge" 131' I,-t'l' MD. 884~ .2'1 YO ~ l-3fA (è ~ /' t.ftCll,)tr : «<-88.ÌJÌ; M\), 8ðOt.6'o'-l vu Tbtal Depth: 15654.04' MD, 8770.2' TVD "'-. ------ ~ !!-3IA Ir " ----- E-31A TH Start [);r8dOO: 14312.6'Mb;-i:WJ2Tro f - /-l.~' Eud::>iI.I'13597'MD,8770.2'TVD õnd Dir : 14576.97 MD, 8774:rrrv&-- -.-' t:-;}IA TC Star [);r 6/1 00' : 14~61 16' M~ 8770.~2'TVD .." ,~ ,.' ' ,~" y- IlT ., ~~ ", ----------- ------- -------- 28DO 3500 4200 4900 West(-)lEast(+) [700ft/in] I 6300 I 7000 5600 r--., /""\ BP Amoco Planning Report - Geographic -------- ------- Date: 10/2212001 TIme: 09:06:45 Page: ! Co-onIInàte(NE) Referéaee: Well: E-31, True North 'I, Vertleal (l'VD) Refereøee: N9ES 60.2 Seetioa (VS) Refereaee: Well (0.OON,O.OOE,144.61Azi) ¡ -____!lan: E-31wp25 --=-=:o_cc_-----------==J ------------------- Company: Field: SIte: Well: I WeUpatb: Field: BP Amoco Prudhoe Bay PBEPad E-31 Plan E-31A Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 ---------------------------------______n_- -- ------- ------------------------------ ------ --- -- ---______n___----_-------------------------- --------------------------------- - ------ ----------------------------------- - --- PB E Pad TR-11-14 UNITED STATES: North Slope : Site Position: Northing: , From: Map Eastlng: ! Position Uneertalnty: 0.00 ft I Ground Level: 0.00 ft Well: E-31 E-31 Suñaee Position: +N/-S 3252.71 ft +E/-W 1987.34 ft Position Uneertalnty: 0.00 ft Referenee Point: +N/-S 3252.71 ft , +EI-W 1987.34 ft ¡Site: 5973160.88 ft 662538.97 ft Latitude: 70 19 59.134 N Longitude: 148 40 53.054 W North Referenee: True Grid Convergenee: 1.24 deg Slot Name: 31 Northing: 5976455.67 ft Latitude: 70 20 31.121 N Eastlng : 664455.22 ft Longitude: 148 39 54.998 W Northing: 5976455.67 ft Latitude: 70 20 31.121 N Easting : 664455.22 ft Longitude: 148 39 54.998 W Measured Depth: 30.20 ft Inellnation: 0.00 deg Vertleal Depth: 30.20 ft Azimuth: 0.00 deg ----------------- ------ ------ --------~---- Current Datum: Magnetle Data: , Field Strength: Vertical Seetion: N9ES 9/1412000 57487 nT Depth From (I'VD) ft ----------------- 0.00 Height 60.20 ft Drilled From: Tle-on Depth: Above System Datum: Dedlnatlon: Mag DIp Angle: +EI-W ft 0.00 E-31 11500.00 ft Mean Sea Level 26.94 deg 80.81 deg Dlreetlon deg 144.61 Wellpath: Plan E-31A +N/-S ft 0.00 ! Plan: E-31wp25 Date Composed: 1011912001 : Version: 1 : Prlndpal: Yes Tied-to: From: 1 : MWD - Standard Plan Seetion Infonaatlon MD IncI AzIm TVD +NI..s +FJ-W DLS BaUd Turn TFO Target ft deg deg ft ft ft deg/100ft c1eg1100ftdegl100ft deg 11500.00 71.98 142.19 8671.14 -6104.50 2827.23 0.00 0.00 0.00 0.00 11520.00 72.21 144.70 8677.29 -6119.79 2838.56 12.00 1.13 12.56 85.00 : 11835.41 70.67 184.68 8781.50 -6400.95 2916.04 12.00 -0.49 12.68 98.83 ¡ 11944.23 70.67 184.68 8817.52 -6503.30 2907.66 0.00 0.00 0.00 0.00 112109.79 90.00 180.00 8845.20 -6665.57 2901.22 12.00 11.68 -2.83 -13.89 E-31A TCa ! 12349.77 90.00 156.00 8845.20 -6898.59 2950.75 10.00 0.00 -10.00 -90.00 ! 12614.82 90.00 156.00 8845.20 -7140.73 3058.55 0.00 0.00 0.00 0.00 ; 12774.84 90.00 140.00 8845.20 -7275.99 3143.07 10.00 0.00 -10.00 -90.00 E-31A TO : 12841.77 89.79 133.31 8845.33 -7324.64 3188.98 10.00 -0.32 -9.99 -91.84 . 13677.91 89.79 133.31 8848.46 -7898.19 3797.39 0.00 0.00 0.00 0.00 ,13741.47 96.09 132.50 8845.20 -7941.38 3843.87 10.00 9.92 -1.28 -7.30 E-31A TE ¡ 14088.01 96.10 104.62 8807.68 -8104.45 4143.47 8.00 0.00 -8.05 -88.47 ; 14312.60 96.10 104.62 8783.82 -8160.80 4359.57 0.00 0.00 0.00 0.00 : 14363.83 92.00 104.62 8780.20 -8173.70 4409.00 8.00 -8.00 0.01 179.95 E-31A TF ; 14576.97 90.90 87.60 8774.77 -8196.28 4620.08 8.00 -0.52 -7.99 -93.46 ¡ 14861.16 90.90 87.60 8770.32 -8184.38 4903.99 0.00 0.00 0.00 0.00 I 14876.13 90.00 87.60 8770.20 -8183.75 4918.94 6.00 -6.00 0.01 179.92 E-31A TG 15135.97 90.00 72.01 8770.20 -8137.90 5173.89 6.00 0.00 -6.00 -90.00 : 15654.04 90.00 72.01 8770.20 -7977.89 5666.63 0.00 0.00 0.00 0.00 E-31A TH -- --- - _n__- ____n______------- ----------- ----------------- ----------------------- ".-...... ~ BP Amoco Planning Report - Geographic Company: BP Amoco FIeld: Prudhoe Bay Site: PB E Pad I Well: E-31 L WeUpadl: Plan E-3~_- Section 1: Start I MD Ind Azim I ft deg deg I ---- '11500.00 71.98 142.19 l~~~.~- -- --2~~!____1~:~ Section 2: Start MD Incl Azlm TVD +N/-S +EI-W VS ft deg deg ft ft ft ft 11525.00 72.12 145.32 8678.82 -6123.69 2841.29 6637.80 11550.00 71.69 148.45 8686.59 -6143.59 2854.27 6661.54 11575.00 71.32 151.59 8694.52 -6164.12 2866.12 6685.14 11600.00 71.00 154.74 8702.60 -6185.23 2876.80 6708.53 11625.00 70.73 157.90 8710.79 -6206.86 2886.28 6731.66 11650.00 70.51 161.07 8719.09 -6228.94 2894.55 6754.45 11675.00 70.36 164.25 8727.46 -6251.42 2901.57 6776.84 ,11700.00 70.25 167.44 8735.89 -6274.24 2907.32 6798.78 : 11725.00 70.21 170.62 8744.35 -6297.34 2911.80 6820.20 : 11750.00 70.22 173.81 8752.82 -6320.64 2914.98 6841.04 : 11775.00 70.28 177.00 8761.27 -6344.09 2916.87 6861.25 , 11800.00 70.41 180.18 8769.68 -6367.62 2917.45 6880.77 : 11825.00 70.58 183.36 8778.03 -6391.17 2916.72 6899.55 : 11835.41 70.67 184.68 8781.50 -6400.95 2916.04 6907.13 L____-- - - - -------- - --- -- -- -------------- ------------------- Date: 10122/2001 11me: 09:06:45 Page: CCHrdlnate(NE) Refereaee: Well: E-31. True North Vertical (fVD) Reference: N9ES 60.2 Section (VS) Reference: Well (0.ooN.O.00E.144.61Azi) Plan: E-31wp25 ----------- ------ TVD +N/-S +EI-W VS ft ft ft ft 8671.14 -6104.50 2827.23 6614.01 8677.29 -6119.79 2838.56 6633.04 ----------- ------- DLS Build Tufn TFO deg/100ft degl100ft degl10Oft deg 0.00 0.00 0.00 0.00 12.00 1.15 12.55 84.89 DLS BuUd Tufn degl100ft degl100ft degl100ft 12.00 -1.82 12.46 12.00 -1.70 12.50 12.00 -1.50 12.55 12.00 -1.29 12.61 12.00 -1.07 12.65 12.00 -0.86 12.69 12.00 -0.63 12.72 12.00 -0.41 12.74 12.00 -0.19 12.75 12.00 0.04 12.75 12.00 0.27 12.75 12.00 0.49 12.73 12.00 0.71 12.71 12.00 0.83 12.69 --- TFO deg 98.83 98.64 97.67 96.67 95.65 94.62 93.56 92.50 91.43 90.35 89.27 88.19 87.12 86.26 Section 3: Start ------------ ----- : MD Ind Azlm TVD +N/-S +EI-W VS DLS Build Turn TFO ; ft deg deg ft ft ft ft degl100ft degl10Qft degl10Oft deg '----- -------- 11900.00 70.67 184.68 8802.88 -6461.70 2911.07 6953.77 0.00 0.00 0.00 0.00 11944.23 70.67 184.68 8817.52 -6503.30 2907.66 6985.72 0.00 0.00 0.00 0.00 Section 1- ¡Pf ! 11950.00 ! 11975.00 ¡ 12000.00 ¡ 12025.00 12050.00 112075.00 ¡ 12100.00 i 12109.79 I 4: Start Ind deg 71.34 74.26 77.17 80.09 83.01 85.93 88.86 90.00 AzIm deg 184.50 183.76 183.04 182.33 181.63 180.95 180.27 180.00 Section 5: Start MD ft 12150.00 12200.00 12250.00 12300.00 12349.77 Ind deg 90.00 90.00 90.00 90.00 90.00 Azlm deg 175.98 170.98 165.98 160.98 156.00 TVD ft 8819.40 8826.79 8832.96 8837.89 8841.56 8843.96 8845.10 8845.20 TVD ft 8845.20 8845.20 8845.20 8845.20 8845.20 +N/-S ft -6508.74 -6532.56 -6556.74 -6581.22 -6605.93 -6630.80 -6655.77 -6665.57 +N/-S ft -6705.75 -6755.41 -6804.38 -6852.31 -6898.59 +EI-W ft 2907.22 2905.50 2904.07 2902.92 2902.07 2901.51 2901.24 2901.22 VS ft 6989.90 7008.32 7027.20 7046.50 7066.15 7086.11 7106.31 7114.28 +EI-W ft 2902.63 2908.31 2918.29 2932.50 2950.75 VS ft 7147.85 7191.63 7237.34 7284.64 7332.94 -- - --- ------------------ --------------------------- DLS BWld Turn degl100ftdegl100ft degl1()()ft 12.00 11.65 -3.04 12.00 11.66 -2.98 12.00 11.67 -2.90 12.00 11.68 -2.83 12.00 11.68 -2.78 12.00 11.69 -2.74 12.00 11.69 -2.72 12.00 11.69 -2.72 DLS Build Tufn degl100ft degl100ft degl100ft 10.00 0.00 -10.00 10.00 0.00 -10.00 10.00 0.00 -10.00 10.00 0.00 -10.00 10.00 0.00 -10.00 --- ------- TFO deg -13.89 -13.83 -13.61 -13.43 -13.29 -13.19 -13.13 -13.12 TFO deg -90.00 -90.00 -90.00 -90.00 -90.00 I I --_J z ----, I I i --_J ------.1 ¡ _I , , --------~ Section 6: Start MD Ind Azim TVD +N/-S +EI-W VS DLS Build Tnm TFO , ft deg deg ft ft ft ft deg/100ft deg/100ft degl100ft deg 1--------- ---- - ; 12400.00 90.00 156.00 8845.20 -6944.48 2971.18 7382.18 0.00 0.00 0.00 0.00 i i 12500.00 90.00 156.00 8845.20 -7035.83 3011.85 7480.21 0.00 0.00 0.00 0.00 ¡ i 12600.00 90.00 156.00 8845.20 -7127.19 3052.53 7578.24 0.00 0.00 0.00 0.00 : i 126~4.:~~--__-~~~____1~:~~~s.:~~.--2140. 7~- ~~~.-!..5!~~__~~~~0_.?:.~---<>,~ -- -----..J I -~ f I Company: BP Amoco II Field: Prudhoe Bay Site: PB E Pad Well: E-31 L ~eUpatb~ Plan_~~1A______------- Section 7: Start ----- ----- ! MD Incl Azlm TVD ! ft deg deg ft t-12650.00 90.00 152:48 8845.20 ! 12700.00 90.00 147.48 8845.20 ! 12750.00 90.00 142.48 8845.20 : 12774.84 90.00 140.00 8845.20 [------------- ---------- Section MD ft 12800.00 12841.77 8 : Start loci deg 89.92 89.79 Section 9: Start r MD ft , 12900.00 13000.00 - 13100.00 , 13200.00 13300.00 13400.00 , 13500.00 13600.00 13677.91 Incl deg 89.79 89.79 89.79 89.79 89.79 89.79 89.79 89.79 89.79 Azlm deg 137.49 133.31 Azlm deg 133.31 133.31 133.31 133.31 133.31 133.31 133.31 133.31 133.31 TVD ft 8845.22 8845.33 TVD ft 8845.54 8845.91 8846.28 8846.64 8847.01 8847.38 8847.74 8848.11 8848.46 - -- -------------------..------------------ Section 10: Start MD Incl ft deg ¡ 13700.00 91.98 : 13741.47 96.09 L_- Section 11 : Start I MD Incl i ft deg 13750.00 96.11 13800.00 96.19 13850.00 96.25 13900.00 96.28 13950.00 96.27 : 14000.00 96.24 14050.00 96.17 ! 14088.01 96.10 Section 12: Start : MD Incl L.~ deg , 14100.00 96.10 ! 14200.00 96.10 : 14300.00 96.10 : 14312.60 96.10 Azlm deg 133.03 132.50 Azim deg 131.81 127.79 123.77 119.74 115.72 111.70 107.67 104.62 Azlm deg 104.62 104.62 104.62 104.62 TVD ft 8848.12 8845.20 TVD ft 8844.29 8838.93 8833.51 8828.05 8822.59 8817.14 8811.73 8807.68 TVD ft 8806.41 8795.78 8785.15 8783.82 -- -- ------- -- -------------- Section 13: Start I MD Incl i ft deg L- .14350.00 93.11 ¡ 14363.83 92.00 .---- ------------------------ Azlm deg 104.62 104.62 TVD ft 8780.82 8780.20 ,,--..., ~ BP Amoco Planning Report - Geographic Date: 10/2212001 TIme: 09:06:45 Page: 3 Co-ordinate(NE) Reference: Well: E~1. True North Vertical (TVD) Reference: N9ES 60.2 Section (VS) Refereace: Wen (O.OON.O.OOE.144.61Azi) Plan: E-31wp25 --------- --------------- +N/-S ft -7172.41 -7215.69 -7256.62 -7275.99 +N/..s ft -7294.90 -7324.64 +N/-S ft -7364.58 -7433.18 -7501.77 -7570.36 -7638.96 -7707.55 -7776.15 -7844.74 -7898.19 +N/-S ft -7913.30 -7941.38 +N/-S ft -7947.07 -7978.89 -s007.94 -8034.10 -8057.22 -8077.20 -8093.94 -8104.45 +N/-S ft -8107.46 -8132.56 -8157.65 -8160.80 ----- +EI-W ft 3073.84 3098.84 3127.52 3143.07 VS ft 7627.45 7677.22 7727.20 7751.99 ----- DLS Build Turn degl100ft deg/100ft degl10Oft 10.00 0.00 -10.00 10.00 0.00 -10.00 10.00 0.00 -10.00 9.99 0.00 -9.99 ----------- +EI-W ft 3159.66 3188.98 ------ +EI-W ft 3231.35 3304.12 3376.88 3449.65 3522.41 3595.18 3667.94 3740.70 3797.39 ------ +EI-W ft 3813.50 3843.87 +EI-W ft 3850.16 3888.34 3928.66 3970.91 4014.89 4060.39 4107.18 4143.47 +EI-W ft 4155.01 4251.22 4347.43 4359.57 VS ft 7777.02 7818.24 vs ft 7875.34 7973.40 8071.46 8169.52 8267.58 8365.64 8463.70 8561.76 8638.16 vs ft 8659.80 8700.28 vs ft 8708.57 8756.62 8803.65 8849.44 8893.76 8936.40 8977.14 9006.72 VS ft 9015.86 9092.03 9168.21 9177.80 TFO deg -90.00 -90.00 -90.00 -90.00 , -----------" DLS BuUd Turn TFO deg/100ft deg/100ft degl100ft deg 10.00 -0.32 -9.99 -91.84 10.00 -0.31 -10.00 -91.78 ~ I i I ! DLS Balld Turn deg/100ft degl100ft degl100ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TFO deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 DLS BaUd Turn TFO deg/1 OOftdegl1 00ft degl100ft deg 10.00 9.92 -1.27 -7.30 9.99 9.91 -1.28 -7.30 DLS BaUd Turn degl100ft degl100ft degl100ft 8.00 0.21 -8.04 8.00 0.17 -8.04 8.00 0.11 -8.05 8.00 0.05 -8.05 8.00 -0.01 -8.05 8.00 -0.07 -8.05 8.00 -0.13 -8.05 7.99 -0.19 -8.03 DLS Build Turn deg/100ft deg/100ft degl100ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TFO deg -88.47 -88 . 54 -88.97 -89.41 -89.85 -90.29 -90.73 -91.16 TFO deg 0.00 0.00 0.00 0.00 , I I I --------------------- ----- ---- ----------------< +N/-S ft -8170.21 -8173.70 +EI-W ft 4395.64 4409.00 VS ft 9206.36 9216.94 DLS Build Tarn TFO degl100ft deg/100ft degl100ft deg 8.00 -8.00 0.01 179.95 8.01 -8.01 -0.02 -179.86 I ¡ ~ , I ! -- -----------~ ".-..... -~ BP Amoco Planning Report - Geographic Company: BP Amoco Field: Prudhoe Bay Site: PB E Pad WeB: E-31 WeBpatb: Plan E-31A -_._---------------- Section 14: Start ,-u -------------- i MD Incl Azlm TVD +N/-8 ¡ ft deg deg ft ft ì 114400.00 91.82 101.73 8778.99 -8181.94 ¡ 14450.00 91.57 97.74 8777.51 -8190.39 ! 14500.00 91.31 93.74 8776.25 -8195.38 ! 14550.00 91.04 89.75 8775.23 -8196.91 ! 