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184-013
) '\ J FRANK H. MURKOWSKJ, GOVERNOR A.., (A.SIiA. OIL AND GAS CONSERVAnONCO~SSION 333 W. TTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 21, 2005 R. L. Skillern Landman BP Exploration Alaska I nc POBox 196612 Anchorage, AK 99519 C' "'" ;¡l~r p:::..' 11 ì) 'S" Fp '9¡ 9 ">0 P1 lr"\""ff'''!>~~~\il:';\-;'1" .:.. ,I l',.' P c.l d.. Dear Mr. Skillern: We have reviewed the well files which contain recommendations for final location clearance for the following wells: Milne Point Unit N-01 (PTD 170-045) Plugged & Abandoned January 5, 1984 Milne Point Unit N-01A (PTD 184-006) Plugged & Abandoned January 18, 1984 ---:::¡ Milne Point Unit N-01 B (PTD 184-013) Plugged & Abandoned March 29, 2002 We found field inspection reports in all of the above files recommending final location clearance. The reports show the locations to be in compliance with (20 AAC 25.170 Onshore Location Clearance) and, therefore, the Commission requires no further work on the subject wells. However, BP Exploration Alaska Inc remains liable if any problems occur in the future with any of the wells. Final location clearance is hereby approved for the above listed wells. Since the actual pad was removed per the requirement of other agencies, any future actions not directly associated with the well will be under the direction of those agencies. If you have any questions or need further information, please contact Jim Regg 907-793- 1236, Sincerely, {}fl ¡JŒ~ J John N2rm;¡~~ Chairman cc: Dan Kara BPX Steve McMains Well File DEPT. OF ENVIRONMENTAL CONSERVATION DIVISION OF ENVIRONMENTAL HEALTH SOLID WASTE PROGRAM 410 WILLOUGHBY AVENUE JUNEAU, ALASKA 99508 http://www.state.ak.us/dec/ deh Telephone: (907) 465-5153 Fax: (907) 465-5164 April 17, 2003 Susan L. Sharp Manager - Global Environmental Management BU BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Reference: Issuance of Permanent Closure Approval for Inactive Reserve Pits located at Sag Delta 1, Sag Delta 2/2A, and Milne Point N Pad , . .... ~ ""\.- ,\" \ '&-- DearMsSharp: ~.. \~l¡. eCCc ~ \<5"-\" The Alaska Department of Environmental Conservation (ADEC) has c~~eteã review and public notice for permanent closure approval of the inactive reserve pits located at the above reference sites located on the North Slope. The closure applications and corrective action plans provided the required information describing the history and conditions of the reserve pits(s), results of required water sampling, an assessment of the potential risks posed by the drilling waste to human health and the environment as well as proposed corrective actions. Corrective actions are completed at these sites. ADEC coordinated field inspections and review of the closure, plans with the appropriate land and resource managers. At these three sites, the drilling waste was excavated ftom the reserve pit(s) and transported to a grind and injection facility for disposal. The excavated pits were backfilled with clean gravel. ADEC has determined that these sites present no material or probable risk to the public health or the environment. Public notice requesting comments on the closure requests was published March 7 and 8, 2003 in the Anchorage Daily News and posted on the state web site March 7, 2003. No public comments objecting to closure approval were received in response to this public notice. ADEC has determined that the reserve pits at these sites meet the closure requirements of 18 AAC 60.440. Closure Approval Under authority of 18 AAC 60.440 (j), ADEC grants permanent closure approval to BP Exploration (Alaska) Inc. for the inactive reserve pits at the following sites: e e Ms. Susan Sharp BP Exploration (Alaska) Inc. April 17 2003 Page 2 of3 Well Name(s) API Number MTRS Landowner Sag Delta 1 (33-12-16) 50-029-20176-00 Section 4, T11N, R16E, UM DNR Sag Delta 2 (10-11-16) 50-029-20234-00 Section 10, T11N, R16E,UM DNR Sag Delta 2A 50-029-20234-01 Milne Point Unit N Pad 50-029-21053-00 Section 30, T13N, RlOE, UM DNR Terms and Conditions This permanent closure approval is subject to the following terms and conditions: 1) In accordance with 18 AAC 60.440(1), the Department will require additional investigation, assessment, monitoring or remediation if new information regarding conditions at the reserve pit facilities indicates that further actions are necessary to protect human health or the environment. 2) The approval granted by this letter is for the inactive drilling waste reserve pit(s) only. Closure for the pad as a whole (if required) must be coordinated between the owner/operator and the appropriate land owner/manager. Any person who disagrees with this decision may request an adjudicatory hearing in accordance with 18 AAC 15.195- 18 AAC 15.340 or an informal review by the Division Director in accordance with 18 AAC 15.185. Informal review requests must be delivered to the Division Director, 555 Cordova, Anchorage, Alaska, 99501 within 15 days of the permit decision. Adjudicatory hearing requests must be delivered to the Commissioner of the Department of Environmental Conservation, 410 Willoughby Avenue, Suite 303, Juneau, Alaska 99801, within 30 days of the permit decision. If a hearing is not requested within 30 days, the right to appeal is waived. Sincerely, ELECTRONICALLY TRANSMITTED Glenn Miller Solid Waste Program Manager Glenn _ Miller@dec.state.ak.us cc: electronic only Harry Bader, ADNR, Fairbanks (Harry_Bader@dnr.state.ak.us) Tom Maunder, AOGCC, Anchorage (Tom_Maunder@admin.state.ak.us) Bruce Webb, ADNR, O&G Division, Anchorage (Bruce_ Webb@dnr.state.ak.us) Jack Winters, ADF&G, Fairbanks (Jack_ Winters@fishgame.state.ak.us) Kaye Laughlin, DGC, Anchorage (klaughli@jpo.doi.gov) Linda Nuechterlein, ADEC, Anchorage (Linda_Nuechterlein@dec.state.ak.us) Terry Carpenter, COE, Anchorage (Terry.A.Carpenter@poa02.usace.army.mil) e e Ms. Susan Sharp BP Exploration (Alaska) Inc. Louise Smith, USFWS, Fairbanks (Louise_Smith@fws.gov) Sheldon Adams, NSB, Barrow (Sheldon.Adams@north-slope.org) Rex A. Okakok, Sr. NSB, Barrow (Rex.Okakok@north-slope.org) April 17 2003 Page 3 of3 ''------. ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor, Commissioner DATE: August 7,2002 THRU: Tom Maunder, it9.- <1'f'/ P. I. Supervisor . . \o,~-,CfJ- . !. ')nll': !....'~.."J.;¡.