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Home My WebLink About190-009MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:33 Township:13N Range:10E Meridian:Umiat Drilling Rig:N/A Rig Elevation:N/A Total Depth:6,182 ft MD Lease No.:ADL0025906 Operator Rep:Suspend:P&A:X Conductor:13-3/8"O.D. Shoe@ 105 Feet Csg Cut@ Feet Surface:9-5/8"O.D. Shoe@ 3,274 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 6,157 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:2-7/8 O.D. Tail@ 3,928 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Balanced 743 ft 300 ft 9.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1655 1587 1569 IA 1667 1597 1579 OA 1659 1594 1577 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: AOGCC approved Combination MIT-TxIAxOA for surface plug per Mel Rixse (AOGCC). Operator reported the tag was at 300 ft witnessed by Guy Cook 9/1/2025. Operator included email approval from Mel for my review. September 5, 2025 Sully Sullivan Well Bore Plug & Abandonment MPU I-01 Hilcorp Alaska LLC PTD 1900090; Sundry 325-128 none Test Data: P Casing Removal: Matt Ross Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0905_Plug_Verification_MPU_I-01_ss                   MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:33 Township:13N Range:10E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:6182 ft MD Lease No.:ADL0025906 Operator Rep:Suspend:P&A:X Conductor:13 3/8"O.D. Shoe@ 105 Feet Csg Cut@ Feet Surface:9 5/8"O.D. Shoe@ 3274 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 6157 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:2 7/8"O.D. Tail@ 3928 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Perforation Balanced 700 ft 300 ft 15.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1740 1638 1585 IA 1748 1646 1593 OA 19 19 18 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Pollard Wireline ran 100 pounds of toolstring with a 5-foot drive down bailer with a mule shoe and a ball valve. Tagged cement at 300 ft MD. The bailer brought back good cement. During the CMIT-TxIA, 0.25 bbls was pumped in and 0.2 bbls was recovered after the test. September 1, 2025 Guy Cook Well Bore Plug & Abandonment MPU I-01 Hilcorp Alaska LLC PTD 1900090; Sundry 325-128 None Test Data: P Casing Removal: Matt Ross Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0901_Plug_Verification_MPU_I-01_gc                     Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 08/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250807 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 6/26/2025 AK E-LINE PPROF T40741 BCU 25 50133206440000 214132 7/16/2025 AK E-LINE Plug/Cement T40742 BRU 211-35 50283201890000 223050 6/11/2025 AK E-LINE Perf T40743 BRU 211-35 50283201890000 223050 6/20/2025 AK E-LINE PPROF T40743 BRU 213-26 50283201920000 223069 7/7/2025 AK E-LINE Perf T40744 BRU 213-26T 50283202040000 225038 7/2/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 7/4/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 6/28/2025 AK E-LINE Perf T40745 BRU 241-23 50283201910000 223061 7/18/2025 AK E-LINE Perf T40746 GP 11-13RD 50733200260100 191133 6/2/2025 AK E-LINE PPFROF T40747 KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF T40748 MPU E-28 50029232590000 202055 5/8/2025 AK E-LINE Caliper T40749 MPU F-21 50029226940000 196135 7/10/2025 AK E-LINE Caliper T40750 MPU G-02 50029219260000 189028 7/6/2025 AK E-LINE Puncher T40751 MPU I-01 50029220650000 190090 7/7/2025 AK E-LINE TubingPunch T40752 NS-19 50029231220000 202207 6/27/2025 AK E-LINE Perf T40753 PBU J-07C 50029202410300 225026 5/29/2025 BAKER MRPM T40754 PBU N-07B 50029201370200 223122 6/7/2025 BAKER MRPM T40755 PCU-05 50283202030000 225037 7/10/2024 AK E-LINE Perf T40756 TBU D-07RD2 50733201170200 192155 7/19/2025 AK E-LINE Perf T40757 TBU M-09 50733204760000 196127 7/18/2025 AK E-LINE Perf T40758 Please include current contact information if different from above. T40752MPU I-01 50029220650000 190090 7/7/2025 AK E-LINE TubingPunch Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.08 11:16:55 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Date:Thursday, August 1, 2024 9:03:42 AM From: Rixse, Melvin G (OGC) Sent: Thursday, August 1, 2024 9:03 AM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Ryan, Hilcorp is approved to punch tubing at 2825’ MD for circulation of surface plugs in all annuli. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Wednesday, July 31, 2024 3:07 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MPI-01 (PTD# 1900900) P&A Sundry #323-018 Mel, Attached is a revision for approval to the MPI-01 P&A sundry adding a line to make an additional TxIxO punch above our IA cement top (CBL log attached for reference). Below is the background. 1. Coiled tubing performed the reservoir cement plug on 10/2/23. 2. SL performed state witness tag of TOC in the tubing @ 3117’ and a passing CMIT-TxI to 1500 psi on 10/29/23. 3. EL performed TxIxO punch @ 3050’ on 11/18/23 4. Multiple attempts to establish circulation TxIxO were unsuccessful. Decision made to run CBL to identify IA TOC (Doyon 14 was on I pad from Feb-May and EL was unable to access the well during this timeframe) 5. EL ran CBL and found TOC in the IA is at ~2870’, on 7/20/24. The request is to perform a second tubing punch @ ~2825’, 1 joint above the IA TOC, once TxIxO circulation is established, perform the remainder of the P&A as approved. Please let me know your thoughts. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 20.00 P M C:LORIXMFILM.DOC E E L E W ATE.RIAL UNDER THIS M ARK ER ARCO ALA,.?KA, INC,. F'. 0,. BOX AF.!CHORA6E, ALA6'KA DATE' 5/'24/9G 995 t ,3 RECEIVED Oil & Gas Cons. ,umnmissio 1 .4 chorage REFERENCE' ARCO CAZED HOLE FINALS t -7 4- 6-- 9£.~ COL. LAR i - i 0 5- t 6-9(:) COLI_AR ~-'~ ,c, "~-i 5-9~ GAMHA · :..a-'b°A,:., 5- i '7-9G F'ERF RECORD 4'-':r,.. 5'"i .:5-' 9 ;"'~ .., COLLAR .5-4 5- t 8-9¢ COLLAR i ,.:. ,,. t 5-- i.,.."~--90 PERF RECORD i 3-t 6. :$-25-9~3 TRACEI;,' CHECK i~.-°~... 5-t 4-°0, COL. LAR i 7-7 4-6-9'3, F'ERF i 8-i t .,,'"~- i .-..~- q:.. n, ,, F'f)K-i.. 0~.3. G/R, i 8-24 5-t2-9G PDK-i ef~ G/R RLIN. t, _;'~' F;:UN 'i, 5' R U N t, 5" RUN i , .5' RUN i , 5:' RUN i , .5' RUN t, ...,.~' RIJN t, 5' RtJN t , 5" RUN I , ~' RUN t , 5' RUN t , :5' F'LEAZE 5'IGN AND RE~'IED COPY · RECEIVED BY AZ RECEIPT OF DATA HAVE A NICE DAY! ~AL.L..Y HOFFECKER AT0-i529 A P P R 0 V E~.C'_ .. 'f'I;,'AN$~ 90i 99 H A L A 'I'I_A'? H A I._ ':.S," C H A 'f' L.A A 'f'l_ A ~.? ,S' C': I-.I HAL A 'f' I... A 3' HAL A '/"L A .':;' ATLA.S' DI~*TRIBUTION CENTRAL FILE~ '"' CHEVRC)N EXTENSION EXF'LORAI'ION -- -'XXON MARATHON ~ MOBIL · ,-'"' F'HI LL IF'.S' F'B WFLL F:'IL. ES R & D ~ BPX ~"TA'f'E OF ALASKA TErXACO A R C 0 A L.. A ~' i'.':: A, I N C:., I::' ... 0,. E: 0 X 'i '~; (-) 3; 6 ANCHOF;.:ACit~i;, ALA."?KA 99':;'..,. 'i ,'"'" F:' i... E A 2 E ,ii; 16;- i'.! A N i) R Iii: T U R ix.! 'T' H iii: A 'T' T A C i"t ti:; D C 0 F:' Y A,ii.' I:< !ii; C; E I i::' T 0 F' :(.:' A 'i" ~'::'.,., R E C': E ill V E D B Y I"!AVE A NIC:lii; DAY! RECEIVED MAR - 8 !990 Alaska OJJ & Gas Cons. Con~lnlsSlO. Anchorage D I ,Ii.' T F;..' I B U T ! 0 N March 2, 1990 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 2-28 & 2-29 As-Built Dear Mr. Chatterton: Enclosed are copies of the subject As-builts for your information. If you have any questions, please call me at 263-4618. rely, Engineering Aide DW RECEIVED MAR - 6 ]990 Alaska Oil & Gas Cons. CommissioP /~chorage ARCO Alaska Inc. Is a subsidiary of Atlantic Richfield Company AR3B-6001-A I LOCATED WITHIN PROTRACTED SECTION 36 TI IN, RI4E, LUIAT MERIDIAN, ALASKA. A.S.P. COORDINATES NORTH l NG EAST I NG 5,950,926.20 6R7,529.59 5,950,219.67 688,513.66 GEODETIC POSITION LAT i TUDE LONG I 31.X)E 713'16'14.TT6' 14~'Z8°59.6~° TO* IE'07 ~RVET~ ' S t~r~T I F I C4 TE I l.[7F'~¥ C~TIFY THAT I AM ~.Y RESI$~ AND LICENSED TO PRAC' TIC& ~ ,.C~RVET I NGIN TI~ ~i',~ ,'rE OF ~ AI~ TH4 T ~ I S ~ T ~~TS ~ ~-~IL T ~ ~ BY ~ ~ ~ ~ DI~CT ~151~ ~ ~T ~L DI~I~ ~ O~ ~AIL$ ~ ~CT X3 or, J~JARY .5, 1990. I I I I RECEIVED 26 THIS D~ ILl 25 35 3~ Pr. ANT CO(ODS 21C~.47 333.49 207.5?. 1150.09 VICINITY Iv~P I 1'56'41' NOTES I) BASIS ro~ LC)CATI~ IS USC&CS MO~ PRUOi-.K)E 2 AND Df{ILL SITE IO-A. 2) c~ I~S ~ STA~ Z~ ~. 31 BASIS ~ ~ (~L~). ~ ~-2~ ~.54-57 & PD ~-~F. I-4. LOCAT I I N SECT 2~ F~ 7~ I~ I?~ LEGEND -~- 03~D~CT~ AS-BUILT THIS SURVEY. o EXIS'TIN6 ~TOR. F. ~ BELL ARCO Alaska, Inc. .lo~,~ ,e~., T J CONDUCTOR AS-BUlL 1_9_ ~'-" STATEOF ALASKA .... "' 0 R 16 IN .