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HomeMy WebLinkAbout198-215 4.P'' of Tye 4. THE STATE Alaska Oil and Gas it4�►;.-s�.��, ofAL �Jc 1��.11 T 1 '� � Conservation Commission ==_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS I- Fax: 907.276.7542 www.aogcc.alaska.gov July 13, 2015 Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration(Alaska) Inc. P.O. Box 196612 Anchorage,AK 99519-6612 RE: No-Flow Verification SHOED J U L 1 5 2015 PBU 13-08A PTD 1982150 Dear Ms. Cocklan-Vendl: On July 9, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit 13-08A. The AOGCC Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit 13-08A. The test methodology used by BPXA was designed to demonstrate the well was incapable of unassisted flow of hydrocarbons to surface as allowed by 20 AAC 25.265(1)(1)(B): (B) well pressure is discharged not later than five minutes after a three-hour charted pressure build-up period. Tubing, inner annulus, and outer annulus pressures were monitored and recorded during a continuous three-hour well shut in period. Upon opening the production tubing to the test tank, the well demonstrated zero tubingpressure and no liquid or gas flow. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Prudhoe Bay Unit 13-08A demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Sincerely, James B. Regg Supervisor, Petroleum Inspections ecc: P. Brooks AOGCC Inspectors AKOPSFFWellOpsCompRep@bp.com AKDCWellIntegrityCoordinator@bp.com Ryan Daniel, BPXA MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �e-44 711016- DATE: July 9, 2015 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: No Flow Test Petroleum Inspector PBU 13-08A • BPXA PTD 1982150 ' July 9, 2015: I witnessed the No Flow test on BPXA well 13-08A in the Prudhoe Bay Unit. Ryan Moore met me this morning along with his DHD crew at the wellsite. A proper rigup with 2" hardline routed to an open top tank was present. The tubing was open to the tankage with no flow detected. After looking over the setup and a brief safety meeting the digital recorder which was hooked up to the Tubing and Inner Annulus was turned on and the well was shut-in at the 2" hardline with the recorder on the upstream side. It should be noted that the digital recorder showed a negative 5 psi at time zero which ' was confirmed by removing the gage from the line and opening it's port to atmosphere. I accepted this as an "offset". The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 7:30 -5/393/125- 0 0 Routed to open top tank 8:00 -5/393/125' 0 - 0 Shut-in well 11:00 -5/392/125- 0 0 Open well. Routed to open top tank, no flow observed. 11:30 -5/392/125'P. 0 • 0 Concluded test. , 1 Pressures are T/IA/OA Summary: This well appears to pass No-Flow test criteria. ' Attachments: None SCANNED " 4 -2011. 2015-0709_No-Flow_PBU_13-08A_lg.docx Page 1 of 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM. iN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend ❑ Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 2 Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 198-215 3. Address: P.O.Box 196612 Anchorage, Development I f Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20667-01-00 7. Property Designation(Lease Number): ADL 0028315 8. Well Name and Number PBU 13-08A 9 Logs(List logs and submit electronic and printed data per 20AAC25 071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 13800 feet Plugs measured feet true vertical 9035 feet Junk measured feet JUL 0 2 2015 Effective Depth: measured 13752 feet Packer measured See Attachment feet true vertical 9038 feet Packer true vertical See Attachment feet AOG CC Casing: Length. Size: MD: TVD: Burst: Collapse: Structural Conductor See Attachment. See Attachment See Attachment See Attachment See Attachment See Attachment Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth See Attachment feet True vertical depth: See Attachment feet SCANNED .;l.!, 3 .1 2 u 1‘..3 See Attachment See Attachment See Attachment Tubing(size,grade,measured and true vertical depth) - Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 42 0 2789 1787 472 Subsequent to operation: 5 0 340 1418 484 14.Attachments:(required per 20 AAC 25 070 25 071,a 25 283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development p Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Catron,Garry R(Wipro) Email Garry Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 41/144/- ��'i —o)`-' Phone +1 907 564 4424 Date 7/2/15 ' Form 10-404 Revised 5/2015 1/7`1- 3"/i c7/ -- R B DM n � I 7 ?roc g ,y7/r/ Packers and SSV's Attachment PBU 13-08A SW Name Type MD TVD Depscription 13-08A PACKER 8827.88 6990.06 7" Baker ZXP Packer 13-08A PACKER 11133.76 8756.2 7" Baker S-3 Packer 13-08A PACKER 11188.68 8796.08 5" Baker ZXP Top Packer Q p 0 0 0 0 0 0 N N- O 0 CO 0 O N IC) N- CO r- U y 0 0 0 0 0 0 0 i CO CO t— 't CO vcr CO 7 Cf) (3) CO N V I— ' m "Zr CO I� co I- CO p N CO O LO N- CO O 0) co co co O) CO O 6) O N N- N N- CO p CO I-- 10 0) p CO CO 0) in CO N N N CO CO LO O C Q O O M 000 O p M N N CO c- A— o o cQ 2 QO COcy)M p co N 0 CO N N N O N N T CO • co I— 0, p O Opo O p O O O OO J U U CS) V J J O M M • w (NI* *k J .N N _ V co • r# O CO N N U O Cr • N N N Ln � N CS)O co u) co O co C co co p co CO J N CO N N W CC 0)0 — C W O U U a u_ c c c Z Z ZUJWW m 00 O p l— Z_ Z_ J D U (n z J J ♦— H a) 0 0 m M r N M V M N N Lo M 00 I- (o U) Co 00 r (0 N ' CO Ln CO M cf V f� N V r M p, O r M O (JO) .4' N- Ln O O) r Co r N a0 0 N N (N 5 0 0 CO = co co O CO CO Nr CO p O) 0) O) O O O O O O O O O O O O O 0 00 0o c 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) O) I- 0 W Y a > < 0 Z N- CO r r 00 0) V CV V CO 0) 00 00 J W w 0 CO r CO N r Co N- O) M CO N N O LU w J U)w . _ Q M O N-- LO O O N- M Co N- O N O LO N r ‹ W a) O N N 0) C) O M N O o O N COM 00 ° -I � ❑ O 0) 0) 0) 0) O O o 0 0 0 0 0 0 0 O O W w Z 0 ❑ J 0 W > Oo 00 00 00 0) 0) o) 0) 0) O) o) o) 0) o) 1- 1- < = w z cn Z ❑ H O oowaJa < Jw ( N 2 0 0 0 cn cn a a) 0 m N N N O 0 0 co O N 0 0 LC) O LU O O a7 O r N N- N O (0 00 N M .Wa MCo I- O ,- (O co O r M -A- Co O V' f- C o r M 00 V In N NN N M M M CD = = = = = = = = ,.. �- N r = r r r E R m a 0) Y U O cn a C) < 2 2 2 O cococan u)_1 can CU 00 _ O a M 12 S L N- N O O COM r 0 0 0 0 0 0 L() O = Q M CO N 00 0) O CO f- C0 N N N 0) r N (0 y M M CD V O Ln N- 0) r N V Ln N- M V M o r = M ,- ,- = r ,- N N N N N M M Li.1 r c-- r r r r r r r Caa Mr = L ) O t O 0- LL 0 0 W 0J U -JH o• w (_ wwtiw � wLLLLw � � � � � a 0 Ti aaaaaaaaaaawwwww 00 J a, Q Q Q Q Q Q Q Q Q Q Q a a a a a w D � z L 0a zz a a a Q w w W N N LL. 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KOP= 319T 20"CONDUCTOR, 112' Max Angle= 99°@ 11753' # ' ' 2082" —'4-1/2"I-ES X NP,D=3.813" Datum MD= 11297' C Datum TVD= 8800'SS 13-3/8°CSG,72#,L-80 BTC,D=12.347' -- 2385' GAS LFT MANDRELS `ST MD TVD DEV VLV TYPE LATCH FORT DATE 9-5/8"X 7'BKR TESACK SLV,D=7.25" —i 8820' L ..is_ 1 3291 3284 12 DOME MMG RK 16 09130/14 9-5/8"X 7'BKR ZXP LW w/1-114C HGR,D=6.313" — 8827' 4 I. i 2 6286 5501 57 SO MMG RK 22 09/30/143 8995 7101 48 DMY KBG2LS-M NT 0 12120198 4 9912 7809 36 DMY KBG2LS-M /YT 0 08/03/12 TOP OF C9,,184T H 9643' 5 10528 8302 36 DMY KBG2LS-M M 0 12/20/98 6 11064 8705 43 *CMY KBG2LS-M 147 0 08/03/12 *STA#6=DMY HAS EXT PACKING/BE}*t)PATCH(6/16/13) 9-5/8°CSG,47#,L-80 BTC,D=8.681' —I —9036 `£ MLLOtJT ATOM(13-08A) 8991'-9036' Minimum ID = 1.875" a@ 11167' 11o56'-11083' D2 ) 4-1/2" X 2-3/8" NIP REDUCER ] L3--- Z X 11133' —{7"X 4-1/2"BKR S-3 PKR,D=3.875" 11167' —14-1/2"HES X NP,D=3.813" 4-1/2"TBG,12.6#,13CR NSCT, —I 11188' 11167' I-14-1/2"X 2-3/8"NP REDUCER,D=1.875"(05/31/13) .0152 bpf,13=3.958' TOP OF 4-1/2"LNR H 1--- 11199' Hr X 5"BKR ZXP FKR,D=??? 11189' -j4-1/2'WLEG,D=3.958' 7"LNR,26#,L-80 BTC MOD,.0383 bpf,D=6.276" — 11374' \ H BAD TT NOT LOGGED PERFORATION SUMMARY \` 11213' —15*X 4-1/2"X0,D=3.956' REF LOG.61-CS ON 10/23/81 , ANGLE AT TOP PERE:45°@ 11337' Note:Refer to Production DB for historical perf data I SIZE SPE INTERVAL Opn/Sqz SHOT - SQZ , 1-11/16" 7.5 11337-11362 0 06/06/15 ' 1-11/16" 7.5 11362- 11373 0 06/05/15 ' 1-11/16" 7.5 11480- 11491 0 06/05/15 1-11/16" 7.5 11490-11511 0 06/04/15 I 3-3/8" 4 11583- 11604 0 08/16/02 I 3-3/8" 4 11773-11815 0 08/16/02 3-3/8" 4 11981-12020 0 08/15/02 I 3-3/8" 4 12120-12172 0 08/15/02 I 3-3/8- 4 12220-12320 0 08/15/02 , 2-3/4' 4 12420-12480 0 12/19/98 2-3/4' 4 12590-12665 0 12/19/98 I 2-3/4" 4 12710-13080 0 12/19/98 , 2-3/4" 4 13320-13425 0 12/19/98 ' 2-3/4' 4 13465-13730 0 12/19/98 I PBTD — 13752' ilillb 4-1/2"LNR, 12.6#,L-80,-0152 bpf,D=3.958" —i 13800' •IP 1 � " At DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/29/81 INITIAL COMPLETION 10/03/14'MGS/JM IGLV CIO(09/30/14) WELL: 13-08A 12/22/98 N22E SIDETRACK(13-08A) 02/25/15 PJC CONDUCTOR)LNR/CSG UPDATE PERMIT Pb: 1982150 08/09/12 CJN/JMD GLV C/O(08/03/12) 06/26/15 GTW/JP C ADPERES(06/04-06/15) API No: 50-029-20667-01 06/10/13 SVVC/JMC SET NP REDUCER(05/31/13) SEC 13,TION,R14E,1409'ESL&130'PM. 06/19/13 MSS/J1.13 LWRbUFFE32 PATCH(06/12-16/13) 07/10/13 RCT/PJC GLV CIO(06/22/13) BP Exploration(Alaska) Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 09/18/03 No. 2963 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99504 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD H-17A IQ -~"i~g')C~ MEM PROD PROFILE 08/13/07 E-27A 'l ~ C~ -(~,=-3~_~ MEM PROD PROFILE 08109103 D.S. 13-08A ~q'~'-C~-[~,~ GLS 09104/03 E-25 I ~ ~ '1 ,~ ~ LDL 09/06/03 D.S. 3-09 ~q '~~ PSP PROD PROFILE 08/06103 D.S. 1-1 ~ [ ~ -~.~ INJECTION PROFILE 09d 6~03 K-07C ~ qq - ~' SBHP 09d 6/03 A-23 ~~~ RST-C G~VEL PACK 09107103 D.S. 15~8A ~ ~~ PSP LDL 08130103 MPS-06 ~O ~ ~ [~ ~MPE~TURE LOG 08/30103 1-3510-25 -i ~ ~ {~ ~J PROD PROFILE/DEFT/GHOST 09/14/03 ~-20B 23076 OH EDIT MWD SLIMPULSE & ARC DATA 10/14102 J-20B 23076 MD VISION RESISTIVI~ ~0/14/02 ~-20B 23076 ~D VISION RESISTIVI~ 10114102 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Jnc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 F ECEIVED Date Delivered: 200,5 Alaska 0;;i & Ga,s" ' Schlumberger GeoQuest 3940 Arctic- Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth -.1981215,.0 ........ pRUDHOE BAY UNiT Roll #1: Start: Stop Roll #2: MD 13800 TVD 09035 Completion Date: L. 13208A ' 50, 029,20667,0'i' Start Stop (AL^Sm4) ri'dC 12/22/98 Completed Status: 1-OIL Current: T Name Interval D 9198 3 SPERRY MPT/GR/EWR4 PB2 OH D 9209 4-8 SPERRY MPT/GR/EWR4/SLD Oki ./~ L DGR/EWR4-MD FINAL 9345-11181 PB2 OH H L DGRfEWR4-MD FINAL 8986-13800 OH j L DGRfEWR4-ME FINAL 7634-8682 PB2 OH .,~ DGR/EWR4-TVD FINAL 7035-9037 OH jL DGR/SLD-MD FINAL 8986-13800 Oki .~L DGR/SLD-TVD FINAL 7035-9037 OH R SRVY RPT SPERRY 8896.L52-13800. OH R SRVY Il. PT SPERRY 9296.52-11181. PB2 OH Sent Received T/C/I) 6/8/99 6/8/99 6/19/99 6/17/99 6/8/99 6/8/99 D 6/17/99 6/17/99 6/8/99 6/8/99 6/17/99 6/17/99 6/17/99 6/17/99 6/17/99 6/17/99 1/27/99 1/28/99 1/27/99 1/28/99 Thursday, January 25, 2001 Page 1 of 1 ~. STATE OF ALASKA .._.. ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator :7. Permit Number ARCO Alaska Inc. 98-215 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20667-01 4. Location of well at surface~.~__ 9. Unit or Lease Name 1409' NSL, 130' EWL, SEC. 13, T10N, R14E, UM '-.:' ~ · ' Prudhoe Unit Bay At top of productive interval r ~~ t~ 10. Well Number 3127' SNL, 3146' EWL, SEC. 24, T10N, R14E, UM / ' ,~..~ 13-08A At total depth ~. . ~. 11 Field and Pool 106' SNL, 2768' EWL, SEC. 25, T10N R14E, UM ~' ' .... Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 74.52'I ADL 028316 17. Total Depth(MD+TVD) 18. Plug Back Depth (MD+TVD)119. DirectionalSurvey 120. Depth where SSSV set121. Thickness of Permafrost 13800 9035 FT 13752 9037 FTI [~;~]Yes I--lNG (Nipple) 2082' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, DEN 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP DO'Iq-OM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 110' 32" 300 sx Permafrost 13-3/8" 72# L-80 Surface 2385' 17-1/2" 2500 sx Fondu, 400 sx Permafrost 'C' 9-5/8" 47# L-80 / S00-95 Surface 8990' 12-1/4" 250 sx Class 'G' 7" 26# L-80 8820' 11374' 8-1/2" 259 sx Class 'G' 4-1/2" 12.6# L-80 11192' 13800' 6" 325 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. ~'?': .: TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr 11189' 11133' MD TVD MD TVD 12420' - 12480' 9023' - 9032' 12590'- 12665' 9119'-9036' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 12710' - 13080' 9036' - 9041' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13320' - 13425' 9043' - 9042' 13465' - 13730' 9040' - 9038' Freeze Protect with 165 Bbls of Diesel . . 27. ';"~ PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.)U II, i L71 b January 6, 1999 ] Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ]GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Si In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 11328' 8897' Shublik 11376' 8931' Sadlerochit 11473' 8991' 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 -~'-) ?'tot ~ DanStone ~.,_ ~. ~...-¢~ Title Senior Drilling Engineer Date ' 13-08A 98-215 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. 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: 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. iTEM 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 Progress Report Facility PB DS 13 Well 13-08A Rig Nabors 22E Page 1 Date 15 January 99 Date/Time 12 Nov 98 09:00-10:00 10:00-12:00 12:00-12:30 12:30-00:00 13 Nov 98 00:00-00:30 00:30-06:00 06:00-09:00 09:00-12:00 12:00-12:30 12:30-18:30 18:30-20:30 20:30-22:00 22:00-00:00 14 Nov 98 00:00-00:30 00:30-02:30 02:30-03:30 03:30-04:30 04:30-06:00 06:00-08:00 08:00-11:00 11:00-12:00 12:00-12:30 12:30-13:00 13:00-13:30 13:30-18:00 18:00-19:30 19:30-00:00 15 Nov 98 00:00-00:30 00:30-06:00 06:00-11:00 11:00-12:00 12:00-12:30 12:30-14:30 14:30-00:00 16 Nov 98 00:00-00:30 00:30-03:00 03:00-04:30 04:30-06:00 06:00-09:00 09:00-12:00 12:00-12:30 12:30-17:00 17:00-19:30 19:30-21:00 21:00-00:00 17 Nov 98 00:00-00:30 00:30-01:30 01:30-02:30 02:30-03:00 03:00-04:30 04:30-06:00 06:00-20:00 20:00-22:00 22:00-00:00 Duration lhr 2 hr 1/2 hr 11-1/2 hr 1/2 hr 5-1/2 hr 3 hr 3hr 1/2 hr 6hr 2 hr 1-1/2 hr 2hr 1/2 hr 2hr lhr 1 hr 1-1/2 hr 2hr 3hr 1 hr 1/2 hr 1/2 hr 1/2 hr 4-1/2 hr 1-1/2 hr 4-1/2 hr 1/2 hr 5-1/2 hr 5hr 1 hr 1/2 hr 2hr 9-1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 3hr 3hr 1/2 hr 4-1/2 hr 2-1/2 hr 1-1/2 hr 3hr 1/2 hr lhr lhr 1/2 hr 1-1/2 hr 1-1/2 hr 14hr 2hr 2hr Activity Held safety meeting Rigged down Drillfloor / Derrick Held safety meeting Rig moved 50.00 % Held safety meeting Rig moved 80.00 % Rig moved 100.00 % Installed Swab valve Held safety meeting Circulated at 11552.0 ft Installed Hanger plug Removed Xmas tree Rigged up BOP stack Held safety meeting Rigged up BOP stack Tested Blind ram Serviced Draw works Retrieved BOP test plug assembly Retrieved BOP test plug assembly Installed Drillpipe retrieval string Installed Tubing handling equipment Held safety meeting Laid down 80.0 ft of Tubing Installed Retrievable packer Tested BOP stack Retrieved Retrievable packer Laid down 2730.0 ft of Tubing Held safety meeting Laid down 10000.0 ft of Tubing Laid down 1581.0 ft of Tubing Rigged up Logging/braided cable equipment Held safety meeting Conducted electric cable operations Ran Drillpipe to 5608.0 ft (5in OD) Held safety meeting Ran Drillpipe to 10200.0 ft (5in OD) Circulated at 10200.0 ft Pulled out of hole to 6500.0 ft Pulled out of hole to 0.0 ft Conducted electric cable operations Held safety meeting Conducted electric cable operations Conducted electric cable operations Made up BHA no. 1 R.I.H. to 7228.0 ft Held safety meeting R.I.H. to 10100.0 ft Circulated at 10060.0 ft Pulled out of hole to 9800.0 ft Circulated at 9800.0 ft Milled Other sub-surface equipment at 9800.0 ft Milled Other sub-surface equipment at 9850.0 ft Circulated at 9850.0 ft Pulled out of hole to 7036.0 ft Facility Date/Time 18 Nov 98 19 Nov 98 20 Nov 98 21 Nov 98 PB DS 13 Progress Report Well 13-08A Rig Nabors 22E Duration Activity 00:00-00:30 00:30-02:00 02:00-03:00 03:00-04:30 04:30-06:00 06:00-07:30 07:30-08:00 08:00-09:00 09:00-10:30 10:30-12:00 12:00-12:30 12:30-16:00 16:00-16:30 16:30-17:30 17:30-21:30 21:30-22:30 22:30-00:00 00:00-00:30 00:30-05:00 05:00-06:00 06:00-08:30 08:30-12:00 12:00-12:30 12:30-14:00 14:00-18:30 18:30-20:00 20:00-20:30 20:30-21:30 21:30-22:00 22:00-00:00 00:00-00:30 00:30-04:30 