14576.97 90.90 87.60 8774.77 -8196.28 Date: 1012212001 TIme: 09:06:45 Page: Co-ordlnate(NE) Reference: Well: E-31, True North Vertical (TVD) Reference: N9ES 60.2 Section (VS) Reference: WeD (0.ooN,O.ooE,144.61Azi) Plan: E-31wp25 4 _____nn____' ------- ----_u_- +EI-W ft 4444.19 4493.44 4543.17 4593.12 4620.08 VS ft 9244.04 9279.45 9312.31 9342.49 9357.58 DLS BnUd Turn degl100ft deg/100ft degl100ft 8.00 -0.49 -7.99 8.00 -0.50 -7.99 8.00 -0.52 -7.99 8.00 -0.53 -7.98 7.99 -0.53 -7.98 TFO deg -93.46 -93.56 -93.67 -93.78 -93.82 ------- ------ Section 15: Start I MD IDcI Azlm TVD +N/-8 +EI-W VS 1146::'00 9~~0 d:.60 877:41 -8195~32 4643~ 937:12 i 14700.00 90.90 87.60 8772.84 -8191.13 4742.99 9424.56 ¡ 14800.00 90.90 87.60 8771.27 -8186.94 4842.89 9478.99 L!~861.16 9O.~____~~.?~~_0.3~~.:.~__~~_~:99 __9~1~.:.29 Section 16: Start MD Incl ft deg I--- ! 14876.13 90.00 DLS Build Turn degl100ft degl100ft degl100ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TFO deg 0.00 0.00 0.00 0.00 ----------- -- DLS Build Turn TFO degl100ft <leg/100ft degl100ft deg 6.01 -6.01 0.00 180.00 TVD ft 8770.20 +N/-S ft -8183.75 VS ft 9520.43 Azlm deg 87.60 +EI-W ft 4918.94 ------------------- -_u_---..------ --------- Section 17: Start MD Incl ft deg ¡ 14900.00 90.00 : 14950.00 90.00 ; 15000.00 90.00 ! 15050.00 90.00 ì 15100.00 90.00 i 15135.97 90.00 -------- TFO deg -90.00 -90.00 -90.00 -90.00 -90.00 -90.00 Azlm deg 86.17 83.17 80.17 77.17 74.17 72.01 VS ft 9533.18 9558.21 9580.95 9601.33 9619.29 9630.69 DLS Build Turn deg/100ft <leg1100ft degl10Oft 6.00 0.00 -6.00 6.00 0.00 -6.00 6.00 0.00 -6.00 6.00 0.00 -6.00 6.00 0.00 -6.00 6.00 0.00 -6.00 TVD ft 8770.20 8770.20 8770.20 8770.20 8770.20 8770.20 +N/-S ft -8182.45 -8177.81 -8170.56 -8160.74 -8148.36 -8137.90 +EI-W ft 4942.77 4992.55 5042.02 5091.04 5139.48 5173.89 I -----' Section 18: Start : MD Incl 1ft deg 15200.00 90.00 i 15300.00 90.00 ! 15400.00 90.00 : 15500.00 90.00 115600.00 90.00 115654.04 90.00 VS ft 9649.83 9679.73 9709.63 9739.52 9769.42 9785.57 - DLS Build Turn degl100ft degl100ft degl100ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TFO <leg 0.00 0.00 0.00 0.00 0.00 0.00 AzIm deg 72.01 72.01 72.01 72.01 72.01 72.01 TVD ft 8770.20 8770.20 8770.20 8770.20 8770.20 8770.20 +N/-8 ft -8118.12 -8087.24 -8056.35 -8025.47 -7994.58 -7977.89 +FJ-W ft 5234.79 5329.90 5425.01 5520.12 5615.23 5666.63 I i f ~ Survey <-- Latitude --> ~ Longitude -> Deg Mln See Deg Mln See Map Eastlng ft 667415.48 667427.14 667429.96 667443.37 667455.67 Map Northing ft 5970415.07 5970400.04 5970396.20 5970376.59 5970356.32 MD ft 11500.00 11520.00 11525.00 11550.00 11575.00 AzIm deg 142.19 144.70 145.32 148.45 151.59 154.74 157.90 161.07 164.25 167.44 Incl deg 71.98 72.21 72.12 71.69 71.32 71.00 70.73 70.51 70.36 70.25 TVD ft 8671.14 8677.29 8678.82 8686.59 8694.52 8702.60 8710.79 8719.09 8727.46 8735.89 +N/-S ft -6104.50 -6119.79 -6123.69 -6143.59 -6164.12 +EI-W ft 2827.23 2838.56 2841.29 2854.27 2866.12 70 19 31.079 N 148 38 32.474 W 70 19 30.929 N 148 38 32.144 W 70 19 30.890 N 148 38 32.064 W 70 19 30.695 N 148 38 31.685 W 70 19 30.493 N 148 38 31.340 W 70 19 30.285 N 148 38 31.028 W I 70 19 30.072 N 148 38 30.752 W ! 70 19 29.855 N 148 38 30.511 W I 70 19 29.634 N 148 38 30.306 W , 70 19 29.409 N 148 38 30.138 W ! 11600.00 11625.00 11650.00 11675.00 11700.00 I i 11725.00 70.21 170.62 ¡ 11750.00 70.22 173.81 ¡ 11775.00 70.28 177.00 L.~.8oo'~....2~~.!n__~~.18 667466.81 667476.76 667485.51 667493.02 667499.27 667504.25 667507.95 667510.35 667511.44 -6185.23 -6206.86 -6228.94 -6251.42 -6274.24 -6297.34 -6320.64 -6344.09 -6367.62 2876.80 5970335.46 2886.28 5970314.05 2894.55 5970292.15 2901.57 5970269.83 2907.32 5970247.14 2911.80 5970224.15 2914.98 5970200.93 2916.87 5970177.53 2917.45 5970154.01 I 70 19 29.182 N 148 38 30.008 W I 70 19 28.953 N 148 38 29.915 W : 70 19 28.722 N 148 38 29.860 W i 70 19 28.491 N 148 38 29'844_~J 8744.35 8752.82 8761.27 8769.68 I-- I Company: BP Amoco I FIeld: Prudhoe Bay ¡ Site: PB E Pad I Well: E.31 L Wellpatb: Plan E-3~ Survey I MD Ind AzIm . ft des des ~----_.- : 11825.00 70.58 183.36 i 11835.41 ¡ 11900.00 i 11944.23 ¡ 11950.00 ! 11975.00 12000.00 12025.00 12050.00 12075.00 ; 12100.00 12109.79 12150.00 . 12200.00 12250.00 12300.00 12349.77 12400.00 12500.00 12600.00 12614.82 12650.00 12700.00 ; 12750.00 : 12774.84 12800.00 ; 12841.77 . 12900.00 ¡ 13000.00 ! 13100.00 . 13200.00 ,13300.00 :13400.00 : 13500.00 13600.00 13677.91 13700.00 : 13741.47 . 13750.00 13800.00 13850.00 13900.00 . 13950.00 ; 14000.00 : 14050.00 . 14088.01 , 14100.00 14200.00 14300.00 . 14312.60 . 14350.00 70.67 70.67 70.67 71.34 74.26 77.17 80.09 83.01 85.93 88.86 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 89.92 89.79 89.79 89.79 89.79 89.79 89.79 89.79 89.79 89.79 89.79 91.98 96.09 96.11 96.19 96.25 96.28 96.27 96.24 96.17 96.10 96.10 96.10 96.10 96.10 93.11 184.68 184.68 184.68 184.50 183.76 183.04 182.33 181.63 180.95 180.27 180.00 175.98 170.98 165.98 160.98 156.00 156.00 156.00 156.00 156.00 152.48 147.48 142.48 140.00 137.49 133.31 133.31 133.31 133.31 133.31 133.31 133.31 133.31 133.31 133.31 133.03 132.50 131.81 127.79 123.77 119.74 115.72 111.70 107.67 104.62 104.62 104.62 104.62 104.62 104.62 :..:'~~:~~~~_~.62 TVD ft 8778.03 8781.50 8802.88 8817.52 8819.40 8826.79 8832.96 8837.89 8841.56 8843.96 8845.10 8845.20 8845.20 8845.20 8845.20 8845.20 8845.20 8845.20 8845.20 8845.20 8845.20 8845.20 8845.20 8845.20 8845.20 8845.22 8845.33 8845.54 8845.91 8846.28 8846.64 8847.01 8847.38 8847.74 8848.11 8848.46 8848.12 8845.20 8844.29 8838.93 8833.51 8828.05 8822.59 8817.14 8811.73 8807.68 8806.41 8795.78 8785.15 8783.82 8780.82 8780.20 ~ BP Amoco Planning Report - Geographic .~ Date: 10/2212001 TIme: 09:06:45 Page: 5 I Co-ordlnate(NE) Reference: Well: E-31. True North II Vertical (TVD) Reference: N9ES 60.2 ~ (VS) Refereace: ~;~~~N.O.OOE._~~~~~) ----_J Map +NI-S +EI-W Northing ft ft ft -6391.17 2916.72 5970130.46 -6400.95 -6461.70 -6503.30 -6508.74 -6532.56 -6556.74 -6581.22 -6605.93 -6630.80 -6655.77 -6665.57 -6705.75 -6755.41 -6804.38 -6852.31 -6898.59 -6944.48 -7035.83 -7127.19 -7140.73 -7172.41 -7215.69 -7256.62 -7275.99 -7294.90 -7324.64 -7364.58 -7433.18 -7501.77 -7570.36 -7638.96 -7707.55 -7776.15 -7844.74 -7898.19 -7913.30 -7941.38 -7947.07 -7978.89 -8007.94 -8034.10 -8057.22 -8077.20 -8093.94 -8104.45 -8107.46 -8132.56 -8157.65 -8160.80 -8170.21 -8173.70 2916.04 5970120.66 2911.07 5970059.83 2907.66 5970018.16 2907.22 5970012.72 2905.50 5969988.87 2904.07 5969964.66 2902.92 5969940.17 2902.07 5969915.44 2901.51 5969890.56 2901.24 5969865.60 2901.22 5969855.80 2902.63 5969815.67 2908.31 5969766.15 2918.29 5969717.40 2932.50 5969669.81 2950.75 5969623.94 2971.18 5969578.51 3011.85 5969488.08 3052.53 5969397.65 3058.55 5969384.24 3073.84 5969352.91 3098.84 5969310.19 3127.52 5969269.89 3143.07 5969250.88 3159.66 5969232.33 3188.98 5969203.25 3231.35 5969164.25 3304.12 5969097.27 3376.88 5969030.29 3449.65 5968963.32 3522.41 5968896.34 3595.18 5968829.36 3667.94 5968762.39 3740.70 5968695.41 3797.39 5968643.22 3813.50 5968628.47 3843.87 5968601.06 3850.16 5968595.51 3888.34 5968564.54 3928.66 5968536.38 3970.91 5968511.16 4014.89 5968489.01 4060.39 5968470.03 4107.18 5968454.33 4143.47 5968444.62 4155.01 5968441.86 4251.22 5968418.88 4347.43 5968395.90 4359.57 5968393.02 4395.64 5968384.41 4409.00 5968381.21 Map Eastlng ft 667511.23 667510.77 667507.13 667504.63 667504.32 667503.12 667502.22 667501.61 667501.30 667501.28 667501.57 667501.76 667504.05 667510.81 667521.87 667537.13 667556.38 667577.81 667620.48 667663.14 667669.46 667685.44 667711.38 667740.96 667756.92 66m3.92 667803.88 667847.12 667921.36 667995.61 668069.86 668144.11 668218.35 668292.60 668366.85 668424.69 668441.12 668472.10 668478.51 668517.38 668558.32 668601.13 668645.61 668691.53 668738.68 668775.18 668786.78 668883.52 668980.25 668992.45 669028.72 669042.15 <- Latitude --> <- Longitude -> Beg Mln See Beg Mln See 70 19 28.259 N 148 38 29.865 W 70 19 28.163 N 148 38 29.885 W 70 19 27.566 N 148 38 30.031 W 70 19 27.157 N 148 38 30.131 W 70 19 27.103 N 148 38 30.144 W 70 19 26.869 N 148 38 30.194 W 70 19 26.631 N 148 38 30.236 W i 70 19 26.390 N 148 38 30.270 W : 70 19 26.147 N 148 38 30.295 W : 70 19 25.903 N 148 38 30.312 W . 70 19 25.657 N 148 38 30.320 W 70 19 25.561 N 148 38 30.321 W 70 19 25.166 N 148 38 30.280 W 70 19 24.677 N 148 38 30.115 W 70 19 24.195 N 148 38 29.824 W 70 19 23.724 N 148 38 29.410 W 70 19 23.269 N 148 38 28.878 W 70 19 22.817 N 148 38 28.282 W 70 19 21.919 N 148 38 27.096 W 70 19 21.020 N 148 38 25.910 W 70 19 20.887 N 148 38 25.734 W . 70 19 20.575 N 148 38 25.289 W 70 19 20.150 N 148 38 24.559 W : 70 19 19.747 N 148 38 23.723 W . 70 19 19.556 N 148 38 23.269 W 70 19 19.370 N 148 38 22.785 W : 70 19 19.078 N 148 38 21.930 W I 70 19 18.685 N 148 38 20.694 W ; 70 19 18.010 N 148 38 18.571 W ; 70 19 17.335 N 148 38 16.449 W . 70 19 16.660 N 148 38 14.326 W 70 19 15.985 N 148 38 12.203 W 70 19 15.310 N 148 38 10.081 W 70 19 14.635 N 148 38 7.958 W 70 19 13.960 N 148 38 5.836 W 70 19 13.434 N 148 38 4.183 W 70 19 13.285 N 148 38 70 19 13.009 N 148 38 70 19 12.953 N 148 38 70 19 12.640 N 148 38 70 19 12.354 N 148 38 3.713 W i 2.827 W ; 2.643 W . 1.530 W 0.354 W 70 19 12.097 N 148 37 59.121 W ' 70 19 11.669 N 148 37 57.838 W : 70 19 11.672 N 148 37 56.510 W 70 19 11.507 N 148 37 55.145 W : 70 19 11.404 N 148 37 54.087 W ! 70 19 11.374 N 148 37 53.750 W ; 70 19 11.127 N 148 37 50.943 W I 70 19 10.879 N 148 37 48.136 W i 70 19 10.848 N 148 37 47.781 W : 70 19 10.756 N 148 37 46.729 W : 70 19 10.721 N 148 37 46.339 W i ----.-...--------..--"------" -' Company: BP.Amoco field: Prudhoe Bay Site: PB E Pad Well: E-31 L~elll!~tb: !Ia~ E-31A Survey I iMD ! ft í ; 14400.00 14450.00 14500.00 14550.00 14576.97 14600.00 14700.00 14800.00 14861.16 14876.13 14900.00 14950.00 ¡ 15000.00 : 15050.00 15100.00 15135.97 15200.00 , 15300.00 ~ 15400.00 15500.00 15600.00 15654.04 Incl deg 91.82 91.57 91.31 91.04 90.90 90.90 90.90 90.90 90.90 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 Azim deg 101.73 97.74 93.74 89.75 87.60 87.60 87.60 87.60 87.60 87.60 86.17 83.17 80.17 77.17 74.17 72.01 72.01 72.01 72.01 72.01 72.01 72.01 -----------------.--- TVD ft 8778.99 8777.51 8776.25 8775.23 8774.77 8774.41 8772.84 8771.27 8770.32 8770.20 8770.20 8770.20 8770.20 8770.20 8770.20 8770.20 8770.20 8770.20 8770.20 8770.20 8770.20 8770.20 ~ BP Amoco Planning Report - Geographic +N/-S ft -8181.94 -8190.39 -8195.38 -8196.91 -8196.28 -8195.32 -8191.13 -8186.94 -8184.38 -8183.75 -8182.45 -8177.81 -8170.56 -8160.74 -8148.36 -8137.90 -8118.12 -8087.24 -8056.35 -8025.47 -7994.58 -7977.89 .~. Date: 10I22l2OO1 TIme: 09:06:45 Page: Co-ordlnate(NE) Reference: Well: E-31. True North Vertical (TVD) Refereace: N9ES 60.2 Section (VS) Reference: Well (0.OON.0.OOE,144.61Az1) Plan: E-31wp25 ._- +FJ-W ft 4444.19 4493.44 4543.17 4593.12 Map Northing ft 5968373.75 5968366.38 5968362.48 5968362.05 4620.08 5968363.27 4643.09 5968364.74 4742.99 5968371.11 4842.89 5968377.49 4903.99 5968381.39 4918.94 5968382.35 4942.77 5968384.17 4992.55 5968389.91 5042.02 5968398.23 5091.04 5968409.13 5139.48 5968422.57 5173.89 5968433.78 5234.79 5968454.88 5329.90 5968487.85 5425.01 5968520.81 5520.12 5968553.77 5615.23 5968586.73 5666.63 5968604.55 ------ ------ Map Easting ft 669077.51 669126.93 669176.75 669226.72 669253.66 669276.64 669376.42 669476.19 669537.22 669552.15 669575.95 669625.61 669674.90 669723.69 669771.84 669806.02 669866.46 669960.87 670055.27 670149.68 670244.08 670295.09 6 ---.-- <-- Latitude --> Deg Min See <- Loagltude -> I Deg Min See -J 148 37 45.312 W I 148 37 43.875 W . 148 37 42.425 W 148 37 40.967 W 70 19 10.640 N 70 19 10.557 N 70 19 10.507 N 70 19 10.492 N 70 19 10.498 N 148 37 40.180 W 70 19 10.507 N 148 37 39.509 W 70 19 10.548 N 148 37 36.594 W 70 19 10.588 N 148 37 33.678 W 70 19 10.613 N 148 37 31.895 W 70 19 10.619 N 148 37 31.459 W 70 19 10.632 N 148 37 30.763 W 70 19 10.677 N 148 37 29.311 W 70 19 10.748 N 148 37 27.867 W 70 19 10.845 N 148 37 26.437 W , 70 19 10.966 N 148 37 25.023 W ! 70 19 11.069 N 148 37 24.018 W 70 19 11.263 N 148 37 22.241 W : 70 19 11.566 N 148 37 19.465 W : 70 19 11.869 N 148 37 16.689 W . 70 19 12.172 N 148 37 13.913 W 70 19 12.475 N 148 37 11.136 W ! 70 19 12.639 N 148 37 9.636 W : ---------- ~ /"""", BP Amoco Anticollision Report 1 Company: BP Amoco Date: 1/1512002 TIme: 10:51:58 Page: I FIeld: Prudhoe Bay I Reference Site: PB E Pad CcH»rdinate(NE) Reference: Well: E-31 , True North II I Reference WeD: E-31 Vertical (fVD) Reference: N9ES 60.2 L~ef~!~ Wellpath: Plan E-31A ------------- __Db: Oracle J ; -ci WBALSCANAPPLt ED;AIÎ;;lïP~t¡;;;ïthln-iöö~+ ïõõïiOÕO;¡r;i~;;~~~-~-Th~re ~;:-~8fells ïn thli~aIPJ8n-&-piÞ.NNEDPROGRAM- ¡ , Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse . Depth Range: 11500.00 to 15654.04 ft Scan Method: Tray Cylinder North ,-_~_~xl,!,~m ~!