~ ' ALASI~A 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. 90-9 . . 3. Address 8. 'APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-22002 j '4. Location of' well at surface 9. Unit or Lease Name 1004' FNL, 1762' FWL, Sec.36, TllN, R14E, UM LOcA'rlo~.~ Prudhoe Bay Unit _ %~'~':~} '; 10'. Well Number At Top Producing Interval t~ , ~'~f'~ i 2-29 At Total Depth !i~, 11. Field and Pool 1004' FNL, 1762' FWL, Sec.36, TllN, R14E, UM ~ ~ Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool RKB 62'I ADL 28308 12. Date Spudded01/14/90 13. Date T.D. Reached01/16/90 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns01/20/90* N/A feet MSL .... N/A 1'7. Total Depth (MD+TvD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSS'V' set 21. Thickness of Permafrost 2139'MD/TVD Surface YES [] NO []~ N/A feet MD 1900' (approx) 22. Type Electric or Other Logs Run None 23. CASING, LINER ~,ND CEMENTING RECORD " ' , , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , 20" 91.5~ H-4O S~rf ]12' 30" . ~!50 .a. Pn3_~t ,.. , , . 24. Perforations open to Production {MD+TVD'of Top and Bottom and 25. TUBING REC6RD , interval, size and number) sIZE ~EPTH SET (MD) PACKER SET (MD) N/A .... None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATEF~IALUSED ,. 700'-900' Spotted 3475 CS II SUrf --il0' plug 330 sx CS II ,. 27N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD i~ ...... , , Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OII~'GRAVITY-API (corr) Press. 24-HOUR RATE ~' 28. CORE DATA Brief description of litholog¥, porosity, fractures, apparent dips and presence of oil, gas or water, Submit core chips. NOTE: Well was plugged and abandoned 1/20/90. ';:~'G __ ................ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. N/A NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31, LIST OF ATTACHMENTS None 32. hereby certify that the foregoing is true and correct to the best of my'knowledge Drilling Analyst Da,e 2 25. 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 l' 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. ~tem 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 cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10--407 ARCO O. and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Well no. County. parish or borouqh PRUDHOE BAY Fie~d PRUDHOE EOA Lease or L~L: 28308 DS2-29 Auth. or W.O. ni~S3498 ITM PLUG & ABANDON API: 50-029-22002 tARCO W I Operator ARCO 21. 7000 I Hour Prier sla!us if a W.O. Spudded or W.Q.~..~un Date 01/14/90 0300 :St,' uu Oate and depth as of 8:00 a.m. 01/14/90 ( TD: 227'( SUPV:TJ 01/15/90 ( TD: 1590'( 1 SUPV:TJ 01/16/90 ( TD: 2139'( SUPV:TJ 01/17/90 ( TD: 1685'( SUPV:TJ 01/18/90 ( TD: 400'( SUPV:JPS 01/19/90 ( TD: 750' ( SUPV: JP S 01/20/90 ( TD: 35'( SUPV:JPS Complet ..... ~L~I~ d~:~ported ) 27) ) 163) ) ,49) ) o) ~o) DRILLING AT 227~ MW: 8.8 VIS:262 MOVE RIG TO DS2-29. ACCEPTED AT 1930 HRS 1/13/90. SPOT RIG. N/U DIVERTER. P/U BHA. FUNCTION TEST DIVERTER. INSTALL STAB BLADES. SPUD @ 0300 HRS, 1/14/90. DRILLED F/ 112-227'. DAILY:S183,831 CUM:$183,831 ETD:S183,831 EFC:$2,230,000 DRILLING AT 1590 DRILLED F/ 227-1590'. MW: 8.9 VIS: 73 DAILY:S49,784 CUM:$233,615 ETD:S233,615 EFC:$2,230,000 POH FOR BHA MW: 8.9 VIS: 83 DRILLED F/ 1590-2050'. CIRC. TRIP FOR KO ASSY. RIH. TAG FILL AT 1970'. 80 FT. REAM 1970-2050'. DRILLED F/ 2050-2075' CIRC. DRILLED F/2075-2139'. CIRC. DAILY:S69,861 CUM:$303,476 ETD:S303,476 EFC:$2,230,000 R/U WESTERN ATLAS MW: 9.0 VIS:169 C AND C MUD. POH TO 1982'. RAISE MW TO 9.3 PPG. WASH TO 2034'. POH. RIH W/ SLICK BHA TO 1621'. REAM TO 1716'. POH. WIH W/ OE DP TO 1717'. PUMPED 525 SX CSII CMT. STUCK PIPE. CLEARED DP W/ 35 BBLS MUD. NO RETURNS WHILE PUMPING LAST 12 BBLS. R/U WI, UNIT TO BACK OFF. DAILY:S54,870 CUM:$358,346 ETD:S358,346 EFC:$2,230,000 POH W/ OE DP MW: 9.3 VIS:ll2 MADE BACKOFF AT 1528'. SPOTTED 16.0 PPG MUD F/1528-900'. SPOTTED 1750 SX CSII F/900-400' MD. POH W/ DP. DAILY:S104,670 CUM:$463,016 ETD:S463,016 EFC:$2,230,000 WOC MW: 9.6 VIS:135 WOC 11.5 HRS'.''R~H. TAG SOFT CMT AT 411'. WASH TO 750'. CBU. POH. WIH W/ OE*DP TO 728'. SPOT 1200 SX CSII F/ 728-400'. POH. WOC. DAILY:S116,891 CUM:$579,907 