04:30-05:00 05:00-06:00 06:00-08:30 08:30-12:00 12:00-15:00 15:00-16:00 16:00-19:30 19:30-21:30 21:30-22:30 22:30-23:30 23:30-00:00 00:00-00:30 00:30-04:00 04:00-06:00 06:00-08:30 08:30-12:00 12:00-12:30 12:30-13:30 13:30-14:30 14:30-15:30 15:30-19:00 19:00-21:30 1/2 hr 1-1/2 hr lhr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1 hr 1-1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr lhr 4hr lhr 1-1/2 hr 1/2 hr 4-1/2 hr lhr 2-1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr 4-1/2 hr 1-1/2 hr 1/2 hr lhr 1/2 hr 2hr 1/2 hr 4hr 1/2 hr lhr 2-1/2 hr 3-1/2 hr 3hr lhr 3-1/2 hr 2hr 1 hr 1 hr 1/2 hr 1/2 hr 3-1/2 hr 2hr 2-1/2 hr 3-1/2 hr 1/2 hr lhr lhr lhr 3-1/2 hr 2-1/2 hr Held safety meeting Pulled out of hole to 200.0 ft Pulled BHA Serviced BOP stack Ran Drillpipe in stands to 5000.0 ft Ran Drillpipe in stands to 8500.0 fi Serviced Top drive Serviced Block line Ran Drillpipe to 9841.0 ft (5in OD) Worked toolstring at 9841.0 ft Held safety meeting Circulated at 9800.0 ft Worked toolstring at 9841.0 ft Circulated at 9800.0 fi Pulled out of hole to 0.0 ft Serviced BOP stack Made up BHA no. 2 Held safety meeting R.I.H. to 9790.0 ft Washed to 9800.0 ft Washed to 9855.0 ft Pulled out of hole to 700.0 ft Held safety meeting Pulled BHA Ran Drillpipe in stands to 9717.0 ft Washed to 9862.0 ft Held safety meeting Batch mixed slurry - 30.000 bbl Pulled out of hole to 9300.0 ft Circulated at 9300.0 ft Held safety meeting Pulled out of hole to 0.0 ft Retrieved Wear bushing Tested BOP stack Tested BOP stack Made up BHA no. 3 R.I.H. to 4000.0 ft Held safety meeting R.I.H. to 9577.0 ft Drilled cement to 9803.0 ft Drilled to 9804.0 ft Circulated at 9800.0 ft Drilled to 9805.0 fi Held safety meeting Drilled to 9820.0 ft Circulated at 9800.0 ft Drilled to 9830.0 ft Circulated at 9800.0 ft Held safety meeting Washed to 9830.0 ft Drilled to 9843.0 ft Circulated at 9800.0 ft Pulled out of hole to 218.0 ft Pulled BHA Page Date 2 15 January 99 Facility PB DS 13 Progress Report Well 13-08A Rig Nabors 22E Page Date 3 15 January 99 Date/Time 22 Nov 98 23 Nov 98 24 Nov 98 25 Nov 98 21:30-00:00 00:00-00:30 00:30-03:00 03:00-04:00 04:00-06:00 06:00-08:00 08:00-12:00 12:00-12:30 12:30-16:30 16:30-17:30 17:30-18:30 18:30-20:30 20:30-21:30 21:30-00:00 00:00-00:30 00:30-04:30 04:30-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-08:45 08:45-09:30 09:30-09:45 09:45-11:00 11:00-12:00 12:00-13:00 13:00-13:30 13:30-16:00 16:00-17:00 17:00-18:30 18:30-19:30 19:30-21:30 21:30-22:00 22:00-01:00 01:00-02:30 02:30-02:45 02:45-03:30 03:30-04:30 04:30-06:00 06:00-13:00 13:00-15:00 15:00-15:30 15:30-20:00 20:00-21:00 21:00-21:30 21:30-21:45 21:45-23:00 23:00-01:30 01:30-02:00 02:00-03:00 03:00-06:00 06:00-07:00 07:00-08:00 08:00-09:00 Duration 2-1/2 hr 1/2 hr 2-1/2 hr lhr 2hr 2hr 4 hr 1/2 hr 4hr lhr lhr 2hr 1 hr 2-1/2 hr 1/2 hr 4hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/4 hr 3/4 hr 1/4 hr 1-1/4 hr lhr lhr 1/2 hr 2-1/2 hr 1 hr 1-1/2 hr lhr 2hr 1/2 hr 3hr 1-1/2 hr 1/4 hr 3/4 hr lhr 1-1/2 hr 7hr 2hr 1/2 hr 4-1/2 hr 1 hr 1/2hr 1/4 hr 1-1/4 hr 2-1/2 hr 1/2 hr lhr 3hr 1 hr lhr lhr Activity Ran Drillpipe in stands to 200.0 ft Held safety meeting Ran Drillpipe in stands to 9800.0 ft Serviced Top drive Washed to 9832.0 ft Circulated at 9800.0 ft Pulled out of hole to 0.0 ft Held safety meeting Ran Drillpipe in stands to 9750.0 ft Serviced Top drive Washed to 9843.0 ft Batch mixed slurry - 40.000 bbl Circulated at 9705.0 ft Monitor pressures Held safety meeting Pulled out of hole to 0.0 ft Made up BHA no. 4 Tested M.W.D. tool - Via string R.I.H. to 4000.0 ft Tested M.W.D. tool - Via string Held safety meeting Serviced Block line Held safety meeting R.I.H. to 9000.0 ft Reamed to 9730.0 ft Circulated at 9730.0 ft Washed to 9803.0 ft Drilled cement to 9832.0 ft Pulled out of hole to 9795.0 ft Circulated at 9795.0 ft Reamed to 9830.0 ft Worked toolstring at 9830.0 ft Drilled to 9840.0 ft Worked stuck pipe at 9840.0 ft Circulated at 9790.0 ft Held safety meeting Reamed to 9840.0 ft Drilled to 9874.0 ft Worked stuck pipe at 9874.0 ft Worked stuck pipe at 9874.0 ft (cont...) Circulated at 9790.0 ft Held safety meeting Pulled out of hole to 0.0 ft Downloaded MWD tool Rigged down Drillstring handling equipment Held safety meeting Rigged up Logging/braided cable equipment Conducted electric cable operations Rigged down Logging/braided cable equipment Made up BHA no. 5 R.I.H. to 9500.0 ft Serviced Top drive Serviced Block line R.I.H. to 9569.0 ft Progress Report Facility PB DS 13 Well 13-08A Rig Nabors 22E Page 4 Date 15 January 99 Date/Time 09:00-10:00 10:00-11:00 11:00-14:00 14:00-15:00 15:00-06:00 26 Nov 98 06:00-11:00 11:00-13:00 13:00-14:30 14:30-15:00 15:00-16:30 16:30-20:00 20:00-21:30 21:30-21:45 21:45-22:00 22:00-22:15 22:15-22:30 22:30-02:00 27 Nov 98 02:00-02:30 02:30-04:00 04:00-05:00 05:00-05:15 05:15-05:30 05:30-06:00 06:00-08:00 08:00-09:00 09:00-09:30 09:30-14:00 14:00-14:30 14:30-15:00 15:00-15:30 15:30-19:00 19:00-19:30 19:30-20:00 20:00-23:00 23:00-00:00 28 Nov 98 00:00-00:30 00:30-04:00 04:00-06:00 06:00-07:30 07:30-09:30 09:30-10:30 10:30-14:00 14:00-06:00 29 Nov 98 06:00-21:30 21:30-22:00 22:00-00:00 30 Nov 98 00:00-00:30 00:30-06:00 06:00-10:00 10:00-12:00 12:00-12:30 12:30-18:30 18:30-20:30 20:30-21:30 Duration 1 hr 1 hr 3hr 1 hr 15hr 5hr 2hr 1-1/2 hr 1/2 hr 1-1/2 hr 3-1/2 hr 1-1/2 hr 1/4 hr 1/4 hr 1/4 hr 1/4 hr 3-1/2 hr 1/2 hr 1-1/2 hr 1 hr 1/4 hr 1/4 hr 1/2 hr 2hr lhr 1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 3hr lhr 1/2 hr 3-1/2 hr 2 hr 1-1/2 hr 2 hr 1 hr 3-1/2 hr 16hr 15-1/2 hr 1/2 hr 2hr 1/2 hr 5-1/2 hr 4hr 2 hr 1/2 hr 6hr 2hr 1 hr Activity Pulled out of hole to 9345.0 ft Milled Casing at 9345.0 ft Flow check Circulated at 9346.0 ft ',,) Milled Casing at 9380.0 ft Milled Casing at 9400.0 ft (cont...) Circulated at 9400.0 ft Pulled out of hole to 7450.0 ft R.I.H. to 9350.0 ft Circulated at 9350.0 ft Pulled out of hole to 811.0 ft Pulled BHA Removed Bore protector Installed Bore protector Held safety meeting Made up BHA no. 6 R.I.H. to 9232.0 ft Circulated at 9232.0 ft Washed to 9517.0 ft Circulated at 9517.0 ft Pumped Water spacers - volume 20.000 bbl Mixed and pumped slurry - 30.000 bbl Displaced slurry - 148.000 bbl Circulated at 8526.0 ft Held 320.0 psi pressure on 1.400 bbl squeezed cement Held safety meeting Wait on cement Rest hole at 8526.0 ft Installed Drillstring handling equipment Held safety meeting Pulled out of hole to 0.0 ft Retrieved Bore protector Held safety meeting Tested BOP stack Installed Bore protector Held safety meeting Made up BHA no. 7 R.I.H. to 5500.0 ft R.I.H. to 8700.0 ft (cont...) Washed to 9184.0 ft Drilled cement to 9348.0 ft Drilled to 9360.0 ft Drilled to 10075.0 ft Drilled to 10700.0 ft (cont...) Held safety meeting Drilled to 10780.0 ft Held safety meeting Drilled to 10980.0 ft Drilled to 11181.0 ft (cont...) Circulated at 11181.0 ft Held safety meeting Backreamed to 9330.0 ft Circulated at 9330.0 ft Flow check Facility PB DS 13 Progress Report Well 13-08A Rig Nabors 22E Page Date 5 15 January 99 Date/Time 01 Dec 98 02 Dec 98 03 Dec 98 04 Dec 98 21:30-22:00 22:00-22:30 22:30-22:45 22:45-23:00 23:00-00:00 00:00-00:30 00:30-03:00 03:00-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-10:30 10:30-14:00 14:00-14:30 14:30-14:45 14:45-16:00 16:00-19:30 19:30-20:00 20:00-00:30 00:30-00:45 00:45-02:30 02:30-03:00 03:00-06:00 06:00-10:30 10:30-12:00 12:00-12:30 12:30-05:30 05:30-05:45 05:45-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-09:00 09:00-10:30 10:30-11:00 11:00-11:30 11:30-12:30 12:30-15:30 15:30-16:00 16:00-17:00 17:00-21:00 21:00-22:00 22:00-22:30 22:30-23:00 23:00-23:30 23:30-00:00 00:00-00:30 00:30-02:30 02:30-03:30 03:30-04:30 04:30-05:45 05:45-06:00 06:00-06:15 Duration 1/2 hr 1/2 hr 1/4hr 1/4hr 1 hr 1/2 hr 2-1/2 hr 1-1/2 hr 1 hr 1/2 hr 1/2 hr 1 hr 3hr 3-1/2 hr 1/2 hr 1/4 hr 1-1/4 hr 3-1/2 hr 1/2hr 4-1/2 hr 1/4 hr 1-3/4 hr 1/2 hr 3hr 4-1/2 hr 1-1/2 hr 1/2 hr 17hr 1/4 hr 1/4 hr 1/2 hr lhr 1/2 hr 1 hr 1-1/2 hr 1/2hr 1/2 hr 1 hr 3hr 1/2 hr 1 hr 4hr 1 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 2 hr 1 hr 1 hr 1-1/4 hr 1/4 hr 1/4hr Activity Pulled out of hole to 8860.0 ft Flow check Pulled out of hole to 7920.0 ft Flow check Pulled out of hole to 5500.0 ft Held safety meeting Pulled out of hole to 700.0 ft Pulled BHA Downloaded MWD tool Removed Bore protector Installed Bore protector Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations Removed Logging/braided cable equipment Held safety meeting Made up BHA no. 8 R.I.H. to 9250.0 ft Held safety meeting Circulated at 9250.0 ft Cleared Mud shakers Circulated at 9250.0 ft Pulled out of hole to 8986.0 fl Milled Casing at 8990.0 fl Milled Casing at 8997.0 fl (cont...) Circulated at 8997.0 fl Held safety meeting Milled Casing at 9036.0 ft Circulated at 9036.0 ft Circulated at 3000.0 ft Circulated at 3000.0 ft (cont...) Pulled out of hole to 0.0 fl Held safety meeting Made up BI-IA no. 9 R.I.H. to 3017.0 ft Fished at 3017.0 ft Pulled out of hole to 2829.0 fl Held safety meeting Pulled out of hole to 0.0 fl Held safety meeting Laid down fish Pulled out of hole to 700.0 ft Pulled BHA Pulled BHA Removed Drillstring handling equipment Serviced Wear bushing Rigged up sub-surface equipment - Mule shoe Held safety meeting Ran Drillpipe in stands to 6500.0 fl Circulated at 6500.0 ft Ran Drillpipe in stands to 8500.0 fl Circulated at 8500.0 fl Ran Drillpipe in stands to 8700.0 fl Ran Drillpipe in stands to 8700.0 fl (cont...) Facility PB DS 13 Progress Report Well 13-08A Rig Nabors 22E Page Date 6 15 January99 Date/Time 05 Dec 98 06 Dec 98 07 Dec 98 08 Dec 98 06:15-07:00 07:00-07:30 07:30-08:00 08:00-08:30 08:30-08:45 08:45-09:00 09:00-09:30 09:30-10:30 10:30-11:30 11:30-12:30 12:30-14:00 14:00-14:15 14:15-14:30 14:30-15:00 15:00-19:30 19:30-20:00 20:00-20:15 20:15-21:00 21:00-00:00 00:00-00:30 00:30-01:00 01:00-03:00 03:00-04:15 04:15-04:30 04:30-04:45 04:45-06:00 06:00-06:15 06:15-06:30 06:30-08:30 08:30-10:00 10:00-12:30 12:30-12:45 12:45-13:30 13:30-06:00 06:00-14:30 14:30-17:30 17:30-18:00 18:00-19:00 19:00-21:00 21:00-21:15 21:15-00:00 00:00-00:30 00:30-06:00 06:00-18:30 18:30-20:00 20:00-00:00 00:00-00:30 00:30-01:30 O1:30-02:00 02:00-03:30 03:30-05:30 05:30-06:00 06:00-06:30 06:30-07:30 Duration 3/4 hr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr lhr lhr 1 hr 1-1/2 hr 1/4 hr 1/4 hr 1/2 hr 4-1/2 hr 1/2 hr 1/4hr 3/4 hr 3hr 1/2 hr 1/2 hr 2hr 1-1/4 hr 1/4 hr 1/4 hr 1-1/4 hr 1/4 hr 1/4 hr 2 hr 1-1/2 hr 2-1/2 hr 1/4 hr 3/4 hr 16-1/2 hr 8-1/2 hr 3hr 1/2 hr lhr 2 hr 1/4 hr 2-3/4 hr 1/2 hr 5-1/2 hr 12-1/2 hr 1-1/2 hr 4hr 1/2 hr lhr 1/2 hr 1-1/2 hr 2 hr 1/2 hr 1/2 hr 1 hr Activity Washed to 9126.0 ft Held safety meeting Circulated at 9126.0 ft Rigged up High pressure lines Pumped Water spacers - volume 20.000 bbl Mixed and pumped slurry - 40.000 bbl Displaced slurry - 147.000 bbl Pulled Drillpipe in stands to 8180.0 ft Circulated at 8180.0 ft Bullhead well Monitor pressures Bleed down well Rigged up Drillstring handling equipment Circulated at 8180.0 ft Pulled out of hole to 0.0 fl Circulated at 0.0 ft Retrieved B ore protector Installed BOP test plug assembly Tested Well control Held safety meeting Rigged down High pressure lines Made up BHA no. 9 R.I.H. to 2970.0 ft Tested M.W.D. tool - Via string Held safety meeting Serviced Block line Serviced Block line (cont...) Serviced Top drive R.I.H. to 8200.0 ft Washed to 8806.0 fl Drilled cement to 8988.0 ft Held safety meeting Circulated at 8988.0 ft Drilled to 9315.0 ft Drilled to 9810.0 ft (cont...) Pulled out of hole to 6118.0 ft Laid down 31.0 ft of 5in OD drill pipe Circulated at 6118.0 ft R.I.H. to 9757.0 ft Washed to 9810.0 ft Drilled to 10012.0 ft Held safety meeting Drilled to 10147.0 fl Drilled to 10694.0 fl Circulated at 10694.0 ft Pulled out of hole to 2400.0 ft Held safety meeting Pulled out of hole to 300.0 ft Pulled BHA Downloaded MWD tool Made up BHA no. 10 R.I.H. to 200.0 ft R.I.H. to 3500.0 ft Serviced Top drive Progress Report Facility PB DS 13 Well 13-08A Rig Nabors 22E Page 7 Date 15 January 99 Date/Time 09 Dec 98 10 Dec 98 11 Dec 98 12 Dec 98 07:30-12:30 12:30-05:00 05:00-06:00 06:00-08:00 08:00-08:30 08:30-09:00 09:00-10:30 10:30-12:30 12:30-14:00 14:00-14:30 14:30-16:00 16:00-17:00 17:00-17:30 17:30-19:30 19:30-01:00 01:00-02:30 02:30-03:30 03:30-05:00 05:00-05:30 05:30-06:00 06:00-09:00 09:00-09:30 09:30-14:00 14:00-16:30 16:30-18:00 18:00-21:45 21:45-22:00 22:00-22:15 22:15-22:30 22:30-22:45 22:45-23:30 23:30-00:30 00:30-04:30 04:30-06:00 06:00-08:00 08:00-08:30 08:30-15:30 15:30-16:30 16:30-17:30 17:30-20:00 20:00-21:00 21:00-21:30 21:30-23:00 23:00-00:30 00:30-01:30 01:30-03:30 03:30-04:00 04:00-06:00 06:00-07:00 07:00-08:30 08:30-10:30 10:30-13:00 13:00-13:30 13:30-16:30 Duration 5hr 16-1/2 hr 1 hr 2hr 1/2 hr 1/2 hr 1-1/2 hr 2 hr 1-1/2 hr 1/2 hr 1-1/2 hr lhr 1/2 hr 2hr 5-1/2 hr 1-1/2 hr lhr 1-1/2 hr 1/2 hr 1/2 hr 3 hr 1/2 hr 4-1/2 hr 2-1/2 hr 1-1/2 hr 3-3/4 hr 1/4 hr 1/4 hr 1/4 hr 1/4 hr 3/4 hr lhr 4 hr 1-1/2 hr 2hr 1/2 hr 7hr 1 hr lhr 2-1/2 hr lhr 1/2 hr 1-1/2 hr 1-1/2 hr lhr 2hr 1/2hr 2hr 1 hr 1-1/2 hr 2hr 2-1/2 hr 1/2 hr 3hr Activity R.I.H. to 10694.0 ft Drilled to 11356.0 ft Circulated at 11356.0 ft Circulated at 11356.0 ft Drilled to 11364.0 ft Circulated at 11364.0 ft Pulled out of hole to 8960.0 fi R.I.H. to 11364.0 ft Circulated at 11364.0 ft Drilled to 11374.0 ft Circulated at 11374.0 ft Pulled out of hole to 10580.0 ft R.I.H. to 11374.0 ft Circulated at 11374.0 ft Pulled out of hole to 800.0 fi Pulled BHA Downloaded MWD tool Rigged up Casing handling equipment Held safety meeting Ran Liner to 300.0 ft (7in OD) Ran Liner to 2600.0 ft (7in OD) Circulated at 2600.0 ft Ran Liner to 8978.0 ft (7in OD) Circulated at 8978.0 ft Ran Liner to 11374.0 ft (7in OD) Circulated at 11374.0 fi Held safety meeting Pumped Water spacers - volume 20.000 bbl Pumped Inhibited brine spacers - volume 50.000 bbl Mixed and pumped slurry - 53.000 bbl Displaced slurry - 243.000 bbl Circulated at 8813.0 ft Retrieved downhole equipment - Cementing packer Tested All functions Tested BOP stack Installed Wear bushing Made up BHA no. 11 Serviced Block line Serviced Top drive R.I.H. to 11209.0 fi Drilled cement to 11295.0 ft Tested Liner - Via string Drilled cement to 11326.0 ft Drilled to 11379.0 ft Circulated at 11379.0 ft Circulated at 11379.0 ft Flow check Pulled out of hole to 6000.0 ft Pulled out of hole to 4781.0 ft Pulled BHA Made up BHA no. 12 R.I.H. to 4876.0 ft Serviced Top drive R.I.H. to 11379.0 ft Progress Report Facility PB DS 13 Well 13-08A Page 8 Rig Nabors 22E Date 15 January 99 Date/Time 13 Dec 98 14 Dec 98 15 Dec 98 16 Dec 98 17 Dec 98 18 Dec 98 19 Dec 98 16:30-04:30 04:30-05:30 05:30-06:00 06:00-11:00 11:00-12:30 12:30-15:00 15:00-19:30 19:30-20:00 20:00-20:30 20:30-21:00 21:00-06:00 06:00-19:00 19:00-21:00 21:00-22:00 22:00-22:30 22:30-03:00 03:00-03:30 03:30-05:00 05:00-06:00 06:00-09:00 09:00-10:30 10:30-12:00 12:00-06:00 06:00-15:00 15:00-17:30 17:30-18:30 18:30-02:00 02:00-03:00 03:00-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-14:00 14:00-17:30 17:30-18:30 18:30-19:00 19:00-23:00 23:00-00:00 00:00-04:30 04:30-06:00 06:00-07:00 07:00-08:30 08:30-11:00 11:00-11:15 11:15-11:45 11:45-13:00 13:00-17:00 17:00-22:30 22:30-23:00 23:00-23:30 23:30-04:30 04:30-05:00 Duration 12hr 1 hr 1/2hr 5hr 1-1/2 hr 2-1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1/2 hr 9hr 13hr 2hr 1 hr 1/2 hr 4-1/2 hr 1/2 hr 1-1/2 hr lhr 3hr 1-1/2 hr 1-1/2 hr 18hr 9hr 2-1/2 hr lhr 7-1/2 hr 1 hr 2-1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 6hr 3-1/2 hr lhr 1/2 hr 4hr lhr 4-1/2 hr 1-1/2 hr 1 hr 1-1/2 hr 2-1/2 hr 1/4 hr 1/2 hr 1-1/4 hr 4hr 5-1/2 hr 1/2 hr 1/2 hr 5hr 1/2 hr Activity Drilled to 11656.0 ft Circulated at 11656.0 fl Pulled out of hole to 11300.0 ft Pulled out of hole to 205.0 fl (cont...) Pulled BHA Made up BHA no. 13 R.I.H. to 11275.0 ft Serviced Top drive R.I.H. to 11466.0 ft Washed to 11656.0 fl Drilled to 11945.0 ft Drilled to 12417.0 ft (cont...) Circulated at 12417.0 ft Pulled out of hole to 11083.0 ft Circulated at 11083.0 fl Pulled out of hole to 205.0 ft Pulled BHA Made up BHA no. 14 R.I.H. to 2000.0 fl R.I.H. to 11200.0 ft (cont...) Serviced Block line R.I.H. to 12417.0 ft Drilled to 13396.0 ft Drilled to 13800.0 ft (cont...) Circulated at 13800.0 fl Pulled out of hole to 12500.0 fl Logged hole with LWD: Formation