~~:_-.!762~~~__~ -------------------- - - ----------____~_ror Suñace: -- EII~s!~_~asi~_~___-------_n_-______i [S;;~ey P~og;~;f~~-~fi~idve W~lIp~----------------------- ------------------------------------- n___n__- 1 : Date: 9/14/2000 Validated: No Version: 25 i Planned From To Survey Toolcode i ft ft I-- --.. ---- --------------- ---------------------------------- --------------------------------------------- J 257.10 11500.00 1 : MWO - Standard (0) GYO-CT -CMS Gyrodata contcasing m/s ! 11500.00 15654.04 Planned: E-31wp25 V1 MWD+IFR+MS MWD + IFR + Multi Station ~------ --~--- ---~------- ---------.-______1 Casing Points I MD TVD Diameter Hole Size ! ft ft in in ; I 8770.08 4.500 6.125 I 15654.03 Name 4 1/2" ---------------------- '----------. ------ --------------- Tool Name ------- -- Summary ---- '0« Offset Wellpath :> Reference Offset Ctr-Ctr No-Go Allowable ; Site Well Wellpath MD MD Distance Area Deviation Wamiog , ft ft ft ft ft On------ . PBCPad C-18 C-18 V1 14240.17 12956.00 676.01 57.24 676.01 Pass: Minor 1/200 : PBCPad C-18 C-18A V1 14283.84 12775.00 805.63 752.18 75.41 Pass: Major Risk . PB DS 15 15-18 15-18 V1 15452.13 13562.00 808.14 253.72 554.48 Pass: Major Risk PB OS 15 15-21A 15-21A V7 Out of range PBEPad E-14A E-14A V2 Out of range PBEPad E-14 E-14 V1 11500.00 11475.00 1154.64 49.35 1154.64 Pass: Minor 1/200 PBEPad E-19 E-19 V1 12349.77 11650.00 685.85 48.94 685.85 Pass: Minor 1/200 PBEPad E-19 E-19A VO 12757.52 12225.00 542.39 42.29 542.39 Pass: Minor 11200 , PBEPad E-31 E-31 V2 11520.59 11525.00 0.39 0.00 0.39 Pass: NOERRORS PBKPad K-O5 K-05A V5 Out of range : PBKPad K-05 K-O5B V1 Plan: Plan #1 13273.18 11752.00 1497.72 231.09 1266.33 Pass: Major Risk ¡ PBKPad K-13 K-13 V1 Out of range : PBKPad K-14 K-14 V1 Out of range ~---------- ----~ Site: PB C Pad Well: C-18 Wellpath: c-18 V1 Reference MD TVD ft ft 14050.00 8811.64 14050.00 8811.64 14050.00 8811.64 14050.00 8811.64 14050.00 8811.64 Offset MD TVD ft ft 11550.00 7886.45 11575.00 7904.06 11600.00 7921.71 11625.00 7939.39 11650.00 7957.12 Rule Assigned: Inter-Site Error: Minor 11200 0.00 ft Allowable Deviation ft 1737.42 1718.27 1702.72 1689.61 1665.98 Semi-Major Axis Ref Offset TFO+AZI TFO-HS Casing ft ft deg deg in 34.91 157.48 165.31 57.64 9.625 34.91 157.98 165.53 57.85 9.625 34.91 158.47 165.75 58.08 9.625 34.91 158.97 165.98 58.31 9.625 34.91 159.47 166.22 58.55 9.625 Ctr.ctr No-Go Distance Area ft ft 1760.86 69.35 1737.05 69.37 1713.30 69.40 1689.61 69.42 1665.98 69.45 14050.00 8811.64 11675.00 7974.91 34.91 159.97 166.47 ! 14050.00 8811.64 11700.00 7992.74 34.91 160.47 166.73 : 14050.00 8811.64 11725.00 8010.64 34.91 160.97 167.00 ¡ 14050.00 8811.64 11750.00 8028.61 34.91 161.47 167.28 ! 14050.00 8811.64 11775.00 8046.65 34.91 161.96 167.58 : 14050.00 8811.64 11800.00 8064.76 34.91 162.46 167.89 : 14050.00 8811.64 11825.00 8082.92 34.91 162.96 168.21 í 14050.00 8811.64 11850.00 8101.14 34.91 163.47 168.54 ; 14050.00 8811.64 11875.00 8119.40 34.91 163.97 168.89 . 14050.00 8811.64 11900.00 8137.71 34.91 164.47 169.26 ; 14050.00 8811.64 11925.00 8156.06 34.91 ; 14050.00 8811.64 11950.00 8174.43 34.91 : 14062.21 8810.33 11975.00 8192.83 34.42 ; 14064.19 8810.12 12000.00 8211.26 34.34 :14~.~~_~9.90 ~~~~5:~_.!229.7~_- 34.2~ 165.00 169.63 165.52 170.02 173.47 169.35 175.22 169.60 177.03 169.86 58.80 59.06 59.33 59.61 59.91 60.21 60.54 60.87 61.22 61.58 61.96 62.35 62.66 63.07 63.49 9.625 1642.41 69.47 1642.41 9.625 1618.91 69.50 1618.91 9.625 1595.49 69.52 1595.48 9.625 1572.15 69.54 1572.15 9.625 1548.91 69.56 1548.91 9.625 1525.76 69.58 1525.76 9.625 1502.72 69.60 1502.72 9.625 1479.78 69.62 1479.78 9.625 1456.95 69.64 1456.95 9.625 1434.24 69.66 1434.24 9.625 9.625 9.625 7.000 7.000 Warning Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass 1411.64 69.68 1411.64 Pass 1389.18 69.69 1389.17 Pass 1366.69 69.64 1366.69 Pass 1344.44 69.64 1344.44 Pass 1322.34 ~~<,>,,_1_322.3<t__~~s:'_-______n- ----..1 ------ ~ ~ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSNUTTALLETTER WELL NAME fl;!J 15-3/ 4- CHECK 1 STANDARD LEITER DEVELOPMENT DEVELOPMENT // REDRILL V EXPLORATION INJECTION WELL INJECTION WELL REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) / ANNUL¿R ~OSAL cTNO ANNULAR DISPOSAL L-) YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well --'---' Permit No, . API No. . . Production should continue to be reported as a function of the original API number stated above. . In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal bas not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated.. . ANNULUS L-) YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved ,sùbject to fuil compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. ~/. r-\ ~~!Æ~! m~ !Æ~!Æ~~~!Æ ALASKA OIL AND GAS CONSERVATION COJDIISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Stone Senior Drilling Engineer BP Exploration (Alaska), Inc. POBox 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit E-31 A BP Exploration (Alaska) Inc. Permit No: 200-175 Sur Loc: 608'SNL, 501 'WEL, Sec. 06, TllN, R14E, UM Btmhole Loc. 4760'SNL, 4606'EWL, Sec. 08, TllN, R14E, UM Dear Mr. Stone: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redri11 does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test ofBOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ðM~ J. M. Heusser Commissioner BY ORDER OF THE COMMISSION DA TED this 2.-~ day of November, 2000 dlfÆnclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .--, STATE OF ALASKA ,~ :... AND GAS CONSERVATION COMrv 310N PERMIT TO DRILL 20 AAC 25.005 11 b Type of well 0 Exploratory 0 Stratigraphic Test 181 Development Oil . 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 60.5' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028304 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number E.31A 9. Approximate spud date 02/15/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 16435' MD / 8760' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 90 0 Maximum surface 2553 psig, At total depth (TVD) 8800' / 3433 psig Setting Depth Top Bottom MD TVD MD TVD 8250' 6758' 10264' 8288' 10114' 8145' 16435' 8760' 11. Type Bond (See 20 AAC 25.025) ALASKA. 1a. Type of work 0 Drill 181 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface V J ../ 608' SNL, 501' WEL, SEC. 06, T11 N, R14E, UM At top of productive interval 491' SNL, 1192' EWL. SEC. 08, T11N, R14E, UM At total depth 4760' SNL, 4606' EWL, SEC. 08, T11N, R14E, UM 12. Distance to nearest property line 113. Distance to nearest well ADL 028305. 519' MD E-31 is 139' away at 12385' MD 16, To be completed for deviated wells Kick Off Depth 8400' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casinq Weiqht Grade Couplinq 7" 26# L.80 IBT-M 4-1/2" 12.6# L-80 IBT-M Number 2S100302630-277 Hole 8-1/2" 6-1/8" Lenqth 2014' 6321' Quantitv of Cement (include staqe data) 460 cu ft Class 'G' 920 cu ft Class 'G' 19. To be completed for Redrill. Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical REl£\VFD Casing Structural Conductor Surface Intermediate Production Liner Liner 13394 feet V" 8831 feet"/ 13385 feet 8831 feet Length Plugs (measured) OCT ~:f..'J ?Q\1fj Size Cemented 1:' m~'¡"~'H"" (' x::: v¡þ', .~ """.", . 1\! ,. "1\ &J\"'~' - .--- ;Ua5Ka ". 'MtMrage MD TVD Junk (measured) 78' 20" 3882' 13-3/8" 10638' 9-5/8" 2244' 7" 820' 4-1/2" 280 cu ft Arcticset (Approx.) 2909 cu ft PF. 432 cu ft Class 'G' 1900 cu ft Class 'G' 110' 3918' 10670' 110' 3533' 8355' 480 cu ft Class 'G' Uncemented Slotted Liner 1 0450' - 12694' 12575' - 13394' 8259' - 8844' 8841' - 8831' Perforation depth: measured Slotted Liner: 12698' - 13370' OR\G\NAL true vertical Slotted Liner: 8844' - 8832' Contact II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Prepared By NamelNumber: Terrie Hubble, 564-4628 20. Attachments 21. I hereby certify Signed Dan to the best of my knowledge Title Senior Drilling Engineer Date 1<:> Permit Number --- API Number .../ 2cb-IÎ!:> 50- 029-22411-01 Conditions of Approval: Samples Required 0 Yes IZJ No Hydrogen Sulfide Measures £\ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: Approval ~ate 11.,- J,/JJ-OO Mud Log Required Directional Survey Required 0 4K 0 5K 0 10K 0 15K See cover letter for other requirements 0 Yes III No IKI. Yes 0 No ~.5K psnar;;J.lJ Approved By Form 10-401 Rev. 12-01-85 O~Ir..INAL SIGNED BY J. M. Heusser Commissioner by order of the commission Date 1I';;'~"'t:Jo Submit In Triplicate Permit to Drill RDIU BP IlISU DRIWIG & WWI Well: E-31 A Drill & Complete AFE: ,--" ~ Drilling Rig XXX Classification: Horizontal Sidetrack Producer Targeting Zone 13P Sands 4P1565 AFE Amount: $3,910 M Days: 32.1 1530 MSTBO Expected 12 Month Avg Incremental Rate: 1600 BOPD Additional Recovery: Estimated Spud: Feb. 15, 2000 Prepared By: Steve Schmitz FOUR OBJECTIVES FOR WELL: 1. NO ACCIDENTS 2. NO SPILLS OR ENVIRONMENTAL VIOLATIONS 3. NO POLICY OR REGULA TORY VIOLA TIONS 4. MEET OR EXCEED COST AND QUALITY OBJECTIVES No portion of this work is so urgent that the time cannot be taken to do it without injuring yourself or others Approved By: Ops. Drilling Engineer Distribution: T. Bunch - MB 6-3 D. Stone - MB 6-3 Well File Drilling Rig Baker - Mail Slot Baroid - Mail Slot Dowell - Mail Slot Nabors - Mail Slot Schlumberger - Mail Slot Directional Co. - Mail Slot Halliburton- Mail Slot Contacts Drlg. Superintendent Senior Drlg. Engr. Ops. Drlg. Engr. Pad Engr. Geologist Geophysicist Reservoir Engr. Date Senior Drilling Engineer Drilling Superintendent Date Date 1 Copy 1 Copy Original 6 Full copies 1 Copy 1 Copy 1 Copy 1 Copy 1 Copy 1 Copy 1 Copy Attach ments: Drilling Program Approved Permit to Dril Sundry Permit to P & A Wellbore Schematics Directional Plan Well Location. Wellhead, BOP Stack Depth - Time Curve AFE Time-Cost Breakdown. Tech Lmts Bit Selections, Drillpipe, Whipstock, Liner Equip Baroid Mud Program Dowell Cement Program Name Tony Bunch Dan Stone Steve Schmitz Claud Balgobin Becky Watson Mike May Mike Rathmann Work 564-5219 564-4002 564-5773 564-5808 564-5363 564-4050 564-4708 1 Home 348-6683 348-0239 240-6094 677-1463 277-2236 348-0324 338-1222 Cell 240-8051 240-8075 240-6094 / r-, ~ Permit to Drill IWell Name: I E-31A I Sidetrack Plan Summary I Type of Redrill (producer or Injector): I Producer Surface Location: 608' FNL, 501' FEL Sec. 06, T11 N, R14E Umiat 5976455.2 N 664455.63 E 491'FNL, 1192' FVVL, Sec. 08, T11N, R14E 5971331 .98 N 666280.28 E TVDss = 8690' Bottom Hole Location: 4760' FNL, 4606' FVVL, Sec. 08, T11 N, R14E 5967141 N 669802 E TVDss = 8700' I MD: 16435 I I TVD: 8760 I I CBE: 32 I I RIG: 28.5 I I RKB: 60.5 Target Location: TZ1 I Rig: I Pending I I Start Date: I 2/15/00 '- Objective: 1. Decomplete & LD 3 Y2" tubing for salvage. 2. Conventional Horizontal Sidetrack orient out of 9 5/8", 47#@8400'. 3. Drill 8 1/2" Intermediate hole directionally to TSGR. 4. Set 7" 26#, L-80 drilling liner, drill-out & FIT. 5. Drill 6 1/8" Production hole into Zone 1A horizontally wI LVVD. 6. Set 4 Y2" solid, cemented liner & DPC 6 JSPF perforate w/2.5"guns. 7. Install 4 Y2 12.6#, L-80 Tubing & completion. Development producer targeting sands in Zone 1 (13P& 14P). Well Design: Mud Program: Milling/Cutting Casing Mud Properties: LSND I Whipstock Window in 9-5/8" 8400' Density (ppg) I Funnel Vis I Yield Point I pH I HTHP FL 10.4 45-55 25-30 9-9.5 <12 Intermediate Mud Properties: LSND 181/2" hole section 8400' to 10287'MD Density (ppg) I Funnel Vis I Yield Point I PV I tauO I pH I 10.4-10.9 45-55 20-28 1 15-1917 3-7 9-9.5 (Have mud weight to 10.9 ppg 200' before entering HRZ shale 2-9300'.) Production Mud Properties: Low Density QUICKDRILn 61/8" hole section 10287 to 16435 Density (ppg)1 Funnel vis I LSRV I PV YP I Ca++ I API FI 8.3 - 8.5 40 - 50 < 20,000 cP 5 - 8 20-27 <100 <10 I API FL <10 pH I 9.0-9.5 Directional: KOP: Side-track @8400' @ 41 degrees inclination Hold: Hold Inclination at 42 degrees into Kingak. Drop: Drop Inclination to 12 deg at intermediate casing point. Build: Build To horizontal wi 20 deg DLS & drill multiple geologic targets in pay sands. Max Inc 90 Degrees in the horizontal leg. 2 Permit to Drill Well Name: API Number: Well Type: Current Status: BHP/BHT: Last H2S Sample: Is this well frac'd? LOT r~, ~ Current Well Information E-31 50-029-22411 Horizontal producer. Shut-in I PSI I TVO I PSI/FT I PPG I BHT I 3500 8800 0.398 7.65 190.00 16 ppm No Mechanical Condition Tubing: 3112",9.2#, L-80, NSCT TO I PBTO I Fill: Casing Head: Casing Hanger: Tubing Head Adapter: Tbg. Hanger: BPV Profile: Tree: Open Perfs: Tubing Fluids: Annulus Fluids: Tubing Test: Annular Test: SFC CSG Test: Casing Pack-off Test: Tubing Pack-off Test: Pre-rig expected P&A cement. 