ETD:S579,907 EFC:$2,230,000 FINAL REPORT MW: 9.7 VIS:154 WOC. RIH W/ 17-5" BIT. TAG AT 340'. WASH DN TO 700'. NO DRILLABLE CMT. POH. L/D BHA. PREP TO P/A. REC'D VERBAL APPROVAL FROM MIKE MINDER (AOGCC) TO P/A @ 1800 HRS, 1/19/90. SET 330SX CS II PLUG F/ 110' TO SURF. N/D DIVERTER. PREP FOR MOVE. DAILY:S131,405 CUM:$711,312 ETD:S711,312 EFC:$2,230,000 The above is correct For forth preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-1-D I,i,ie Drilling Supt, Number all daily well history forms consecutively ~Page as they are prepared for each well. I ARCO ,.,~1 and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon cumulation, report completion and representative test data. in blocks provided The "Final Report" form may be used for reporting the entire operation if space is ~aHable. Accounting cost center code District County or Parish State ARCO ALASKA INC. Lease PRUDHOE BAY AK Field or Unit Well no PRUDHOE EOA ADL: 28308 DS2-29 Auth, or W.O. no. T tie AS3498 PLUG & ABANDON API: 50-029-22002 Operator A.R.Co. W.I. ARCO 21. 7000 Spudded or WO. begun Date SPUD 01/14/90 Date and depth !Complete record for each day reported- as of 8:00 a.m NABORS 28E 01/21/90 ( TD: 110' ( SUPV: JPS I otal number of wells (active or inactive) on this cst center prior to plugging and bandonment of this well Prior status our 0300 if a W,O. t) 75) W/O W/L TO SET PLUG IN DS2-2 MW: 0.0 VIS: 0 MOVE PITS OFF DS2-29. PREP TO MOVE TO DS2-29A. SETTING PLUGS IN DS2-2 (OFFSET WELL). RIG RELEASED @ 2200 MRS, 1/20/90. DAILY:S49,308 CUM:$760,620 ETD:S760,620 EFC:$2,230,000 Old TO New TD PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.} Type completion (single, dual, etc.) Producing method Official reserve r name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P, Water % GOR Gravity Allowable Effective date corrected The above is correct Signat %.~ ~.~ IDle.% ~ Title For form pr~parat~ion and distribution, see Procedures Manual, Section 10. Drilling, Pages 86 and 87. AR3B-459-3-C Number ail daily well history forms consecutively I Page no. as they are prepared for each well. I Oivi~on of AtlanticRIchtleldCompany I I Teleco Oilfield Se as Inc. TELECO 8116 Nielson way A nchorage. AK 99518 (907) 562-2646 February 13, 1990 JOB #737 ARCO ALASKA INC. WELL: DS-2-29 PRUDHOE BAY RIG: NABORS 28-E Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to ARCO Alaska Inc. Teleco is committed to providing the highest quality MWD Service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Jonathan G. Mapes Field Operations Supervisor JGM/el Enclosures RECEIVED ~AR - 8 !990 Alaska Oil & Gas Cons. commtSsto. ~ Anchorage A ~r,~J~'l' COMPANY ,company: ARCO ALASK;%.., Well: DS.2.-29m L.ocation: ~PRUDHOE BAY, R.i.q: NABORS 28-E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi , Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg ,feet feet feet feet feet deg deg/100& 2050 45 0.7 121.9 2049.97 5.77 3.74S 6.95E 7.90 S 61.69E 0.00 PAGE 2 TELECO OILFIELD SERVICES SURVEY CALCULATIONS Date 2/8/90 Company: ARCO ALASKA Well: DS2-29 Location: PRUDHOE BAY Rig: NABORS 28-E TELECO Job # 737TAK Grid Correction: 0.0 Magnetic Declination: 30.8 Total grid correction: 30.8 Proposed Direction: 75.3 MINIMUM CURVATURE CALCULATION ************************************ Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/1006 ******************************************************************************************************* TIE IN AT SURFACE LOCATION 0 0 0.0 0.0 0.01 0.01 0.01N 0.01E 0.01 N 45.00E 0.00 TELECO MWD SURVEYS 480 480 0.1 238.3 480.00 -0.38 0.17S 0.35W 0.39 S 64.10W 0.02 963 483 0.4 143.3 963.00 -0.15 1.74S 0.30E 1.77 S 9.86E . 0.09 1460 497 0.3 58.2 1459.99 1.74 2.45S 2.45E 3.46 S 44.98E 0.10 2005 545 0.7 121.9 2004.97 5.40 3.45S 6.48E 7.35 S 61.96E 0.12 PAGE . -250 - 0 250 5OO 575O ~000 >~250 1500 750 TL_ CO Oilfield Servicc VERTICAL PROJECTION 250 500 750 ~000 1250 480 ' . ! deg ARCO ALASKA DS2-29 PRUDHOE BAY NABORS 28-E JOB# 737TAK/O0 SCALE: 1 'inch = 250 feet 963 ' .4 oleg 1460 ' .3 ;leg . .~. . .~ .....: ..... . ..--. ,~. ~. :g ~:~,,~-* -'._. :..,~ ,,...,~-~'%_'~,~* ~,..~.-,.-*. OeO - ~-.~'.. ". :- 2050 , .7.-._.: .' .?. - ::.._ . .... -..~:. ....... ~.,, ........ . _,-.~ .,.:.