~~~I~~tj; SEP 1. ~ (_uu,,~ iJ \ø;.,rt1'¡~ ìì¡ t: \'~ ~.;~ FROM: John Spaulding, Petroleum Inspector -". SUBJECT: Surface Abandonment's North Slope Multiple Locations Auaust 72002: I traveled to multiple locations as listed below, to witness the location abandonments. ~ MPU N-01~TD 184-013): BPXA, the pad and the area surrounding the abandoned /' well was clean and did not have any standing water located over the area that was presumed to be the casing stub. I recommend this well for surface location clearance. West Sak 25 (PTO 182..027): As noted in the accompanying photos there is water standing over what is presumed to be the old well, also there . appears to be old drilling mud mixed in with the gravel that is kind of bunched in a haphazard manner. I. do not recommend this well for a surface location clearance until further remediation to the site has been done. '\'-\- 5 S- Gwyder Bay South 1 (PTO ~): The area around the pad has considerable gravel. Mr. Osborne the Fairweather rep. informed me that some or all of the gravel would be removed leaving the airstrip behind. I feel that until the gravel has been removed and all work has been finalized, a location clearance should not be granted. Kuparuk River State 1 (PTD 169-042): The pad area around the well head was in excellent shape and was hard to tell where the well was located as noted. I recommend Kuparuk St. 1 for final abandonment. Sag Delta No.1 (PTO 175-058): The pad area is located on an old island that is washing away and going back t 0 it's natural state. As noted in the photos the area looks quite good. I recommend a location clearance be granted. SUMMARY: I inspected the ExxonMobil and BPX locations for suitable location clearances. Attachments: Location photos surface location abandonments.doc PLUGGiNGr & LO~ATION CLEA_~A._NCE REPORT State cf Alaska ALAS~ 0iL & GA~ C-~NSERVATION CCHHISSION Lease :..~amc r~.nd'a.~ '_ c F:: e: AFi .'..70. Wei! }fame Ccera~--r . Lcca:icn Review ~h~e we!! fi!e, and-c?~.eu: cn plu~g, well head sUaUus, ~ !ocaUi=n c!ea~ce~ ~=r~e loc. c!e~. co~e. Well head ccc c:~-~: .Har.~er 'poet cr place: Loca:icn C"_aar~nca: f' Z ' '" Signed E & P SERVICES, INC. 18-Apr-02 Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Re.' Permanent Abandonment: BP Exploration (Alaska) Milne Point Unit N-01B (PTD 184- 013) Dear Commissioners: Please find enclosed, the following documents which are required to be submitted following work performed on a well. These submittals are made on behalf of BP Exploration (Alaska) Inc. The well, Milne Point N-01 B, was permanently plugged and abandoned this past winter, with operations being completed on the March 31, 2002. 1. Three (3) originals; AOGCC Form 10-407 for the well; 2. Three (3) copies: Plug and abandonment operations summary for N-01B with photo's and AOGCC correspondence while performing P&A operation. If you have any questions or concerns, please contact the undersigned at 258-3446. Thank you for your help. Duane H. Vaagen for BP Exploration (Alaska) Inc. enclosures Cc: Jason Moncrieff P.E., BPXA Steve Rossberg BPXA DeWayne Schnorr BPXA 715 L Street · Anchorage, Alaska 99501 · (907) 258-3446 · FAX (907) 258-5557 650 North Sam Houston Parkway East, Suite 505 ° Houston, Texas 77060 ° (281) 445-5711 'o FAX (281) 445-3388 STATE OF ALASKA ALASKAq: )IL AND GAS CONSERVATIOr COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,,, 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED: ABANDONED: X 2. Name of Operator ~I ~,,;~ ~ 7. Permit Number BP Exploration (Alaska) Inc. :~ 184-013 3. Address ~~~ 8. APl Number P.O. Box 196612, 900 E. Benson Boulevard, Anchorage, AK 99519-6612"~ - ~ ~~.~;' 50- 029-21053-02 4. Lo~tion of well at suda~ ~ ............... ~ 9. Unit or Lease Name 1619' FNL, 1428' FEL, Sec. 30, T13N, R10E, UM ASP's 543330, 6015002 ~ :" ~;~ Milne Point Unit At Top Producing Inte~al ~ 10. Well Number NA ................... ' MPU N-01B 1295' FNL, 4081' FEL, Sec 31 T13N, R10E, UM ASP's 540715, 6011032 5. Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease Designation and Serial No. Milne Point Unit / Kuparuk River Sands 54.5' KB (AMSL) I 12. Date Spudded12,17,1983 13. Date T.D. Reached1,27,1984 14. Date~o~., Susp. or Aband. J 15. Water Depth, if offshore3,~2~_~ (Abandoned) NA feet MSL J 16. No. of Completions0 17. Total Depth (MD+~D) 18. Plug Back Depth (MD+~D) J 19. Dire~ional Su~ey 20. Depth where SSSV set 21. Thickness of Permafrost 9208' MD (6816' ~D) 6' Below Tundra Grade LevelJ Yes: No: X NA feet MD NA 22. Type Ele~ric or Other Logs Run GR/CC~ubing Punch~ubing CuEPlug Se~Casing Punch-2/18/02 23. CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER FT. GRADE TOP BOSOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13 3/8" 72~ L-80 0 130' To Sufiace 0 9 5/8" 47~ H-90 0 2496' To Sufia~ 0 7" 2~ L-80 0 9183' 10-5/8" 1100 Sks 0 24. Pefiorations open to Produ~ion (MD+~D of Top and BoEom and 25. TUBING RECORD inte~al, size and number) SIZE J DEPTH SET (MD) PACKER SET (MD) 3 1/2"J 3325' 3258" None, Well P~'d. See aEached well diagram. Tbg cut at 320' RKB and pulled 26. ACID, F~CTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 3103' - 3325' 31.3 Bbls Class "G" (Squeeze Plug) 2159' - 2~7' 8.0 Bbls Ar~i~et I (Balan~d Plug) Sufia~ - 285' 17.5 Bbls Arcticset I (Sufia~ Plug) .... 27. PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL ~TIO 4/27/1984 NA TEST PERIOD => 0 0 0 NA~ NA Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (corr) Press. 0 0 24-HOUR RATE => 0 0 0 NA 28. CORE DATA Brief description of lithology, porosi~, fractures, apparent dips and presence of oil, gas or water. Submit ~re chips. L Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ~' 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. · 31. LIST OF ATTACHMENTS Wellbore schematic, Summary of Well Plug and Abandonment Operations, Log of tubing and casing punch and packer set, Photo's Signed Title C/~--~ 7/~_ Date Form 10-407 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 space 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 productin 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"..~ i:' :'~ ~ .ii', '! '~ ii '?',. i BP Exploration (Alaska) Inc. Milne Point N-O1B Well and P&A Procedure Information The Milne Point N-01 stratigraphic test well was spudded December 17, 1983 from a remote gravel pad on the tundra in the western part of the Milne Point Unit. The well was directionally drilled to a TD 7650' MD (7232' TVD) on December 30, 1983. Open hole logs were run and cores were obtained. The wellbore was then plugged back with a series of AOGCC approved cement plugs placed at 6776', 3600', 3150', and 2400' in preparation for drilling N-01A. N-01A kicked off of N-01 at 2586' MD and TVD on January 7, 1984. It was directionally drilled to a TD of 8603' MD (7010' TVD) on January 14, 1984. Again, open hole logs were run and the well was plugged back with a series of approved cement plugs placed from 7900' - 8200', 3600' - 3950', 3050' - 3400' and 2350 - 2700' MD. N-01B kicked offofN-01A at 2550' MD and TVD on January 19, 1984. It was directionally drilled to a TD of 9208' MD (6810' TVD). After openhole logs were run, 7" production casing was set from surface to 9193' MD and cemented with 1100 sacks of cement around the shoe. The 7" X 9 5/8" annulus at surface was then cemented with 16.5 barrels of Cold Set I cement followed by 50 barrels of Arctic Pack pumped through the 4" 5M annular valve on the casing head. The well was then perforated and tested over various intervals prior to suspension on April 27th, 1984. The perforated intervals below 3964' MD were isolated with cement retainers as the test zones became shallower. The final test