133/8" x 135/8" Gen. VI, FMC 5M , Emerg. Slips 135/8" 5M x 11" 5M, 95/8" Mandrel tested 5000 psi 11/93 11" 5M x 4 1/16" 5M 4" CIW, wi SCSSSV ports 4" 5M wi Baker Actuator To be P&A'd as part of pre-rig work Seawater and diesel as per handover Seawater and diesel as per handover Pending Pending Pending Pending Pending 3 ,¡--, Permit to Drill .~ Formation Markers: RKB: 60.5 Formation TVDss TVD MD Comments: WS2/Top West Sak 5895 5956 CM3/K1 a/Top Colville Mds 6305 6366 Side-track, KOP 6810 6871 8400 CM1/KS 7313 7374 9084 THRZ 7473 7534 9302 BHRZ 7655 7716 9551 Put River Kuparuk Ss N/A N/A Kingak/LCU T JD/Top Kingak D T JB/Top Kingak B ) 8130 Sag River Ss 8228 WD-TSHU/Shublik 8267 Eileen N/A WD-TSAD/TZ4B 8343 WD-TZ3 8458 WD-TZ2C 8530 WD-TZ1B 8690 14N 8703 WD-TDF/13N 8735 12N 8774 BSAD not penetrated TD 8700 7705 Logging Program: Intermediate Section Drilling: Open Hole: Cased Hole: Drilling: Open Hole: Cased Hole: Production Hole 7766 8191 8289 8328 8404 8519 8591 8751 8764 8796 8835 8761 9619 10264 10304 fault this interval 7" Csg Point 10381 10499 10572 10755 11000 Start Horizontal 16435 End Horizontal MWD / GR / RES(optional per geologist) None None MWD / GR / RES/DEN/NEU real time None None 4 ¡-'-, ~ Permit to Drill CasinglTubing Program: Hole Size CsglTbg #/ft Grade Conn Ft, Req'd Top MD TVD Btm MD TVD ID 81/2 7 26 L-80 IBT-M 2014 8250 6758 10264 8288 6.276 Liner 61/8 41/2 12.6 L-80 IBT-M 6321 10114 8145 16435 8760 3.958 Liner 9.625 & 7 41/2 12.6 L-80 IBT-M 10114 0 0 10114 8145 3.958 Tubing Cement Calculations: Liner: Intermediate Lead: None Tail: Design based on 80' shoe track volume, open hole @ 30% XS, 150' liner lap, 200' XS. Barrels I CF I Sacks I PPG I CFlsk TOC, MD TOL Top OH Btm, MD Type 82.0 460 397 15.8 1.16 7750 7950 8100 10264 Dowell Class 'G" Cement Length, feet 200 150 2164 80 Barrels/ft calc's 0.058 0.026 0.029 0.038 Liner: Production Lead: None Tail: Design based on 80' shoe track volume, open hole @ 50% XS, 150' liner lap, 200' XS. Barrels I CF I Sacks I PPG I CFlsk TOC, MD TOL Top OH Btm, MD Type 163.8 920 786 15.8 1.17 9914 10114 10264 16435 Dowell CI 'G"+adds Cement Length, feet 200 150 6171 80 Barrels/ft calc's 0.023 0.019 0.025 0.015 Drilled Interval 1: Total length to be drilled this interval:»»>- KOP 95/8" 47# ID 8.681 I KOP: 8400 I Bit: Drift 8.525 Bit Run Bit Mfr Model IADC Krev's Hrs In Out Run 1 Run2 Drilled Interval 2: Total length to be drilled this interval:»»>- Drill out: 7 26 ID 6.276 I Shoe: 10264 I Bit: Drift 6.151 Bit Run Bit Mfr Model IADC Krev's Hrs In Out Run 1 Run2 Run3 8 1/2 inch bit in liner 4 7 6 1/8 inch bit 4 1/2 in liner 4 5 81/2 1864 to 10264 Ftg 6171 61/8 to 16435 Ftg in. DP in. DP , . ¡---.., ~ Permit to Drill Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams. and annular preventer will be installed and capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. . Maximum Anticipated Surface Pressure: (based on BHP & full gas column at 0.10 psi/ft). . Section Max Sfc Pres. Presv TVD Gas Grad. EMW FM Intermediate 2427 3264 8369 0.1 7.5 Sag R Production 2553 3433 8800 0.1 7.5 Zone 1 . Planned BOP test pressure: Planned completion fluid: 3500 psi Intermediate/3500 psi Production 8.6 ppg Seawater / 6.8 ppg Diesel . Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S . E-Pad is not designated as H2S drill sites and do not have wells with over 16 ppm. Standard Operating Procedures for H2S precautions should be followed at all times. RIG MOVE & SHUT-IN REQUIREMENTS . Adjacent wells E-12 & E-13 are 74' & 36' distance, respectively, from the proposed wellhead. Establish a minimum rig distance of 5' from each of the adjacent wellheads or wellhouses. Discuss the move at a pre-job safety meeting and designate a spotter to ensure that there is no danger of collision. . DRILLING CLOSE APPROACH: There are close approach wells associated with the directional plan for this well. The risk of collision is considered to be minor as the trajectory immediately begins diverging away from the offset wellbore(s). The consequences of a collision could include lost circulation or a hydrocarbon influx (kick). Remedial action could include squeeze cementing and sidetracking. I Close Approach Well: I Status E-31 To be P & A'd Ctr-Ctr Distance 139' While Drilling at: 12385' 6 , ,,-..., ~ Permit to Drill INTERMEDIATE SECTION DISCUSSION: . Hydrocarbons are unlikely to be encountered in the intermediate section. However, follow good well control practices at all times. Monitor pit volumes and mud returns for any signs of insufficient mud weight. . There should not be significant wellbore stability problems within the intermediate interval. Kick-off with sufficient mud weight into the K5 marker shale and maintain MW into the Kingak shale that will be encountered. Good drilling practices and 10.5 ppg mud weight will be used to maintain the shales in the intermediate hole section. Also, asphalt shale products such as Baranex and Barotrol in the mud system and the HTHP filtrate values below 10 cc/30 minute will assist with shale stability. It would be advisable to minimize pressure surges while drilling, tripping, and running liner. After sidetracking- the intermediate hole will be drilled to casing point. Tight hole, stuck pipe, and packing off have been the main problems throughout this interval. Lost circulation has been experienced when running liners (possibly due to excessive surge pressures). . . KICK TOLERANCE: In intermediate open hole section is 51 bbls at an ISIP of 468 psi. This assumes an influx from the Sag River formation, a 7.5 ppg pore pressure within that interval, a 10.5 ppg mud in the hole, exerting pressure against an 12.5 ppg fracture gradient at the whipstock window. LOT 12.5 ppg 20' out of window. PRODUCTION SECTION DISCUSSION: . Fault crossings can be expected in the hydrocarbon bearing reservoir at 14705' (expect to drill into an up-thrown fault block). Lost circulation may be encountered and adequate bridging agents must be on location for drilling fluid treatment if necessary. . KICK TOLERANCE In production hole, at the drilling liner shoe would be the entire annular volume assuming an influx at section TD. This is a worst case scenario based on a 7.5 ppg pore pressure, a minimum fracture gradient of 9.5 ppg at the 7" casing shoe, and 8.5 ppg mud in the hole. LOT to 9.5 ppg 20' out of drilling liner. Disposal: . No annular injection in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. 7 ----- ~ Permit to Drill Detailed Operations: *Review the Hydrogen Sulfide Standard Operating Procedures prior to opening the well* *Complete a pre-rig inspection wI the DS Operator prior to the rig moving on the well* *Notify the AOGCC representative 24 hours in advance to witness BOP testing* * Note wellhead, lA, and OA casing pressures and bleed-off as required prior to MIRU. 1. MIRU Drilling Rig. Remove BPV wI lubricator. RU to tree w/ circulation lines and displace diesel freeze protection from well, with seawater, through choke. Continue to circulate until clean seawater returns to surface. Verify that the well is dead. 2. Install BPV/Plug or TWC(as req'd by type of hanger) and test from below to 3500 psi. Nipple down tree and adapter. Send tubing hanger, tree and adapter in for inspection/repairs as required, and re-running on this well if possible. NORM test all wellhead equipment and retrieved completion equipment. Strap rotary table to Þélse flange distance. Reference RP: "Decompletions". Lo#yy ,.-...... hq,,?"fY7 3StJà~'"{ "J,u e>SÒ~ \,/", ( 3. NU & test BOPE to 250 psi low & ~si high. Test the annular to 250 psi low and"3SQQ..e..si high. Pull BPV through lubricator. 4. PU landing it and screw into tubing hanger. LD tubing from the E-line cut. Do not exceed the tubing tensile rating @ 80%. If the tubing cannot be pulled then work the tubing repeatedly in an attempt to weaken the cut and prepare for a 2nd CUt. 3 1/2" L80 Pc Pb Tensile ID/Drift Conn. 100% 10530 10160 202220 2.992 NSCT 80% 8424 8128 161776 2.867 I Length I 11ft I AirWt I B.F. seawater Wt I 8400 9.2 77280 0.868 67079 5. Make "dummy" mill run to drift casing. RIH on DP w/ watermelon mill assembly to top of tubing cut or KOP/sidetrack depth -8400'. CBU & POOH. (leave-out the starter mill on this run). 6. Set CIBP on e-line 2' below csg collar or per Baker rep. Pressure test the casing to 3500psi. 7. Replace casing pack-off if necessary. End de-completion phase. 8. Whipstock BHA No.1: RP: "Whipstock Sidetracks" Top to btm as follows: . 4" DP, 15.7# HT, S-135 . - 12 HWDP (3 % HWDP) . 9 DC's, . UBHO . 4 % MWD . Bumper Jars . Float Sub . Upper Watermelon Mill . Lower Watermelon . Starter Mill 8 r-- ~ Permit to Drill . 7 5/8" Bottom Trip Whipstock & Anchor. Note: Whipstock should be equipped w/ weld-on centralization when orienting to greater than 60 degrees from high side. 9. Set bottom trip anchor & shear-off Whipstock. Displace well to LSND drilling fluid. Position ditch magnets in mud system. Orient using gravity high side readings 75-85 degrees as required. Mill window. Circulate the hole clean w/ viscous sweeps. 10. Ensure all BOP equipment is operable & wash out BOP stack(using PBL tool) of any settled cuttings. 11. BHA No.2: PU 8 W' Kick-off & hold assembly. . 4" DP to sfc . 20 jts HWDP . Hydrauloc Drilling Jars . 3 Flex NMDC's . Pulser/UBHO . 6 %" MWD (DIR) . 6 3J¡" MWD(RES/GR/DIR) . Float/XO . 6 3J¡" Pos. Displacement Motor . Bit Top to Bottom: Bit Motor Flow Rate RPM's Req'd Doglegs 12/100 8 Y2" Insert Pending... 12. Drill off using high side gravity readings (-125 deg) to get away from existing casing. Drill 20' of formation & conduct FIT to 12.5 ppg. Reference RP: LOT & FIT. Drill ahead to section TD @ TSGR. Drop ESS to satisfy JORPS, & POOH to run liner. a. Run MWD/GR/RES over the entire interval b. Run a recorded MAD pass across the cased hole at least 200' above KOP & include this footage in the final log print. c. At section TD circulate & condition the mud. Drilling fluids at this point are critical to avoid excessive surge/swab pressures while POOH & running 7" liner. d. Prior to final trip out to run casing, conduct a short trip, circulate & spot a Barotrol/Lubetex liner running pill in the open hole. Open hole volume as required. Note: RP: Safely Drilling Kingak & HRZ shales. See formation marker depths. Adjust flowrate, RPM's, & ROP as necessary to clean the hole. . Maintain 4ppb Baranex & 4 ppb Baratrol & reduce HTHP to < 10cc/30 min w/ N-Dril HT through the Kingak. See attached Baroid mud program. . Maintain MW through the interval or as dictated by hole conditions. . Treat the system wi 4 ppb Barafiber LCM prior to entering Sag R. Note: Survey program per JORPs: . DLS 1-5 deg/100: 90' (Every stand, not exceeding 100') . DLS > 5 deg/100': 30' (Every jt) Note: Locating top of Sag River (TSGR). . The on-site Geologist will be needed throughout the intermediate hole section for correlation of formation markers and selection of interval TD. Locating TSGR: The desired casing point is the thin siltstone at the base of the Kingak. In order to prevent drilling into the Sag R. and the risk of associated lost circulation, control drill at 5' intervals from 25' above the TSGR until the siltstone cap is ID'd. Correlate depth using GR. Each 5' interval will be circulated btms up for sample 10. 9 ~ -~ Permit to Drill 14. Run 7",26#, BTCM casing as follows: . Float Shoe . 2Jt . Float Collar . Landing Collar . 7" 26#. L-80 as req'd plus 150' of overlap into previous casing. . HMC Liner Hanger . ZXP Liner top packer wi 6' Tieback Receptacle . C-2 Setting Tool (Non-rotatable) . HWDP as needed for weight set packer . 4" DP to surface . Use Best-o-Life 2000 thread compound. Threadlock all connections to FC . Run 4 solid, straight blade, 1,4" under-gauge, centralizers. (Jts 1,2, 4, 6) Jt 1 locked down -5'fromFS.AII others locked down mid-it. . Break circulation at the window, circulate & condition mud. . Once on btm break circulation slowly to avoid breaking down Sag R. . Do not exceed HMC hanger setting pressure. (800 psi max circ pressure until on btm) 7" Pc Pb Tensile Connection ID/Drift 100% 5410 7240 604000 519000 6.276 80% 4328 5792 483200 415200 6.151 BTCM Length I #/ft I AirWt I B.F. I Buoy Wt. M.W. 2014 26 52364 0.84 43970 10.5 15. Cement liner in place. Reference RP: Modified Conventional Cementing Guidelines. See Dowell cement program for slurry and additives. Max 6 bpm pumping rate to avoid excessive ECD. . 50 bb111.5 ppg weighted spacer. . Cement slurry @ 15.8 ppg wladditives . 