~: .... ,~.~.~-, .... ~~~. ;. ~-'..~ ...... ~:.- ..... :~ . ~.-......_- ~ ~ . ~- -- ....... ..~-~. '.~ .... ' ~" -' ~-- "'- '' " ::.~- '. ': J - ' "' · "~ ,-.-: -'.': 'T" ' ..... - .' .. ~:~,' ..... ~'~,~:' ~ '*'-- .,:.'.,: .:~.~,, .' ~/:;: · . .., ::..~.~...:: ,..~, ~, ';.~, .: -., ; . :.'/.:~,'~.~.~:'t~,-:. -. ... ~ .: :. . . .... ......~ ...... ,, .. . .. ., . ..,....'-, ..'-?:. 5..:.:j~ i .. ............................. : ~..'..r?,~r:..:~-~f ~ '" ' ' :~'*' '.'._' ''~::.;''.: '* '. .... TF-,-'CO 0 i 1 f i e 1 d PLAN VIEW Servic~s lO0 ARCO ALASKA DS2-29 PRUDHOE BAY NABORS 28-E ,JOB# 737TAK/O0 5O 5O 100 ~50 2O0 250 3OO . . 35O 200 -~/84 .... /~"~'~ SZABO; O~ AL^S~ " JAN 1990. OIL & GAS COBSERVI, TION CO[rdlSSION B.O.P,E. Inspection g~po~t ~Ma~ Oil & Ga~ Cons. Commission ' ~ ~chorage - Date ~ ~ , O~era~or Representative Locatton~ gec . ,sing S~, ~ t%~.. ...... . _- _. Drillin Contractor. Ei )tesentattve LocaCion~ General ~ell $i ACCU[fULA~OR S¥$TE~I . ~..".':..'~Cene~,I ~ou,ekeep~u-~~--Eig ~'11 Full~~Cha~g, Pze~,ut pe/g . ..... __~ _ .::"::":' Ees.rve Pi.t .. '~,~, ........... ~JPzessure After Clo~ure~ p~ig ........ '')"'Pu Svste-~ ' ' Visual- Audio 'Fump incr. clos. pres. 200 . , _- _- ~.---- :" ~ , ' .2 .... . .' ...... [J ~_ i ~ .__--~ -7-- ..... . ...... .. .-_ .... ~ I~all Iype.___~ ' Test Pressure Inside BOP___~__Test Pressure Choke Manifold No, Valves No. flanges Adjustable Chokes ........ ~ · . .~:"' 'i:' . "pl~ ~ibu,~.~O'~ orig, - AO&GCC , "ce - Operator . ~ cc - Supervisor · ' .' '.Iest Results: ._. ............. . ' . , . . ~v ..... " .... Repair or .Replacement,,of.failed equtpmen~ to be made within days and In~pect°~/ ,~, · ' Con~nisstoa off/c, notified,. Rema~k~ ',~ , Inspecter STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon.~.'-f' Alter casirfg" Change approved program __ 2. Name of Operator ARCO Alaska, Inc. Suspend __ Operation shut~lgwn __ Re-enter suspended well __ Repair well __ Plugging ~ Time extension __ Stimulate __ Pull tubing __ Variance m Perforate __ Other 5. Type of Well: Development Exploratory Stratigraphic Service 3. Address P.O. Box '100360 Anchora.qe~ AK 4. Location of well at sudace 9951 0-0360 '1005' FNL, .1760' FWL, Sec.36, TI.1N, R14E, UM At top of productive interval N/A At effective depth (2.100 'TVD/MD) .1005' FNL, .1760' FWL, Sec.36, T.11N, R.14E, UM At total depth . ~;(90~, ,TVD/MD)., 1005' FNL, ~/ou rwL, bec..~6, TllN, R14E~ UM 12. Present well condition summary Total depth: measured true vertical 6. Datum elevation (DF or KB) RKB 62', GL 30' 7. Unit or Property name Pr.,dhn~_ R~y I In{ t- 8. Well number DS 2-29 9. Permit number 90-9 10. APl number 50-- 11. Field/Pool Prudhoe, Bay Fi el¢ Plugs (measured) .1586-17'17 ' (525 ax) surface to 100' (330 ax) 2.100 ' MD feet 2.1 O0 ' TVD feet Effective depth: measured true vertical feet Junk (measured) feet Length Size Cemented Measured depth True vertical depth 80 ' 20" 2000# Pol eset 1.10 'MD '11 O' TVD Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: feet DS 2-29 was permanently plugged and abandoned due to hole instability and the inability to get a sidetrack cement plug. Verbal approval was measured received from Mike Minder of the AOGCC on 1/19/90 to plug and abandon DS 2-29 as per the attached schematic. Surface cement plugging operation true vertica~aS witnessed by Bobby Foster of the AOGCC. : Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal _.~ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 16. If proposal was verbally approved Oil __ Gas Name of approver /")~; kg m ,°¢~ g 4, ¢' ua[e approveo Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,l~ ~ ~,g(~ Title Drilling Analyst Conditions of ~roval: otif~ Corn ission so roprosontativo may witnoss 15. Status of well classification as: Suspended. Plug integrity __ BOP Test __ Location clearance __ /-[Lo *7 Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 (.II H) L ,,,_,?