interval from 3601' to 3894' MD was left isolated with a tubing packer at 3258' MD, and PXN at 3294' MD and a TRDP SCSSV at 2009' MD. The wellbore schematic in Attachment I details the configuration of the MPU N-01B well prior to commencing P&A Operations on February 1 lth, 2002. The permanent abandonment work summary attached details: 1) slickline operations to gain access to and remove prong and PXN from tubing tail; 2) pressure testing 3 ½" tubing and 3 ½" tubing X 7" casing annulus; 3) displacement of cement plug across open perforations below packer and subsequent AOGCC witnessed pressure test and tag of TOC; 4) perforation of tubing and displacement of diesel out of 3 ½" X 7" annulus; 5) displacement of cement plug No. 2 across surface casing shoe interval in tubing and 3 ½" X 7" annulus and subsequent tag of TOC; 6) cutting of tUbing string, setting a bridge plug and perforating casing above bridge plug to circulate out Arctic Pack; 7) displacing cement plug in 7" casing and 7" X 9 5/8" annulus; 8) severing casing strings 6' below original tundra grade level and installing steel well ID marker plate. A diagram (Attachment I) shows the final abandoned condition of the well. Also attached are copies of AOGCC correspondence while on the job, site photos taken during the P&A procedure and a daily P&A operations summary report. Fairweather E&P Services, Inc. MPU N-01B P&A Summary Page 1 of 6 4/9/2002 Final P&A'd Condition Mixed and pumped 17.5 bbls Arcficset I Cement plug to surface. Cement pumped down 9 5/8" X 7" annulus until returns at surface. Cut casing at -6' below original Tundra grade level. Welded on Steel ID marker Plate and covered. 7" perforated 274' - 276', "' Arctic Pack displaced 13 318" 72# L-80 '.h..~" out with Cement. 130' MD · :~ Tubing Severed 32d' Rridge Plug ~285' MD il: ~ii~i! TOC (~ ~ 2000' MD in 10.5 ppg CaCI2 9 7/8" X 7" annulus TOC Plua #2 (~_ :g159' :J'~- 9 5/8", 47# L-80 Tubing perforated 2496'M D(2496' ~VD) 2545' - 2547' wi6 .38" TOC Plua #1 (t~ 3103' holes (~ 3 spf. Placed 8 bbl 15.7 ppg Tubing Packer 3258' MD Arcticset I balanced plug PXN 3294' MD (Plug Pulled) 3 1/2" 9.3# L-80 8RD Tubing 3325' Squeezed perfs 4 spf 3980'- 3982' Perfs 12 spf88 Milne Point N-01B Milne Point Field, North Slope Alaska Squeezed 31.3 bbl Class "G" cement )lug from 3103'-3325' EZSV Cement Retainer 3964' MD (3585' ~/D) Size Wt. Grde Thrd Depth Sks/Cmt COMAETOR 13~s- 72# L-80 130' SURFACE 95/8" 47# H-90 2496' INTERMEDIATE LINER PRODUCTION 7" 26# L-80 BUT 9193' 1100sks TUBING 3 1/2" 9.2# L-80 8 RD 3325' Description OD ID Depth Well To Be P&A'd with following Hardware in Hole EZSV Cement Retainer 7" 9020' EZSV Cement Retainer 7" 8800' EZSV Cement Retainer 7" 3964' Baker FHL Hyd Ret. Packer 7" 3258' Description Start Depth' End Depth P&A Plug Location Referenced to RKB 253 ft (17.5 bbl) Cmt Plug Surface 276' 7" Bridge Plug 285' 8 bbl Cmt Plug Balanced 2159' 2547' 639 ft (31.3 bbl) Cmt Plug 3103' 3964' ATTACHMENT i PTD: 184-013 APl: 50-029-21053 Spud Date: Dec. 17, 1983 Date Suspended: April 27, 1984 Date P&A'd: March 30, 2002 Elev. (RKB) 54.50' AMSL All depths are RKB measured depths. EZSV Cement Retainer at 8860' Perfs 12 spf Squeezed perfs 4 spf 9025'-9050' 7" 26# L-80 ~ 9193' TD 9208' MD EZSV 9020' DRAWING NOT TO SCALE MILNE Pt. N-01B FA[RWEATHER E&P Final P&A / DHV SER VICES INC. 05~April-02 Fairweather E&P Services, Inc. MPU N-01B P&A Summary Page 2 of 6 4/9/2002 BP Exploration (Alaska) Inc. Milne Point N-O1B P&A Operations Summary DATE/Time OPERATIONS 09-Feb-02 to Fly crew to Deadhorse and proceed to Milne Point. Attend MPU 10-Feb-02 orientation and Milne Authorization To Proceed meetings. Mob crew and equipment to Milne Point. Spot fab shop, boiler, gen set and weather shack. Meet with Schlumberger cementers to discuss job requirements and notify AOGCC (Chuck Schieve) of plan to begin well Plug and Abandonment operations on Milne Point N-01B. 11-Feb-02 RU heaters, scaffolding and wind barrier around wellhead to thaw 0300 - 2100 hrs. cellar and warm valves. Well crew on site, lube and function test valves. Pressure test tree to 5000 psi, OK. RU lubricator and RIH with slickline. Tag backpressure valve in wellhead, POOH, RD lubricator, call out valve crew with BPV extractor and lubricator for same. RU and pull BPV. RD BPV extractor and lubricator and RU slickline lubricator and RIH with slickline and 2.83" gauge ring, drift check tubing and verify location of PXN prong. RU hydraulics to control line and cycle hydraulics, open SCSSV, pressure in lines holding steady. RIH, hit obstruction in tubing at 1977' slm. POOH, C/O assembly and PU 2.6" gauge ring, RIH to 1977' slm, obstruction seems to be soft. POOH, C/O assembly and PU 2.5" drive down bailer. RIH to 1977'slm tag and drive bailer down 2', POOH to examine contents. Bailer full of mud, RD close in well and return to camp. 12-Feb-02 Pressure test tree to 3500 psi, OK. Hook up on control line, 0600 - 2100 hrs hydraulically lock open SCSSV, pressure test tubing to 3500 psi, OK no loss. RU 10' X 2" bailer and bail to 2004' slm when assembly fell through (mud settled out on top of SCSSV at 2009' MD). RIH to 2782' slm and tag mud again. POOH dump bailer and continue bailing operations to 3070' slm. RD close in well and return to camp. 13-Feb-02 RU, pressure test surface equipment to 3500 psi, check pressures and 0600 - 2000 hrs cycle SCSSV, OK. Continue bailing operations, alternating between 10' X 2" and 5' X 2.5" bailer to facilitate quicker surface turnaround times on dumping bailer. Bail from 3070' - 3222' slm. RD, close in well and return to camp. 14-Feb-02 RU, pressure test surface equipment to 3500 psi, OK. Check 0600 - 2000 hrs pressures and cycle SCSSV, OK. Continue to bail as before alternating between 10' X 2.25", 10' X 2.0" and 10' X 1.75" bailers to 3252' slm. RD, close in well and return to camp. 15-Feb-02 RU, pressure test surface equipment to 3500 psi, OK. Check 0600 - 2100 hrs pressures and cycle SCSSV, OK. Continue to bail as before alternating between 10' X 2.25", 10' X 2.0" and 10' X 1.75" bailers. Fairweather E&P Services, Inc. MPU N-01B P&A Summary Page 3 of 6 4/9/2002 15-Feb Contd... Bail to 3264' sim, cannot bail further, when dumping bailer at surface noted metal marks on bottom face. LD bailer and RU LIB, RIH to tag obstruction at 3264' slm. Tap down 3 times and POOH to examine LIB. Intendation indicates top of prong in PXN. RD, close in well and return to camp. 16-Feb-02 RU, pressure test surface equipment to 4000 psi, OK. Check 0600 - 1400 hrs pressures and cycle SCSSV, OK. Pressure test tubing to 4000 psi, hold for 30 minutes, OK. RU and RIH with prong extraction tool. First extraction attempt failed when tool sheared off. POOH, redress tool and RIH to latch onto prong. Latch on and pull prong. RU and RIH with PXN pulling tool. Unable to latch, POOH and RIH with bailer to remove mud. LD bailer and RIH with PXN pulling tool, latch on and pull PXN plug. POOH and LD tool and pick up bailer, RIH to 3680' slm. Observe