10' reciprocation if practical . Drop drillpipe wiper dart & displace wi mud. Approx 2-4 bbls before latching liner wiper plug slow pump rate as req'd. Correct displacement volumes. . Set pipe on btm and bump plug wi req'd psi to set liner hanger. . Slack off weight as req'd, bleed pressure, & check floats. 16. Release C2 running tool wi 8-10 turns to the right. Pressure DP to 1000 psi, PU to clear seals & packer setting dogs from tie-back sleeve. Immediately break circulation to clean hole above liner top while slacking off req'd weight to mechanically set the liner top packer. Circ. Out XS cement. Do not pressure test liner top at this time. (WOC). Upon POOH, check indicator pins on settinglrotating dog sub to confirm pkr setting force. 17. BHA No. 3:6 1/8" Production hold, drop, build to horizontal assembly: . 4" Drill-pipe to surface . -21 its 3 W' HWDP . 4" DP, 15.7#, HT, length as req'd . JARS . NMDC'S . MWD (DIR/GR/RES/DEN/NEU) . Float Subs & Xo . Mud Motor . BIT Bit 61/8" Motor See Anadril BHA recommendation Flow Rate _GPM _dP RPM's Rotary: xxx Motor: xxx Req'd Doglegs 16 deg/100' 10 ~ ~ Permit to Drill 18. TIH to landing collar. Pressure test casing to 3500 psi. Drill out shoe track (cement float equipment). 19. Displace the well to Low Density Quickdrill Mud System per attached program. Drill 20' of new formation & Conduct LOT to 9.5 ppg EMW. 20. Drill the 61/8" "heel" section per directional plan. TOOH for bit (probably after Zone 3 Conglomerate) 21. BHA No.4 6 1/8" Production build through heel and start horizontal. . 4" Drill-pipe to surface . -21 its 3 W' HWDP . 4" DP, 15.7#, HT, length to be determined by expected bit trip . Circulating Sub (for LCM) . JARS . NMDC'S . MWD (DIR/GR/RES/DEN/NEU) . Float Subs & XO . Mud Motor . BIT Bit 61/8" Motor Flow Rate/dP RPM's Rotary: Motor: Req'd Doglegs 20 deg/100' 22. BHA No.5 61/8" Production build through heel and start horizontal. . 4" Drill-pipe to surface . -21 its 3 W' HWDP . 4" DP, 15.7#, HT. length as req'd . Circulating sub (for LCM) . JARS . NMDC'S . MWD (DIR/GR/RES) through horizontal section. . Float Subs & XO . Mud Motor . BIT Bit 61/8" Motor Flow Rate/dP RPM's Rotary: Motor: Req'd Doglegs 12deg/100' 23. Drill to horizontal section TD in Zone 1 B sands utilizing wiper trips as required to minimize cuttings "banks". circulate & condition hole. RP: "Prudhoe Bay Directional Guidelines" and "lubricants for Torque and Drag Management". . TD picked by on-site geologist 24. TIH, circulate, & condition hole for casing. Spot a liner running pill composed of 5% Lubetex wi -50000 LSRV on final trip out. 25. Run solid production liner. Reference RP: Modified Conventional Liner Cementing. . Halliburton Float Shoe . 2 jt . Float Collar . Landing Collar . Sufficient joints for 150 liner lap. Marker short jt located top zone 2. . HMC Liner Hanger & ZXP Liner Top Packer wI 6' Tieback Receptacle( 3.625 ID) 11 /---- ~ Permit to Drill . C2 setting/running tool 4" DP to surface Best-o-Life 2000 thread compound. Thread-lock all connections through LC Run 1 unsecured turbulator per jt on every 4th Jt except near shoe. Centralizer on jt. 1 should be locked down -5' from the shoe. Break circulation after PU 1st stand of DP & at the intermediate liner shoe. Circulate & condition mud. Do not exceed shear pressure of the hanger. Once on bottom, break circulation and increase pump rate slowly to avoid breaking down the formation and losing returns. Circulate only long enough to establish adequate pump rate for the cement job or minimum of liner annulus volume. . . . . . 4.5" Pc Pb Tensile Connection ID/Drift 100% 7500 8440 289000 289000 3.958 80% 6000 6752 231200 231200 3.833 BTCM Length I #/ft I AirWt I B.F. /BUOY Wt. M.W. 6321 12.6 79645 0.87 69309 8.5 29. Cement production liner as per Dowell cementing program: (Use 'Modified Conventional Liner Cementing' RP as a guideline) . 50 bbls, 9.5 ppg, B45 viscosified spacer. . Class "G", 15.8 ppg, Cement slurry as per cementing program. . Drop DP dart and displace with 'perf pill' (liner volume + 30 bbls) followed by mud. Max circ rate to avoid excessive ECD is 4.5 BPM. Reciprocate pipe until the pre-flush reaches the shoe. Spot string on bottom until the pre-flush, spacer, and -10 bbls of cement round the shoe then resume reciprocation if hole conditions allow. Approx. 2-4bbls before DP volume is displaced, slow pump rate as required to observe latching of dart into liner wiper plug. Correct displacement volume as required. . Continue displacement. Approx. 5 bbls before calc'd plug bump into landing collar, slow pump rate to -2bpm. . Set Hanger & Liner Top Packer . Do not reverse circulate. . Displace the well to clean seawater above the liner top. POOH standing back DP. LD liner running tool. Pull wear bushing. 30. Once the cement has had adequate time to set(-8 hrs) close blind rams and test casing to 3500 psi for 30 mins using chart recorder. 31. Perforate using DPC guns. Perforation intervals will be determined after logs are reviewed. Reference: 'Drill Pipe Conveyed Perforating' RP. PU perforating assembly as follows: . Halliburton, 11 gm, HMX, Perf guns 2.5" 00 @ 4 & 6 SPF (Expect -4000') . Firing head & Circulation sub. . 31/8" Hydraulic Jars (see Dailey recommendation) . HWDP, 2 7/8" DP, & 4" DP to surface. 32. RIH wI 2718 drillpipe (to clear 4 W' liner top) & 4" DP to surface. Pipe should auto-fill through the ported sub. Slow running speed at top of liners. Continue to PBTD.Tag up on landing collar for space-out. Record PU & SO weights. With pipe on depth, RU sound recorder to monitor shots fired. Close Annular Preventer & pressure to 2500 psi to fire guns. Upon firing, open Annular and POOH until guns are above top perf. Note over pull and monitor hole fill closely. When free, circulate & monitor hole to establish loss rates. 33. POOH and lay down all DP and perf guns. Keep hole full wI seawater. Note shots fired on IADC. Pull wear bushing. 34. Run completion equipment. RP: 'Completion Design and Running. Top to bim as follows: . 4 W' Tubing An 'X' nipple should be run at -2200' MD . 12 /"""'- /"",,, Permit to Drill . Top MMG GLM wi RP Shear Valve in place @ 3688' MD 3250' TVD. 4 W' Tubing 4 W' x 1 W' GLM @ 6559' MD, 5500' TVD 4 W' Tubing 4 W' x 1 W' GLM @ 8373' MD, 6850' TVD 4 W' Tubing 4 W' x 1 W' GLM @ 9777' MD, 7850' TVD (note top of 7" liner -8250') 'X' nipple tubing tail (with RHC plug installed) & 10' Pup 10'Pup Halliburton 7" X 4-1/2" TNT Production Packer (Badami, BP surplus property) 10' pup 20'pup XN wi RHC plug installed 20'Pup WLEG . . . . . . . . . . . . . . . Space out the WLEG into the 4-1/2" production liner tie-back sleeve (tie-back sleeve has 5 %" ID and WLEG has a 4.95" aD) 4.5" Pc Pb Tensile Connection ID/Drift 100% 7500 8440 289000 289000 3.958 80% 6000 6752 231200 231200 3.833 BTCM Make-up tc Length I #Ift I AirWt I B.F. IBUOY Wt. M.W. 10114 12.6 127436 0.87 110899 8.5 35. With the tubing spaced out and landed in wellhead, reverse circulate clean corrosion inhibited seawater into the annulus. Circulate sufficient volume to see bottoms up returns to ensure tubing in clean. Once complete, drop ball I rod to RHC plug. Set the packer and test the tubing to 3500 psi for 30 minutes. Slowly bleed tubing pressure to 1500 psi and test the annulus to 3500 psi for 30 minutes. Bleed off tubing pressure and shear RP valve. Freeze protect the well by reverse circulating in a sufficient volume of diesel to freeze protect both the tubing and annulus to 2200' TVD. Allow diesel to U-tube from annulus to tubing and equalize at -2200' TVD. 36. Install a BPVfTest Plug.Test from below to 3500 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 37. Install BPV. Secure well. 38. Rig down and release the rig. II * Complete a post-rig inspection with the DS Operator prior to the rig moving off the well * II Post-Rig Work: . MIRU slickline. Pull the ball I rod and RHC plug from 'X' nipple below the new production packer. . Install gas lift valves. . Place well on production. 13 ~. ~ Permit to Drill RiQsite Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Intermediate Section: ~ The intermediate section will be drilled with adequate mud weight to combat shale instability in the HRl shale and Kingak shale, after side-tracking from the kick-off-point. ~ Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRl shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. Production Interval: ~ Lost Returns & Stuck Pipe have been experienced during past Drill Site Operations. Mud weight will be maintained at an adequate weight range to control formation pore pressure estimated at EMW at 7.5 ppg. ~ A fault crossing is expected while drilling horizontally in the reservoir. See site geologist for depth. Slight risk of lost circulation is possible. LCM additions may be warranted to restore circulation. ~ This Drill Site is not a designated H2S pad. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 14 .~ TREE: 4" - Carbon 5M ACUATOR: BAKER WELLHEAD: 13-31" FMC - 5M 13-3/8",68#, L-80, BTC I 39/6' I l KOP @ 1000' J Max Angle: 93 ° @13,393' 3-1/2" 9.2#/ ft, L-80 Tbg NSCT. Tubing ID = 2.992" Capacity = .0087 BBU FT HORIZONTAL COMPLETION Baker 9-5/8 x 7 Liner Hanger wi TBE 110,450' ~ 110,457' L--1 110,670' ~ I 9-5/8",47# NSCC T'x 4-112" TIW SS Packer W/ Scoup head 112,57$' 1 .I. PERFORATION SUMMARY REF: LOG: I SIZE I SPF I OPENISQZ'r INTERVAL I BOTTOM OF '"t.\ 2.~ 113,39'\' I LINER (\1.,tø"",L,SO) DATE 12-11-93 COMMENTS COMPLETION REV. BY MDO >~ E-31 KP ELEV = 65.20 BF ELEV = 35.25 ~ 0 --_.£>TIS XBD Landing Nipple (2.75" MIN 10) l 1973' I GAS LIFT MANDREL Cameo MMG W/ 1-1/2" "RK" Latch N" MD (BKB) TVOss 3 4901' 4266' 42.3 J 2 8365' 6844' 40.7 1 9305' 7547' 43.2 . 3-112"SWSNipple 110183'1 01 (2.75"MINI0) , 56 1 NOTE: 11,000'66°111.500' 71° I I Baker SABL 3- g<fflr' "sws" Nipple .Gæ'lSWIIII tÐpple ( 2.635 MIN ID ) 112,191'1 87°1 112,228' I 112,245' 187°1 112,256' I = 3-1/2" WLEG I I ~ 7",26#, NT80 Liner 112,694' I 4-1/2" Slotted Se.c:..~ot\ l'2.(o~8'- 13'3'10' PRUDHOE BAY UNIT WELL: E-31 API NO: 50-029-22411 BP/ARCO PBU DRILLING TREE: 4" Carbon L-80 ACTUATOR: BAKER WELLHEAD: 133/8" FMC 5m KOP -1000' 133/8",68#, L-80, BTC 3918' TOC Calculated 9589" Tail TOL (7") 10450' 95/8" 47#@ 10670' Pkr 7" x 31/2" @ 12191' - TOL (4 1/2") @ 12575' 7" 26#@ 12694' ,r---, E-31 Proposed ~, . r:::::;J =::;;¡ P & A Cmt from 12597' to PBTD 13393' I I I I I I I I I I I I I I I I I I I I I I OKB: 65.20 RKB =60.5 est'd BF = 35.25 4112" 12.6#, L80, BTCM Tubing ~ 7 I I I I I I I I I I I I I I I I I I I I I I I I I I I ~ 9 5/8" x 7" Liner HangerlPacker I .t. Proposed: Whipstock set on clap @ -8400" MD' Cut 4 1/2" tubing below 8400 'MD /7 X 41/2 Prod. Pkr 10114'MD, 8132'TVD / / 7 X 4 1/2 Liner Hanger/Pkr " / Proposed: 8 1/2" borehole / /' 26 . LBOIBT-M ""lIIno Un" ..... TSG" Proposed: 6 1/8" borehole 41/2" Prod. Liner to 16435' MD ~~ /"'-... /"'-........~~ ~ ~~ ---~ --.....-- ----- L::::::... /"-...../"-..... /'... /'....... 41/2" slotted liner @ 12698 to 13370' ~'\....--"""~~~v- Date Revised by Comments 9/13/00 SHS Proposed completion 4-1/2",12.6#, L-80 @ 13395' ~~~;:f~ I Single Well Target Data for E-31A WPS ft Shared Services Drilling E-31 A Wp 08A I DrillQuest Measurement Units: Target Name E-J!AN,wPI E-1IAN,wP2 E-3IAN,wP3 Fit T",ot E-1IA W,ypoim#1 (l1900) W"""int#2 (l23<K» W,)point#3(l4200) Waypoint #4 (l5HH" W"""int#5(164()O) 7200 - ..c - Co ( ) 0 ëii () t ( ) > -= 0 0 CX) II .r:: u .!;; 8000 - 2 8800 -- ItS U (f) Proposal Data for E-31A Wp DBA Coordinate Polnl TVDrkb TVDa. Northing. Eastlng. ASPY ASPX Typ. EnuyPoint 5091.13 5 \ßß3.<H\E 5971400.00N 666450.00E Boun",",Point A 5()97.715 18U<KIE 5971400.(){) N 666450.00 E B 5302.075 2078.56E 5971200.00 N 666650.00 E C 5568.465 2822.90 E 5970950.00 N 66741){).I81 E ) 5559.69 S 2422.99 E 5970950.1K) N 6611K){).1K1 E E 5346.585 182753 E 5971150.00N 6664IKIOOE Entry Point 6321.77 5 3056.39 E 59702<KI.OO N 667650.1K) E BouudaryPaint A 6321.77 5 3056.39 E 5970200.00 N 661650.00 E B 6789.01 5 3746.35 E 5969750.00 N 668150.00 E C 7036.765 3640.89 E 59695<KI.OO N 668250.l){) E D 7389.91 5 3783.17 E 5969150.(){) N 6684(){).I)O E E 8401.935 4135.06E 5968146.00N 668774.00 E F 8496.13 5 3960.95 E 5968048.18) N 668602.IKI E G 7868.365 3704.66 E 5968670.1K) N 668332.00 E H 7312.425 3348.77 E 5969218.00N 667964.1){) E I 6828.03 S 3245.37 E 59697<KI.OO N 661850.00 E J 6520.435 2902.03 E 59700<KI.OO N 667500.()0 E EmryPoint 8310.595 4713.20E 5968250.00N 669350.00E Bouudary Poiut A 8110595 4713.20 E 5968250.00 N 669350.00 E B 8216.10 5 4965.31 E 5968350.00 N 6696(){).<K) E C 9262.825 5351.47 E 5967312.00N 67(){)()9.00E D 9515.795 4936.82 E 5967050.(){) N 669600.00 E E 8600.485 4613.82 E 5967958.18) N 669251.