-, PBU DS . -29 P&A SCHEMATIC CUT OFF 20" CONDUCTOR AT THE BASE OF THE CELLAR WELDED HATE ON TOP OF 20" CONDUCTOR 330 SX CS II PLUG FROM SURFACE TO 110' RKB 20" at 110' RKB 5" DRILL PIPE IN PLUG FROM ~ 1717-1586' RKB 525 SX CSII PLUG FROM 1586-1717' RKB 17-1/2" hole to 2139' TVD / MD January 4, 1990 Telecopy No. (907) 276-7542 J D Gillespte Regional Drilling Engr ARCO Alaska, P O Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Unit DS 2-29 ARCO Alaska, Inc ' Permit ~ 90-9 Surf Loc 1005'FNL, 1760'FW~,., Sec 36, TllN, RI4E, UM Btm~hole Loc 12i'FNL, 57'FEL, Sec 36, TllN, R14E, UM Dear Mr Gillespie~ Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing o£ the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve/.y truly yours, ~ Chairman Alaska Oil and Gas Conservation BY ORDER OF THE CO~iiSSION jo Enclosure Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl la. Type of STATE OF ALASKA -- ALASKA _ ,L AND GAS CONSERVATION CL...,1MISSION PERMIT TO DRILL 20 AAC 25.005 work Drill ~ Redrill '-I lb. Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil Re-Entry - Deepen~-~ Service ~ Developement Gas ~_ Single Zone ~E Multiple Zone 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 995'10-0360 4. Location of well at surface 'I005'FNL, 1760'FWL, Sec.36, At top of productive interval R14E, UM 5. Datum Elevation(DF orKB) RKB 62' 30'GL feet 6. Property Designation ADL ~ .2..85~g 7. Unit or property Name Prudhoe Bay Unit 8. Well number 10. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay Oil Pool 11. Type Bondlsee 2o AAC 25.025) Statewi de Number 60'FNL, 300'FEL, Sec.36, TI'IN, R14E, UM PBU DS 2-2~ At total depth 9. Approximate spud date 2'I'FNL, 57'FEL, Sec.36, TllN, R14E, UM 01/04/90 14. Number of acres in property 12. Distance to nearest property line 121 ' feet 13. Distance to nearest well DS 2-3 54' at 2000' TVD/Hf[¢et 16. To be completed for deviated welts 33°/46 Kickoff depth 2'100 T'~(De/MD Maximum hole angle 0 18. Casing program size Specifications Hole Casing Weight ! Grade I Coupling i Length 30" 2o" 9', .5#I H-40! Weld 180' '13-3/8' 68# I L-801 BTC I 3750' 'l 2-'I/4 9-5/8" 47# I L-80 IBTC/Modl 927'i ' 8-1/2" 7" 29# IL-801 BTC I 985' III 19. To be completed for Redrill, Re-entry, and Deepen 0 Present well condition summary Total depth: 2640 measured true vertical No. U-6306'10 Amount $200,000 15. Proposed depth (MD and TVD) '10636'MD 9736 ' TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 3 5 8 4 psig At total depth (TVD) 44- 5 0 0 Setting Depth Top Bottom 30'II -,-,o,i 50'1' '50'13800'1 3o, I l i )orations. feet Plugs (measured) feet psig Quantity of cernent TVD (include stage data) 110' 2000# Po]eset 50' 2000 CS II I & 3703~ 8422' 9097' 600 CS G 4 5 0,,. 6.5 G 200 sx CS G Effective depth: measured feet true vertical feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth RECEIVED A.chorage True Vertical depth 20. Attachments Filing fee 1~ Property plat [] BOP Sketch ~' Diverter Sketch ~ Drilling program ~ Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements ~, 21. I hereby certify that the foregoing is true and correct to the beSt of my knowledge/CJb~_, Signed ~.A..~. /'~~..~.... Title Regional Drilling Engine.er // Z Commission Use Only (J LH) PD3/1 00, Perrn~.t N(,~n. be_..r J APl number J Approval date ,/~Jj See cover letter Yo, ¥- 1,, I for other reqL, irements Conditions of approval Samples requ. ired ri. Yes .~ No Mud log required L--] Yes No Hydrogen sulfide.measures ~ Yes ]~L'No Directional survey required .'~Yes [] No Required working./l!~sure for B~¢'~ E~M; ? 3M.; ~ 5M; [] 10M; [] 15M Other: / I...~ / / . /~ /'. ,/ -- ~ Approved by ", Commissioner the commission Date Form 10-401 Rev. 12-1-85 SU~m~/~-n t'ripi~ate PBU DS 2-29 OPERATIONS SUMMARY 1. MIRU ddlling dg. NU diverter and function test same. 2. Ddll 17-1/2" hole to 2100' TVD/MD and kickoff. Build angle at 2.0 degrees/100 ft. to 33° deg 46' at 3692' TVD / 3788' MD. Drill 17-1/2" hole to 3703' TVD / 3800' MD maintaining the 33 deg 46' hole angle in a N 75 degrees 17' E direction. 3. Set 13-3/8" casing and cement same. Nipple up BOPE and test to 5000 psi. Test casing to 2500 psi for 30 minutes. 4. Pick up 12-1/4" BHA and GIH. Drill 10 ft of new hole and perform leakoff test. 5. Drill 12-1/4" hole to 6940' TVD / 7695' MD maintaining the 33 deg 46' hole angle in a N 75 deg 17' E direction. Drop angle at 1.5 deg / 100 ft to 10 degrees at 8400' TVD / 9280' MD. 6. Drill to the 9-5/8" casing point at 8422' TVD / 9301' MD maintaining the 10 degree hole angle. 