soft and sticky "Mud" in tubing, POOH, RD and demob slickline. Pressure up SCSSV control line to 5000 psi to lock open for P&A operations. Slickline off site at 1400 hrs. 1400 - 2400 hrs Notify AOGCC of intent pump cement and indicate may be ready for witness of pressure test and tag tomorrow. Order out water and cementers to displace cement plug No. 1 across the open perforations through bullhead squeeze technique. RU, pressure test lines, initiate injection and establish injection rate using seawater. Pump 50 barrels seawater, batch and pump 31.3 barrels 15.8 ppg Class G cement, displace 2 barrels freshwater spacer and displace with 28 barrels methanol to freeze protect tubing. Shut in well with 800 psi at wellhead. Wash down lines and vac out pump lines on surface, release cementers. Complete vac of remaining cellar fluids to allow access to annular valves. Return to camp. 17-Feb-02 WOC. Cement sample in warm up shack is mush, call Schlumberger 0600 - 1800 hrs to discuss findings and told system would not set up as quickly as desired due to surface temperature and retarder added. Recommended we wait full 24 hours after displacement before tagging and pressure testing against it. Order out eline to perforate, mix water, cementers and vac trucks. Unable to coordinate all to site due to high activity rate currently on slope. Schedule all for 18th of Feb. Let AOGCC know about schedule change. Change out flanges and valving on 7" X 9 5/8" annulus to prep for pumping and Arctic Pack displacement. Return to camp. 18-Feb-02 AOGCC witness John Crisp on location, waiting on eline, vac trucks, 0600 - 1800 hrs. cementers. RU eline and RIH. Tag TOC at 3103'. Tag witnessed and OK'd. John indicated it would not be necessary to have AOGCC on location to witness remaining plugs. Just need to record and call for witness when casing strings are cut and marker plate is installed. POOH with eline and RD eline and RU cementers to pressure test. Alternately test and monitor 3 ½" tubing and 3 ½" X 7" annulus to 1500 PSI each. Pressure test witnessed and OK'd. RD cementers Fairweather E&P Services, Inc. MPU N-01B P&A Summary Page 4 of 6 4/9/2002 18-Feb Contd... and RU eline, RIH with tubing punch to :2545'. Perforate tubing with six (6) .39" diameter holes from 2545' - 2547'. POOH and RD eline. RU cementers and vac trucks to place balanced plug from 2147' - 2547' inside 3 ½" tubing and in 3 ½" X 7" annulus. Initiate circulation with CaC12 brine to displace out methanol in tubing and diesel in tubing/casing annulus. Pump 4.35 barrels of freshwater as spacer ahead of cement and displace 8 barrels of cement. Chase cement with fresh water and CaC12 to freeze protect tubing. Wash down and vac out pump lines. WOC. Will not release eline or cementers as hope to complete operations tonite while equipment is available. 1800 - 2400 hrs. WOC. Order out Hot Oil pump truck to heat and displace out Arctic Pack. Order out crane to pick off Christmas tree and pull tubing after cut. RU flow hardline and valves to tie in to annulus. RU Schlumberger eline. RIH to tag TOC. CCL failure, POOH to change out. 19-Feb-02 C/O CCL on eline and RIH to Tag TOC. TOC at 2159'. POOH to 0030 - 1200 hrs. 305' and cut tubing with jet cutter. POOH and RD eline. Pull tree and set aside. RU Hot Oil and circulate hot brine through tubing and back up tubing / casing annulus. RD Hot Oil, RU crane and elevators to pull tubing. Tubing is obviously not cut. Pulled 50,000 lbs with crane. Observed tubing hanger unseating from slip bowl, so tubing is stretching. RD crane and RU Schlumberger with jet cutter to attempt recut on tubing. RIH to 293' and attempt 2nd cut. RD eline and RU crane. Again pull 50,000 lbs and observe same pipe stretch. Cementers released from location, order out chemical cutter. RU Hot Oil to again circulate hot fluids to warm wellbore for chemical cutter. 1200 - 2130 hrs. Standby waiting on Schlumberger hands to deliver two chemical tubing cutters and perforating guns for back up plan. 2130 - 2400 hrs RU eline with chemical cutter, hold safety meeting to discuss hazards of using same. RU crane to put tubing in tension when executing cut. RIH to 320' and execute tubing cut attempt #3, cut successful. POOH with eline and RD. Had release of CaC12 spray when cutter went off and tubing hanger unseated. Report as spill to proper authorities, clean up contaminated snow. Proceed to pull and lay down tubing with crane. 20-Feb-02 Finish laying down tubing. RU eline with gauge ring to inspect id of 0030 - 1800 hrs 7" casing. RIH to top of tubing stub. POOH, pick up Baker wireline set bridge plug, RIH and set BP at 285'. POOH and PU casing punch, RIH and punch 7" casing with six (6) holes at 3 spf from 274' to 276'. POOH RD eline. RU Hot Oil and break circulation with hot water down 7" X 9 5/8" annulus with returns up ID of 7" to holding tank. Release eline from location when circulation observed. Fairweather E&P Services, Inc. MPU N-01B P&A Summary Page 5 of 6 4/9/2002 20-Feb contd... Circulate and flush out Arctic Pack until clean returns are observed. Swap lines and pump down ID of 7" taking returns from OA to holding tank. Circulate and flush out Arctic Pack until clean returns are observed. RD Hot Oil, swap lines, RU cementers, initiate circulation down OA with returns up ID of 7" casing. Clean returns observed. Batch and displace 17.5 barrels ofArcticset I cement, pumping until good cement returns observed at surface. Clean up cementing lines and RD cementers. Clean up lines and rig down all equipment, clean location and begin mobilizing equipment to Sag Delta No. 1. 21 -Feb-02 Finish site clean up and complete mob process of equipment to Sag Delta No. 1 for P&A work there. Will leave site until gravel has been removed and come back at later date to cut casing 4' - 5' below original Tundra grade level and weld on well ID P&A marker plate. Demob until later date... 26-Mar-02 Return to site, find gravel contractors have cut pad gravel down, but have not removed or dug out below cellar. Instruct to dig out. Off site until next morning. 27-Mar-02 Gravel contractors have not dug out cellar yet, again instruct on how to dig out and how deep, standby and help with clean up of foam insulation which is peeling off cellar box as it is being removed. Discover some diesel residue on gravel just below cellar, instruct to stockpile for disposal off-site and to keep digging. Bell holes have been dug around 4 rig anchor piles, and piles have been marked by surveyor so instruct crew to cut and remove anchors while waiting. Anchors cut 5' below Tundra grade level. Decision made to go to Sag Delta No. 1 to cut casing string as contractor there is waiting on us. Demob all off site to Sag Delta No. 1. 