evaluation (FE) from 12500.0 ft to 11374.0 ft R.I.H. to 13800.0 ft Circulated at 13800.0 fl Circulated at 13800.0 fl Circulated at 13800.0 ft (cont...) Pulled out of hole to 11360.0 ft Circulated at 11360.0 fl Pulled out of hole to 228.0 ft Pulled BHA Rigged up Tubing handling equipment Held safety meeting Ran Liner to 2700.0 fl (4-1/2in OD) Circulated at 2700.0 fl Ran Liner on landing string to 11280.0 fl Circulated at 11280.0 fl Circulated at 11280.0 fl (cont...) Ran Liner on landing string to 13800.0 ft Circulated at 13800.0 ft Pumped Water based mud spacers - volume 20.000 bbl Mixed and pumped slurry - 65.000 bbl Displaced slurry - 214.000 bbl Circulated at 11192.0 ft Pulled Drillpipe in stands to 0.0 fl Retrieved Wear bushing Tested Casing Tested BOP stack Installed Wear bushing Facility PB DS 13 Progress Report Well 13-08A Page 9 Rig Nabors 22E Date 15 January 99 Date/Time 20 Dec 98 21 Dec 98 22 Dec 98 05:00-06:00 06:00-07:00 07:00-07:30 07:30-09:00 09:00-13:00 13:00-19:00 19:00-20:00 20:00-21:30 21:30-06:00 06:00-07:30 07:30-12:00 12:00-13:30 13:30-14:00 14:00-06:00 06:00-08:30 08:30-09:30 09:30-10:00 10:00-10:30 10:30-13:30 13:30-14:30 14:30-15:00 15:00-16:00 16:00-17:00 17:00-17:30 17:30-18:00 18:00-21:00 21:00-21:30 21:30-23:00 23:00-23:30 23:30-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-10:00 10:00-12:00 12:00-12:30 12:30-14:00 14:00-14:15 14:15-19:30 19:30-21:00 21:00-00:00 Duration lhr lhr 1/2 hr 1-1/2 hr 4hr 6 hr 1 hr 1-1/2 hr 8-1/2 hr 1-1/2 hr 4-1/2 hr 1-1/2 hr 1/2 hr 16hr 2-1/2 hr lhr 1/2hr 1/2 hr 3hr lhr 1/2 hr lhr lhr 1/2 hr 1/2 hr 3hr 1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 2hr lhr 1/2 hr 1/2 hr lhr 2hr 2 hr 1/2 hr 1-1/2 hr 1/4 hr 5-1/4 hr 1-1/2 hr 3 hr Activity Rigged up Drillstring handling equipment Rigged up Drillstring handling equipment (cont...) Held safety meeting Installed TCP Singled in drill pipe to 2700.0 ft Ran Drillpipe in stands to 13730.0 ft Perforated from 12420.0 ft to 13730.0 ft Reverse circulated at 10995.0 ft Laid down 10000.0 ft of 5in OD drill pipe Laid down 1200.0 ft of 2-7/8in OD drill pipe (cont...) Retrieved Gun assembly Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 4-1/2in (9240.0 ft OD) Ran Tubing to 11187.0 ft (4-1/2in OD) (cont...) Installed Tubing Installed Tubing hanger Ran Tubing on landing string to 11187.0 ft Reverse circulated at 11187.0 ft Set packer at 11133.0 ft with 4000.0 psi Tested Tubing Tested Permanent packer - Via annulus Retrieved Tubing landing string Installed Hanger plug Held safety meeting Rigged down BOP stack Held safety meeting Installed Adapter spool Held safety meeting Rigged down BOP stack Serviced Adapter spool Installed Adapter spool Installed Adapter spool (cont...) Tested Adapter spool Installed Swab valve Removed BOP stack Removed Hanger plug Held safety meeting Reverse circulated at 3300.0 ft Held safety meeting Laid out Drillpipe from derrick Installed Hanger plug Laid out 5in drill pipe from derrick Prudhoe Bay Unit Alaska State Plane Zone 4 PB U_ EOA DS 13, Slot 13-08A 13-08A ~ Job No. AKMM90006, Surveyed: 5 December, 1998 ORIGINAL SURVEY REPORT RECEIVED 29 January, 1999 Your Reft AP1-500292066701 KBE-74.52 MWD SURVEY INSTRUMENT Surface Coordinates: 5931478.84 N, 687359.48 E (70° 13' 03.6008" N, 148° 29' 18.6921" W) sp~r~r,~-sun DRILLING SIERVI, CES A HALLIBURTON FEB 02 Alaska Oil & Gas Cons. Commission And~om.qe Survey Ref: svy4524 Sperry-Sun Drilling Services Survey Report for 13-08A Your Ref: API-500292066701 Job No. AKMM90006, Surveyed: 5 December, 1998 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 8896.52 48.250 144.000 6961.12 7035.64 8991.00 48.250 143.050 7024.03 7098.55 9008.34 45.520 145.900 7035.88 7110.40 9040.78 45.040 151.240 7058.72 7133.24 9072.06 43.670 156.390 7081.09 7155.61 9102.26 43.170 161.360 7103.03 7177.55 9132.52 43.170 166.340 7125.11 7199.63 9165.48 42.300 168.900 7149.32 7223.84 9196.93 41.890 170.420 7172.66 7247.18 9228.67 40.620 171.440 7196,52 7271.04 9259.67 40.080 172.870 7220.14 7294.66 9291.11 39.760 172.960 7244.26 7318.78 9384.09 38.880 171.860 7316.19 7390.71 9476.95 38.620 171.990 7388.61 7463.13 9570.10 38.240 171.560 7461.58 7536.10 9663.13 37.600 172.760 7534.97 7609.49 9757.45 37.290 172.540 7609.85 7684.37 9853.04 36.130 173.420 7686.48 7761.00 9947.29 36.590 174.130 7762.38 7836.90 10041.65 35.160 174.840 7838.84 7913.36 10137.56 37.500 176.110 7916.10 7990.62 10203.16 36.970 175.970 7968.33 8042.85 10234.70 36.140 176.330 7993.67 8068.19 · 10327.66 37.440 175.320 8068.11 8142.63 10425.02 38.670 177.790 8144.78 8219.30 Alaska State Plane Zone 4 PBU_EOA DS 13 Local Coordinates Global Coordinates Dogleg Northings Eastings Northings Eastings Rate (ft) (St) (ft) (tt) (°/100ft) 2903,10 S 2902.76 E 5928648.69 N 690333.40 E 2959.77 S 2944.66 E 5928593.07 N 690376.70 E 0.750 2970.07 S 2952.02 E 5928582.96 N 690384.31 E 19.792 2989.72 $ 2964.03 E 5928563.61 N 690396.81 E 11.787 3009.33 S 2973.68 E 5928544.25 N 690406.94 E 12.313 3028.67 S 2981.16 E 5928525.10 N 690414.90 E 11.430 3048.55 S 2986.92 E 5928505.37 N 690421.15 E 11.258 3070.39 S 2991.72 E 5928483.66 N 690426.49 E 5.894 3091.13 S 2995.50 E 5928463.02 N 690430.79 E 3.492 3111.79 S 2998.80 E 5928442.44 N 690434.60 E 4.528 3131.68 S 3001.54 E 5928422.63 N 690437.83 E 3.457 3151.70 S 3004.03 E 5928402.68 N 690440.82 E 1.034 3210.10 S 3011.81E 5928344.49 N 690450.04 E 1.207 3267.64 S 3019.97 E 5928287.16 N 690459.63 E 0.293 3324.95 S 3028.26 E 5928230.08 N 690469.33 E 0.499 3381.58 S 3036.06 E 5928173.66 N 690478.54 E 1.050 3438.46 $ 3043.39 E 5928116.98 N 690487.28 E 0.358 3495.17 S 3050.38 E 5928060.47 N 690495.68 E 1.332 3550.71S 3056.44 E 5928005.09 N 690503.11 E 0.662 3605.75 S 3061.76 E 5927950.20 N 690509.80 E 1.578 3662.39 S 3066.23 E 5927893.69 N 690515.67 E 2.563 3701.99 S 3068.97 E 5927854.17 N 690519.39 E 0.818 3720.73 S 3070.23 E 5927835.47 N 690521.12 E 2.718 3776.25 S 3074.29 E 5927780.06 N 690526.55 E 1.542 3836.15 S 3077.88 E 5927720.27 N 690531.63 E 2.010 Vertical Section (ft) Comment 3756.81 3824.81 3837.07 3859.74 3881.50 3902.25 3922.86 3944.96 3965.66 3986.12 4005.64 4025.21 4082.46 4139.07 4195.48 4251.10 4306.78 4362.17 4416.14 4469.38 4523.79 4561.70 4579.63 4632.86 4689.99 Tie on Point Window Point Continued... 29 January, 1999 - 10:31 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 13-08A Your Ref: API-500292066701 Job No, AKMM90006, Surveyed: $ December, 1998 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 10520.94 35.730 177.480 8221.17 10614.74 36.830 178.220 8296.79 10651.93 38.990 178.550 8326.13 10710.04 39.600 179.770 8371.10 10806.11 43.520 183.440 8442.98 10868.46 43.400 185.680 8488.24 10900.81 43.310 186.220 8511.76 10965.12 42.920 188.020 8558.71 10996.12 42.830 189.650 8581.43 11091.84 43.600 189.650 8651.19 11185.97 43.390 188.570 8719.48 11282.29 43.790 188.400 8789.24 11315.58 44.340 188.990 8813.16 11354.13 44.830 189.000 8840.62 11383.50 45.210 189.560 8861.38 11415.01 49.290 188.800 8882.76 11449.84 54.350 185.720 8904.29 11478.77 59.570 183.480 8920.06 11510.00 65.470 183.820 8934.46 11543.23 71.880 183.770 8946.54 11575.52 77.590 184.750 8955.04 11606.28 83.150 183.230 8960.18 11623.05 86.670 183.130 8961.67 11655.84 91.630 180.550 8962.15 11687.01 94.960 176.720 8960.36 Vertical Depth (ft) 8295.69 8371.31 8400.65 8445.62 8517.50 8562.76 8586.28 8633.23 8655.95 8725.71 8794.00 8863.76 8887.68 8915.14 8935.90 8957.28 8978.81 8994.58 9008.98 9021.06 9029.56 9034.70 9036.19 · 9036.67 9034.88 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 3894.08 S 3080.26 E 5927662.41 N 690535.45 E 3949.55 S 3082.34 E 5927607.02 N 690538.91 E 3972.39 S 3082.98 E 5927584.20 N 690540.11 E 4009.18 S 3083.52 E 5927547.43 N 690541.57 E 4072.85 S 3081.66 E 5927483.73 N 690541.28 E 4115.60 S 3078.25 E 5927440.92 N 690538.94 E 4137.69 S 3075.95 E 5927418.78 N 690537.18 E 4181.30 S 3070.50 E 5927375.04 N 690532.82 E 4202.14 S 3067.26 E 5927354.13 N 690530.10 E 4266.76 S 3056.28 E 5927289.26 N 690520.72 E 4330.72 S 3046.02 E 5927225.06 N 690512.05 E 4396.41S 3036.22 E 5927159.15 N 690503.89 E 4419.30 S 3032.72 E 5927136.18 N 690500.96 E 4446.02 S 3028.49 E 5927109.36 N 690497.39 E 4466.53 S 3025.14 E 5927088.78 N 690494.55 E 4489.36 S 3021.45 E 5927065.86 N 690491.43 E 4516.51 S 3018.02 E 5927038.63 N 690488.68 E 4540.68 S 3016.09 E 5927014.43 N 690487.35 E 4568.31 S 3014.32 E 5926986.75 N 690486.27 E 4599.19 S 3012.28 E 5926955.84 N 690484.99 E 4630.24 S 3009.96 E 5926924.74 N 690483.44E 4660.48 S 3007.85 E 5926894.46 N 690482.09 E 4677.15 S 3006.93 E 5926877.77 N 690481.57 E 4709.91 S 3005.88 E 5926844.99 N 690481.34 E 4741.01S 3006.61 E 5926813.92 N 690482.85 E Alaska State Plane Zone 4 PBU_EOA DS 13 Dogleg Vertical Rate Section (°/100ft)(fi) Comment 3.071 4744.86 1.262 4797.32 5,834 4818.84 1,694 4853,34 4.802 4912.02 2,479 4950.64 1,179 4970.40 2.007 5009.08 3.589 5027.34 0.804 5083.60 o.821 5139.52 0.433 5197.20 2.061 5217.27 1.271 5240.66 1.869 5258.56 13.069 5278.51 16.102 5302.58 19.174 5324.41 18.916 5349.53 19.290 5377.57 17.925 5405.68 18.719 5433.11 20.999 5448.32 17.049 5478.47 16.266 5507.73 Continued... 29 January, 1999 - 10:31 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 13-08A Your Ref: API-500292066701 Job No. AKMM90006, Surveyed: 5 December, 1998 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 11721.43 97.840 173.140 8956.52 9031.04 11752.71 98.580 172.570 8952.06 9026.58 11782.32 98.780 172.000 8947.59 9022.11 11816.08 98.440 171.130 8942.54 9017.06 11846.98 94.470 172.200 8939.06 9013.58 11876.65 92.590 172.300 8937.24 9011.76 11908.92 93.110 172.690 8935.63 9010.15 11941.64 93.050 175.980 8933.87 9008.39 11975.22 92.280 178.670 8932.31 9006.83 12007.78 92.000 178.840- 8931.09 9005.61 12039.23 91.540 179.070 8930.12 9004.64 12069.48 91.750 179.520 8929.25 9003.77 12102.46 92.580 183.390 8928.01 9002.53 12132.80 91.570 185.870 8926.91 9001.43 12163.07 91.660 186.210 8926.06 9000.58 12195.25 90.710 188.790 8925.39 8999.91 12227.35 86.990 190.840 8926.04 9000.56 12258.90 85.350 191.510 8928.14 9002.66 12291.24 83.210 192.590 8931.37 9005.89 12323.37 83.030 192.510 8935.21 9009.73 12354.63 82.620 194.650 8939.12 9013.64 12379.86 82.010 196.580 8942.49 9017.01 12413.70 81.510 196.010 8947.34 9021.86 12444.23 81.480 195.670 8951.86' 9026.38 12474.78 81.480 194.810 8956.39 9030.91 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4775.07 S 3009.63 E 5926779.94 N 690486.71 E 4805.79 S 3013.48 E 5926749.33 N 690491.32 E 4834.80 S 3017.41 E 5926720.43 N 690495.97 E 4867.81 S 3022.31 E 5926687.54 N 690501.69 E 4898.19 S 3026.76 E 5926657.29 N 690506.89 E 4927.53 S 3030.75 E 5926628.06 N ' 690511.61 E 4959.48 S 3034.96 E 5926596.22 N 690516.61E 4991.99 S 3038.19 E 5926563.80 N 690520.64 E 5025.49 S 3039.75 E 5926530.34 N 690523.04 E 5058.02 S 3040.46 E 5926497.84 N 690524.55 E 5089.45 S 3041.03 E 5926466.44 N 690525.90 E 5119.69 S 3041.40 E 5926436.22 N 690527.03 E 5152.63 S 3040.57 E 5926403.27 N 690527.01 E 5182.85 S 3038.12 E 5926373.00 N 690525.31 E 5212.94 S 3034.94 E 5926342.84 N 690522.87 E 5244.83 S 3030.74 E 5926310.85 N 690519.47 E 5276.45 S 3025.27 E 5926279.11 N 690514.79 E 5307.33 S 3019.17 E 5926248.09 N 690509.45 E 5338.80 S 3012.45 E 5926216.46 N 690503.52 E 5369.93 S 3005.52 E 5926185.16 N 690497.36 E 5400.08 S 2998.24 E 5926154.84 N 690490.83 E 5424.16 S 2991.51 E 5926130.60 N 690484.70 E 5456.30 S 2982.11 E 5926098.24 N 690476.11 E 5485.35 S 2973.87 E 5926068.99 N 690468.59 E 5514.50 S 2965.93 E 5926039.66 N 690461.37 E Alaska State Plane Zone 4 PBU_EOA DS 13 Dogleg Vertical Rate Section (°/100ft) (fi) Comment 13.297 5540.58 2.975 5570.61 2.019 5599.07 2.740 5631.62 13.300 5661.55 6.345 5690.35 2.013 5721.66 10.042 5753.13 8.324 5784.93 1.006 5815.51 1.635 5845.02 1.641 5873.34 11.993 5903.74 8.821 5931.02 1.161 5957.92 8.542 5986.14 13.231 6013.63 5.613 6040.21 7.405 6067.12 0.612 6093.63 6.918 6119.10 7.957 6139.11 2.228 6165.68 1.106 6189.77 2.784 6214.07 Continued... 29 January, 1999 - 10:31 -4- DrillQuest Sperry-Sun Drilling Services Survey Report for 13-08A Your Ref: AP1-$00292066701 Job No. AKMM90006, Surveyed: 5 December, 1998 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 12506.92 81.970 194.450 8961.01 9035.53 12538.95 86.090 196.910 8964.34 9038.86 12570.37 90.980 199.480 8965.15 9039.67 12603.37 92.520 198.830 8964.14 9038.66 12636.30 92.520 198.230 8962.69 9037.21 12664.16 91.690 195.820 8961.67 9036.19 12696.62 90.060 197.350 8961.17 9035.69 12728.40 90.800 197.780 8960.93 9035.45 12760.23 91.080 196.710 8960.41 9034.93 12792.01 90.800 196.900 8959.89 9034.41 12824.44 88.090 197.030 8960.20 9034.72 12857.04 88.090 196.450 8961.29 9035.81 12888.89 88.400 195.690 8962.26 9036.78 12921.51 88.210 195.830 8963.23 9037.75 12951.54 88.680 192.260 8964.04 9038.56 12985.02 88.460 197.870 8964.88 9039.40 13015.84 89.080 197.080 8965.54 9040.06 13047.36 88.980 196.940 8966.08 9040.60 13080.37 88.340 198.310 8966.85 9041.37 13113.03 88.370 197.310 8967.79 9042.31 13141.33 88.490 197.070 8968.56 9043.08 13173.85 88.920 196.270 8969.30 9043.82 13206.74 89.110 195.840 8969.86 9044.38 13238.47 90.920 194.690 8969.85 9044.37 13273.91 91.170 194.990 8969.21 9043.73 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5545,28 S 2957.89 E 5926008.69 N 690454.11 E 5575.94 S 2949.29 E 5925977.83 N 690446.26 E 5605.77 S 2939.48 E 5925947.76 N 690437.20 E 5636.92 S 2928.66 E 5925916.35 N 690427.15 E 5668.11 S 2918.20 E 5925884.91 N 690417.47 E 5694.73 S 2910,05 E 5925858.09 N 690409,99 E 5725.84 S 2900,79 E 5925826.77 N 690401.50 E 5756.14 S 2891.20 E 5925796.24 N 690392.66 E 5786.53 S 2881.76 E 5925765.62 N 690383.99 E 5816.95 S 2872,58 E 5925734.99 N 690375.56 E 5847.96 S 2863.11 E 5925703,75 N 690366.87 E 5879.16 S 2853.73 E 5925672,32 N 690358,26 E 5909,75 S 2844.92 E 5925641.52 N 690350,21E 5941.13 S 2836.06 E 5925609.93 N 690342.14 E 5970.25 S 2828.78 E 5925580.64 N 690335.58 E 6002.56 S 2820.08 E 5925548.13 N 690327,69 E 6031.95 S 2810.83 E 5925518.52 N 690319,17 E 6062.08 S 2801.61 E 5925488.16 N 690310.70 E 6093.54 S 2791.62 E 5925456,47 N 690301,49 E 6124.62 S 2781.63 E 5925425.15 N 690292.28 E 6151.64 S 2773.27 E 5925397.93 N 690284.59 E 6182.79 S 2763.95 E 5925366.56 N 690276.04 E 6214.39 S 2754.85 E 5925334.74 N 690267,73 E 6245.00 S 2746.50 E 5925303.94 N 690260.14 E 6279.25 S 2737,42 E 5925269.47 N 690251.92 E Alaska State Plane Zone 4 PBU_EOA DS 13 Dogleg Vertical Rate Section (°/100ft) (ft) Comment 1.885 6239,86 14.959 6265.32 17.580 6289.58 5.065 6314.71 1.820 6340.00 9.143 6361.87 6.887 6387.51 2.693 6412.29 3,474 6437.21 1.065 6462,24 8.366 6487.73 1,778 6513,42 2.576 6538,74 0.723 6564.79 11.986 6589.30 16.764 6616.27 3.258 6640.32 0.546 6665.08 4.580 6690.78 3.062 6716.14 0.948 6738.31 2.792 6763.97 1.429 6790.14 6.758 6815.65 1.102 6844.29 Continued... 29 January, 1999 - 10:31 - 5 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 13-08A Your Ref: API-500292066701 Job No. AKMM90006, Surveyed: $ December, 1998 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 13302.42 91.320 193.450 8968.59 9043.11 6306.88 S 2730.42 E 5925241.68 N 690245.61E 13332.70 90.280 193.520 8968.16 9042.68 6336.32 S 2723.36 E 5925212.07 N 690239.28 E 13365.66 90.310 193.050 8967.99 9042.51 6368.40 S 2715.79 E 5925179.81 N 690232.50 E 13397.46 90.490 191.930 8967.77 9042.29 6399.45 S 2708.91 E 5925148.61 N 690226.40 E 13427.85 90.580 191.550 8967.49 9042.01 6429.20 S 2702.73 E 5925118.71 N 690220.96 E 13459.87 91.020 191.460 8967.04 9041.56 6460.57 S 2696.34 E 5925087.19 N 690215.35 E 13491.52 91.380 191.350 8966.38 9040.90 6491.59 S 2690.08 E 5925056.02 N 690209.87 E 13520.90 91.660 191.220 8965.60 9040.12 6520.39 S 2684.34 E 5925027.09 N 690204.84 E 13553.90 91.570 190.580 8964.67 9039.19 6552.78 S 2678.10 E 5924994.55 N 690199.40 E 13585.91 89.450 190.020 8964.38 9038.90 6584.27 S 2672.38 E 5924962.93 N 690194.46 E 13613.07 89.910 190.390 8964.54 9039.06 6611.00 S 2667.56 E 5924936.09 N 690190.32 E 13644.82 90.090 190.170 8964.54 9039.06 6642.24 S 2661.90 E 5924904.71 N 690185.43 E 13675.04 90.370 189.510 8964.41 9038.93 6672.02 S 2656.73 E 5924874.82 N 690181.00 E 13705.32 90.580 189.390 8964.16 9038.68 6701.89 S 2651.76 E 5924844.84 N 690176.78 E 13737.52 91.760 188.670 8963.51 9038.03 6733.68 $ 2646.71 E 5924812.93 N 690172.51 E 13800.00 94.000 187.330 8960.37 9034.89 6795.47 S 2638.03 E 5924750.94 N 690165.37 E 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. Magnetic Declination at Surface is 27.861 o (11 -Jan-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 158.784° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13800.00ft., The Bottom Hole Displacement is 7289.55ft., in the Direction of 158.784° (True). Alaska State Plane Zone 4 PBU_EOA DS 13 Dogleg Rate (°llOOft) Vertical Section (ft) Comment 5.426 3.442 1.429 3.567 1.285 1.4o3 1.189 1 .o51 1.958 6.850 2.174 0.895 2.372 0.799 4.293 4.176 6867.52 6892.41 6919.57 6946.02 6971.52 6998.46 7o25.11 7049.88 7077.82 71o5.1o 7128.28 7155.35 7181.24 7207.29 7235.1o 7289.55 Projected Survey Continued... 