7. Set 9-5/8" casing and cement same. 8. Pick up 8-1/2" BHA and GIH. Test casing to 3000 psi. 9. Drill 10 ft of new hole and perform EMW test. 10. Drill 8-1/2" hole to 9097 TVD / 9986' MD maintaining the hole angle at 10 degrees. 11. Run wireline logs as programmed. 12. Set 7" liner and cement same. 13. P/U 6" BHA and GIH. Test liner to 3000 psi. 14. Drill 10 ft of new hole and perform EMW test. 15. Drill 6" hole to 9736' TVD / 10636' MD. 16. Run wireline logs as programmed. 17. Set a balnced cement plug ( 150 sx ) in the 6" open hole. 18. Clean out the 7" liner to 9906' MD ( 80' above liner shoe) and test liner to 3000 psi for 30 minutes. Circulate well to brine and freeze protect with diesel. 19. Release drilling dg. Run cased hole logs 7 days after rig release. 20. MI and RU completion rig. Run 3-1/2" tubing and packer assembly. N/U 3-1/2" tree and test to 3000 psi. Release completion rig. 21. Rig up wireline unit and perforate. NOTE; PBU DS 2-29 OPERATIONS SUMMARY CONT. ao Excess non-hazardous fluids developed from the well operations and as necessary to control the reserve pit fluid level will be pumped down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid dudng any extended period. The annulus will be sealed with 300 sx of cement followed by Arctic Pack. b. Well within 200 ft. of the proposed well is: DS 2-03 54 ft @ DS 2-04 59 ft @ DS2-02 171 ft @ DS 2-05 179ft @ SURFACE TO 2600' TVD / MD SURFACE TO 2800' TVD / MD SURFACE TO 2800' TVD / MD 200' TVD / MD c. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.033. d. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi). e. Based on previous logs on DS 2, no potential productive zones are anticipated above 3500' TVD. f. No potential hazardous levels of H2S are anticipated in this well. PBU DS 2-29 MUD PROGRAM SPUD to 13-3/8 csg pt. DEPTH DENSITY ViS YP INT 10MIN FL OIL SOLIDS MUD (TVD) (PPG) GELS GELS CC/30MIN (%) (%) TYPE 8.8 300 70 30+ 50+ 25 0 2 GEL-BENEX to to to to SPUD MUD 9.2 100 40 RECEIVED SET 1 3-3/8" DEPTH DENSI~ PV YP INT 10 min FL ~n~~-' SOLIDS MUD (~D) (PPG) (CP) (~/ft GEL GEL ~/30min (%) (%) ~PE 13-3/8" 9 10 6 2 4 25 0 2 LIGHTLY to to to to to to to to to TREATED 5400 9.5 15 10 4 10 15 6 POLYMER 5400 9.6 10 6 2 4 15 0 2 LIGHTLY to to to to to to to to to TREATED K-10 9.7 15 10 4 10 10 6 POLYMER K-10 9.8 10 6 2 4 10 2 4 LIGHTLY to to to to to to to to to TREATED 9-5/8" 10 15 10 4 10 6 5 9 POLYMER SET 9-5/8" CASING DEPTH DENSITY PV YP INT 10min FL OIL SOLIDS MUD (TVD) (PG) (CP) (#/ft) GEL GEL cc/30min (%) (%) TYPE 9-5/8" 8.7 10 6 2 8 8 2 4 LIGHTLY to to to to to to to to to TREATED 7" Liner 9.1 15 10 4 10 6 5 6 POLYMER SET 7" LINER DEPTH DENSITY PV YP INT 10 min FL OIL SOLIDS MUD (TVD) (PG) (CP) (#/ft) GEL GEL cc/30min (%) (%) TYPE 7" Liner 9.6 10 6 2 8 8 2 4 LIGHTLY to to to to to to to to to TREATED TD 9.8 15 10 4 10 6 5 6 POLYMER . THIS MUD PROGF~M IS ONLY A GUIDELINE. ACTUAL HOLE CONDITIONS WILL DICTATE THE ACTUAL MUD PROPERTIES. ANY MAJOR CHANGES SHOULD BE DISCUSSED WITH THE ANCHORAGE OFFICE. 0 ]000 2000 3000 4UUU .~Uuu ouuu ~ u~u , i i , , , . . , ' .... RKFI ~I]~2VATION 62' 20" Casing TVD=I10 TM D=ll0 =0 AR{ O ALA SKA, I1 lC. ds2-5!9 ~"~"' =' I" I000' SHL: U 1 IN 14E 36 100.5' F~IL 1760' FWL THL: U 1 IN 14E 36 160' FNL 300' FEL BHL: U llN 14E36 121' FNL 157' FEL N75 17' KOP TVD=2100 2.0 4.0 6.0 8.0 1114.0 1116.0 1118.0 ~ 30.0 '~zo EOC 'IVD=3692 TMD=3788 )EP--483 o " Casing TVD=3703 TI~ D=3800 DEP--489 [ TVD=4500 TM[--4758 DEP=1022 2 TMD=4965 DEP=ll ,7 ~kVERAGE ANGLE = 3: 46' BOD T~rD=6940 TMD=7695 L3 [-5 TVD=7562 TMD=: =2990 23.3 1.8 Leu TV1~-8192 'IMD=9067 DEP=3197 14.3 ~ ~, ~ ~ ~' ! ~ ' ~12.8 SAGRiver TVD=8332 T~ID=9210 DEP=3227 SHUBLIK TVD=-8372 1~MD=9250 DEP=3234 ii') I-~ ('~ ~ ~"~ ~ ~ 9 EOD TVD=8400 YMD=9280 DEP=3241~_~ 9-5/8" asing TVD=8422 TM[~-9301 DEP=3244 r'~' Top Sadie ochit TVD=8432 TMD=9311 DEP=3246 Gl( Contact TVD=8827 TVID=9712 DEP=3315 ' $ulchol'ag~ TARGET TVD=8892 TMD=9779 D]~=~3:!8 _ Base Sad ~ochit TVD=8957 TM D=-9843 DEP=3339 7" liner TVD=-9097 TM D=9986 DEP=3363 Lisburne TVD=9167 ~IMD=-10057 DEP=3376 Base of Lisburne TVD=9662 T dD=10559 DEP=3463 TD TVD=9736 TMD=10636 DEP=:~47 ....................................................... I ....... 