()() E Emry Poiot 8310.20 8250.1K) 5H){).I){) S 1585.26E 5971191.20N 666152.38 E Entrypolm 8850.20 8790.t){) 5852.125 2687.37E 5970663.44 N 667270.71 E Emry Point 8835.20 8775.00 6206.415 2872.95E 5970313.11N 667464ŒE EmryPoint 8835.20 8775.18) 7900.015 3732.37 E 5968618.96 N 668360.40 E EmryPoim 8785.20 8725.()() 8368.82 S 4488.04 E 5968186.85N 669126.18E Emrypoim 8760.20 87(){).I)() 9429.245 5140.76E 596714U8)N 669802.00E ~~~~:~t~lriBì~ :in : Measurementl{Jnits: North Reference: Well Well It True North Terge' Shape Polygtm Dogleg severity: Degrees per 100ft Vertical Section Azimuth: 148.782' Vertical Section Description:Well Vertical Section Origin: O.DO N,O.DO E Measured Incl. Azlm. Vertical Northlngs Eastlngs Vertical Dogleg Depth Depth Section Rate 841X).OO 41.155 159.356 6869.79 3931.145 1702.74E 4244.44 8440.lX) 41.384 166.628 6899.88 3956.345 17W.44E 4269.98 12.IX)() 8564.29 42.907 188.819 6992.55 4038.595 1713.47E 4341.89 I2.<XX) 9940.38 42.907 188.819 8000.47 4964.375 1569.84E 5059.18 O.IXX) 10286.38 t1.800 112.000 83W.20 5100.005 1585.26E 5183.16 12.1XX) 10286.97 11.847 112.258 8310.78 51()().O55 1585.38 E 5183.26 12.()(X) 10586.79 11.847 112.258 8604.22 5123.365 1642.34 E 5232.72 O.(X)() 10938.64 82.(XX) 123.1XX) 8830.()() 5248.()() 5 1848.46E 5446.15 20.lXK) II(XI1.74 89.506 123.999 8834.67 5282.705 1900.89 E 5503.<K> 12.1XX) 11797.67 89.506 123.999 8841.54 5727.765 2560.73 E 6225.60 O.O()() 11976.42 85.()(X) 145.0()() 8850.20 5852.125 2687.37E 6397.60 12.0()() ) 12074.46 93.299 153.347 8851.66 5936.155 2737.51 E 6495.45 12.1XX) 12343.58 93.299 153.347 8836.17 6176.285 2858.04 E 6763.27 O.()(K) 12377.21 90.IXX) 154.IXK) 8835.20 6206.415 2872.95 E 6796.76 10.000 12385.47 89.947 153.176 8835.20 6213.805 2876.62 E 6804.99 IO.IXX) 14215.31 89.947 153.176 8836.89 7846.745 3702.34 E 8629.45 O.IXX) 14276.51 93.218 148.0()() 8835.20 7900.015 3732.37 E 8690.57 W.lXX) 14705.23 93.582 105.051 8808.52 8148.785 4068.20 E 9077.38 IO.lXX) 14839.72 93.582 105.051 881)().I1 8183.645 4197.83 E 9174.37 O.lXX) 15189.73 91.150 141),(XX) 8785.20 8368.825 4488.1)4 E 9483.16 IO.IXX) 15276.60 91.150 148.689 8783.45 8439.325 4538.62 E 9569.67 IO.IXX) 16435.49 91.150 148.689 8760.20 9429.245 5140.76E 10728.33 O.()(X) Polygon Polygon PoInt Point Point Poin, Point Current Well Properties E-31A WPS Poin' WeR: Honzorlal Coordi""le.: Ref. Global Coordi",,'es: Ref. Stru:lt.re Reference: Ref. Geographical Coordinales: RKB Elevalion: 5976455.20 N, 664455.63 E 3250.34 N, 1988.44 E 70° 20'31.1168' N, 148' 39' 54.9867" W 60.2Oft above Mean Sea Level 60.2Oft above Stru:ft.re Reference ST Exit @ 12.0000/100lt, ~ 90.000° TF: 8400,OOft MD, 6869.79ft TVD A~~ Continue Dir @ 12.0000/1O0ft: ¡::¡ t>,' 8440.00ft MD, 6899.881t TVD 'ò\)<:J . End Dir : 8564.29ft MD, 6992.551t TVD ~Ç), ri,'ò~ ~. ~ ~~Ç) ..ci,Ç) ~~~ \)\)~ ..:... ..'... .o.@,~#\:..."'1~;"o'~;~~O'~.... ..#,<þ~",o. ;,,~~..... .... .'::;: ;:::~:~. ,~ ~ #"'~ ~ "'('~~~~~Hn~'Pcp1~q~~..~~~~\)~~~$H"'P1~~Ç)~~~;¡i!~' H..,qq, . ri,~~~Ç)' ~~~Ç)~~~~Ç) .00 , .<:Iv \),,' O\"A~ ~. ",' _.æ: .~. <','1~ bP " ..' . , 0\" ¡::¡<::s 'P' 1ci, 'P'P" L<t..3P' t>,r¡;.' ç','ò.\'f>þJ 'òri,. ";'<f" - \)\)<::s - ~r¡;.~'ò't. -"""'~~ ~~. '8;~J' "~ ~~" 'ò1 <>~:,"",,~~',<f!":Ø',:..~1#! "".."""'",@,o,.ø:~~~~.;J!'~Q' ... ...... m"~,"",, ~~HH' 'ð"" ¡;~-' l ~'~::," ,{«);;.'r:¡i,; c' /:tt~"'i"'" ~~. :Ú1:¡:~~. I I I 8800 9600 10400 \ i~;~.~~~D 8760.20 TVD Section Azimuth: 148.7820 (True North) North Reference: Urits: True North Feel ) "þ~~~' ""Ii-:OO" I 4800 Scale: 1 inch = 800ft I 5600 I 6400 I I 7200 8000 Vertical Section ~ ~ spel"T"y-sun I DAIL.~=""",~.:.:VII:::IiiS Shared Services Drillìng F-31 A Wp ORA I DrillQues{ We!: Current Well Properties E-31A WPS Horizontal Coordinates: Ref. Global Coordinates: Ref. SI""h..e Reference: Ref. Geograpl1cal Coordinates: RKB Elevafion : 5976455.20 N. 664455.63 E 3250.34 N. 1988.44 E 70" 20'31.1168" N. 148" 39' 54.9867' W 60.2011 above Mean Sea Level 60.2011 above Struclure Reference North Relerence : Units: True North Feet Scale: 1 inch = 900ft 1800 :...'~.... I 2700 I Eastings 3600 I 4500 I 5400 I -3600 - - -3600 >dl @ 12.000°/10011, ---. 0° TF : 8400.0011 MD, 6869.7911 TVJ::j~~:,~, Continue Dir@12.OO00/100l1:7'-- 8440.0011 MD, 6899.8811 TVD \ d Dir : 8564.2911 MD, 6992.5511 TV \. 1400.00 .. -4500 - \;c."".. - -4500 en 0> oS .s=. t::: 0 Z 190000 /.Begin Dir @ 12.000°/10011: 9940.3811 MD, 8000.4711 TVD ~ ~End Dir: 10286.9711 MD, 8310.7811 TVD ". ~"'---------~Begin Dir @ 20.000°/10011: 10586.7911 MD, 8604.2211 TVD ~O~;'~~MD/~' ~ Decrea~e in Dir Rale @ 12.000°/10011: 10938.6411 MD, 8830.00ItTVD 8288.2DTVD '-Ç-~End Dlr: 11001.7411 MD, 8834.6711 TVD -5400 - """'- \ - -5400 Y-Begin Dir @ 12.000°/10011: 11797.6711 MD, 8841.54ltTVD ~:.~End Dir: 12074.461t MD, 8851.6611 TVD \~ 'Begin Dir @ 10.000°/10011: 12343.5811 MD, 8836.1711 TVD V- End Dir: 12385.4711 MD, 8835.2011 TVD /\ - -6300 \' -6300 - -7200 - en 0> r:: :E t::: 0 Z - -7200 ------- Begin Di~ @ 10.000°/10011: 14215.3111 MD, 8836.8911 TVD """"'---\.. '" -8100 . '~" End D,r: 14705.2311 MD, 8808.5211 TVD.........--- ' Begin Dir @ 10.000°/10011: 14839.7211 MD, 8800.1111 lVD -- / End Dir: 15276.6011 MD, 878i.4511 TVDÅ8098 - -8100 ~ 0 g -9000 - II .c u c: - -9000 Q) (ij u en 4112" Uner 16435.49 MD ,--< B760.20 TVD I 1800 Scale: 1 inch = 900ft I 2700 I 3600 Eastings I 4500 I 5400 Reference is True North Iprepared: fheCked: ~proved: North Slope Alaska Alaska State Plane 4 PBU- WOA E Pad E-31A WPS-E-31A We ) PROPOSAL Surface Coordinates: 5976455.20 Kelly Bushin 63 E (70020' 31.1168" N, 148039' 54.9867" W) above Mean Sea Level ) Ei:l-=-P""i"Y-~ In gFt.'~ .~';'.'l'~,', 'I,',',.:',',", ..' ~"'lIJ:IS . ~',H;"j\i(k1"""f-"'1 Proposal Ref: pro10468 Sperry-Sun Drilling Services Proposal Report for E-31A WPS - E-31A Wp OBA Alaska State Plane 4 North Slope Alaska PBU_WOA E Pad Measured Sub-Sea Vertical Local Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (a/100ft) (ft) 8400.00 41.155 159.356 6809.59 6869.79 3931.14 S 1702.74 E 666244.19 E 4244.44 8T Exil @ 12.000°/10011 ) 90.000° TF : 8400.0011 MD. 6869.7911 TVD 8440.00 41.384 166.628 6839.68 6899.88 3956.34 8 1710.44 E 666252.45 E 12.000 4269.98 Conlinue Dir @ 12.000°/10011: 8440.0011 MD. 6899.8811 TVD 8500.00 41.582 177.502 6884.68 6944.88 3995.58 8 12.000 4306.37 8564.29 42.907 188.819 6932.35 6992.55 4038.59 8 12.000 4341.89 End Dir : 8564.2911 MD. 6992.5511 TVD 8600.00 42.907 188.819 6958.50 7018.70 4062.61 8 666254.08 E 0.000 4360.50 8700.00 42.907 188.819 7031.75 7091.95 3.59 N 666245.12 E 0.000 4412.63 8800.00 42.907 188.819 7104.99 7165.19 5972296.10 N 666236.16 E 0.000 4464.75 8900.00 42.907 188.819 7178.24 7238.44 5972228.61 N 666227.20 E 0.000 4516.88 9000.00 42.907 188.819 7251.48 7311.68 5972161.12 N 666218.24 E 0.000 4569.00 9083.99 42.907 188.819 7313.00 7373.20 5972104.43 N 666210.72 E 0.000 4612.78 CM1/K5 9100.00 42.907 188.819 7324.73 7384.93 5972093.63 N 666209.28 E 0.000 4621.13 9200.00 42.907 188.819 7397.97 7458.17 5972026.14 N 666200.32 E 0.000 4673.25 9300.00 42.907 188.819 7471.22 7531.42 5971958.65 N 666191.37 E 0.000 4725.38 9302.43 42.907 188.819 7473.00 7533.20 5971957.01 N 666191.15 E 0.000 4726.65 THRZ 9400.00 42.907 188.819 7544.46 7604.66 5971891.16 N 666182.41 E 0.000 4777.50 9500.00 42.907 188.819 7617.71 7677.91 4668.108 1615.80 E 5971823.67 N 666173.45 E 0.000 4829.63 ) 9550.91 42.907 188.819 7655.00 7715.20 4702.358 1610.49 E 5971789.31 N 666168.88 E 0.000 4856.17 BHRZ 9600.00 42.907 188.819 7690.96 7751.16 4735.388 1605.37 E 5971756.18 N 666164.49 E 0.000 4881.75 9619.17 42.907 188.819 7705.00 7765.20 4748.28 S 1603.36 E 5971743.24 N 666162.77 E 0.000 4891.75 LCU/Kingak 9700.00 42.907 188.819 7764.20 7824.40 4802.65 8 1594.93 E 5971688.69 N 666155.53 E 0.000 4933.88 9800.00 42.907 188.819 7837.45 7897.65 4869.93 8 1584.49 E 5971621.20 N 666146.57 E 0.000 4986.01 9900.00 42.907 188.819 7910.69 7970.89 4937.21 S 1574.05 E 5971553.71 N 666137.61 E 0.000 5038.13 9940.38 42.907 188.819 7940.27 8000.47 4964.378 1569.84 E 5971526.46 N 666133.99 E 0.000 5059.18 B~in Dir @ 12.000°/10011: 99 0.3811 MD, 8000.4711 TVD 10000.00 36.135 185.182 7986.24 8046.44 5001.988 1565.13E 5971488.75 N 666130.11 E 12.000 5088.90 10100.00 25.180 175.425 8072.18 8132.38 5052.748 1564.16E 5971437.99 N 666130.26 E 12.000 5131.81 Continued... 29 September, 2000 - 15:06 -2- DrillQuest 1.05.058 Sperry-Sun Drilling Services Proposal Report for E-31A WPS - E-31A Wp DBA Alaska State Plane 4 North Slope Alaska PBU_WOA E Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) (ft) 10162.39 18.937 164.299 8130.00 8190.20 5075.75 S 1567.97 E 666134.56 E 12.000 5153.46 TJB ) 10200.00 15.683 153.729 8165.91 8226.11 5086.19 S 1571.87 E 666138.69 E 12.000 5164.41 10263.89 12.109 124.967 8228.00 8288.20 5097.79 S 1581.20E 666148.27 E 12.000 5179.16 7" Casing SAG 10286.38 11.800 112.000 8250.00 8310.20 5100.00 S 1585.26 E 666152.39 E 12.000 5183.16 Fit Target E-31A, Geological 10286.97 11.847 112.258 8250.58 8310.78 5100.05 S 1585.38 E 666152.50 E 12.000 5183.26 End Dir: 1 0286.971t MD, 8310.78ft TVD 10300.00 11.847 112.258 8263.33 8323.53 5101.06 S .ON 666155.00 E 0.000 5185.41 10303.75 11.847 112.258 8267.00 8327.20 5101.35 S 9.92 N 666155.72 E 0.000 5186.03 SHU 10381.40 11.847 112.258 8343.00 8403.20 5107.39 S 5971384.21 N 666170.60 E 0.000 5198.84 TSADfTZ4B 10400.00 11.847 112.258 8361.20 8421.40 5108.84 S 5971382.84 N 666174.16 E 0.000 5201.91 10498.90 11.847 112.258 8458.00 8518.20 5116.53 S 5971375.57 N 666193.12 E 0.000 5218.22 TZ3 10500.00 11.847 112.258 8459.07 8519.27 5971375.49 N 666193.33 E 0.000 5218.41 10572.47 11.847 112.258 8530.00 8590.20 5971370.15 N 666207.22 E 0.000 5230.36 TZ2C 10586.79 11.847 112.258 8544.02 8604.22 5971369.10 N 666209.96 E 0.000 5232.72 B~in Dir @ 20.000o/100ft: 10 86.791t MD, 8604.221tTVD 10600.00 14.446 114.333 8556.88 8617.08 5971367.97 N 666212.75 E 20.000 5235.17 10700.00 34.333 119.945 8647.51 8707.71 5971349.35 N 666249.33 E 20.000 5270.52 10755.45 45.401 121.049 8690.00 8750.20 5162.01 S 1711.82 E 5971331.98 N 666280.28 E 20.000 5301.79 TZ1B 10800.00 54.298 121.666 8718.70 8778.90 5179.72 S 1740.87 E 5971314.91 N 666309.70 E 20.000 5331.99 ) 10900.00 74.278 122.675 8761.86 8822.06 5227.51 S 1816.71 E 5971268.80 N 666386.58 E 20.000 5412.17 10938.64 82.000 123.000 8769.80 8830.00 5248.00 S 1848.46 E 5971249.01 N 666418.77 E 20.000 5446.15 Decrease in Dir Rate @ 12.000o/100ft: 10938.641t MD, 8830.00ft TVD 11000.00 89.299 123.972 8774.45 8834.65 5281.73 S 1899.45 E 5971216.40 N 666470.48 E 12.000 5501.42 11001.74 89.506 123.999 8774.47 8834.67 5282.70 S 1900.89 E 5971215.46 N 666471.95 E 12.000 5503.00 End Dir: 11001.74ft MD, 8834.671t TVD 11100.00 89.506 123.999 8775.32 8835.52 5337.65 S 1982.35 E 5971162.32 N 666554.59 E 0.000 5592.21 11200.00 89.506 123.999 8776.18 8836.38 5393.57 S 2065.25 E 5971108.24 N 666638.70 E 0.000 5683.00 11300.00 89.506 123.999 8777.04 8837.24 5449.48 S 2148.15 E 5971054.15 N 666722.81 E 0.000 5773.78 11400.00 89.506 123.999 8777.91 8838.11 5505.40 S 2231.06 E 5971000.07 N 666806.92 E 0.000 5864.57 Continued... 29 September, 2000 - 15:06 -3- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for E-31A WPS - E-31A Wp DBA Alaska State Plane 4 North Slope Alaska PBU_WOA E Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ("/100ft) (ft) 11500.00 89.506 123.999 8778.77 8838.97 5561.31 S 2313.96 E 666891.03 E 0.000 5955.36 ) 11600.00 89.506 123.999 8779.63 8839.83 5617.23 S 2396.86 E 666975.13 E 0.000 6046.14 11700.00 89.506 123.999 8780.50 8840.70 5673.14 S 2479.76 E 667059.24 E 0.000 6136.93 11797.67 89.506 123.999 8781.34 8841.54 5727.76 S 2560.73 E 667141.39 E 0.000 6225.60 BfJ1in Dir @ 12.000°/10011: 11 97.6711 MD, 8841.54ft TVD 11800.00 89.445 124.272 8781.36 8841.56 5729.06 S 2562.66 E 667143.35 E 12.000 6227.72 11900.00 86.879 136.001 8784.58 8844.78 5793.37 S 667221.02 E 12.000 6322.25 11976.42 85.000 145.000 8790.00 8850.20 5852.12 S 667270.73 E 12.000 6397.60 Tar~el:Waypoinl#1 (11900), Gee oglCai 12000.00 86.993 147.014 8791.65 8851.85 5871.62 S 667284.31 E 12.000 6421.09 12074.46 93.299 153.347 8791.46 8851.66 5936.15S 667322.70 E 12.000 6495.45 End Dir: 12074.46ft MD, , 8851.661tTVD 12100.00 93.299 153.347 8789.99 8850.19 5970557.99 N 667334.64 E 0.000 6520.87 12200.00 93.299 153.347 8784.23 8844.43 5970469.77 N 667381.37 E 0.000 6620.39 12300.00 93.299 153.347 8778.48 8838.68 5970381.55 N 667428.10 E 0.000 6719.90 12343.58 93.299 153.347 8775.97 8836.17 5970343.10 N 667448.47 E 0.000 6763.27 B~in Dir @ 10.000°/10011: 12 43.58ft MD, 8836.17ft TVD 12377.21 90.000 154.000 8775.00 8835.20 5970313.31 N 667464.03 E 10.000 6796.76 Tar~el: Waypoinl #2 (12300), Gee oglcal 12385.47 89.947 153.176 8775.00 8835.20 6213.80 S 2876.62 E 5970306.00 N 667467.87 E 10.000 6804.99 End Dir: 12385.4711 MD, 8835.2011 TVD 12400.00 89.947 153.176 8775.02 8835.22 6226.77 S 2883.18E 5970293.18 N 667474.71 E 0.000 6819.48 ) 12500.00 89.947 153.176 8775.11 8835.31 6316.01 S 2928.30 E 5970204.95 N 667521.78 E 0.000 6919.19 12600.00 89.947 153.176 8775.20 8835.40 6405.25 S 2973.43 E 5970116.72 N 667568.85 E 0.000 7018.89 12700.00 89.947 153.176 8775.29 8835.49 6494.49 S 3018.55 E 5970028.49 N 667615.92 E 0.000 7118.60 12800.00 89.947 153.176 8775.39 8835.59 6583.73 S 3063.68 E 5969940.26 N 667662.99 E 0.000 7218.30 12900.00 89.947 153.176 8775.48 8835.68 6672.97 S 3108.80 E 5969852.03 N 667710.07 E 0.000 7318.01 13000.00 89.947 153.176 8775.57 8835.77 6762.21 S 3153.93 E 5969763.81 N 667757.14 E 0.000 7417.72 13100.00 89.947 153.176 8775.66 8835.86 6851.45 S 3199.05 E 5969675.58 N 667804.21 E 0.000 7517.42 13200.00 89.947 153.176 8775.75 8835.95 6940.69 S 3244.18 E 5969587.35 N 667851.28 E 0.000 7617.13 13300.00 89.947 153.176 8775.85 8836.05 7029.93 S 3289.31 E 5969499.12 N 667898.35 E 0.000 7716.84 Continued... 