29 January, 1999 - 10:31 - 6 - DrillQuest Sperry-Sun Drilling Services Survey Report for 13-08A Your Ref: API-500292066701 Job No. AKMM90006, Surveyed: 5 December, 1998 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_EOA DS 13 Comments Measured Depth (~) 8896.52 8991.00 13800.00 Station Coordinates TVD Northings Eastings (~) (~) (~) 7035.64 2903.10 S 2902.76 E 7098.55 2959.77 S 2944.66 E 9034.89 6795.47 S 2638.03 E Comment Tie on Point Window Point Projected Survey 29 January, 1999 - 10:31 - 7- DrlllQuest Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_ EOA DS 13, Slot 13-08A 13-08APB2 Job No. AKMM90006, Surveyed: 28 November, 1998 ORIGINAL SURVEY REPORT 29 January, 1999 Your Ref: API-500292066771 KBE-74.52 MWD SURVEY INSTRUMENT F ECEIVED ~a 0ti & Gas Cons. Commi~si(~ Surface Coordinates: 5931478.84 N, 687359.48 E (70° 13' 03.6008" N, 148° 29' 18.6921" W) DRILLING SERVICES Survey Ref: svy4522 Sperry-Sun Drilling Services Survey Report for 13-08APB2 Your Ref: API-500292066771 Job No. AKMM90006, Surveyed: 28 November, 1998 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 9296.52 46.250 144.o0o 7233.55 935o.00 43.905 147.103 7271.32 9362.24 43.380 147.85o 728o.17 9391.o4 41.03o 149.64o 73Ol.51 9423.60 40.550 151.77o 7326.16 9484.05 40.61o 155.78o 7372.08 9578.15 40.620 158.28o 7443.52 9669.14 40.500 158.51o 7512.64 9763.81 40.370 158.75o 7584.70 9858.56 40.520 158.55o 7656.81 9953.60 40.13o 158.22o 7729.27 10045.75 40.490 158.890 7799.54 10140.71 40.720 158.87o 7871.63 10235.75 42.400 161.81o 7942.75 10331.18 43.280 165.o3o 8o12.73 10426.42 41.11o 167.54o 8083.29 10520.23 40.570 171.26o 8154.27 10618.92 44.830 179.51o 8226.84 10716.83 46.840 185.75o 8295.09 10811.85 46.680 186.48o 8360.19 109o6.01 48.780 189.250 8423.52 11000.29 48.440 191.27o 8485.86 11095.22 47.680 192.98o 8549.31 11181.00 47.680 192.98o 8607.06' 7308.07 3138.44 S 3076.92 E 7345.84 3169.65 S 3098.35 E 7354.69 3176.77 S 3102.89 E 7376.03 3193.30 S 3112.93 E 7400.68 3211.85 S 3123.34 E 7446.60 3247.11 S 3140.71 E 7518.04 3303.50 S 3164.61 E 7587.16 3358.51 S 3186.40 E 7659.22 3415.69 S 3208.77 E 7731.33 3472.94 S 3231.15 E 7803.79 3530.11 S 3253.80 E 7874.06 3585.60 S 3275.60 E 7946.15 3643.25 S 3297.87 E 8017.27 3702.62 S 3319.05 E 8087.25 3764.80 S 3337.54 E 8157.81 3826.92 S 3352.73 E 8228.79 3887.19 S 3364.03 E 830.1.36 3953.79 S 3369.21E 8369.61 4023.87 S 3365.92 E 8434.71 4092.70 S 3358.55 E 8498.04 4161.70 S 3348.99 E 8560.38 4231.29 S 3336.39 E. 8623.83 4300.33 S 3321.57 E 8681.58 4362.13 S 3307.32 E Global Coordinates Northings Eastings (~) (~) 5928417.74 N 690513.35 E 5928387.08 N 690535.55 E 5928380.07 N 690540.27 E 5928363.79 N 690550.72 E 5928345.51N 690561.58 E 5928310.69 N 690579.82 E 5928254.91N 690605.11E 5928200.46 N 690628.26 E 5928143.85 N 690652.04 E 5928087.18 N 690675.84 E 5928030.58 N 690699.90 E 5927975.65 N 690723.07 E 5927918.57 N 690746.76 E 5927859.75 N 690769.41E 5927798.05 N 690789.44 E 5927736.32 N 690806.17 E 5927676.34 N 690818.96 E 5927609.90 N 690825.79 E 5927539.76 N 690824.24 E 5927470.77 N 690818.58 E 5927401.55 N 690810.74 E 5927331.67 N 690799.87 E 5927262.28 N 690786.77 E 5927200.15 N 690774.06 E Alaska State Plane Zone 4 PBU_EOA DS 13 Dogleg Rate (°/100fi) Vertical Section (ft) Comment 6.008 6.008 9.165 4.521 4.316 1.729 0.211 0.214 0.209 0.468 0.611 0.243 2,708 2.472 2.885 2.656 7.119 5.o10 0.584 3.116 1.647 1.561 0.000 1993.10 2015.84 2o21.14 2o33.61 2o47.87 2075,75 2121.57 2166.76 2213.81 2260.93 2307.90 2353.54 24Ol.07 2450.58 25o3.61 2557.65 2611.17 2672.63 2740.11 2807.69 2876.14 2946.11 3o16.27 3079.39 Tie-On survey Window Point Projected Survey Continued... 29 January, 1999 - 10:41 - 2 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 13-08APB2 Your Ref: API-500292066771 Job. No. AKMM90006, Surveyed: 28 November, 1998 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_EOA DS 13 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. Magnetic Declination at Surface is 27.897° (28-Nov-98) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 198.600° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11181.00ft., The Bottom Hole Displacement is 5474.17ft., in the Direction of 142.831° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9296.52 7308.07 3138.44 S 3076.92 E Tie-On survey 9350.00 7345.84 3169.65 S 3098.35 E Window Point 11181.00 8681.58 4362.13 S 3307.32 E Projected Survey 29 January, 1999 - 10:41 - 3 - DrlllQuest 11/30/94 Alaska hared ervices riiling To: From: Date: Subject: Blair Wondzell, AOGCC Jim Smith, SSD November 30, 1998 Plan Revision, Well 13-08A Per our telephone discussion of November 30, 1998, SSD plans to abandon efforts to complete the present 8-1/2" intermediate section on well 13-08A in favor of moving uphole 300' to a new sidetrack kickoff depth. The Kingak shales of the existing borehole have degraded to such a point that continued drilling is not productive, The welibore was drilled to 11150'MD (400' above the Sag River formation) at which depth sloughing shale difficulty became severe. There are no hydrocarbon zones exposed in the wetlbore from kickoff depth at 9350'MD to 11150'MD. We plan to set a bridge plug inside the 9-5/8" casing at 9250'MD (100' above the existing section in the 9-5/8") and perform section milling from 9000'MD to 9050'MD to produce a new KOP at 9025'MD in the K-10 shale. The new wellbore will be ddlled back to the odginal bottom hole targets with a 7" intermediate drilling liner set in top of the Sag River formation and 4-1/2" production liner run and cemented at TD. Regards, Jim Smith, SSD RECEIVED 1998 & Gas C0~s. C0mmissior~ Anchorage spenn -sun I~ F! I L-I-- I IM I~ SER~JIr'E S To: State of Alaska June 17, 1999 Alaska Oil mt Gas Conservation Corem Atm.: Loft Taylor 3001 Porcupine Dr. _ Anchorage, Alaska 99501 MWl)_Frmmtion EYal-afionLogs: 13-08A, AK-MM-90006 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. ran Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 13-08A: 2" x 5" MD ~'ty & Cranam Ray Logs: 50-029-20667-01 2" x 5" TVD ResimMty & Gamma Ray Logs: 50-029-20667-01 2"x 5"MD Density Logs: 50-029-20667-01 2"x 5" TVD Density Logs: 50-029-20667-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1.Blueline 1 Folded Sepia JUN 1 7 1999 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halllbmton Company 0 I:! I I_1--11M G WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corem_ Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 13-08A, June I0, 1999 AK-MM-90006 The technical data listed bebw is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.. Jan Galvin, Sperry-Sun Dh]ling Services, 5631 Silverado Way, gG, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20667-01. RECEIVED JUN 1 7 1999 Alaska Oil & Gas Cons. Commission 5631 Siiverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 0 !:t I I--I--I IM G S ~:~ I~lk~l C ~ S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Com~ Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 June 8, 1999 RE: MWD Formation Evaluation Logs - D.S. 13-08APB2, AK-MM-90006 The technical dina listed bebw is being submitted herewith. Please acknowledge receipt by returning a signed copy ofthis transmittal letter to the attention o~ Jim Galvin, Sperry-Sun ~ Services, 5631 Silvemdo Way, gG, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20667-71. RECEF _.,D JUN 0 8 1999 Alaska 0il & Gas CMs. C0mmi~sion 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company D I::! I I_.1-- I N CS WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD FormafionEvahmtionLogs :.13-08APB2, June 8, t999 AK-MM-90006 to the attention o~ Jun C_mlvin, Stxa'ry-Stm Dr~qling Services, 5631 Sitvemdo way, gG, Anchorage, AK99518 13-08A PB2: 2" x 5" MD R~ & Cramma-Ray-Logs: 50-029-20667-71 2" x 5" TVD Res~ & Cranm~ Ray-Logs: 50-029-20667-71 t Btueline 1 Folded Sepia Bluetine Folded Sepia , '~ J~..! 0 8 1999 Alaska Oil & Gas Cons. C0mmi~n 5631 Silvemdo Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Nalliburton Company 0 R I i_l_l I~ CS SEE F! ~/I r- l= S 02-Feb-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 13-08A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey' Window / Kickoff Survey: Projected Survey: 8,896.52' MD 8,991.00' MD 13,800.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ; RECEiVED FEB 02 1999 Oil & 6~ Cons, Commi~ion 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company OF:III--I--lNG 02-Feb-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 13-08A PB2 Dear Lori Taylor: --~ Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,296.52' MD 9,350.00' MD 11,181.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, fv~.~ 3',,¢__¢,~ ~ William T. Allen Survey Manager Attachment(s) FEB 02 1999 Alaska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 0 Ft I I--I-- I I~1G SGI:I~JI C ~ S 27-Jan-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 13-08A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,896.52' MD 8,991.00' MD 13,800.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 0 I::! I I--I-- I I~1G S E I:!~.~1C G S 27-Jan-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 13-08A PB2 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,296.52' MD 9,35O.OO' MD 11,181.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 7'ONY KNOWLE$, GOVERNOR ALASKA OIL ~ GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 4. 1998 James E. Smith Senior Drilling Enginccr ARCO Alaska. Inc. P O Box 196612 Anchorage, AK 99519-6612 Prudhoe Bay Unit 13-08A ARCO Alaska. Inc. Permit No: 98-215 Sur Loc: 1409'NSL. 130'EWL. Sec. 13. T10N. R14E. UM Bt~nhole Loc. 202'NSL. 2567'WEL. Sec. 24, T10N. R14E. UM Dear Mr. Smith: Encloscd is the approvcd application for permit to rcdrill the above rcfcrcnccd well. The permit to rcdrill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and docs not authorize conducting drilling operations until all other requircd permitting dcterminations arc made. Blov,-out prcvcntion equipment (BOPE) must bo tcstcd in accordance with 20 AAC 25 035. Sufficicnt notice (approximatcly 24 hours) must be givcn to allow a rcprcscntative of the Commission to witness a test of BOPE installed prior to drilling new hole. Noticc may be given by contacting thc Co~nmission pctrolcum field inspector on thc North Slope pager at 659-3607. ~ ~David W. Johnston \ ~ Chairman BY ORDER OF TIlE COMMISSION dlffEnclosurcs cc~ Dcpartmcnt of Fish &Gamc. Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. .... STATE OF ALASKA ~. r ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill J lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI []Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RKB = 74.35' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028315 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1409' NSL, 130' EWL, SEC. 13, T10N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 1591' NSL, 2099' WEL, SEC. 24, T10N, R14E, UM 13-08A At total depth ~. Approximate spud date Amount $200,000.00 202' NSL, 2567' WEL, SEC. 24, T10N, R14E, UM 11/07/98 12. Distance to nearest property lineJ 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028316, 202'I No Close Approach 2560 13624' MD /9044' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 13624' MD Maximum Hole Angle lO4° Maximum surface 2550 psig, At total depth (TVD) 8996' / 3450- Psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-M 1920' 9650' 7544' 11570' 8940' _~20 sx Class 'G' 6" 4-1/2" 12.6# L-80 IBT-M 2204' 11420' 8838' 13624' 9044' 283 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 13200 feet Plugs (measured) Fill at 12226' MD (07/94); Cement Plug at 12200' MD true vertical 9616 feet Effective depth: measured 12226 feet Junk (measured) true vertical 9058 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 300 sx Permafro..st--'"" 110' 110' Surface 2307' 13-3/8" 2500 sx Fondu, 400 sx PF 'C' 2385' 2385' Intermediate Production 11912' 9-5/8" 250 sx Class 'G' 11990' 8905' Liner 1518' 7" 420 sx Class 'G' 11677' - 13195' 8708' - 9614' DUPLICATE PeRoration depth: measured 12135' - 12155' ('](~ ~ ~ ~!° true vertical 8999' - 9014' Alaska 0il & Gas Cons. 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: C. Michae/ Jackson, 564-5480 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify tha(.t,t,~e f.~or;~/~in~is ~._ ~ct to the best of my knowledge //~ SignedJames E. Smith,~-~ ~ '""-'~" Title Senior Drilling Engineer Date / Commission Use Only Permit Number APl Number I Approval Dat..e,,~ I See cover letter ~2'... ~./,jZ- 50-029-20667-01 if,,/ _~,, ~¢,,~ for other requirements Conditions of Approval: Samples Required []Yes ~'No Mud Log Required [] Yes [] No Hydrogen Sulfide Measures []Yes [] No Directional Survey Required [~Yes [] No Required Working Pressure for DOPE []2K; []3K; []4K; [~5K; [] 10K; [] 15K Other: 0i'igi:,1~l ~,~ ...... by order of Approved By David W. Johnston Commissioner the commission Date//' '/"'~ ~¢ ~i0n STATE OF ALASKA ALASKA .:,IL AND GAS CONSERVATION CO~r~,,v~lSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oili [] Re-Entry [] Deepenl [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 110. Field and Pool ARCO Alaska Inc. Plan RKB = 74.35' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028315 4. Location of well at surface i7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1409' NSL, 130' EWL, SEC. 13, T10N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 1591' NSL, 2099' WEL, SEC. 24, T10N, R14E, UM 13-08A At total depth 9. Approximate spud date Amount $200,000.00 202' NSL, 2567' WEL, SEC. 24, T10N, R14E, UM 11/07/98 12. DistanceADLtO nearest028316, propertY202, line 13. DistanCeNo Closet° neareStApproachWell 14. Number of 2560acres in property 15. Proposed13624, depthMD / 9044'(MD andTvDTVD) 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 13624' MD Maximum Hole Angle 404° Maximum surface 2550 psig, At total depth (TVD) 8996' / 3450 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-M 1920' 9650' 7544' 11570' 8940' 220 sx Class 'G' 6" 4-1/2" 12.6# L-80 IBT-M 2204' 11420' 8838' 13624' 9044' 283 sx Class 'G' ~19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 13200 feet Plugs (measured) Fill at 12226' MD (07/94); Cement Plug at 12200' MD true vertical 9616 feet Effective depth: measured 12226 feet Junk (measured) true vertical 9058 feet Casing Length Size Cemented M D TVD Structural Conductor 110' 20" 300 sx Permafrost 110' 110' Surface 2307' 13-3/8" 2500 sx Fondu, 400 sx PF 'C' 2385' 2385' Intermediate Production 11912' 9-5/8" 250 sx Class 'G' 11990' 8905' Liner 1518' 7" 420 sx Class 'G' 11677' - 13195' 8708' - 9614' RECEIVE Perforation depth: measured 12135'-12155' 0 RIG INA L 0c ? true vertical 8999' - 9014' &las,ka 0ii & Gas Cons. 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program/.~llCrlorag8 [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: C. Michael Jackson, 564-5480 Prepared By Name/Number: Terrie Hubble, 564-4628 21' I hereby certifY tha~/~_Zr;g~i~-is ~~ct t° the best °f mY kn°wledge Signed -' -,.-.,¢_., ~ ,.~-..- , James E Smith./7~-~ Title Senior Drilling Engineer Date / Commission Use Only Permit Number I APl Number Approval Date See cover letter ~'~:;'-~/'._-5'-I 50-029-20667-01 /~/.,, -~---~ (~ for other requirements Conditions of Approval: Samples Required []Yes I~No Mud Log Required []Yes J~No Hydrogen Sulfide Measures J~Yes []No Directional Survey Required [~qYes[]No Required Working Pressure for DOPE EI2K; []3K; [--14K; j!~5K; [] 10K; [] 15K Other: Oi'J~ii-;&:~ ~.~.~T;~;fJ ~,~'j by order of // .