28-Mar-02 On site, inspect excavation and determine not deep enough. Instruct excavator operator to deepen hole and clean up access ramp for better ingress and egress. RU heater, compressor, guillotine casing saw and parachute for heat retention. Cut wellhead and casing strings 6' below original tundra grade. Note that no cement exists in annulus between 13 3/8" conductor and 9 5/8" casing. ID of 7" casing and 7" X 9 5/8" annuli are full of good clean cement. Contact Dowell and line up cement for top job before welding on P&A marker ID plate. Mobilize off site to West Sak 25 to cut casing strings there, while WOC. AOGCC witness, John Crisp on site to inspect cut. 29-Mar-02 On site with cement, mix and pour 5 gallons cement to fill 9 5/8" X 13 3/8" annulus. AOGCC (John Crisp) back on site to inspect ID plate and weld and to photograph same, all approved. AOGCC also approved West Sak 25. Mobilize across field to Sag Delta No. 1 to perform second cut on casing. Order out junk dumpster to remove wood scraps and scrap metal for disposal. 30-Mar-02 Pick and load all debris into dumpster and remove from location. Fairweather E&P Services, Inc. MPU N-O 1 B P&A Summary Page 6 of 6 4/9/2002 Milne Point N-0 lB Well P&A Photo's BPXA, Winter 2002 P&A Program Fairweather E&P Services, Inc. Milne Point N-01B P&A Photo's Page 1 of 6 4/16/20O2 6 B r MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' THRU' DATE: Camille O. Taylor, Chair Tom Maunder, ?~¢'~o_~.~.~/~( P. I. Supervisor FROM' John Crisp, SUBJECT: Petroleum Inspector March 29, 2002 Plug & Abandon MPU N-01B PTD 184-013 March 29, 2002' I traveled to BP's Milne Point Field to witness cement to surface on all casing strings & Marker Plate installed on MPU N-01B. I witnessed that the conductor pipe on MPU N-01B had been cemented & also witnessed the installation of the Marker Plate. Two pictures are attached for reference. Summary: I witnessed all casing 'strings on MPU N-01B had cement to I witnessed the installation of the Marker Plate. Attachment: Dsc 00024. jpg Dsc 00026. jpg surface & NON-CONFIDENTIAL P & A MPU N-01B 03-29-02jc.doc J,PEG image 640x480 pixels -> ~ ) ~ ,~~ \ ~-O\ \ ø- \~ c: , , , \-J- C) \ ~/ .", ~ . \N~\\ ~~"~fi\~ <;~~~f~j d- (d- - '6 ~.. ~çC-\':c~i-\CR~. w ( c ~\- ~. " 1'~~:5 \oJ:> \ (J~\.: .~S;-O 'o\)\ A ~. .' . ~9fJ¡}1--4\ \ .. 1,,<> éz..~\t~~Y ~Oj~:~ '$cv~~'e rzx~~ ~o¿);s-aS1 )':';:I'l~~..1 );;ilt.il'j"',':'~.::.t,' """"', , ",/\k)L \.",',."P"", ,,;(,j" """ ",.' , ., r \\""'~~ ~ 'J,.V" """~~ ;~t:j'v9' '~d-\ 6 b.~~ '6.\ \ ,. ",,' ,'". ,;/~\\€.~ ( ,,', ',/ " , ,.r \b'S~t~~~~~ ~ -,; '!~,,)-~.~~! 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MPU N-O1B 13-3/8", 72 #fit, L-80 / K-551 +1-130' I 9-5/8", 47 #fit, L-80 I+1- 2496'(2496' TVD)I Squeeze(2) Perfs 4spf 13330'. 3332'I Perfs 12 spf Hollow 13354' - 3388' Carder Perfs 12 spf Hollow 13398' - 3464' Carder Squeeze Perfs 4spf{ 3468'. 3580' Perfs 12 spf Hollow 13601' - 3814' Carder Pen's 12 spf Hollow 13636' - 3661' Carder Pen's 12 spf Hollow 13668' - 3674'J Carder Squeeze Perfs 4spf13720'. 3722' Perfs 12 spf Hollow 13749' - 3788'1 Carder Pen's 12 spf Hollow 13794' - 3830' Carder Squeeze Perfs 4spf13980' - 3982'I ~ ~ Pen' 12 spf Hyper II I 8820' ~ Charges Pen' 12 spf Hyper II I 8985' ~ Charges(lst time w/4sp0 I 9015' J Pen' 12 spf Hyper II ~ Charges - sqz'd 7", 26 #/ft, L-80 ~ nt Condition 12/15100 GL Elevation = 27.8' RKB = 54.5' Max Dev = 63.5 degrees Permafrost I +/-1800'I Tubing PKR I 3258' I TubingTailI 3325' I 3.5" 9.2#/ft Halliburton 13964, {3858' TVD)I EZSV TOC = ???? Halliburton J 8800' ~ EZSV ILegen~ ~ P~maiy cem nt ~ squeeZe C~ment/ Lyne ECP I 9020' I MILNE POINT UNIT WELL: N-01B APl #: 50-029-21053-02 MPU N-01B 13-318", 72#1ft, L-801K-551 +1-130'I 9-5/8", 47 #/ft, L-80 [+1- 2496'{2496' TVD)I Squeeze(2) Perfs 4spf 13330'. 3332' Pen's 12 spf Hollow 13304'. 3388'1 Carrier Perfs 12 spf Hollow 13390' - 3464' Carder Squeeze Perfs 4spfI 3498'. 3600' Pen's 12 spf Hollow 13601' - 3014'J Carder Perfs 12 spf Hollow 13636' - 3661 Carrier Pen's 12 spf Hollow 13668'. 3674' Carder Squeeze Perfs 4spf13720'. 3722' Pen's 12 spf Hollow 1374.9'. 3766 Carder Perfs 12 spf Hollow 13794'. 3830' Carder Squeeze Perfs4spf 136,80'.3982'] ~ Ped 12 spf Hyperll18820'l Charges Pen' 12 spf Hyper II 1 8985' I Charges(lst time w/4spf) ~ Perf 12 spf Hyper II ~ 9025' I Charges - sqz'd 7", 26 #fit. L-80 ~ nt Condition 12115/00 GL Elevation = 27.8' RKB = 54.5' Max Dev = 63.5 degrees Permafrost J +/. 1800' J Tubing PKR I 3258, I Tubing TailI 3325' I 3,5" 9.2#/ff Halliburton 13964, (3858' TVD)I EZSV TOC = ???? Halliburton I 8800' ~ EZSV Legend Primary Cement squeeze Cement Lyne ECP I 9020' I MILNE POINT UNIT WELL: N-01B APl #: 50-029-21053-02 MPU N-01B After Pro 13-3/8", 72 #/fi, L-80 / K-551 +1-130' J 9-5/8", 47 #/ft, L-80 ~ Squeeze(2) Pads 4spf 13330'-3332'1 Perfs 12 spf Hollow 13354' - 3388'I Carder Pen's 12 spf Hollow 13395' - 3464'I Carder Squeeze Pads 4spf I 3498' - 3500 Pen's 12 spf Hollow 13G01' - 3614' Carder Perfs 12 spf Hollow 1363G'. 365t'1 Carrier Pen's 12 spf Hollow 13668' - 3674' Carder Squeeze Perfs 4spf13720' - 3722' Pen's 12 spf Hollow 13749' - 3766' Carder Pen's 12 spf Hollow 13794' - 3830' Carder Squeeze Pen's 4spf13980' - 3982'I Pen' 12 spf HyperllI 8820' Charges I 8940, Pen' 12 spf Hyper II Charges(lst lime w/4sp0 Pen' 12 spf Hyper II I 9025' Charges - sqz'd I so59' I 7", 26 #/~t, L-80 I +/' 9193' I Abandonment GL Elevation = 27,8' RKB = 54.5' Max Dev = 63.5 degrees Permafrost I +1-1800' I Tubing PKR I 3258' I Tubing TailI 3325' [ 3.5" 9.2#/ft Tubing Punch Halliburton [3964' (3858' TVD)[ EZSV TOC = ???? Halliburton [ 8800' [ EZSV Legend Primary cement : initiai ArCtiC Pa~k; Lyne ECP I 9020' I MILNE POINT UNIT WELL: N-01B APl Cf: 50-029-2t 053-02 ) ) 184-013-MPU-N01Babdn-010126.txt subject: Re: N-01B (184-013) Date: Sat, 27 Jan 2001 06:20:27 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Franks, James 0" <FranksJD@bp.com> CC: Lou Grimaldi <lou_grimaldi@admin.state.ak.us> James, sorry about that. I have reviewed the well file as you know and discussed what I was able to determine from the record. 1. Based on the testing information, the Kuparuk zones appear to have been successfully isolated outside by the primary cement job. 2. Following the Kuparuk testing, a retainer was set above the perforations and the tagglng and weight testing witnessed by an AOGCC inspector. 3. The 7" caslng above the retainer was filled with 10.1 or 10.3 inhibited bri ne. 4. No other zones were perforated between the Kuparuk and schrader. 5. In order to test the schrader intervals, it was necessary to squeeze cement. 6. A retainer was set about 3964' (16' above squeeze perforations) and cement squeezed through it. That retainer and the cement below it has never been disturbed. 