29 September, 2000 - 15:06 -4- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for E-31A WPS - E-31A Wp DBA Alaska State Plane 4 North Slope Alaska PBU- WOA E Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) (ft) 13400.00 89.947 153.176 8775.94 8836.14 7119.16 S 3334.43 E 667945.43 E 0.000 7816.54 ) 13500.00 89.947 153.176 8776.03 8836.23 7208.40 S 3379.56 E 667992.50 E 0.000 7916.25 13600.00 89.947 153.176 8776.12 8836.32 7297.64 S 3424.68 E 668039.57 E 0.000 8015.95 13700.00 89.947 153.176 8776.22 8836.42 7386.88 S 3469.81 E 668086.64 E 0.000 8115.66 13800.00 89.947 153.176 8776.31 8836.51 7476.12 S 3514.93 E 668133.72 E 0.000 8215.37 13900.00 89.947 153.176 8776.40 8836.60 7565.36 S 668180.79 E 0.000 8315.07 14000.00 89.947 153.176 8776.49 8836.69 7654.60 S 668227.86 E 0.000 8414.78 14100.00 89.947 153.176 8776.58 8836.78 7743.84 S 668274.93 E 0.000 8514.48 14200.00 89.947 153.176 8776.68 8836.88 7833.08 S 668322.00 E 0.000 8614.19 14215.31 89.947 153.176 8776.69 8836.89 7846.74 S 668329.21 E 0.000 8629.45 B~in Dir @ 10.0000/1O0ft: 14 15.31ft MD, 8836.891t TVD 14276.51 93.218 148.000 8775.00 8835.20 5968638.96 N 668360.40 E 10.000 8690.57 Tar~et ~ Waypoint #3 (14200), Goo oglcal 14300.00 93.289 145.649 8773.67 8833.87 5968619.62 N 668373.66 E 10.000 8714.01 14400.00 93.529 135.634 8767.71 8827.91 5968543.94 N 668438.56 E 10.000 8812.70 14500.00 93.661 125.615 8761.42 8821.62 5968480.72 N 668515.62 E 10.000 8907.41 14600.00 93.681 115.594 8755.00 8815.20 5968431.87 N 668602.49 E 10.000 8995.27 14700.00 93.590 105.574 8748.64 8808.84 8147.40 S 4063.17 E 5968398.89 N 668696.55 E 10.000 9073.59 14705.23 93.582 105.051 8748.32 8808.52 8148.78 S 4068.20 E 5968397.62 N 668701.61 E 10.000 9077.38 End Dir: 14705.23/t MD, 8808.52ft TVD ) 14800.00 93.582 105.051 8742.40 8802.60 8173.34 S 4159.54 E 5968375.07 N 668793.47 E 0.000 9145.73 14839.72 93.582 105.051 8739.91 8800.11 8183.64 S 4197.83 E 5968365.62 N 668831.96 E 0.000 9174.37 B~in Dir @ 10.0000/1OO/t: 14 39.72ftMD,88oo.11ftTVD 14900.00 93.235 111.079 8736.33 8796.53 8202.29 S 4255.01 E 5968348.22 N 668889.54 E 10.000 9219.96 15000.00 92.584 121.071 8731.24 8791.44 8246.13 S 4344.60 E 5968306.36 N 668980.07 E 10.000 9303.89 15100.00 91.854 131.052 8727.36 8787.56 8304.88 S 4425.27 E 5968249.39 N 669062.01 E 10.000 9395.95 15189.73 91.150 140.000 8725.00 8785.20 8368.82 S 4488.04 E 5968186.85 N 669126.18 E 10.000 9483.16 Tar~et ~ Waypoint #4 (15100), Goo oglcal 15200.00 91.152 141.028 8724.79 8784.99 8376.75 S 4494.58 E 5968179.06 N 669132.88 E 10.000 9493.33 15276.60 91.150 148.689 8723.25 8783.45 8439.32 S 4538.62 E 5968117.47 N 669178.29 E 10.000 9569.67 End Dir: 15276.60/t MD, 8783.45ft TVD Continued... 29 September, 2000 -15:06 -5- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for E-31 A WPS - E-31 A Wp DBA Alaska State Plane 4 North Slope Alaska PBU_WOA E Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) (ft) 15300.00 91.150 148.689 8722.78 8782.98 8459.31 S 4550.78 E 669190.88 E 0.000 9593.07 ) 15400.00 91.150 148.689 8720.78 8780.98 8544.73 S 4602.74 E 669244.70 E 0.000 9693.05 15500.00 91.150 148.689 8718.77 8778.97 8630.15 S 4654.70 E 669298.52 E 0.000 9793.03 15600.00 91.150 148.689 8716.76 8776.96 8715.57 S 4706.66 E 669352.34 E 0.000 9893.01 15700.00 91.150 148.689 8714.76 8774.96 8800.99 S 4758.62 E 669406.16 E 0.000 9992.99 15800.00 91.150 148.689 8712.75 8772.95 8886.41 S 669459.98 E 0.000 10092.97 15900.00 91.150 148.689 8710.74 8770.94 8971.83 S 669513.80 E 0.000 10192.95 16000.00 91.150 148.689 8708.74 8768.94 9057.24 S 669567.62 E 0.000 10292.93 16100.00 91.150 148.689 8706.73 8766.93 9142.66 S 669621.44 E 0.000 10392.91 16200.00 91.150 148.689 8704.73 8764.93 9228.08 S 669675.26 E 0.000 10492.89 16300.00 91.150 148.689 8702.72 8762.92 5967255.17 N 669729.08 E 0.000 10592.87 16400.00 91.150 148.689 8700.71 8760.91 5967170.91 N 669782.90 E 0.000 10692.85 16435.49 91.150 148.689 8700.00 8760.20 5967141.00 N 669802.00 E 0.000 10728.33 Total DWtth : 16435.49ft MD. 8760.20 t TVD 4 1/2" Liner Tar~et ~ Waypoint #5 (16400). Goo oglcal All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. ) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 148.782° (True). Based upon Minimum Curvature type calculations. at a Measured Depth of 16435.49f1.. The Bottom Hole Displacement is 10739.55ft., in the Direction of 151.401° (True). Continued... 29 September, 2000 - 15:06 -6- DrillQuest 1.05.05s H 175142 DATE DESCRIPTION INVOICE I CREDIT MEMO 092600 :K092600F PYMT C JMMENTS: HANDLI 'IIG INST: GROSS I 100.00 PERMIT TO DRILL FEE S/H TERRIE HUBBLE X4628 E.3 lit 'HE AlTACHED CHECK /S IN PAYMENT FOR ITEMS DESCR/BED ABOVE, ~ 1I.~?5~"'211. AK 99501 1:0"'~20:ìBq51: -.-"'..- ~: ..- ,i:; , ~:';, ~i:;i ~~::; ~~ ~;<," ~~:: '. r :,ii; fí' 1'/'; ~:: 100.00 ~ATE I r CHECK NO, I p9/26/00 pO175142 VENDOR ALASKAST A T 10 DISCOUNT NET 100.00 H ) 100.00 i'ÎRSTÑATIONAtsANKOf ASHIiANO ":'"", ",' ,A~'A~IL1ATE,Oíi' ,:""", ,,' NAT.lONÄ('CITY,SANK t,lEVEÌ-ÄND, QHIO Nq.,,'.""'17~t42 ',' CONSOliDAtED c:;OMMERCIALACCOUNT ,'.. ",'::-56,389" , 412 OOB""" ~qll. - 00175142 US~DOLLAR "AMOUNT $100_0°1 ) NOTN.o,pD AFTER 120 DAYS :~~~i~ /~¿¡ WELL PERMIT CHECKLIST COMPANY ff~?<. WELL NAME;: -. :j' //1 PROGRAM: exp - dev V redrll---L selV - wellbore seg _ann. disposal para req - FIELD & POOL & YO /J:; () INIT CLASS ~ 1 rY L GEOL AREA fflD UNIT# 0/ It, Sf:) ON/OFF SHORE ð.v. ADMINISTRATION 1.Permitfeeattached..:.................... Y ~ /of~U/~ as; ~~ ié)..a..~. ~L_,ÙL.¡~;k~:.~ 2. Le~senumberappropnate. . . . . . . . . . . . . . . . . . . Y ~ ¡/¿¿ ~/?7r?l..þ d",/I , 'lid 1t/z.~~/){)rrðY-Æ, 3. Unique well ~ame and number. ., . . . . . . . . . . . . . . . " (:5'¡ 4/'Í (ffr / //, "'J O~-1q nS:.. ' 4. Well located 10 a defined pool.. . . . . . . . . . . . . . . . . ' N {) {/ 5. Well located proper distance from drilling unit boundary. , . . ," N 6. Well located proper distance from other wells.. . . . . . . . . : N 7. Sufficientacreageavailable'indrillingunit............ )N. 8. If deviated, is wellbóre plat induded.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . , 'N 11. Permit can be issued without conselVation order. . . . . . . . ' N APjÞP.R DATE ,. /' 12. Permit can.be issued without administrative approval.. . . . . N . 3(D^¡....--' . . I . 13. Can permit be approved before 15-day walt.. . . . . . . . . . N ENGINEERING L 14. Conduct O,r string provided. . . . . . . . .. . . . . . . . . . . Y N .~ ¡ oj¡ .'.' ',Iz ' . ' /, i' ~ 15. Surface casing protects all known USDWs. . . . . . . . . .. /Lliv-N re-' r, (tf~/5 k5 ~1 " \(..\.~ . 16. GMT vol adequate to circulate on conductor & surf csg. . . . . Y N ' , . ~í¿)-r-';~'r- 17. CMT v~1 adequate to tie-in long s~ng t~ surf csg. . . . . . .. ,Y N <¡.J-. . t. 1 8. GM~ WIll co~er all known productive honzons. . . . . '. . . . . ~ N C '~oO 19. CaslOgdeslgnsadequateforC,T,B&permafrost. ...,.. . N ~ ( \ \\ÌP '\ 20. Adequate tankage or reselVe pit.. . . . . . . . . . . . . . . . N \ 21. If a re-drill, has a 10-403 for abandonment been approved. . . Y N 22. Adequate wellbore separation proposed.. . . . . . . . . . . . (f) N 23. If diverter required, does it meet regulations. . . . . . . . . . Y N /oJ/A. 24. Drilling ,fluid program schematic & equip list adequate. . . . . IN 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N APP AT 26. BOPE press rating appropriate; test to 3500 psig. N îJJGr;. ¡~ !,JOL ' 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N ,~ 't ~ 28. Work will occur without operation shutdown. . . . . . . . . . . N /':P-'I'I '3\-() 29.lspresenceofH~gasprobable................. Y@ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. . . .. Y @ 4....,1:.-., ~I C, /ð H!.-Lcr? ¿ß iít t;;, ~ ~5 ~ .~ 1'/, 31. Data presented on potential overpressure zones. . . . . . . ~ ' () I r.¡ 32. Seismic analysis of shallow gas zones. . . . . . . . . . . .. ~ ~ Y N APP~ DATE 33. Seabed condition survey ('If off-shore). . . . . . . . . :':"*'J. Y N ., )(t) /, 3/ CYZ-. 34. Contact name/phone for weekly progress reports [exp/~, T only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater. or cause drilling waste. .. to surface;" ' (C) will not impair mechanical integrity ()f the well used for disposal; Y N (D) will not damage producing fonnation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annuiar COMMISSION: ~Þ8 ~ v' WM -8~s _Â--- t~~ 6 ~~ '/a, , JMH ,1M'H , r " - APPR DATE Y N Y N a1A.n bl ( a" ý rj; : ¿ flJ çeu( ¡Jo Com m e ntsllns tructi ons: \ fa¡/D2. c:\msoffice\wordian\diana\checklist (rev. 11/01/100) fe 1'<ß ) Ie d. ,I c 0 Z 0 -f :E ::0 } -f m Z -f :I: - C/) » ::0 m » ) ~ ~ ¡;g¿¡ \WELL PERMIT CHECKLIST COMPANY þ{ WELL NAM :: E -;3/11 PROGRAM: exp - dev --.:!.. redrll ~ serv - wellbore seg _ann. disposal para req- FIELD & POOL ((JVO/~7J INITCLASS ~Ft/ fOIL- GEOLAREA B1'õ UNIT# Olltn<.-t:;D ON/OFFSHORE rJr¿ . ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3.Uniquewellnameand'number..............,... N 4.Welilocatedinadefinedpool.................. N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N 8. If deviated. is wellbore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N !,. R . DATE 12. Permit can be issued without administrative approval.. . . . . Y N '0 -2{) CD. . 1-' ':;'¡ I 13. Can permit be approved before 15-day walt.. . . . . . . . . . N , NGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . Y N ~ 15. Surface casing protects all know. n USDWs. . . . . . . . . . . Y N ~ \ ~ Ç.. c<.: "'- ~"'C'- ~ \ \ 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N c.; Ct: ~ 0 ~\.C:;;'" . 17. CMT vol adequate to tie-in long string to surf csg. . . . , .' . . Y N 18. CMT will cover all known productive horizons. . . . . . . . . . iN 19. Casing designs adequate for C, T. B & permafrost. . . . . . . Y N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . Y N 21. If a re-drin, has a 10-403 for abandonment been approved. . . N sa:>-d""t'::> ,~<::"'Cf\.-.,}~ \.\.l ~ 22. Adequate wellbore separation proposed.. . . . . . . . . . . . Y N 23. If diverter required, does it meet regulations. . . . . . . . . . ..1f-tot- 24. Drilling fluid program schematic & equip list adequate. . . . . IN 25, BOPEs. do they meet regulation. . . . . . . . . . . . . . . . Y N DATE _?V~6. BOPE press rating appropriate; test to 3SDO psig. l\j I "=> ~7. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . Y '...Þl. 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. . ..' . Zy N - 31. Data presented on potential overpressure zones. . . . . . . Y 32. Seismicanal~~isofshallo~gaszones. . . . . .~. . . .. A- N AR DATE 33. Seabed condition survey (Ifoff-shore). . . . . . . .. ... Y N : ~ /0, 3D ,00 34. Contact name/phone for weekly progress reports Joratory only] Y N . ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. ., to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) win not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ~Þ8g¡r. ./ Q~W W~ ~~g ,.dMI+ id2ÒJuz) ;ZJ5 ~E~?n1 'Y( <,..-cõ t;ö w r 0 0 Z 0 -I ~ :;0 } -I m APPR DATE Y N Y N \.) '" <>- ........'" \c:>.r ì"~ ~ 0,,", ~,,(:~~:J Z -I :z: - CJ) » ::0 m » \ \1 / ---- / Commentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 02/17/00) ~ ~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, information of this nature is accumulated at the end of the file under APPENDIX. No specialeffort has been made to chronologically organize this category of infonnation. ~ ~ ¿;¡OO-/75 1/5°<7 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Feb 03 09:45:50 2003 Reel Header Service name............ .LISTPE Date.....................03/02/03 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments............. '" .STS LIS Writing Library. Scientific Technical Services Tape Header Service name...... ..... ..LISTPE Date.....................03/02/03 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 MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA E-31A 500292241101 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 31-JAN-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22075 J. SACK J. RALL / D. MWDRUN 2 AK-MW-22075 J. SACK J. RALL / D. MWDRUN 4 AK-MW-22075 J. SACK J. RALL / D. # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 1ST STRING 2ND STRING 6 11N 14E 608 501 MSL 0) 58.70 30.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 11331. 0 # WELL CASING RECORD ~, ~. 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK, THE TOP OF WHICH WAS AT 11331'MD AND THE BOTTOM WAS AT 11343'MD. SGRC DATA OVER THIS INTERVAL WERE ACQUIRED DURING MWD RUN 2. 4. MWD RUNS 2 & 4 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; COMPENSATED THERMAL NEUTRON POROSITY (CTN); AND AT-BIT INCLINATION (ABI). NO PROGRESS WAS MADE ON MWD RUN 3. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN E-31A ON 8 AUGUST 2002. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY DEWAYNE SCHNORR ON 8 DECEMBER 2002. A 20' +1- DEPTH DISCREPANCY WAS DISCOVERED WHILE DEPTH SHIFTING. AS THE BIT-TO-SENSOR DISTANCE FOR THE MWD TOOLS WAS THE SAME FOR BOTH RUNS 2 & 4, IT APPEARS THAT A STRAPPING ERROR (ABOVE THE MWD TOOLS) WAS MADE DURING A SIGNIFICANT BHA CHANGE BETWEEN MWD RUNS 2 & 4. 6. MWD RUNS 1, 2, AND 4 REPRESENT WELL E-31A WITH API#: 50-029-22411-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15572'MD/8798'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.125" MUD WEIGHT: 8.4 PPG MUD SALINITY: 1000 PPM CHLORIDES FORMATION WATER SALINITY: 18,000 FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ PPM CHLORIDES File Header Service name............ .STSLIB.OOl Service Sub Level Name... ~ Version Number.......... .1.0.0 Date of Generation.... ...03/02/03 Maximum Physical Record. .65535 File Type........... .....LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE NPHI FCNT NCNT GR ROP $ 1 ~ clipped curves; all bit runs merged. .5000 START DEPTH 11293.5 11293.5 11293.5 11298.0 11339.5 STOP DEPTH 12166.5 12167.5 12166.5 15540.0 15602.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE 11298.0 11356.0 11385.0 11398.0 11408.0 11425.0 11435.5 11446.0 11450.5 11505.0 11526.0 11534.0 11544.5 11556.0 11559.5 11565.0 11631. 0 11637.0 11643.5 11657.5 11678.0 11698.0 11747.5 11757.5 11764.0 11770.0 11772.5 11781.5 11787.5 11793.0 11801.5 11823.5 11834.5 11853.5 11864.0 11875.0 11886.0 11903.5 11907.0 DEPTH GR 11289.5 11347.5 11380.0 11394.5 11403.5 11419.0 11431. 0 11442 .0 11446.0 11501. 0 11520.5 11526.5 11539.0 11548.0 11554.0 11560.5 11627.5 11633.5 11639.5 11653.0 11674.5 11692.5 11741.5 11752.5 11758.5 11764.0 11768.0 11776.5 11782.0 11787.0 11796.5 11818.0 11827.5 11848.0 11860.0 11871.0 11880.5 11898.5 11902.0 ~ ............ 11951. 5 11956.0 11959.0 11964.0 11973.5 11986.5 12022.0 12031. 0 12044.0 12060.5 12069.0 12073.5 12099.0 12103.0 12106.5 12116.5 12135.5 12147.5 12160.5 12170.0 12175.0 12177.5 12207.0 12213.5 12225.5 12238.5 12250.5 12255.5 12260.0 12263.0 12267.0 12270.0 12275.5 12280.5 12287.0 12298.5 12301.0 12311.0 12316.5 12333.5 12342.0 12344.5 12359.0 12388.0 12399.5 12402.5 12404.5 12442.5 12446.5 12458.0 12466.0 12489.0 12513.0 12534.5 12541.0 12559.0 12602.0 12659.0 12666.5 12674.5 12678.0 12679.5 12707.5 12710.0 12715.5 11946.5 11949.0 11953.0 11958.5 11968.5 11983.0 12017.5 12026.5 12041. 0 12055.5 12065.0 12069.0 12095.5 12099.0 12103.0 12111.5 12130.5 12142.0 12155.0 12165.0 12168.5 12173.0 12195.5 12198.5 12207.5 12218.0 12227.5 12231.5 12235.0 12238.5 12242.0 12245.5 12250.5 12256.5 12262.0 12272.0 12275.5 12286.5 12291.5 12307.0 12317.0 12318.5 12334.0 12362.0 12373.5 12376.5 12378.0 12416.0 12420.5 12432.0 12439.0 12463.0 12484.0 12508.0 12515.0 12533.0 12575.5 12632.0 12640.5 12648.5 12652.0 12653.5 12681. 5 12684.0 12689.5 .~ ~ 12742.0 12759.5 12775.5 12810.5 12831. 0 12849.0 12882.0 12885.0 12910.0 12915.0 12921. 5 12925.5 12943.5 12948.0 12979.0 13032.0 13039.0 13105.5 13131. 0 13156.0 13185.5 13190.5 13208.0 13210.5 13220.5 13241. 0 13248.0 13262.5 13270.5 13308.5 13328.5 13360.5 13397.5 13426.5 13440.0 13452.5 13475.0 13507.0 13533.0 13584.0 13594.5 13596.0 13610.0 13623.0 13646.0 13667.5 13682.5 13713.5 13730.5 13755.0 13777.5 13795.5 13802.5 13806.5 13813.5 13829.0 13838.0 13842.5 13850.0 13862.0 13865.5 13868.5 13875.5 13880.0 13905.5 12717.0 12736.0 12752.5 12787.0 12807.5 12826.0 12859.0 12862.0 12889.5 12894.5 12899.0 12902.5 12920.0 12925.5 12954.0 13008.0 13015.5 13079.5 13101.5 13129.5 13158.5 13164.0 13181. 5 13184.5 13194.5 13217.0 13225.0 13240.0 13247.5 13283.0 13302.0 13332.5 13371.5 13401. 0 13414.0 13425.5 13451. 0 13480.5 13508.0 13558.5 13568.5 13570.0 13587.5 13598.5 13619.0 13639.5 13657.0 13686.0 13705.5 13727.0 13750.5 13765.0 13775.0 13779.0 13785.0 13797.5 13806.5 13815.5 13821.5 13835.0 13838.5 13841.0 13849.0 13853.0 13876.5 .~ ~ 13917.5 13928.0 13934.0 13936.5 13942.0 13947.5 13969.0 13982.0 13988.5 14002.5 14016.0 14038.0 14053.5 14064.5 14075.5 14081. 5 14111.5 14123.5 14128.5 14171.0 14207.5 14220.0 14224.5 14240.0 14243.5 14270.5 14284.0 14309.5 14316.5 14322.5 14333.5 14336.5 14340.0 14411. 5 14492 . 5 14513.0 14544.5 14560.5 14625.0 14666.0 14679.5 14711. 0 14714.5 14725.0 14734.5 14745.5 14755.5 14810.0 14811.5 14826.0 14830.0 14869.0 14872 .0 14887.5 14896.5 14901. 0 14905.0 14908.5 14919.5 14934.0 14942.0 14950.0 14960.5 14969.0 14980.0 13889.5 13899.5 13907.0 13910.5 13916.5 13920.5 13942.5 13958.0 13963.0 13976.5 13990.5 14008.0 14025.0 14038.0 14048.0 14053.0 14080.5 14091.0 14098.5 14145.0 14179.5 14193.0 14198.0 14213.5 14216.5 14245.5 14258.5 14282.0 14290.0 14295.0 14306.5 14308.5 14314.0 14384.0 14468.0 14483.5 14517.5 14533.0 14597.0 14642.5 14654.0 14684.5 14687.5 14702.0 14710.5 14722.0 14732.0 14784.5 14786.5 14801. 5 14805.5 14843.5 14845.0 14860.0 14868.0 14873.0 14876.0 14881. 0 14893.5 14909.0 14917.0 14924.0 14934.0 14942.0 14952.5 ~ ~ 14985.5 14987.5 14990.0 15000.5 15035.5 15046.0 15057.0 15062.0 15087.5 15097.0 15100.0 15104.5 15110.0 15112.0 15119.0 15122.5 15129.5 15134.5 15147.0 15164.0 15183.5 15186.5 15188.5 15194.0 15198.5 15210.5 15226.5 15242.5 15256.0 15262.5 15283.0 15287.0 15307.5 15322.0 15332.0 15356.5 15362.0 15370.0 15389.0 15602.5 $ 14957.5 14960.5 14962.0 14972.5 15010.5 15021. 0 15030.5 15034.0 15059.5 15069.5 15072.5 15077.5 15081.5 15084.0 15091.0 15094.0 15102.0 15107.5 15121. 5 15136.5 15155.0 15158.5 15161. 0 15165.0 15170.5 15183.0 15198.5 15214.5 15227.5 15234.5 15254.0 15259.0 15280.0 15295.0 15304.5 15326.5 15330.5 15338.5 15358.5 15572.0 # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 4 MERGE TOP 11331. 0 11285.0 12175.0 MERGE BASE 11354.5 12237.5 15572.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type............ ......0 Data Specification Block Type... ..0 Logging Direction.......... ...... . Down Optical log depth units...... .... .Feet Data Reference Point.... """" ..Undefined Frame Spacing.............. """ .60 .1IN Max frames per record............ . Undefined Absent value..... """"""'" ..-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel ,~ ~ DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 NPHI MWD PU-S 4 1 68 12 4 FCNT MWD CNTS 4 1 68 16 5 NCNT MWD CNTS 4 1 68 20 6 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11293.5 15602.5 13448 8619 11293.5 15602.5 ROP MWD FT/H 0.11 514.71 80.0771 8527 11339.5 15602.5 GR MWD API 11.02 379.2 51.1525 8485 11298 15540 NPHI MWD PU-S 11.57 57.44 22.0998 1747 11293.5 12166.5 FCNT MWD CNTS 208.47 1348.73 761.046 1749 11293.5 12167.5 NCNT MWD CNTS 20729.5 39258.5 31068.5 1747 11293.5 12166.5 First Reading For Entire File.. ""'" .11293.5 Last Reading For Entire File..... ..... .15602.5 File Trailer Service name........... ..STSLIB.001 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation...... .03/02/03 Maximum Physical Record..65535 File Type............... .LO Next File Name.. """" .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/02/03 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 11331. 0 STOP DEPTH 11354.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): 13-MAY-02 Insite Memory 11355.0 ~ TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type. ....0 Logging Direction.. """"""" . Down Optical log depth units.... """ .Feet Data Reference Point............ ..Undefined Frame Spacing............ """" .60 .1IN Max frames per record......... ... . Undefined Absent value........... .......... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 11331. 0 11355.0 .0 .0 TOOL NUMBER 6.125 11331. 0 QUIKDRIL-N 8.40 55.0 8.2 900 14.0 .000 .000 .000 .000 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 11331 1 Max 11354.5 19 First Reading For Entire File......... .11331 Last Reading For Entire File..... ..... .11354.5 Mean Nsam 11342.8 48 3.75396 48 ~ .0 .0 .0 .0 First Reading 11331 11331 Last Reading 11354.5 11354.5 ~, ~ File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/02/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.... .......STSLIB.003 physical EOF File Header Service name...... .......STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/02/03 Maximum Physical Record. .65535 File Type............... .LO Previous File Name... ... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 11285.0 11285.0 11285.0 11289.5 11355.0 STOP DEPTH 12161.5 12162.5 12161. 5 12174.5 12237.5 # 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: 15-MAY-02 Insite 66.37 Memory 12238.0 11355.0 12238.0 67.5 90.7 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON TOOL NUMBER 129046 16777215 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 11331. 0 # ~ BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............. .....0 Data Specification Block Type... ..0 Logging Direction.......... """ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.............. ...... .60 .1IN Max frames per record......... ....Undefined Absent value........... """"" .-999 Depth Units....................... Datum Specification Block sub-type...O ~ QUIKDRIL-N 8.45 48.0 8.8 2200 12.0 .000 .000 .000 .000 . a 159.8 . a . a Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 NPHI MWD020 PU-S 4 1 68 12 4 FCNT MWD020 CNTS 4 1 68 16 5 NCNT MWD020 CNTS 4 1 68 20 6 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11285 12237.5 11761.3 1906 11285 12237.5 ROP MWD020 FT/H 3.12 231. 5 48.8825 1766 11355 12237.5 GR MWD020 API 11. 02 182.05 31.1288 1771 11289.5 12174.5 NPHI MWD020 PU-S 11.57 57.44 22.1085 1754 11285 12161. 5 FCNT MWD020 CNTS 208.47 1348.73 760.703 1756 11285 12162.5 NCNT MWD020 CNTS 20729.5 39258.5 31054.1 1754 11285 12161.5 First Reading For Entire File.... "'" .11285 Last Reading For Entire File.......... .12237.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/02/03 .~ Maximum Physical Record..65535 File Type. .... ..., """ .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/02/03 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 ~ header data for each bit run in separate files. 4 .5000 START DEPTH 12175.0 12238.0 STOP DEPTH 15509.5 15572.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 21-MAY-02 Insite 66.37 Memory 15572.0 12238.0 15572.0 86.7 97.0 TOOL NUMBER 129046 6.125 11331. 0 QUIKDRIL-N 8.45 44.0 8.6 2200 9.0 .000 .000 .000 .0 144.0 .0 /~ ~ MUD CAKE AT MT: .000 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............... ...0 Data Specification Block Type.....O Logging Direction........... "'" . Down Optical log depth units......... ..Feet Data Reference Point..... ... "'" . Undefined Frame Spacing................. '" .60 .1IN Max frames per record............ . Undefined Absent value................. .... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 GR MWD040 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12175 15572 13873.5 6795 12175 15572 ROP MWD040 FT/H 0.11 514.71 88.7259 6669 12238 15572 GR MWD040 API 13.44 379.2 56.5171 6670 12175 15509.5 First Reading For Entire File...... ....12175 Last Reading For Entire File.. """" .15572 File Trailer Service name........ .....STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/02/03 Maximum physical Record. .65535 File Type..... ""'" ....LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date.....................03/02/03 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.....................03/02/03 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. ~. Scientific Technical Services