~ Approved By n,~,,ir~ W .lnhnstOrt Commissioner the commission Date * Form 10-401 Rev. 12-01-85 Submit In Triplicate Alaska hared ervlces rilling DRILLING PERMIT/SUNDRY/PRE-RIGcovER SHEET I IThe attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. I "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) DRILLING PERMIT I~l Permit Documentation Prepared: ODE: ~,~ Date: ~t~9~t~ Permit At~plicatioXn Re e~c_w, ed: Permit ~pplication Submitted: TA: /~/~i~ ~ Date:10//'~ PRE-RIG WORK Pre-Rig Memo Reviewed: SDE/ES: Date: Pre-Rig Memo Sent to Slope: ODE: Date: Pre-Rig Sundry Documentation Prepared: ODE: Date: Pre-Rig Sundry Application Reviewed: SDE/ES: Date: Pre-Rig Sundry Application Submitted: TA: Date: I~'] SUNDRY NOTICE ~i Sundry Documentation Prepared: ODE: Date: D Sundry Application Reviewed: SDE/ES: Date: D Sundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK~ USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW Reason for Sundry (Check all that apply) Abandon Change Approved Program Alter Casing Operation Shutdown Suspend Re-enter Suspended Well Repair Well Time Extension Plugging Perforate Pull Tubing Stimulate Variance Other(Explain): I APPROVAL TO PROCEED I Approved AOGCC Permit/Sundry Received TA: Date: Approval to Commence Operations SDE/ES: Date: I Well Name: I PBU DS 13-08A I Redrill Plan Summary I Type of Redrill (producer or injector): I Producer ISurface Location' Target Location: Bottom Hole Location: 1408 FSL5150 FEL S13T10N R14E Umiat 1591 FSL 2099 FEL S24 T10N R14E Umiat 202 FSL2567 FEL S24T10N R14E Umiat I AFENumber: 14J0389 I Estimated Start Date:I 11/07/98 IMD: 1~3,624' I ITVD: 19°44' I I Rig: I Nabors 22E I Operating days to complete: 122 I BF/MSL: 146.11'I I RKB: 174.35' I Well Design (conventional, slimhole, etc.): I Horizontal Sidetrack I Objective: I Development production targeting Zone 4 sands. Mud Program: Intermediate ~ud Properties: LSND 8.5" hole section I Density (ppg) Funnel vis Yield Point 10 sec gel 10 min gel pH Fluid Loss 10.0 - 10.5 40-55 5 - 17 5 - 10 15 - 25 8.5 - 9.5 6 - 10 cc Production Mud Properties: Quickdril-n 16" hole section Density (ppg) Funnel vis LSRV LSR YP pH 8.6 - 8.8 45-65 >45,000 cP 10-20 8.5-9.0 Directional: KOP: 113,624' MD Maximum Hole Angle: Close Approach Well: 104° From 11,943' to 12,150'. BHL will be 90°. None Logging Program: Intermediate Production Hole(Horizontal) Drilling: MWD / GR Open Hole: None Drilling: MWD / GR/4 Phase Resistivity Open Hole: Platform Express + Sonic DS 13-08A Permit to Drill I Formation Markers: Formation Tops MD TVDss West Sak Not Penetrated 6225' K 10 9800' 7557' K.O.P. @ 9800' MD(7632' TVD, 7557' TVDss) K 5 10,054' 7729' Put River N/A 8408' Not present, truncated by LCU Base LCU 10,989' 8408' Kingak JB 11,280' 8668' Sag River 11,563' 8861' 7" Intermediate casing point. Set shoe _5' in Sag. Shublik 11,595' 8883' Sad(Z4) 11,675' 8928' Horizontal target HOT Not Penetrated 9000' Heavy Oil/Tar COWC Not Penetrated 9032' Current Oil / Water Contact Zone 3 Not Penetrated 9095' Casin! I/Tubinq Proqram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MDrFVD 8.5" 7" 26# L-80 BTC-M 1920' 9650'/7544' 11,570'/8940' 6" 41/2" 12.6# L-80 IBT-M 2204' 11,420'/8838' 13,624'/9044' Tubing 41/2" 12.6# 13Cr-80 NSCT 11,420' 0/0 11,420'/8838' Cement Calculations: Kickoff Plug I Cased / Open hole I Basis: Based on 200' of 9-5/8" casing volume above the section, 50' of 12-1/4" milled section and 100' of 9-5/8" casing below the section. TOC: At -9600' md(7517' TVD, 7443' TVDss) Total Cement Volume: I Tail 32 bbl/180 ft~ / 181 sks of Halliburton Premium 'G' at I 17 ppg and 0.99 cf/sk. Liner Size 17" Intermediate I Basis: Lead: Based on 770' open hole above tail with 50% excess and 150' liner lap. Lead TOC: At top of liner -9650' md(7546' TVD, 7471' TVDss). Tail: Based on 80' shoe track and 1000' of open hole with 30% excess. Tail TOC: At 10,570' md(8225' TVD, 8151' TVDss). Total Cement Volume: Lead 3211.0bblppg/ 180and ft~3.24 / 55cf/sk.Sk of Halliburton Premium 'G' at Tal 3415.8bblppg/190and ftc1. / 11565cf/sk.Sk of Halliburton Premium 'G' at Liner Size 14 1/2" Production I Basis: Tail: Based on 80' shoe track volume, 2054' of open hole with 50% excess, 150' of 7" x 4.5" liner lap and 200' of 7"x 4" drill pipe annulus volume. Tail TOC: At top of liner -11,420' md(8837' TVD, 8763' TVDss) Total Cement Volume: Tail 58 bbl/325 ft~ / 283 sk of acid resistant Halliburton Premium 'G' at 15.8 ppg and 1.15 cf/sk. DS 13-08A Permit to Drill 2 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. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. · Maximum anticipated BHP: 3450 psi @ 8996' TVDss - Zone 4 · Maximum surface pressure: 2550 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned completion fluid: 8.5 ppg Seawater / 6.8 ppg Diesel Drillin_cl Hazards/Contingencies · None DRILLING CLOSE APPROACH: H2S: · Drill Site 13 is considered to be an H2S Drill Site. The scope and objectives for H2S operations are outlined in the attached 'H2S- Standard Operating Procedure(SOP)'. INTERMEDIATE SECTION: The Kingak shale is considered mechanically unstable over 50° inclination. The 1800' intermediate section will be drilled at inclinations up to 47° with mud .asphalt products added for reduced shale reactivity. The kick tolerance for the 8.5" open hole section would be 42 bbls assuming an influx at the 11,570' TD. This is a worst case scenario based on a 9.0 ppg pore pressure gradient and a fracture gradient of 11.0 ppg with a 10.0 ppg mud in the hole. PRODUCTION SECTION: · Faults are known to be conductive in the Drill Site 13 area. A 50-70' throw fault will be crossed just prior to penetrating the target polygon. ~ Stuck pipe has not been recorded in the production interval but differential . sticking will be a problem if loss circulation is occurring. · The kick tolerance for the 7" shoe would be an infinite influx(annular volume) assuming an influx at the 13,624' TD. This is a worst case scenario based on a 7.4 ppg pore pressure and a minimum fracture gradient of 10.0 ppg with a 8.5 ppg mud in the hole. DS 13-08A Permit to Drill 3 Disposal · No annular injection in this well. · Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC-2A for disposal, except any metal cuttings which will be sent to the North Slope Borough. SUMMARY SIDETRACK PROCEDURES Pre-Riq Work 1. Pull the 4 1/2" SSSV. Valve is set at 2143' MD. 2. Shoot as many holes as possible in the tubing above the IBP and below the packer from 11,670' to 11,636'. 3. Perform a cement P&A of 15.8 ppg class 'G' cement with adequate cement volume to cover the 7" liner from PBTD at 12,209' to a minimum of 100' above the top perforation at 11,987' plus squeeze 5 bbls to the perforations. Estimated cement volume needed is 17 barrels. A CTU or full bore P&A is at the discretion of the Wells Group - bear in mind there is a 2.687" ID tubing patch at 11,560'. ~/Note: Top of cement must be at a minimum of 11,887' for AOGCC compliance. Top of cement may ~-{"~°~'4o extend into the tubing as long as it does not interfere with the tubing cuffing operations. 4. Rig up slickline and tag and document top of cement. 5. Cut the 4 1/2" IPC L-80 tubing in the middle of the full joint of tubing below the bottom GLM(bottom /~ ,~" GLM @ 10,459'; estimated cut depth @ 10,489'). This cut will not be fished and is at the discretion of the Wells Group as to chemical or jet cut. 6. Test the Gray 9-5/8" mandrel packoff and Gray tubing hanger to 5000 psi for 30 minutes. 7. Test the casing against the cement plug to 3000 psi for 30 minutes. Freeze protect top 2200' MD with diesel. 8. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. Secure well. 9. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. Ri.q Operations: 1. MIRU Nabors22E 2. Circulate out freeze protection. Set TVVC. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull 4-1/2" tubing. 5. Rig up e-line. Run a 8.50" gauge ring / junk basket to 10,200'. Run and set a 9-5/8" bridge plug at 10,100'. 6. RIH with 9-5/8" Baker section mill assembly and mill a 50' window from 9800' to 9850'. 7. Cement 50' section from 100' below to 200' above from 9600' to 9950' md. 8. Kick-off drilling the 8-1/2" intermediate section to TSag @ ___11,570' md(8940' TVD). 9. Run and fully cement a 7", 26# intermediate liner with a minimum of 150' liner lap in the 9-5/8". 10. Test the 7" and the 9-5/8" casing from the 7" landing collar to surface to 3000 psi for 30 minutes. 1 1. Drill the 6" production section building to horizontal targeting the Zone 4 sands(9002' TVD, 8928' TVDss) to an estimated depth of 13,624' md(9044' TVD, 8970' TVDss). 12. Run DPC 'Platform Express' + Sonic logs from horizontal to 7" shoe. 13. Run and fully cement a 4-1/2", 12.6# production liner with a minimum of 150' liner lap in the 7". DS 13-08A Permit to Drill 4 14, Test the 4-1/2", 7" and 9-5/8" casing from the 4-1/2" landing collar to surface to 3000 psi for 30 minutes. 15. The 4-1/2" production liner will be perforated with DPC 2.75" guns on a 200 psi under balance. Perforating intervals to be determined after reviewing logs. 16. Run 4-1/2" completion tying into the 4-1/2" liner. 17. Test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 18. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 19. Freeze protect the well to -2200' and secure the well. 20. Rig down and move off. Estimated Pre-rig Start Date: Estimated Spud Date: 10/16/98 11/07/98 C. Michael ;Jackson 564-5486 10/12/98 DS 13-08A Permit to Drill 5 Untt~. ....... : ~ SuiYao) i~t..: 70.21766689 Surf~ I~.: 148.48852559 Surf~ ...... : 1408 I~L 5150 ~ 813 TIOR ~4E U~ Tie-in survey: 3237 {~L i896 ~ S24 flog ]!14~ ~ ~t Eiqh Pt.,: 1498 ~L 2130 ~ ~24 TIt~ lll~ ~ ~ .......... : 262 I~L 2567 ~ ~4 TIO}{ R14E ~ PRRIHINA{ Y l-Cmui T-Coord 687359.48 5931478.84 690740,80 5928111,83 r~539.7~ 592646O.00 690510.83 5926366.40 7630,26 1555.91 2218.32 763;2.32 7557.9*/ 2220,15 1693.21 -3~[~ 2271,41 7762.35 7688.00 2324,10 7803.35 ??~.OO 23,53,26 {]H~R~ 'dKU~H~M) X {~ t'{CB IH0 3450.I0 S 3296.91 g 690140.~ 5928111.83 147R <TIE 3452,60 8 3298o5~E 69~742o~ 592810~o3;8 t451{1.50 3520.45 ,q3339.49 {{6911785.32 5928042.56t411{8,00 3586.10 $ 336~.35 E 690816.62 5~27917.68 136]{8,00 362i),74 $ 3380.89 E '690828,99 5927943.34133t{8.00 8/loo cumin 811ou 10100,~ 37.7{) 168,36 10175,87 3~. lCJ 17&.?O 10661.38 M.19 176.~ 10700.00 35.9/ 181,11 I0800.00 41.18 190.86 7~.41 7~64.06 2377.17 7899.83 7825.48 2417.07 8301.41 8227.06 261B.25 8333.02 8258,67 2691.14 84tt,25 8335,~ 2751,87 ~=48.26 S 3387.67 E 690836.46 5927916.50 1MR 8,0{) 3692.35 $ 3393.59 E 690843.41 5927872,08 RS 8,00 3964.76 S 3409.28E 690865.91 5927600.15 5711 3986.945 3409.69 S;590866.87 5927518.00 53R 8.00 4048.73 ~ 3402.90 E , 690861.62 5927516.06 46R 8,00 198.60 8482.35 84~.00 2820.46 41t5.14 S 3385.19 ~ 69{)845,56 5927449.23 HS 8.00 (2tnadrill (c)98 130&NPlO 3.2C I2:45 ClUB 16/10(1 ll~l.gg 41.1~ l~.~ 8948.I7 ~73,~ 3319.99 l160LO0 (g.B~ ~98.60 Bg60oll ~)B8.)6 333).~6 4601.35 8 ~1.$! ) 6gO694.~ ~g~6g6g. l( ~ 16.0~ ~16~0.00 51.B~ 198.60 BgBg.~6 BgX5.~l $375.~ ~63g.~g $ 3~OB.6g E 690E~2.14 D9~0.59 ~ 16.OD t1575.52 61.96 198.60 9002.35 8928.00 3395,90 1660.52 S 32ilt.65 !6906~5.62 592689g.5~ I~ 16.00 /too caws 12249.5I ~,00 198.60 8g~.57 88g~.22 3953.91 5189,$95 3023.67 ~;690516,83 59'2:6366,40 LS t5.00 12250.00 3~,93 1~.~ 8966.57 8892:,22 13954.40 5189,86;;83023.5t ]~690510,69 592E06~.93 t~ I5.00 12300.00 82,43 198.60 8989.~ 8895.55 4004.26 5237.tl $ 3007.6I ll'690495,97 ~8.30 Lq 15,00 12323.29 78.93 196.60 8973,67 8899.32 402L23 525~,885 3gOO.28)t 690489.18 ~J26~6.35 BS 15,00 t267t.6,1 18.93 198.60 9~1.69 8967,31 4374.96 558:8.485 2389.31 g 6g0386,48 5925~,13 BS O,OO 12100.60 81.17 198,50 90t5.56 8971.21 4391.0,? S609.35,5 21~2.34i g660179,98 5925943.08,~ 16'.09 12781t.31 gO.O0 198.60 0,052.358978.60 44Bl. g~ SG92.72,~ 2854,2g l:6g03:54.~ 59258~,05 ~ 10.09 ).2793.80 90,55 198.~0 9052.,~ 8977.97 4490.18 5697.g35 2852.531: .6~L%.~2,3~ 5925&~3.,80 tl~ 10. OD (tnadrtll (c)9~ 13083,P10 3,2C 12:&5 Plt P) Shared Servlces Orllll DS13-OBA (P 1 DA) VERTICAL SECTtDN VIEW Sect., on at: 1 §8. 60 TVD Scale. t I inch - 500 froot ~p Scale.: 1 inch = 500 fo,~ Oro~ ..... t O~ ~ IgOB · Shore S~rv~c~s Dr~ ! ~ ~ PLAN VIE~ g ~ ~tm ,m~ s ~ [ ...... ~ ..... - .... ' ........ - ........ '--- m ~ {tl~ 1~[ ~ ~ ~ ~ CLO~ ..... , ~89 f~e~ ot Azlmu~h 158. 25 ~ ~ ~ 1~ 4~1~ 9 ~ E ~CLI~TI~, +27. 958 (E) ~ ~RI~F~~ ll~ ~S ~E SCAL~ ... ~ I inch - ~0 fe~ ~ ~ 1~1~ I I~ ~ 5 ~ E ''' I) ~ ~I~ ll~l ~ $ 2l~ E ~ '~ r P~ELII' [lflgl [ [ ~ ~ --- .~ ............................. ~ ..... . ..... . ........J..._[ ............................. ~............. /l · ~ ~:~ ........ --~ "' .......... t'l _ ...... . .......... . ... ~ ........ . , _~ .... .~ .... , .... . - .~ .. - -.. .... ~.._. ........ :, _ , , ~,,,,_-.. , Well: 13-08 Spud Date:10-03-81 Original RKBE:78' Top of Formation: 12132' Annular Fluid:Diesel/9.6 NaC1 Reference Log:BHCS '~RCO Alaska, Inc. - Prudhoe Bay API #: 50-029-20667-00 Completion: 10-29-81 Hanger Type: Gray Max Hole Angle: 58° @ MD: 10700' Date: 10-23-81 Tie In: Type:PRODUCER Status:New Hanger:27' Angle @ TS:49° Angle @ TD:58° Date: 00-00-00 Ann. Comm: LDL 10/11/95 Indicates Leak @ Lower Element of Patch ALL DEPTHS ARE RKB DRILLING MI) TO TOP OF EQUIPMENT EXCEPT WHERE NOTED. , m SSSV CAT #2 ,?eweZr~, (~) SSSV = CAT#2 Depth Description I 2143 4-1/2" Otis DBE SSSV Nipple 1]]=3.813" 2 11560 4-1/2" Alpha Soft Set Tubing Patch (Set 03/12/94). ID=2.687" 3 11617 4-1/2" BOT PBR Assembly 4 11636 9-5/8" x 4-1/2" B0T 3-H Packer 5 11710 4-1/2" Otis XN Nipple ID=3.725" J-1 6 11709 4-1/2" BO? Shearout Sub 7 11711 4-1/2" Tubing Tail C-1 11708 ELM Tubing Tail. (Logged 01/18/86) 9 12209' Cement (Tagged 04/09/94) 10 11670' IBP (Set 10/15/95) ID=0.001" G-1 J-2 J-3 J-4 J-lO J-5 J-6,7 C-2 4-1/2" Alpha Soft Set Tubing Patch (Set 03/12/94) ID=2.687" Casing and Tubing (C) Size Weight Grade 1 13-3/8" 72# L-80 2 9-5/8" 47# L-80 3 7" 29# L-80 4-1/2" 12.6# L-80 Gas Lift Information (G) MD TVD Stn Mandrel 2948 (2945')' 1 0T 5319 (4926') 20T 7292 (6059') 30T 8157 (6555'} 40T 8850 (7006') 5 OT 9596 (7512') 6 OT 10459 (8015') 7 OT 11352 (8509') 8 OT P-1 CmtTo~@Perforation Data (ELM DEPTES) (P) 12209' J-9 Top Bottom Description O' 2385' Casing O' 11990' Casing 11677' 13195' Liner 0' 11711' Tubing-PC Interval Zone FT SPF 1 11987-12015 SAG 28 0 12135-12155 4 20 4 12155-12174 4 19 0 12184-12204 4 20 0 12206-12214 4 8 0 12218-12228 4 10 0 12232-12246 4 14 0 Valve T~pe CA RD T-2 CA RD T-2 CA RD T-2 OT RD-1.5 RA 0T RD-1.5 RM CA RD T-2 OT RD-1.5 RA CA RD T-2 Latch Port TR0 Date 09-16-95 03-25-94 09-16-95 09-16-95 09-16-95 Date Comments 06-03-94 SQZ - LARC -06-30-94 RPERF 06-03-94 SQZ - LARC 06-03-94 SQZ - LARC 03-28-94 SQZ 03-28-94 SQZ 03-28-94 SQZ C-3 FRAC 07/04/9& BALL SEALER TREATMENT 03/04/89 Datum 8700' SS=11790' MD PBTD=13150' 8800' SS=11949' MD TD=13200' Revision Dates 07-16-96 by EN~ Reason: SSSV = CAT#2 Previous Reason: 10-22-95 Well 13-08 DS 13-08 Pre-Rig Plug & Abandon Freeze Pro~ctlon ID) GLM S~tlons: 1) 2948' 2) 5319' 3) 7292' 4) 8157' s) 8850' 6) 9596' 7) 10,459' 8) tl,352' EsDmated Tubing Cut 4-1/2" Alpha Soft Set Tubing Path ID = 2.687" IBP ~ 11,670' g~8", 47 ~ L~O ~ -- ~ 9-~8" x 4-1/2" BOT '3-H' Packer Minimum Top of Cement ~ -- 11,98T - 12,015' 12,135' - 12,155' 12,155' - 12,174' 12,184' - 12,204' 12,20~. 