7. Following the shallow testing, tubing and a packer were run and the well was suspended. I have discussed the condition of the wellbore with one of our inspectors (LOU Grimaldi). We are in agreement that the well is satisfactorily abandoned from the retainer at 3964' to TO. We look forward to receiving your final plan from the remaining portions of the wellbore. Good luck. Tom Maunder AOGCC "Franks, James 0" wrote: > Tom, > > > > > > > please advise when you have some time. I would have called, but I figure > that e-mail let's you decide when you want to discuss the subject. > > Thanks for your time and consideration. > > james > > James Franks > BP Alaska Drilling & wells > office: 907-564-4468 > cell: 907-440-0187 I am very sorry for bugging you again, but I have not heard anything from your inspector with regards to the EZSV'S in the well. I have adapted the procedure for the tubing plu~ you pointed out to me(thanks) and for a possible cement "bullheading if all works out. -~j~, ,_' f~\'! '~" 1:. ~ ~.~Er / ,- «(UO':) CJ C\~~CP ~~J€ù ~l;f)~ocÇ$1V1 --------------------------------------------------------------------- Tom Maunder <tom_maunder@admin.state.ak.us> Petroleum Engineer Alaska oil and Gas Conservation commission page 1 ,) ) 184-013-MPU-N01Babdn-010126.txt Tom Maunder petroleum Engineer Alaska oil and Gas Conservation commission 3001 porcupine Dr. Anchorage AK 99501 USA Additional Information: Last Name Maunder First Name Tom version 2.1 <tom_maunder@admin.state.ak.us> Fax: 907 276-7542 work: 907 793-1250 Conference Software Address ~p \:J '- \J--~ ç \''' ~ \P~4'VV\ page 2 RE: MPU N-01B Subject: RE: MPU N-01B Date: Tue, 16 Jan 2001 16:12:03 -0600 From: "Franks, James D" <FranksJD@bp.com> To: '"Tom Maunder'" <tom_maunder@admin.state.ak. us> Tom, I am in complete agreement that it would be desirable to get rid of the Arctic Pack fluid. I have spoken with the Schlumberger folks and they have informed me of the same issue you have with regards to perfing the 9-5/8" as well. For that issue, we might need to get a rig out to pull the tubing ~D we can punch a little easier or even to remove a top portion ofthe 7". The work is slated to start having an ice road built around the 1st to 15th of Feb, but if we need a full blown workover rig to do the work, they might wait. I just want to clarify, if we were to abandon the zone with coil, we would not have to remove any of the EZSV's in the well? I was hoping that was the case, but could you confirm that point specifically? I do thank you for your time. Hopefully the work load you have isn't too high:). Thanks again, james franks I of 1 1/19/01 10:24 AM N-01 B Subject: N-01B Date: Thu, 11 Jan 2001 13:40:47 -0600 From: "Franks, James D" <FranksJD@bp.com> To: '"tom_maunder@admin.state.ak. us"' <tom_maunder@admin.state.ak. us> Mr. Maunder, Thanks for your assistance. Attached is the file in question. The procedure is not finalized and I may have a few typos at this point. I hope the drawings are useful. Give a shout if you need anything more. The big questions I see are the EZSV's and the arctic pack fluid in the outer annulus. We would like to do this with coil, but it may not be possible depending on your evaluation. Thanks for your time. james <<N-01B tentative procedure.doc>> James Franks BP Alaska Drilling & Wells office: 907-564-4468 cell: 907-440-0187 <<Franks, James D.vcf>> ~N-01B tentative procedure.doc Name: N-01B tentative procedure.doc Type: Microsoft Word Document (application/msword) Encoding: base64 Franks, James D <FranksJD~,BP.com> Drilling Engineer bp Exploration Alaska ADN 1 of 1 1/19/01 10:26 AM MPU N-01B After Pro 13-3/8", 72 #/ft, L-80 / K-55[ +/- 130' 9-5/8", 47 #/ft, L-80 ~ Squeeze(2) Perfs 4spf 13330' - 3332'I Perfs 12 spf Hollow 13354'. 3388'J Carder Peris 12 spf Hollow 13395'. 3404'I Carder Squeeze Perfs 4spf Peris 12 spf Hollow 13601' - 3614' Carder Peris 12 spf Hollow Carder Peris 12 spf Hollow J 3668' - 3674' Carder Squeeze Peris 4spf13720' . 3722' Peris 12 spf Hollow 13749' - 3796' Carder Peris 12 spf Hollow 13794' - 3830' Carder Squeeze Perfs 4spf13980' - 3982'J Abandonment GL Elevation = 27.8' RKB = 54.5' Max Dev = 63.5 degrees Permafrost I +/-1800'I Tubing PKR t 3258' I Tubing TailI 3326' I 3.5" 9.2#/ff Tubing Punch Halliburton 13964, (3858' TVD)J EZSV TOC = ???? Peri 12 spf Hyper II I 8820' Charges I 8940' I Halliburton I 8800' EZSV Legend pdmary cement Squeeze cement PlUg cement : Ihitial ArCtic Pack Peri 12 spf Hyper II J 8985' J Cha rges(lst time w/4spt) I 9015' I Peri 12 spf Hyper II I 9025' J Charges- sqz'd I 9059' I 7", 26 #fit, L-a0 I +/- 9193' I Lyne ECP I 9020' I MILNE POINT UNIT WELL: N-01B APl #: 50-029-21053-02 N-01 B Tentative Abandonment procedure: version 4 This procedure is contingent on the state letting us leave the arctic pack fluid in the outer annulus and not making us take out any of the EZSV's in the well. If we can pump fluid in the outer annulus, then we will do so. Plug Pre-work: 1) Rig up HB&R and pressure test the 7" X 9-5/8" annulus to 2000 psi using freeze protected fluid. Hold and record the pressure on the outer annulus for 30 minutes. If the pressure bleeds off rapidly, perform an injectivity test up to 3 bpm or 2000 psi on the outer annulus using iMeOH or Diesel. Monitor and record the pressure on the inner annulus for possible communication during the pressure test operations. - Should Dowell do this and then the cement job on. the outer annulus? 2) RDMO HB&R. 3) Rig up Slick line and run in to tag EZSV or fill. Record Depth. RDMO. 4) If Slickline tag depth is 3894' or deeper, then continue with step 6. If the Slickline tag was higher than 3894', then continue with step 5. - Can we get rid of the slickline and .just do 'this with coil? 5) If a Fill Clean Out above the EZSV ~ 3964' is needed, rig up Dowell Coiled Tubing unit to clean out fill on top of the EZSV ~ 3964'. Perforation Plugein~ Ol~erations: Notit}r AOGCC 24 hours prior to plugging operations 6) Rig up Dowell Coiled Tubing Unit to lay in cement plug. 7) Circulate 2 hole volumes with 100-degree water prior to cement placement. 8) Squeeze/Plug. Rig up Dowell Cement unit and Pressure test lines to 4000 psi. 9) Pump the following for a squeeze/plug over the zone of interest. a. Cement volume based on the volume of the 7" from the EZSV ~ 3964' to 3325' and 20% excess squeezed behind pipe. Cement volume is 30 bbls. b. Estimated cement design. To be verified by Dowell: 146 sacks of Class G 0.5% SO01 - CaC12 Accelerator 0.2% D046- Antifoam 0.3% D065 - Dispersant 10) Lay in 30 bbls cement 1:1 from the EZSV depth of 3964' into the tubing tail to 2635' keeping 50-100 ft of cement volume above the nozzle. Be aware of the volume change as the cement top enters the tubing tail on the backside. Attempt to squeeze 6 bbls of cement slurry behind 7". If the cement will not go behind pipe, leave it in the tubing. Do not: let pressure go above 1000 psi. Watch the pressure on the 7"x 9-5/8" annulus for indication of communication to surface. If pressure is indicated, contact ODE. 11) Freeze protect the tubing to 2200' MD. RDMO Coiled Tubing Unit. 12) WOC - time to be determined by lab testing - 24 hours. 13) Rig up HB&R to pressure test the cement plug to 1500 psi. 14) RDMO HB&R. 15) Rig up Slickline. Run in and tag the top of cement and record the depth. 16) Contingency items. a. If the TOC is below 3501' MD contact ODE in regards to additional cement plug. b. If pressure test is not satisfactory, contact ODE to determine setting of another cement plug. c. If the pressure test and the tag are satisfactory. 