1000 2000 3000 ~'~ 4000 < ~ 5000 6OOO 7000 8000 9O0O 10000 0 1000 2000 3000 4000 5000 6000 700o VERTICAL SECTION ?L~-O2 O~ 7 J I lO ,,, 5 5 q -22 ARCO ALASKA, INC. ds2-29 N75 17'E [- o2~5 © © E - W COORDINATES -2000 - 1000 0 1000 2000 3000 4000 5000 6000 2000 iir , , , , i i i ii i i i i i i i ii i i i i i i i ii i i i i ............................. ' ' ' ' ' ' ' ' ' ' ' 02-02.~. s7~3 ,,~ ~o ~313 693 ~ ~ ~ 3704 4414 4492 'N~x 4~ 86 6~29 166 /85~ M472 02-~ /,~, ~7~, 089 .............................................. o~,~o~ ?.~ .................. 4000 -4000 3000 · 3000 -20O0 1000 0 0 -1000- - -1000 -2000- ---2000 -3000- - -3000 -2000 -1000 0 1000 2000 3000 4000 5000 6000 NABORS 28E DIVERTER SYSTEM ARCO ALASKA, INC. FILL-UP LINE RISER FLOWUNE I 20" 21:XX) PSI DIVERTER I 10" BALL VALVE 10" BALL VALVE I ~ I I CONDUCTORI NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS THIS IS A VARIANCE FROM 20AAC25.035. RESERVE PIT 10" VENT LINE 10" VENT UNE DIVERTER LINES DISCHARGE 100 FT. FROM RIG IGNITION SOURCE. ALL TURNS ARE TARGETED TEES. R. ~ C ~. 13-5/8" 5000 psi BOP STACK DIAGRAM I I pPIPE RAMS~ IPE RAM~.~ SPOOL BLIND RA _J [CASING ~ SPOOL BRADEN r~ HEAD ~ ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVIOR TO THE PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT THE ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH THE CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRES- SURE. 13-5/8" STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING FLUID. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK THE RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN THE TEST PLUG ON DRILL PIPE AND SEAT IN WELL- HEAD. 3. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4. FUNCTION TEST CHOKES. 5. IN EACH TEST, FIRST HOLD 250 PSI FOR 3 MINUTES PRIOR TO THE HIGH PPRERSSURE TEST. 6. INCREASE PRESSURE ON ANNULAR TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF THE CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS. CLOSE BOTTOM PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 10. TEST REMAINING MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF THE VALVE AND ZERO PRESSURE DOWNSTREAM. 11. BLEED PRESSURE TO ZERO. OPEN BOTTOM PIPE RAMS. 12. BACK OFF RUNNING JOINT AND POH. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. BLEED OFF ALL PRESSURE. OPEN BLIND RAMS. FILL MANIFOLD AND LINES WITH NON-FREEZING FLUID. SET ALL VALVES IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO 5000 PSI. CHECK DEGASSER OPERATION. RECORD BOP TEST INFORMATION ON THE BOP TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 17. PERFORM COMPLETE BOP TEST WEEKLY AND FUNCTION TEST DAILY. NABORS 28E SYSTEM PIT #1 130 BBLS PIT #2 81 BBLS PIT #5 117 BBLS PILL PIT 20 BBLS PIT #6 135 BBLS TRIP TANK 170 BBLS PIT #3 137 BBLS PIT $4 179 BBLS EQUIPS~NT - DRILLING FLUID SYSTEM (3) DERRICK FLO-LINE CT.~.ANER (1) DERRICK MUD CLEANER (1) BRANDT CF-2 CENTRIFUGE (1) PIONEER MARK I CENTRIFUGE (1) RIG BUILT GAS BUSTER (1) DRILCO DEGASSER (1) PVT SENSOR PER PIT w/ visual and audio warning devices (1) AGITATOR PER PIT (1) DRILLING FLOW SHOW SENSOR W/ readout convenient to the driller's console CHECK LIST FOR NEW WELL PER}fITS ITEM APPROVE DATE (2 thru (8) (3) Admin/~,~f_ ~ 9. (9-thru'l~) ' - 10. (10 and 13) 12. 13. (4) Casg ~.,~, /~-Sg-~q (14 thru 22) (23 thru 28) Company 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Lease & Well No. ~A ~f~ ~ NO REMARKS 1. Is the permit fee attached .......................................... · ( 2. i'Is well to' be located in a defined pool ............................. 3. ~Is well located proper distance from property line ................... 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... YES ,/ Does operator have a bond in force .................................. Is a conservation order needed ...................................... , , Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ................ . ... . Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER (29 thru 31) (6) Add: -~, ~, · Geology:__. Engineering: DWi- LCS -"~" 'BEW / rev: 0'1/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE · , Additional Remarks: ~_~9 ~,~, ~ ~j ~,:'~'~., ~'~" %.. s,~£- ~ '? ,T~ '~,-~ .~_zl ,~. .~..,~_ ~