12,209' 12,209' - 12,214' 12,218' - 12,228' 12,232' - 12,246' PBTD ~__ 7',29#,L'80 ~ -- DATE REV. BY COMMENTS 10/~ CMJ Proposed Pre-rig Cond~lon APl NO: 50-02~- 20667-00 ARCO Alaska Inc. DS 13-08 Wellhead: BF / MSL = 46.11' Nabore 22E: KB / MSL = 74.35' 'X' Nipple @ 2000' t3-318", 72#, L-80 ~ 6 Gas Lift Mandrels 4-1/2", 12.6~, 13Cr-80 Tubing 9-5/8", 47# L-80 BTC Casing From El' to 10,533' 9-r. d8'', 47# SOO-95 BTC Casing From 10,533' to 11,990' -- ~ 7", 26~ L-80 BTC-Mod Liner Top 7" x 4.5" Baker Packer ~ 12.6~ L-80 IBT-Mod Production Liner Top ~ 4~" Shoe~ 7" 29# L-80 ~ DATE 10105/98 REV. BY CMJ COMMENTS Proposed Completion APl NO: 50-029-20667-01 Arco Alaska Inc Hydrogen Sulfide Authority: Scope: Issue Date: Control Status: CONTENTS Drilling Manager All SSD Operations January, 1995 Department controlled document Scope and Objectives Roles and Responsibilities Training and Drills Monitoring & Personal Protective Equipment Equipment and Site Conditions Rig Operations Contingency Planning & Emergency Procedures Custodian: Issuing Dept.: Revision Date: SSD Assurance Team Leader Shared Services Drilling (SSD) June 10, 1998 REFERENCES Drilling Policy Alaska Safety Handbook Regulations (AOGCC, MMS, OSHA) APl RP 49 ARCO Safety Booklet Standard Operating Procedures are mandatory. Scope and Objectives This procedure establishes minimum requirements to ensure health, safety and environmental protection related to Hydrogen Sulfide (H2S) in Shared Services Drilling operations. Scope of this procedure is limited to activities associated drilling and SSD-managed waste disposal operations. Following this Standard Operating Practice is mandatory. Any Drillsite or Pad (or area) that has a source (process stream) containing H2S above 100 ppm is a designated an H2S Area. If a single well on a Drillsite or Pad has H2S exceeding 100 ppm, the entire Drillsite or Pad is designated an H2S Area. H2S designated facilities (other than drillsites and pads) are outside the scope of this SOP, and are addressed in the Alaska Safety Handbook. This procedure is intended to address state and federal regulatory requirements related to drilling and workover operations in H2S designated areas. Exceptions to this SOP are only allowed with approval from the SSD Drilling Superintendent or SSD Drilling Manager, based on completion of a site- specific risk assessment. Roles and Responsibilities 1. Drillsite or Pad Operators (field personnel) are responsible for designating H2S areas. Field/Asset personnel are responsible for posting signs at entrances to designated H2S pads. , Drilling Engineers are responsible to obtain H2S designations from Drill Site or Pad Operators during well planning. The Permit to Drill and Well Plan must address requirements for H2S detection monitoring, contingency and control, and training per AOGCC regulations (20 AAC 25.065) and SSD Drilling Policy. Operations in H2S designated areas are "non-routine" (see Drilling Policy) and are subject to risk assessment and pre-spud meetings per the SSD Drilling Policy. SSD Company Representatives are responsible to ensure that SSD work activities are in accordance with this procedure and is to reconf"mn pad designation with the Drillsite or Pad Operator prior to moving the rig on location. , The Drilling Contractor is responsible to ensure that rig equipment, including detection monitoring, personal protective equipment (for contractor's personnel) and contingency control equipment are in-place and operable. Drilling Contractor management are also responsible for ensuring their equipment addresses requirements in this SOP, AOGCC Version 1.0 Page I of 5 Hydrogen Sulfide PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. The control version of this document is at http://nslope.bpweb.bp.com/drilling_manuals on the BP Intranet. regulations, AP1 RP 49, and other applicable regulations. Note that AP1 RP 49 is incorporated by reference into AOGCC regulations. The Drilling Fluids Contractor is responsible to ensure hydrogen sulfide treating material for the drilling mud is available on or near the location, in good condition and in sufficient quantity to adequately treat the mud system should hydrogen sulfide be encountered while drilling. All personnel (SSD and Contractors) working in SSD operations are responsible to obtain and conform with H2S training. Personnel essential to on-going rig operations must be covered by a respiratory protection program. Each Employer (SSD and Contractors) with employees working in SSD operations is responsible is required to implement a respiratory protection program for its employees, and equip its personnel with appropriate breathing equipment. Employers are responsible to train their personnel in use of the equipment and calibrate and maintain equipment in accordance with OSHA and manufacturers requirements. Escorted visitors are not required to have the H2S training (but the escort must have the training). Unescorted visitors and temporary workers must have necessary training, rig-site orientation and PPE as stated herein. Training And Drills 1. Training. Every person working in an SSD operation in an H2S designated area will have Hydrogen Sulfide and sulfur dioxide training. Training will include H2S orientation training provided through the North Slope Training Cooperative, as well as company and rig specific training. Operation-specific training will begin in the Pre-spud meetings, with H2S discussed during Pre-tour HSE meetings, and Weekly Safety meetings for the duration of the operation. Training is to include the following: · explanation of the hazards of H2S and SO2 in produced fluids during drilling operations; explanation of rig layout including location and use of detection equipment, alarms, prevailing winds, importance of adequate ventilation, use of mechanical blowers, utilization of windsock and wind indictors, and personnel movement in an upwind direction; · emergency response procedures contained in the contingency plan including well control, and evacuation plans (including immediate actions); · location, use and care of self-contained breathing apparatus, emergency escape air bottles, hose lines, etc.; stationary and portable hydrogen sulfide detection equipment; combustible gas indicator equipment, resuscitation equipment and requirements, portable fire extinguishers, and the emergency alarm system; · use of buddy system, air testing before entering an area, materials selection and the drilling fluid treating procedures. Version 1.0 Page 2 of 5 Hydrogen Sulfide PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. The control version of this document is at http://nslope,bpweb,bp.com/drilling_manuals on the BP Intranet, Drills. Drills with breathing equipment are to be initiated by actuating the H2S alarm; personnel are to don breathing apparatus and proceed to the previously assigned area in accordance with emergency procedures. Periodically, drills should incorporate working a short period of routine work in the breathing equipment; following use, cylinders and breathing apparatus shall be refilled and made ready for use. The Toolpusher will initiate drills to ensure personnel understand expectations and adequately respond to the alarm; drills will be conducted before penetrating formations anticipated to contain H2S. Monitoring & Personal Protective Equipment Monitoring. State and federal regulations require permanent fixed, portable, and personal monitors on drill rigs. All monitors (permanent, fixed, portable, and personal) are to be fit- for-purpose and approved by the appropriate Safety Department. Stationary Fixed Monitors: Rigs and disposal facilities (Ball Mills) are to be equipped with permanently mounted H2S monitors in areas of probable H2S concentrations. Monitors are to have visual and audible alarms set to alert at 10 ppm H2S. Monitoring and alarm equipment are required on rigs by regulation, regardless of H2S designation. Monitors on rigs must be positioned in at least the following locations: bell nipple, pit room, sub base (cellar area). Monitors in the disposal facilities (Ball Mill facilities) are to be placed in areas of high risk exposure and probable high concentration areas. Portable Manual Monitors: A minimum of three manual H2S detectors are to kept at the rig-site (with an adequate supply of extra detector tubes, as appropriate) per AOGCC. Personal Monitors: In H25 designated areas, personal H2S monitors shall be worn at all times. Where more than one individual will be working in the same area (e.g. outside the rig on an H2S designated pad), at least one H2S monitor is to be used by the group. Each vehicle entering a designated area is to have a monitor. The stationary fixed monitors on the drill rig will be installed to protect personnel working in the installed area. In areas monitored by stationary fixed monitors, personal monitors are not required. All monitors are to be calibrated to alarm at 10 ppm H2S concentration. Calibrations are to completed every 30 days by qualified personnel or as specified by the manufacturer. Disposable monitors may be used. Respiratory Protection Equipment. Each employer will provide respiratory protection equipment to its personnel Equipment will include emergency escape equipment and/or breathing apparatus, as appropriate and will be provided through an OSHA-compliant respiratory protection program: In H2S designated areas, all personnel are to carry, or have immediate access to a 5- minute emergency escape pack (including visitors) when in areas of restricted egress or where evacuation would require passing through a toxic atmosphere. [Example: derrickman must have one in derrick]. Version 1.0 Page 3 of 5 Hydrogen Sulfide PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. The control version of this document is at http://nslope.bpweb.bp.com/drilling_manuals on the BP Intranet. Personnel essential to on-going rig operations must be covered by a respiratory protection program and be equipped with self-contained breathing apparatus. Personnel working in a designated Hg.S Area are to be clean shaven to the extent that the SCBA face mask seal is effective and a positive fit test is obtained. Visitors are exempt if they will be using a 5-minute escape pack. All personnel working in areas with H2S levels greater than 10 ppm are to use supplied breathing air (SCBA) and are to use the Buddy System. If other protective equipment is to be used at the worksite (air supply systems, compressors, etc.), personnel are to be trained prior to use. Equipment And Site Conditions 1. BPX(A) / AAI Expectations. Personnel are not to enter well houses unless absolutely necessary. Outside the rig footprint, the H2S procedures in the Alaska Safety Handbook are to be followed. The atmosphere in a well house must be tested before each entry. If the H2S concentration is >10 ppm, entry is not permitted without SSD or BP/AAI supervision approval, and entry is then only allowed utilizing all necessary and approved guidelines for working in H2S environments (buddy system, supplied breathing air-SCBA, personal monitors, etc.). SSD Drilling Policy requires that all materials that may be exposed to an H2S environment are to be designed and constructed to withstand the environmental effects of H2S (reference AP1 RP 49 requirements). 3. Rig equipment and tubulars are to be designed and constructed to withstand the effects of H2S (reference AP1 RP 49 requirements). Full-sized camps will not be placed on H2S designated pads. Satellite camps may be placed on drillsites/pads within areas designated H2S areas, but will be placed to ensure the camp is upwind of prevailing winds. 5. A system for check-in/check-out of all personnel (workers and visitors) is required to track locations of personnel within the Designated H2S area. 6. At least one wind indicator is required on each location. . Two evacuation routes from the rig or camp must be designated and reviewed with all personnel on the location (workers and visitors). Maps must be posted at various locations for reference (camp, rig floor, etc.) and are to be discussed in Safety Meetings o Two muster points must be allocated in designated safe areas, in opposing wind directions from a probable source. Weather shelters must be provided at the muster sites. In addition, equipment as specified in the SSD Emergency Management Plan must be provided at these sites. 9. The need for supplemental mechanical ventilation equipment will be assessed by the Drilling Contractor in conjunction with SSD prior to commencing operations. Version 1.0 Page 4 of 5 Hydrogen Sulfide PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. The control version of this document is at http://nslope.bpweb.bp.com/drilling_manuals on the BP Intranet. Rig Operations 1. SSD and the Drilling Fluids Contractor will consider management ofpH, hydrogen sulfide scavengers, corrosion inhibitors to minimize release of H2S and protection of equipment. 2. If H2S gas breaks out of the drilling fluid following a drilling break or trip, returns are to be routed through the mud/gas separator until the level of H2S is deemed safe. o Wireline, coring, and testing operations should be reviewed for H2S hazards and should be performed with the minimum number of personnel in the immediate vicinity. Pre-job safety meetings will emphasize H2S issues prior to operations Contingency Planning And Emergency Procedures 1. In SSD operations in H2S designated areas, site specific written contingency plans must be prepared. The plan is to address personnel, equipment and procedures to ensure a safe working environment (consistent with API RP 49). The plan is to be posted on the rig and reviewed with all personnel on location. The plan is to discussed at Pre-spud meetings, Weekly Safety Meetings, PJSM, as appropriate. 2. The posted Written Contingency Plan is to include: · A Pad / Drillsite Map showing safe locations and evacuation routes. · The Drilling Contractor's rig-specific plan including emergency and warning procedures, and a map showing safe locations and evacuation routes. · Safety equipment and supplies, including hydrogen sulfide scavengers; · A copy of this Standard Operating Procedure including roles and responsibilities of personnel. 3. Response to Alarm: · all personnel are to don an Emergency breathing apparatus and proceed to one of the pre-designated safe zones (depending on wind direction). · personnel are not to attempt source control (shut valve, etc.) or rescue. · personnel are to call for help (notify Field/Asset). · re-enter the area only under instruction from a SSD, BP or AAI supervisor (including rescues). Re-entry personnel must use proper equipment (monitors, SCBA, buddy system, communication system (radio), etc.), and procedures for working in H2S areas. Notifications. The AOGCC must be notified within 24-hours of encountering hydrogen sulfide gas. In addition, the BPX(A) or AAI environmental departments may need to notify the Borough, ADEC, or EPA. of an H2S release. Revision Log Rev. Date Authority Reviser Revision Details Version 1.0 Page 5 of 5 Hydrogen Sulfide PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. The control version of this document is at http://nslope.bpweb.bp.com/drilling_manuals on the BP Intranet. _. hared _ .ervices sk, a rilling WELL NAME DS 13-08A DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET The attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. I "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) DRILLING PERMIT Permit Documentation Prepared: ODE: e,_~~ Date:~ t~t~t~f Permit At~plicatioXn Re~__C._w_ed: SDE/ES: ¢~ ~ ~ ~ merm~plica[~on)~¢~tted: TA://~A~. ~ Date:lO/t~ PRE-RIG WORK Pre-Rig Memo Reviewed: SDE/ES: Date:~ Pre-Rig Memo Sent to Slope: ODE: Date:~ Pre-Rig Sundry Documentation Prepared: ODE: Date:~ Pre-Rig Sundry Application Reviewed: SDE/ES: Date:~ Pre-Rig Sundry Application Submitted: TA: Date:~ SUNDRY NOTICE D Sundry Documentation Prepared: ODE: Date: m"] Sundry Application Reviewed: SDE/ES' Date: D Sundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK~ USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW Reason for Sundry (Check all that apply) Abandon Alter Casing Suspend Repair Well Plugging Pull Tubing Variance Change Approved Program Operation Shutdown Re-enter Suspended Well Time Extension Perforate Stimulate Other(Explain): I APPROVAL TO PROCEED I Approved AOGCC Permit/Sundry Received TA: Date: Approval to Commence Operations SDE/ES: Date: I Well Name: I PBU DS 13-08A I Redrill Plan Summary I Type of Redrill (producer or injector): I Producer Surface Location' 1408 FSL 5150 FEL S13 T10N R14E Umiat Target Location: 1591 FSL 2099 FEL S24 T10N R14E Umiat Bottom Hole Location: 202 FSL 2567 FEL S24 T10N R14E Umiat I AFENumber: 14J0389 I I Estimated Start Date: I 11/07/98 I MD: ]13,624'] I TVD: 19044' I Rig: I Nabors22E I Operating days to complete: 122 I BF/MSL: 146.11'I I Well Design (conventional, slimhole, etc.): I Horizontal Sidetrack IRKB: 174.35, I I Obiective: I Development production targeting Zone 4 sands. Mud Program: 'intermediate Mud Properties: LSND 8.5" hole section I Density (ppg)l Funnel vis Yield Point 10 sec gel 10 min gel pH Fluid Loss ..10.0-10.5I 40-55 5-17 5-10 15-25 8.5-9.5 6-10cc Production Mud Properties: Quickdril-n 16" hole section Density (ppg) Funnel vis LSRV LSR YP pH 8.6 - 8.8 45-65 >45,000 cP 10-20 8.5-9.0 Directional: KOP: 113,624' MD Maximum Hole Angle' Close Approach Well' 104° From 11,943' to 12,150'. BHL will be 90°. None Logging Program: Intermediate I Drilling: MWD / GR I Open Hole: None Production Hole(Horizontal) Drilling: Open Hole: MWD / GR / 4 Phase Resistivity Platform Express + Sonic DS 13-08A Permit to Drill I Formation Markers: Formation Tops MD TVDss West Sak Not Penetrated 6225' K 10 9800' 7557' K.O.P. @ 9800' MD(7632' TVD, 7557' TVDss) K 5 10,054' 7729' Put River N/A 8408' Not present, truncated by LCU Base LCU 10,989' 8408' Kingak JB 11,280' 8668' Sag River 11,563' 8861' 7" Intermediate casing point. Set shoe _+5' in Sa9. Shublik 11,595' 8883' Sad(Z4) 11,675' 8928' Horizontal target HOT Not Penetrated 9000' Heavy Oil / Tar COWC Not Penetrated 9032' Current Oil / Water Contact Zone 3 Not Penetrated 9095' Casincl/Tubinq Proqram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 8.5" 7" 26# L-80 BTC-M 1920' 9650'/7544' 11,570'/8940' 6" 4 1/2" 12.6# L-80 IBT-M 2204' 11,420'/8838' 13,624'/9044' Tubing 4 1/2" 12.6# 130r-80 NSCT 11,420' 0/0 11,420'/8838' Cement Calculations: Kickoff Plug I Cased / Open hole I Basis: Based on 200' of 9-5/8" casing volume above the section, 50' of 12-1/4" milled section and 100' of 9-5/8" casing below the section. TOC: At -9600' md(7517' TVD, 7443' TVDss) T°talCementV°lume: I Tail 132bbl/180f¢/181sks°fHalliburt°nPremium'G'at17ppgand0.99cf/sk. Liner Size J7" Intermediate Basis: Lead' Based on 770' open hole above tail with 50% excess and 150' liner lap. Lead TOC' At top of liner -9650' md(7546' TVD, 7471' TVDss). Tail: Based on 80' shoe track and 1000' of open hole with 30% excess. Tail TOC: At 10,570' md(8225' TVD, 8151' TVDss). Total Cement Volume: I Lead 132 bbl/180 f¢ / 55 sk of Halliburton Premium 'G' at I 11.0 ppg and 3.24 cf/sk. I Tail 134 bbl/190 f¢ / 165 sk of Halliburton Premium 'G' at 115.8 ppg and 1.15 cf/sk. Liner Size 14 1/2" Production I Basis: Tail: Based on 80' shoe track volume, 2054' of open hole with 50% excess, 150' of 7" x 4.5" liner lap and 200' of 7"x 4" drill pipe annulus volume. Tail TOC: At top of liner -11,420' md(8837' TVD, 8763' TVDss) Total Cement Volume: Tail 58 bbl/325 ft3 / 283 sk of acid resistant Halliburton Premium 'G' at 15.8 ppg and 1.15 cf/sk. DS 13-08A Permit to Drill 2 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. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. · Maximum anticipated BHP: 3450 psi @ 8996' TVDss - Zone 4 · Maximum surface pressure: 2550 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned completion fluid: 8.5 ppg Seawater / 6.8 ppg Diesel Drilling Hazards/Contingencies · None DRILLING CLOSE APPROACH: H2S: · Drill Site 13 is considered to be an H2S Drill Site. The scope and objectives for H2S operations are outlined in the attached 'H2S- Standard Operating Procedure(SOP)'. INTERMEDIATE SECTION: · The Kingak shale is considered mechanically unstable over 50° inclination. The 1800' intermediate section will be drilled at inclinations up to 47° with mud asphalt products added for reduced shale reactivity. · The kick tolerance for the 8.5" open hole section would be 42 bbls assuming an influx at the 11,570' TD. This is a worst case scenario based on a 9.0 ppg pore pressure gradient and a fracture gradient of 11.0 ppg with a 10.0 ppg mud in the hole. PRODUCTION SECTION: · Faults are known to be conductive in the Drill Site 13 area. A 50-70' throw fault will be crossed just prior to penetrating the target polygon. · Stuck pipe has not been recorded in the production interval but differential sticking will be a problem if loss circulation is occurring. · The kick tolerance for the 7" shoe would be an infinite influx(annular volume) assuming an influx at the 13,624' TD. This is a worst case scenario based on a 7.4 ppg pore pressure and a minimum fracture gradient of 10.0 ppg with a 8.5 ppg mud in the hole. DS 13-08A Permit to Drill 3 Disposal · No annular injection in this well. · Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal, in addition, haul all cuttings from drilling operations to CC-2A for disposal, except any metal cuttings which will be sent to the North Slope Borough. SUMMARY SIDETRACK PROCEDURES Pre-Riq Work 1. Pull the 4 1/2" SSSV. Valve is set at 2143' MD. 2. Shoot as many holes as possible in the tubing above the IBP and below the packer from 11,670' to 11,636'. 3. Perform a cement P&A of 15.8 ppg class 'G' cement with adequate cement volume to cover the 7" liner from PBTD at 12,209' to a minimum of 100' above the top perforation at 11,987' plus squeeze 5 bbls to the perforations. Estimated cement volume needed is 17 barrels. A CTU or full bore P&A is at the discretion of the Wells Group - bear in mind there is a 2.687" ID tubing patch at 11,560'. Note: Top of cement must be at a minimum of 11,887' for AOGCC compliance. Top of cement may extend into the tubing as long as it does not interfere with the tubing cutting operations. 4. Rig up slickline and tag and document top of cement. 5. Cut the 4 1/2" IPC L-80 tubing in the middle of the full joint of tubing below the bottom GLM(bottom GLM @ 10,459'; estimated cut depth @ 10,489'). This cut will not be fished and is at the discretion of the Wells Group as to chemical or jet cut. 6. Test the Gray 9-5/8" mandrel packoff and Gray tubing hanger to 5000 psi for 30 minutes. 7. Test the casing against the cement plug to 3000 psi for 30 minutes. Freeze protect top 2200' MD with diesel. 8. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. Secure well. 9. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. Riel Operations' 1. MIRU Nabors 22E , 3. 4. 5. . 7. 8. 9. 10. 11. 12. 13. Circulate out freeze protection. Set TWC. Nipple down tree. Nipple up and test BOPE. Pull 4-1/2" tubing. Rig up e-line. Run a 8.50" gauge ring /junk basket to 10,200'. Run and set a 9-5/8" bridge plug at 10,100'. RIH with 9-5/8" Baker section mill assembly and mill a 50' window from 9800' to 9850'. Cement 50' section from 100' below to 200' above from 9600' to 9950' md. Kick-off drilling the 8-1/2" intermediate section to TSag @ _+11,570' md(8940' TVD). Run and fully cement a 7", 26# intermediate liner with a minimum of 150' liner lap in the 9-5/8". Test the 7" and the 9-5/8" casing from the 7" landing collar to surface to 3000 psi for 30 minutes. Drill the 6" production section building to horizontal targeting the Zone 4 sands(9002' TVD, 8928' TVDss) to an estimated depth of 13,624' md(9044' TVD, 8970' TVDss). Run DPC 'Platform Express' + Sonic logs from horizontal to 7" shoe. Run and fully cement a 4-1/2", 12.6# production liner with a minimum of 150' liner lap in the 7". DS 13-08A Permit to Drill 4 14. Test the 4-1/2", 7" and 9-5/8" casing from the 4-1/2' landing collar to surface to 3000 psi for 30 minutes. 15. The 4-1/2" production liner will be perforated with DPC 2.75" guns on a 200 psi under balance. Perforating intervals to be determined after reviewing logs. 16. Run 4-1/2" completion tying into the 4-1/2" liner. 17. Test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 18. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 19. Freeze protect the well to -2200' and secure the well. 20. Rig down and move off. Estimated Pre-rig Start Date: Estimated Spud Date: 10/16/98 11/07/98 C. Michael ;Jackson 564-5486 10/12/98 DS 13-08A Permit to Drill 5 Ihska District 1111 l~t 80th lwnu~ ~n~_c~ar_~a~, RE 99518 ~11 .........: DS13-Dil (PIOA) Field ........ : Prudhoe Bay Ccuputatton,.: Minimmm Curvatmr~ Units. ....... : FEET Slh-face Lat..: ?0.21766689 Surface kacj.: 148.4885255!) Surface ...... : I408 ~ 5150 ~ Tic-in surwy: 3237 ~L 1856 ~ 824 TI(IW Tarot Start.: 1591 BI, 2~9g IEI, S24 Y~t High Pt.,: 1498 ~SL 2130 1~ ~ YI~ ll4E US Bi~ .......... : 2o2 ~[, 2567 ~ s24 It3CITIOMS - ~ Zone: 4 X-Coord ?-Coati 687359,48 5931478.84 690740,80 5928111,83 690539.71 592~V:,9.00 690510.83 5926366,40 6g0107.0{) 5925060,00 Vert sect az.: 198.60 KB elevatioo.: 74,3S ft Scale Factor.: 0,99993988 Oxr, m,_rge~c~..: +1.42231289 55,2r5 146.00 7630,26 l~r~.gl 55.70 I46.04 7632.32 7557,97 49,29 152.07 7692).21 -3c61-g2-g6 43,25 159.34 7762,35 7688.08 40.16 164,04 7803.35 7729.00 $ICCT1C~ (X3(3~IIg,.TES-FBOK )l~q~ ~ 4 ~ DI/ I)~l.~ ~ X Y ~ I00 ~18.32 ~.I0 S ~.91 g 6~7~.~5~Ill.a t4~ ¢~ 2220,15 34~,~ S 3~,~B 6~7~,~ ~.~ t~R 1.50 227t,~ 3~.~S 3339,49 g 6~7~.~ ~.~ t4~ 8.00 2324,10 3~,10 S 3~,38 E ~.~ ~2~7.~ 13~ 8,00 10100.08 1017§,B7 lOBO0.O0 131.76 168.36 1838.41 7764.06 34,t9 175,70 7899,83 7825.48 34.19 176. T0 8301.41 8227,06 35.~ 151.I1 8333,02 ~,67 41.18 1~o86 84tl.25 8336,90 2377.17 3648.26 S 3387.67 'E690836.46 5927916.00 13(}R 8.00 2417.07 3692.35 S 3393,59 Ii690843.41 592782'2.08 261B.25 3964.76 $ 3i~.28g 69Q865.91 5927600,15 57R 0.00 2691,14 3986.94, $ 34U9.69 E f~866.87 592~52r8,00 53R 8.00 2751,87 4048.73 ;S 3402.90 g , 690861,62 5927516,06 46R 8,00 B&CU 10B98.97 47.00 (lnadrill (c)98 13081P10 3.2(2 ~2:45 ~ {)) 198,60 8482,35 8408.00 2820.46 41t5.14 S 3385.1g ~ 690~5.56 5927449.23 ES 8.00 ,, II[~fr!YIC~I0~ [IEP]2{ ~ L2IMl~ YVI) Y,0B-~ []~L~ {(~ZLli]~K) X ¥ ~'.A:~ 100 EXI) 8/100 1~,97 47.00 ~ ~ Ll280.20 4t,00 ?S&(; 11.%3.1g 47.00 7" C]~SI~ P~ I1570.53 41.00 ~ ~~ I~T 115;1.99 47.00 198.68 8482,35 8408.~ 2~20.~6 4/15,14 $ 3385,19 g 690845.56 5927449.23 ~ 8,00 198.60 87~,35 8568.00 3099.27 07g-.39 S 3296.26 g ~0753.22 5gD'I82.87 1~ O.OO 198.68 89t5.35 8861.80 3306.24 ~1'5.55 $ 3230,25 l~ 69070~.10 5926g~.15 ~ 0,08 198.60 8940.35 8866.00 3311.60 ~.63S 3228,54 g 690700.52 592~.02 ~ 0,~0 198.68 8941.35 8867.50 3312.67 4581.64S 3228,20 ~ 690700.20 ~26979.00 RS 0,80 16/lOO lt581.gg 47.00 198.60 8948.17 8:8?3.82 3319.99 4588.585 3225.86I~ 6g0698.04 11595.74 19.20 198.60 8957.15 888~.0~ 3330.22 1598.27 $ 3222.6(1I~ 6g0695.02 59~962.24 l~ 16.00 11600.00 49.88 198.60 8950.11 8885.76 3333.46 4601.35 $ 3221.57 l~ 690694.86 5926~.N ~ 16.80 11650.{30 57.88 t98.60 8989.56 8915.21 3373.82 4639.59 S 3208.69 Z 690682.14 5926920.59 ]~ 16,00 t1675,52 61.96 198.60 9002.3,58928.0{] 3395.90 4660.52 S 3~t.65 R 69067'5,62 5926~.50 ES 16.00 117~,00 65.88 198.68 90/3.11 8938.76 3417.88 4681.36 $ 3194.64 E 6g066g. t3 5926878.49ES 16.00 11756,00 73.8B 198.60 9030.29 8955.94 3464.79 4725.825 3179.681~ 690655,28 5926833.~ ~ t$,80 11800.80 81.88 I98.60 9040.78 8966.4~ 3513.64 4772.11 $ 3164.1~ B 690640.85 5926787.01 KS I6,00 I1850.0D 89.88 198.60 9044.37 8978.02 3563,,47 4819.345 3148.26 B 690626.14 5926739.41 ES 15,~0 11850.7'4 90.00 198,60 9044.37 8970.02 3564,21 4828.04..q 3147.97 ~ 6c~.92 5926?38.70 RS 16,00 11900.00 97,88 198.60 9010.99 8966.64 3613,31 4866.58 S 3132.31 i{690611.42 5cJ26691,Tg~ 16,00 gZa) 16/100 ' 11943.63 104.86 198.68 9032.39 8958.04 3656.~ 4907.10,5 3118.6{' g690598.79 ~,95 ]iS 16,00 -- ~ ,~-- 12150.43 104.86 198,68 8979.35 8905.00 3855.94 5096;53.5 3054.92 ]:690539.77 592:6460,00LS 0,~ £11t~ t5/100 12L50.43 10~4,86 198.60 8':Y/9.35 8905.00 3855.94 5096,~ $ 30r~.92 g 690539.77 592f,450,00 12200.00 97'.43 198.6(1 8969.~8 8895.43 3904.54 5142.60,5 3039.42 ]: 690525.41 5926413,51 L5 1:5.00 .. 12249.51 90.00 198.60 8966.57 8892,22 3953.91 5189.395 3023.6'/ g690510.83 5926366.40 t,S 15,00 12251}.00 89.93 198.60 8966,5? 8892,22 3954.40 5189.86S 3023,5t ]:690511).69 592:6365.93 L5 I5.00 12300.00 82.43 198.60 :8969,908895,55 4004.26 523t.ti $ 3807,6I Il '69049537 59263Z8.30 t,S 15,00 12323.29 }'8.93 198.60 8973.67 8899.32 4021r.23 5258.888 3000,28 {: 690489,18 5926296.35 BS 15,~0 t2677.64 78.93 198.60 9041.69 8967.34 4374.99 5588.48,.q 2889,37 ~ 69038~.4~ 5925~.13 BS 0,00 I2700.0g 81.11 198.60 9045.56 8971.21 4397'.~ 5609.358 2882.34 R 69037938 5925943.88 BS 10,00 12788.31 90.00 198.60 9052.35 8978.00 4484.98 5692.72~ 2854,2g g 690354.00 5925859.05 ~ 10,0~ 1.2793,8Q 90,55 198.60 9052..3289??.cj7 4490,48 5697.935 2852,53 g ,690352.3.8 5925853,80 (Anadrtll [0)98 1308XYlO 3.2C 12:45 DS13-OB^ (P1DA) VERTICAL SECTtDN VIEW Sect{~ at: lgB. BO TVD~le., I Inch- 500 feet Oep ScoI~, 1 t~h = 500 0~ ..... : O~S~p lgg~ r DS ! 3-OB^ (P IOA) PLAN VIEW ....... ,--- .... --t w .... IA- _ ......... -- ......... '- --' CLOSLJRE ..... ~ ~83 fmet at Azimuth 158. 25 ~ECLINATION., -27.95§ (E) 'SCALF~ ...... : ! ln=h = §00 feel; DRAM ...... : 02 S~p lg§fl EAST ~" Well: 13-08 Spud Date:10-03-81 Original RKBE:78' Top of Formation: 12132' Annular Fluid:Diesel/9.6 NaC1 Reference Log:BHCS ARCO Alaska, Inc. - Prudhoe Bay API #:50-029-20667-00 Completion:10-29-81 Hanger Type:Gray Max Hole Angle: 58° @ MD: 10700' Date:10-23-81 Tie In: Ann. Comm: LDL 10/11/95 Indicates Leak @ Lower Element of Patch Type: PRODUCER Status: New Hanger: 27 ' Angle 8 TS:49° Angle @ TD:58° Date: 00-00-00 ALL DEPTHS A~tE lq/{B DRILLING MI) TO TOP OF EQUIPME[TT EXCEPT WHERE NOTED. , SSSV = CAT #2 J ,~ewe].r~' (,~) I SSSV = CAT#2 " Depth DescriDtion 1 2143' 4-1/2" Otis DBE SSSV Nipple ID=3.813" 2 11560' 4-1/2" Alpha Soft Set Tubing Patch (Set 03/12/94) ID=2.687" 3 11617' 4-1/2" BOT PBR Assembly 4 11636' 9-5/8" x 4-1/2" BUT 3-H Packer 5 11710' 4-1/2" Otis XN Nipple ID=3.725" J-1 6 11709' 4-1/2" BOT Shearout Sub 7 11711' 4-1/2" Tubing Tail 0-1 11708' ELM Tubing Tail-(Logged 01/18/86) 9 12209' Cement (Tagged 04/09/94) 10 11670' IBP (Set 10/15/95) ID=0.001" Min ID: 4-1/2" Alpha Soft Set Tubing Patch (Set 03/12/94) ID=2.687" G-1 J-2 J-3 J-4 J-10 Casing and Tubing (C) Size Weight grade 1 13-3/8" 72# L-80 2 9-5/8" 47# L-80 3 7" 29# L-80 4-1/2" 12.6# L-80 ToD Bottom Description 0' 2385' Casing 0' 11990' Casing 11677' 13195' Liner 0' 11711' Tubing-PC Gas Lift Information MD TVD Stn Mandrel 2948' (2945') 1 OT CA 5319' {4926') 2 OT CA 7292' (6059 ') 3 OT CA g-5 8157' (6555') 4 OT J-6,7 8850' (7006') 5 OT 0-2 9596' (7512') 6 OT 10459' (8015') 7 OT P-1 11352' (8509') 8 0T CmtTop @ Perforation Data (ELM DEPTHS) (P) Interval Zone FT SPF 1 11987-12015 SAG 28 0 12135-12155 4 20 4 12155-12174 4 19 0 12184-12204 4 20 0 12206-12214 4 8 0 12218-12228 4 10 0 12232-12246 4 14 0 12209' J-9 Valve ~2pe RD T-2 RD T-2 RD OT RD-lo5 RA OT RD-1.5 RM CA RD T-2 0T RD-1.5 RA CA RD T-2 Latch Port TRO Date 09-16-95 03-25-94 09-16-95 09-16-95 09-16-95 Date Comments 06-03-94 SQZ - LARC -06-30-94 RPERF 06-03-94 SQZ - LARC 06-03-94 SQZ - LARC 03-28-94 SQZ 03-28-94 SQZ 03-28-94 SQZ C-3 FRAC 07/04/94 BALL SEALER TREATMENT 03/04/89 Datum 8700' SS=11790' MD PBTD=13150' 8800' SS=11949' MD TD=13200' Revision Date: 07-16-96 by ENH Reason: SSSV = CAT#2 Previous Reason: 10-22-95 Well 13-08 i DS 13-08 Pre-Ri(] Plu(] & Abandon ~.~ ~ 4-112" Otis 'DBE' SSSV Nipple :~'~::~: (3.8~3' ID) Freeze Protection I ~tO0' I~ L GLM S~flons: ~ 1) 2~' L2) 5319' ~ ~ 3) 7~2" ~. s) 8~' ' ~ 6) 95~' 4-1/2", 12.6~, L~° BTO IPO Tubing , ~ i L ; ~atch ID ~ ~ o oJ~ ~~ 11'636'19~8" x '1~" BOT '3-H' Packer Pe~o~tlons ~ I , 1 Minimum Top of Ce~nt 111,887I I~  ~ 11,98~-12,015'  ~ 12,135'-12,t~' 12,15~ - 12,174' 12,1~' - 12,2~' 12,2~' - 12,209' ~:'~¥:[~ j 12,2~'- 12,214' J~:~:~? 12,218' - 12,228' 12,232' - 12,2~' 7', 29~, L-80 . i, DATE REV. BY COMME~S , PRUDHOE BAY UNIT 10/~/98 CMJ Proceed Pre~lg Cond~i~ WELL: DS 13-~A APl NO: 5~02~ 20667-00 . ARCO Alaska Inc. · - DS 13-08A r 4~ 'reposed Completion ~?:!~:~i.;: DS 13-08 Wellhead: B F / MSL = 46.11' ?¢:i.i?: . 'X' Nipple @ 2000' L -- 6 Gas Lift Mandrels 4-1/2", 12.6~, 13Cr-80 Tubing , ~ , ~ 19'518'', 47# L'80 BTC Casing {/3 From ~' to 10,533' ~3~ , ¢3. ~ 9-5/8", 47# SOO-95 BTC Casing ~. From 10,533' to 11,990' · i ~ ~ ~ 7", 26~ L-80 BTC-Mod Liner Top ;. 9-5/8" Milled :;il. d ~ ~ectlon from !.?-.:~. '~::,.-.',.~. . 9800'to9850'i~:!':~~~i 7 x4.5"BakerPacker 111,370 I ::i~i~:.:'~ "~!;i!i~4-112", 12.6~ L-80 IBT-Mod Production Liner Top 1'~,420' , ~ ~___ -;~AA~rS~.Eoe @ TSag J11,570'} 4-1/2" Shoe '[ -- · [ ~ TSag r. in 4-1/2" : ' Liner :?::'i":i:??:~:~:.:.':.:~!~--IMinimum Top of CementI '?T'P~:.i:::!iSqz'd Perforations: , DATE REV. BY COMMENTS PRUDHOE BAY UNIT 10~05~98 CMJ Proposed Completion WELL: 13-08A APl NO: 50-029-20667-01 SEC 18: T10N: R14E Arco Alaska Inc DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET HANDLINQ INST- fi/H TERRI HUBBLE ×4628 · WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION 1. COMPANY /~'~_..-/'~ WELL NAME,~f/_ /L'~ '"(:~',~.. PROGRAM: exp [] dev~/redrll~serv [] wellbore segl, ann. disposal para reqll INIT CLASS _/"~_~'~c/ 7-'~,/? GEOL AREA v.~~ UNIT, /,"/~._~'~..~ ON/OFF SHORE ~.~_._i_' , 3. 4. 5. 6. 7, 8, 9. 10, 11. ?-'~R DATE / .. 12, . _ lqn W. Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper dislance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficienl acreage available in drilling unil ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING APPR 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMl' vol adequate to circulate on conductor & surf csg ..... 