17) RDMO Slickline. MIRU Schlumberger Wireline with tubing punch and punch the tubing ~ 3235' MD or just above the TOC, whichever is shallower, with 1 foot at 4 spf. 18) RDMO Schlumberger Wireline. Surface Plu~in~ Ooerations: Noti~ AOGCC 24 hours prior to plugging operations 19) Outer Annulus Plug Depending on the injection test :in. Step 1. If the outer annulus pressure test was satisfactory, move on to step 20. If the pressure test on the outer annulus was not satisfactory and injection was established, rig up Dowell Cementers to establish injection with water followed by 50 bbls ArcticSet I. Stay below 2000 psi during the pumping operation. 20) Surface Plug. Rig up Dowell cementers to the tubing and circulate 114 bbls (depending on 1 st plug height) ArcticSet I cement down the tubing and up the tubing to casing annulus. When cement returns get to surface, shut down Dowell cementers and clean up. RDMO Dowell cementers.- How do we :make sure we can cra the casing/tubing and still satis~ the state regs to have cement at the surface of the annular spaces? 21) Turn over to Asset. Post Plug~in~ Operations 22) 23) 24) 25) 26) WOC 24 hours. ND wellhead. Verify that cement top inside 3-1/2". Veri~~ the cement in the 3~ 1/2" to 7" annulus and is at surface..Also verit}~ cem.ent in the outer armulus if cement was pumped. Remove the tree prior to cutting casing strings. Ensure all pressure has been bled off. of the casing/tubing prior to cutting. Dig out around conductor and cut off. all casing strings at a point 4' m 5' below original ground level. Weld a steel plate across all the casing/tubing strings. The steel plate should have the following information bead welded on top: BP Exploration Alaska, Inc./Milne Point Bay Unit/N-01B/2660' FSL, 1425' FEL, Sec 30, T13N, R10E, UM, API# 50-029-21053-02 Remove cellar, back fill hole to pad grade level. N-01 B Tentative Abandonment procedure: version 4 This procedure is contingent on the state letting us leave the arctic pack fluid in the outer annulus and not making us take out any of the EZSV's in the well. If we can pump fluid in the outer annulus, then we will do so. Plug Pre-work: 1) Rig up HB&R and pressure test the 7" X 9-5/8" annulus to 2000 psi using freeze protected fluid. Hold and record the pressure on the outer annulus for 30 minutes. If the pressure bleeds off rapidly, perform an injectivity test up to 3 bpm or 2000 psi on the outer annulus using iMeOH or Diesel. Monitor and record the pressure on the inner annulus for possible communication during the pressure test operations. - Should DowelI do this and then the cement job on the outer annulus? 2) RDMO HB&R. 3) Rig up Slick line and run in to tag EZSV or fill. Record Depth. RDMO. 4) If Slickline tag depth is 3894' or deeper, then continue with step 6. If the Slickline tag was higher than 3894', then continue with step 5. - Cm~. we get rid of the slickline m~d just do this with coil? 5) If a Fill Clean Out above the EZSV ~ 3964' is needed, rig up Dowell Coiled Tubing unit to clean out fill on top of the EZSV ~ 3964'. Perforation Plu~,~inff Ooerations: Notit}r AOGCC 24 hours prior to plugging operations 6) Rig up Dowell Coiled Tubing Unit to lay in cement plug. 7) Circulate 2 hole volumes with 100-degree water prior to cement placement. 8) Squeeze/Plug. Rig up Dowell Cement unit and Pressure test lines to 4000 psi. 9) Pump the following for a squeeze/plug over the zone of interest. a. Cement volume based on the volume of the 7" from the EZSV ~ 3964' to 3325' and 20% excess squeezed behind pipe. Cement volume is 30 bbls. b. Estimated cement design. To be verified by Dowell: 146 sacks of Class G 0.5% SOO 1 - CaC12 Accelerator 0.2% D046 - Antifoam 0.3% D065 - Dispersant 10) Lay in 30 bbls cement 1:1 from the EZSV depth of 3964' into the tubing tail to 2635' keeping 50-100 ft of cement volume above the nozzle. Be aware of the volume change as the cement top enters the tubing tail on the backside. Attempt to squeeze 6 bbls of cement slurry behind 7". If the cement will not go behind pipe, leave it in the tubing. Do not let pressure go above 1000 psi. Watch the pressure on the 7"x 9-5/8" annulus for indication of communication to surface. If pressure is indicated, contact ODE. 11) Freeze protect the tubing to 2200' MD. RDMO Coiled Tubing Unit. 12) WOC - time to be determined by lab testing- 24 hours. 13) Rig up HB&R to pressure test the cement plug to 1500 psi. 14) RDMO HB&R. 15) Rig up Slickline. Run in and tag the top of cement and record the depth. 16) Contingency items. a. If the TOC is below 3501' MD contact ODE in regards to additional cement plug. b. If pressure test is not satisfactory, contact ODE to determine setting of another cement plug. c. If the pressure test and the tag are satisfactory. 17) RDMO Slickline. MIRU Schlumberger Wireline with tubing punch and punch the tubing ~ 3235' MD or just above the TOC, whichever is shallower, with 1 foot at 4 spf. 18) RDMO Schlumberger Wireline. Surface Plugginff Operations: Noti~r AOGCC 24 hours prior to plugging operations 19) Outer Annulus Plug Depending on the injection test in. Step 1. If the outer annulus pressure test was satisfactory, move on to step 20. If the pressure test on the outer annulus was not satisfactory and injection was established, rig up Dowell Cememers to establish injection with water followed by 50 bbls ArcticSet I. Stay below 2000 psi during the pumping operation. 20) Surface Plug. Rig up Dowell cementers to the tubing and circulate 114 bbts (depending on 1 st plug height) ArcticSet I cement down the tubing and up the tubing to casing annulus. When cement returns get to surface, shut down Dowell cementers and clean up. RDMO Dowell cementers.- How do we make sure we can cut the casing/tubing and still satis~~ the state regs to have cement at the surface of the annular spaces? 21) Turn over to Asset. Post Plu~in~ Ooerations 22) WOC 24 hours. 23) ND wellhead. Verify that cement top inside ~ ~/'" _~-~, ~, . Verify the cement in the 1/2" to 7" annulus and is at surface..Also veri~.}r cement in. the outer annulus if cement was pumped. 24) Remove the tree prior to cutting casing strings. Ensure all pressure has been bled. offofthe casing/tubing prior to cutting. Dig out around conductor and cut offal[ casing strings at a point 4' to 5' below original ground level. 