17. CMl- vol adequate to tie-in long string to surf csg ........ 18. CM[ will cover all known productive horizons .......... ~ N 19. Casing designs adequate for C, T, B & permafrost ....... (~ N 20. Adequate tankage or reserve pit ................. (.~ N 21. If a re-drill, has a rl0-403 for abandonment been approved... 22. Adequate we,bore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ (~ N 26. BOPE press rating appropriate; test to _5'-~Oc~ psig. ~¢) N 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY DATE/ ¥ N ¥ N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y NJ~I~ I (~N N N 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... Y./N 32. Seismic analysis of shallow gas zones. ' 33. Seabed condition survey (if off-shore) ............. 34. Contact namelphon.e.for weekly progress reports ...... ~ Y N [exploratory only] ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receivipg zone; ....... (B) will not contaminate fre~water;pr~use drilling waste... Io surface; (C) wii[~i~timpair._mechanic~y of the well used for disposal; (D) will nol damage Produ/F.~fig formati'On-er_impair recovery from a pool; and (E) will not circumv~~,A,C' 25,2.52 o.r 20 AAC 25.412.~, , , GEO_I~G_Y: ENGINEERING: ~/A. r~lar COMMISSION: co 1 Y N Y N 7--0 ~___~C.._~ Y N Y N Y N Comments/Instructions: Mcheklisl rev 05129198 rltf C ~nl'~¢)fh('<~\wol('Jin~l~d~al i;l\, hi-H I, Imf Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Fri Jun 04 09:37:51 1999 Reel Header Service name ............. LISTPE Date ..................... 99/06/04 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 99/06/04 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 3 AK-MM-90006 PIEPER K. WHITE 13-08A PB2 500292066771 ARCO ALASKA, INC. SPERRY-SUN DRILLING. SERVICES 04-JUN-99 13 i0N 14E 1409 130 74.50 74.50 29.10 RECEIVED , !! 1N 0 8 1999 ;-,Jaska Oil & Gas Cons. Commission Anchorage WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 9.875 9345.0 PRODUCTION STRING 8.500 11181.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 CONTAIN NO VALID DATA AND ARE NOT PRESENTED. 3. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PH3~SE-4 (EWR-4) . 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN MARSHALL MUNYAK OF SPERRY-SUN DRILLING SERVICES AND DEDE SCHWARTZ OF ARCO ALASKA, INC. ON 03 J73NE, 1999. SPERRY-SUN MWD DATA IS CONSIDERED PRIMARY DEPTH CONTROL (PDC) FOR WELL 13-08A PB2. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF lll81'MD, 8682'TVD. SROP = SMOOTHED P~ATE OF PENETP~ATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FET 9345 0 RPD 9345 0 RPM 9345 0 RPS 9345 0 RPX 9345 0 GR 9345 0 ROP 9348 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: 11146 5 11146 5 11146 5 11146 5 11146 5 11132 5 11181 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 9345.0 11181.0 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 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 RPX MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPM MWD OHMM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 ROP MWD FT/H 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Min DEPT 9345 GR 56.74 RPX 0.49 RPS 0.2 RPM 0.32 RPD 0.69 ROP 0.06 FET 0.24 Max 11181 407 85 9 58 8 69 7 93 1506 56 2520 97 13 26 First Last Mean Nsam Reading Reading 10263 3673 9345 11181 161.424 3576 9345 11132.5 2.24603 3604 9345 - 11146.5 2.33956 3604 9345 11146.5 2.43908 3604 9345 11146.5 4.0226 3604 9345 11146.5 98.6007 3667 9348 11181 3.1718 3604 9345 11146.5 First Reading For Entire File .......... 9345 Last Reading For Entire File ........... 11181 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/04 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 ....... 99/06/04 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 9345.0 11146 5 RPD 9345.0 11146 5 RPM 9345.0 11146 5 RPS 9345.0 11146 5 RPX 9345.0 11146 5 GR 9345.0 11132 5 ROP 9348.0 11181 0 $ LOG HEADER DATA DATE LOGGED: 30-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2 DOWN-HOLE SOFTWARE VERSION: VARIOUS DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 11181.0 TOP LOG INTERVAL (FT) : 9345.0 BOTTOM LOG INTERVAL (FT) : 11181.0 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 EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTP~ATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA/XTDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 40.1 48.8 TOOL NUMBER Pl169HWGVR6 Pl169HWGVR6 8.500 8.5 LSND / Bk~AS~, 10.30 70.0 12.0 30000 2.4 .130 .070 .090 .200 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 API 4 1 68 8 3 RPX MWD 3 OHMM 4 1 68 12 4 RPS MWD 3 OHMM 4 1 68 16 5 RPM MWD 3 OHMM 4 1 68 20 6 RPD MWD 3 FET MWD 3 OHMM HOUR 1 68 1 68 24 28 Name Min DEPT 9345 ROP 0.06 GR 56.74 RPX 0.49 RPS 0.2 RPM 0.32 RPD 0.69 FET 0.24 Max 11181 2520 97 407 85 9 58 8 69 7 93 1506 56 13 26 Mean 10263 98.6007 161.424 2.24603 2.33956 2.43908 4.0226 3.1718 Nsam 3673 3667 3576 3604 3604 3604 3604 3604 First Reading 9345 9348 9345 9345 9345 9345 9345 9345 Last Reading 11181 11181 11132 5 11146 5 11146 5 11146 5 11146 5 11146 5 First Reading For Entire File .......... 9345 Last Reading For Entire File ........... 11181 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/04 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/06/04 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/06/04 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Tue Jun 08 13:54:51 1999 Reel Header Service name ............. LISTPE Date ..................... 99/06/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 99/06/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT ~n/~ LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MM- 90006 R. KRELL K. WHITE RECEIVED JUN 1 7 1999 ~aska ~1 & Gas Cons. Comn'Js$~n 13-0SA 50029206670~ SPERRY-SUNDRILLING SERVICES 08-JI/N-99 MWD RUN 5 MWD RUN 6 AK-MM- 90006 AK-MM-90006 B. ZIEMKE B. ZIEMKE C. DIXON C. DIXON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MWD RUN 7 AK-MM-90006 B. ZIEMKE C. DIXON MWD RUN 8 AK-MM- 90006 B. ZIEMKE C. DIXON 13 10N 14E 1409 FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 130 74.50 74.50 29.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 9.875 8986.0 3RD STRING 8.500 7.000 11374.0 PRODUCTION STRING 6.000 13800.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) U1FLESS OTHERWISE NOTED. 2. MWD RUNS 1,2 AND 3 CONTAIN NO VALID DATA AND ARE NOT PRESENTED. 3. MWD RUNS 4,5, AND 7 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4) . 4. MWD RUN 6 IS DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 6. MWD RUN 8 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), AND STABILIZED LITHO DENSITY (SLD). 7. A CHANGE OF GAMMA RAY TOOL OCCURRED AT 11336'MD' 8902'TVD (DGR TO NGP) AND AGAIN AT ll600'MD, 9034'TVD (NGP TO DGR) . 8. STABILIZED LITHO DENSITY (SLD) DATA FROM 11364'MD, 8922'TVD TO 12434'MD, 9025'TVD WAS MEASURED AFTER DRILLING (MAD) WHILE TRIPPING INTO THE HOLE FOR MWD RUN 8. 9. MWD DATA IS DEPTH SHIFTED/CORRECTED USING SWS CNT GR LOGGED IN PARENT WELLBORE 13-08 IN 1981. DEPTH REFERENCE KBE=78~00. 10. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13800'MD, 9034'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED GAMMA RAY. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED. SCO2 = SMOOTHED STANDOFF CORRECTION. SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: HOLE SIZE= MUD FILTRATE SALINITY= MUD WEIGHT= FORMATION WATER SALINITY= FLUID DENSITY= MATRIX DENSITY= LITHOLOGY= $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 6 w! 21500 PPM. 8.7 PPG. 11500 PPM. 1.o G/CC 2.65 G/CC SANDSTONE Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 8898.0 FET 8990.5 RPD 8990.5 RPM 8990.5 RPS 8990.5 RPX 8990.5 ROP 8990.5 PEF 11379.5 DRHO 11379.5 RHOB 11379.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 8898.0 8900 8906.5 8908 8914.5 8916 8920.0 8921 8921.5 8922 8924.0 8925 8934.5 8933 8939.0 8936 8941.0 8940 8944.5 8942 8946.5 8944 8952.0 8946 .0 .5 .5 .5 .5 0 5 5 0 5 5 5 all bit runs merged. STOP DEPTH 13759.0 13765.5 13765.5 13765.5 13765.5 13765.5 13804.5 13729.5 13729.5 13729.5 EQUIVALENT UNSHIFTED DEPTH 8955 8956 8958 8960 8962 8964 8967 8970 8975 13804 $ 0 895O.O 0 8951.0 5 8953.5 5 8955.5 5 8957.5 0 8960.5 5 8963.0 .0 8965.0 .5 8971.0 .5 13800.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 4 MWD 5 MWD 6 MWD 7 MWD 8 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP MERGE BASE 8986.0 10693.0 10693.0 11374.0 11374.0 11653.0 11653.0 12414.0 12414.0 13800.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset DEPT FT 4 1 68 0 ROP MWD FT/H 4 1 68 4 GR MWD API 4 1 68 8 RPX MWD OHMM 4 1 68 12 RPS MWD OHMM 4 1 68 16 RPM MWD OHMM 4 1 68 20 RPD MWD OHMM 4 1 68 24 FET MWD HOUR 4 1 68 28 RHOB MWD G/CC 4 1 68 32 DR/40 MWD G/CC 4 1 68 36 PEF MWD BAR/~ 4 1 68 40 Channel 1 2 4 5 6 7 8 9 10 11 Name Min Max Mean Nsam DEPT 8898 13804.5 11351.2 9814 ROP 0.62 1901.94 96.7134 9629 GR 19.02 795.32 97.2194 9723 RPX 0.4 2000 13.0923 9497 First Reading 8898 8990.5 8898 8990.5 Last Reading 13804.5 13804.5 13759 13765.5 RPS RPM RPD FET RHOB DRHO PEF 0 47 0 51 0 45 0 17 0 77 -0 85 1 18 2000 14.7537 9497 2000 9.06697 9497 2000 13.6545 9497 179.06 6.87148 9497 4.53 2.36701 4701 2.25 0.0348436 4701 14.18 2.2337 4701 8990.5 8990.5 8990.5 8990.5 11379.5 11379.5 11379.5 13765.5 13765.5 13765.5 13765.5 13729.5 13729.5 13729.5 First Reading For Entire File .......... 8898 Last Reading For Entire File ........... 13804.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/08 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 ....... 99/06/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE N-UMBER: 2 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH STOP DEPTH 8900.0 10648.0 8986.0 10657.5 8986.0 10657.5 8986.0 10657.5 8986.0 10657.5 8986.0 10657.5 8986.0 10692.5 07-DEC-98 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 EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPER3kTURE (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 STAlqDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical lo9 depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 INSITE 3.2 VARIOUS MEMORY 10693.0 8986.0 10693.0 35.7 45.5 TOOL NUMBER l180HWGVR6 1180HWGVR6 8.500 8.5 LSND 9.50 50.0 9.6 800 5.6 1.300 .662 1.200 1.400 58.9 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 'GR MWD 4 API 4 1 68 4 2 RPX MWD 4 OHMM 4 1 68 8 3 RPS MWD 4 OHMM 4 1 68 12 4 RPM MWD 4 OHMM 4 1 68 16 5 RPD MWD 4 OHMM 4 1 68 20 6 FET MWD 4 HOUR 4 1 68 24 7 ROP MWD 4 FT/H 4 1 68 28 8 Name DEPT GR RPX RPS RPM RPD FET ROP Min 8900 43 54 0 53 0 52 0 54 0 55 0 17 0 89 First Max Mean Nsam Reading 10692.5 9796.25 3586 8900 406.71 146.172 3497 8900 17.13 2.39136 3344 8986 2000 3.62621 3344 8986 2000 4.244 3344 8986 2000 6.05142 3344 8986 7.67 1.03531 3344 8986 430.95 100.835 3414 8986 Last Reading 10692.5 10648 10657.5 10657.5 10657.5 10657.5 10657.5 10692.5 First Reading For Entire File .......... 8900 Last Reading For Entire File ........... 10692.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/08 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 ....... 99/06/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NIIMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10648.5 11336.0 FET 10658.0 11345.5 RPD 10658.0 11345.5 RPM 10658.0 11345.5 RPS 10658.0 11345.5 RPX 10658.0 11345.5 ROP 10693.0 11374.0 $ 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 EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (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): 09-DEC-98 INSITE 3.2 VARIOUS MEMORY 11374.0 10693.0 11374.0 39.6 43.8 TOOL NUMBER 1180HWGVR6 ll80HWGVR6 8.500 8.5 LSND 10.10 47.0 8.9 800 3.7 1.300 1.230 1.200 1.400 21.7 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 5 API 4 1 68 RPX MWD 5 OHMM 4 1 68 RPS MWD 5 OHMM 4 1 68 RPM MWD 5 OHMM 4 1 68 RPD MWD 5 OHMM 4 1 68 FET MWD 5 HOUR 4 1 68 ROP MWD 5 FT/H 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 10648.5 11374 11011.2 1452 GR 62.64 306.13 131.556 1376 RPX 1.27 17.3 2.13841 1376 RPS 1.26 19.11 2.1931 1376 RPM 1.28 18.43 2.2148 1376 RPD 1.27 19.82 2.2808 1376 FET 0.27 18.12 1.79152 1376 ROP 2.88 608.27 76.1681 1363 First Reading 10648.5 10648.5 10658 10658 10658 10658 10658 10693 Last Reading 11374 11336 11345.5 11345.5 11345.5 11345.5 11345.5 11374 First Reading For Entire File .......... 10648.5 Last Reading For Entire File ........... 11374 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11336.5 ROP 11374.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11598.5 11653.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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: 13 -DEC-98 INSITE 3.2 VARIOUS MEMORY 11653.0 11374.0 11653.0 45.2 83.2 TOOL NUMBER NGP SPC 278 6.000 6.0 LSND 8.60 78.0 9.3 20000 7.5 .000 .000 .000 .000 49.5 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 API 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11336.5 11653 11494.8 634 11336.5 GR 27.65 795.32 106.01 525 11336.5 ROP 2.36 432.95 50.8432 558 11374.5 Last Reading 11653 11598.5 11653 First Reading For Entire File .......... 11336.5 Last Reading For Entire File ........... 11653 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEA]DER FILE NLIMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE ST/LRT DEPTH STOP DEPTH FET 11373.0 12376.0 RPD 11373.0 12376.0 RPM 11373.0 12376.0 RPS 11373.0 12376.0 RPX 11373.0 12376.0 GR 11601.5 12368.5 ROP 11653.5 12414.0 $ 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 EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : 14-DEC-98 INSITE 3.2 VARIOUS MEMORY 12414.0 11653.0 12414.0 82.6 98.8 TOOL NUMBER P1043GR4 P1043GR4 6.000 6.0 QUIK DRILN 8.70 64.0 9.3 21000 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .6 .180 .130 .160 .220 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 7 API 4 1 68 RPX MWD 7 OHMM 4 1 68 RPS MWD 7 OHMM 4 1 68 RPM MWD 7 OHMM 4 1 68 RPD MWD 7 OHMM 4 1 68 ROP MWD 7 FT/H 4 1 68 FET MWD 7 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean DEPT 11373 12414 11893.5 GR 20.29 418.97 49.1787 RPX 0.4 2000 42.707 RPS 0.47 2000 46.5135 RPM 0.51 1719.32 18.5643 RPD 0.45 2000 35.9574 ROP 0.62 371.05 71.8623 FET 0.54 179.06 25.0339 Nsam 2083 1535 2007 2007 2007 2007 1522 2007 First Reading 11373 11601.5 11373 11373 11373 11373 11653.5 11373 58.9 Last Reading 12414 12368.5 12376 12376 12376 12376 12414 12376 First Reading For Entire File .......... 11373 Last Reading For Entire File ........... 12414 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... version Number ........... 1.0.0 Date of Generation ....... 99/06/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PEF 11375.0 13725.0 DRHO 11375.0 13725.0 RHOB 11375.0 13725.0 GR 12370.5 13754.5 FET 12377.5 13761.0 RPD 12377.5 13761.0 RPM 12377.5 13761.0 RPS 12377.5 13761.0 : RPX 12377.5 13761.0 ROP 12414.5 13800.0 $ LOG HEADER DATA DATE LOGGED: 17-DEC-98 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2 DOWNHOLE SOFTWARE VERSION: VARIOUS DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 13800.0 TOP LOG INTERVAL (FT) : 12414.0 BOTTOM LOG INTERVAL (FT) : 13800.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 81.5 MAXIMUM ANGLE: 94.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER P1043GR4 P1043GR4 P1043GR4 6.000 6.0 LSND 8.70 64.0 9.0 21500 6.6 · 160 .130 .130 .250 91.1 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 API 4 1 68 4 2 RPX MWD 8 OHMM 4 1 68 8 3 RPS MWD 8 OHMM 4 1 68 12 4 RPM MWD 8 OHMM 4 1 68 16 5 RPD MWD 8 OHMM 4 1 68 20 6 FET MWD 8 HOUR 4 1 68 24 7 ROP MWD 8 FT/H 4 1 68 28 8 RHOB MWD 8 G/CC 4 1 68 DRHO MWD 8 G/CC 4 1 68 PEF MWD 8 BARN 4 1 68 32 9 36 10 40 11 Name Min Max Mean DEPT 11375 13800 12587.5 GR 19.02 141.48 43.5143 RPX 2.81 21.56 9.9979 RPS 3.11 21.49 11.4186 RPM 3.37 20.36 11.4152 RPD 4 20.96 12.3267 FET 0.35 52.47 3.27352 ROP 1.29 1901.94 124.618 RHOB 0.77 4.53 2.36701 DRHO -0.85 2.25 0.0348436 PEF 1.18 14.18 2.2337 First Last Nsam Reading Reading 4851 11375 13800 2769 12370.5 13754.5 2768 12377.5 13761 2768 12377.5 13761 2768 12377.5 13761 2768 12377.5 13761 2768 12377.5 13761 2772 12414.5 13800 4701 11375 13725 4701 11375 13725 4701 11375 13725 First Reading For Entire File .......... 11375 Last Reading For Entire File ........... 13800 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/06/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/06/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File