25) Weld a steel plate across all the casing/robing strings. The steel plate should have the following information bead welded on top: BP Exploration Alaska, Inc./Milne Point Bay Unit/N-01B/2660' FSL, 1425' FEL, Sec 30, T13N, R10E, UM, API# 50-029-21053-02 26) Remove cellar, back fill hole to pad grade level. MEMORANDUM State of Alaska TO: THRU: Alaska Oil and Gas Conservation Commission Camille O. Taylor, Chair Tom Maunder, P. I. Supervisor t,-\t'~-'O"~ DATE: March 28, 2002 FROM: John Crisp, SUBJECT: Petroleum Inspector Plug & Abandon MPU N-01B PTD 184-013 March 28, 2002: I traveled to BP's Milne Point Field to witness the casing cut @ least 3' below tundra level & cement to surface in all casing strings on well MPU N-01B. I witnessed all casing strings cut 6' below tundra level on MPU N-01B. The conductor to surface casing annulus was void of cement & had ice deposits inside annulus. I requested BP to thaw ice deposits as deep as possible & fill void wi cement. I told BP Rep. Duane Vaagen I would like to witness final cement in place & installation of marker plate. Marker plate installation would be accomplished 3/29/02. Summary: i witnessed all casing strings on MPU N-01B cut 6' below tundra level. Attachment: Dsc 00016. jpg NON-CONFIDENTIAL P & A MPU N-01B 03-28-02jc.doc -0\ \ ~ \ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_X Suspend_ Operational shutdown _ Re-enter suspended well _X Alter casing_ Repair well _ Plugging _X Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 54.5 feet 3. Address Exploratory_X 7. Unit or Property name P. O. Box 196612 Stratigraphic Anchorage, AK 99519-6612 Service__ Milne Point Unit 4. Location of well at surface 8. Well number 2619' FNL, 1428' FEL, Sec. 30, T13N, R10E, UM (asp's 543330, 6015002) MPN-01B~'~ ......... '~' At t~uctive interval 9. Permit number / approval num~,~; ~.~-~ 2843' FNL, 1591' FEL, SEC 30, T13N, R10E, UM (asp's 543169, 6014777) 184-0130 At effective depth 10. APl number 3002' FNL, 1705' FEL, Sec. 30, T13N, R10E, UM (asp's 543057, 6014617) 50-029-21053-02 At total depth 11. Field / Pool 1295' FNL, 4081' FEL, Sec 31 T13N, R10E, UM (asp's 540715, 6011032) Milne Point Unit/Kuparuk River Sands 12. Present well condition summary Total depth: measured 9208 feet Plugs (measured) EZSV Retainers @ 9020', 8800', 3964' true vertical 6810 feet 7" Float Collar @ 9112' Effective depth: measured 3964 feet Junk (measured) true vertical 3585 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 95' 13-3/8" To Surface 130' 130' Surface 2461' 9-5/8" To Surface 2496' 2495' Production 9158' 7" 1100 sxs 9193' 6782' Perforation depth: measured Open Perfs 3601 '-3614', 3636'-3651 ', 3668'-3674', 3749'-3756', 3794'-3830', 3874'-3894', Below EZSV Retainers @ 3964' & 8800' Open Perfs 8820'-8940', 8985'-9015', Sqzd Perfs 3330'-3332', 3354'-3388', 3395'-3464', 3498'-3500', 3720'-3722', Below EZSV Retainers @ 3964' & 8800' Sqzd Perfs 3980'-3982', 9025'-9050' true vertical Open Perf 3553'-3564', 3583'-3596', 3611'-3616', 3680'-3686', 3718'-3748', 3784'-3801' Below EZSV Retainers @ 3964' & 8800' Open Perfs 6588'-6657', 6683'-6700' Sqzd Perfs 3308'-3310', 3330'-3361', 3368'-3430', 3461'-3463', 3655'-3657', Below EZSV Retainers @ 3964' & 8800' Sqzd Perfs 3871'-3872', 6706'-6721' Tubing (size, grade, and measured depth 3-1/2", 9.2 Ib/ft 1_-80 @ 3325' Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker "FHL" Hydraulic Retrieveable Packer @ 3258' MD. 3-1/2" Camco TRDP-1A @ 2009' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: 11 February 2, 2002 16. If proposal was verbally approved Oil __ Gas __ Suspended _X Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Monte Townsend @ 564-4602. Signed j~~,..~'_~ Title: Staff Petroleum Engineer Date January 14, 2002 Monte Townsendli¢~ Prepared by DeWayne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Com~sion so representative may witness I Appr_oval~no. Plug integrity __~ BOP Test__ Location clearance%1--,-,I ~:~ Mechanical Integrity Test__ Subsequent form required 10- L'~0 ' ~ Original Signed By Approved by order of the Commission ~,mm,, n,w, hol; Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 09-Jan-02 Ms. Julie Heusser Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Re: Application for Sundry Approval; Permanent Abandonment: BP Exploration (Alaska) Milne Point Unit N-01B Dear Commissioner Heusser: BP Exploration (Alaska) Inc. (BPXA) hereby applies for Sundry Approval of its plan to plug and abandon the Milne Point N-01B Well. The anticipated commencement date of this work is approximately February 1, 2002. The well will be permanently plugged and abandoned by squeezing off and cementing over open perforations below the tubing packer currently in place. The tubing will then be perforated and a 200 foot balanced cement plug will be placed in the tubing and across the surface casing shoe and tubing annulus. The tubing will then be cut and a bridge plug will be set over the top of the tubing stub. The 7 inch casing will then be perforated above the bridge plug and the Arctic Pack will be circulated out of the surface annuli. A cement plug will then be placed across all casing strings above the bridge plug at surface (200 foot minimum). The cellar will be removed, and all casing strings will be cut a minimum of 5 feet below original datum and removed. A permanent marker plate will then be welded to the top of the casing stub. The excavation will be backfilled, and the site will be turned over to the gravel reclamation contractors for site reclamation. Pertinent information attached to this application includes the following: 1. Three (3) originals; AOGCC Form 10-403 for the well; 2. Three (3) copies: Plug and abandonment operations program for N-01B with schematics showing current and proposed condition of the wellbore. If you have any questions or concerns, please contact Duane Vaagen at 258-3446. Thank you for your help. Ms. Julie Heusser Page 2 Sincerely, Monte Townsend BP Exploration (Alaska) Inc. Attachments Cc' Jason Moncrieff P.E., BPXA Duane Vaagen (Fairweather) PTD 84-13 OPERATIONS PLAN PERMANENT ABANDONMENT BP Exploration (Alaska) Inc. (BPXA) Milne Point N-01B API No. 29-21053 The following Operations Program addresses the work scope to be performed in the course of reentry and P&A operations only. This program assumes a winter operation with access and support by ice road and truck. Obtain all required permits and regulatory approvals before starting job. Complete all BPXA HSE requirements before job start-up. Anticipated permits and forms for the well work include the following: · Application for Sundry Approvals, Form 10-403(AOGCC) · North Slope Borough Administrative Approval · BPXA Authorization to Proceed . Mobilize all required personnel and equipment to the MPU N-01B location on an as needed basis via ice road. Note: Driving to this site will be rather time consuming so crew and equipment call out and expediting will have to take this into account. o Hold safety meeting before starting work on the well. Notify AOGCC of intent to begin operations. Notify Milne Point Field Supervisors of P&A operations start. . Remove guard rails and cover from cellar. RU steam skid and thaw and evacuate fluids to gain access to all components of wellhead. o Move in portable well head shelter, work shop and hot air heaters. Spot open top tanks for handling wellbore fluids. Heat wellhead, function test and lubricate valves as necessary while testing for pressures in both the 9 5/8" x 7" casing annuli, the 3 ½" tubing x 7" casing annulus and the ID of the tubing. . RU test pump for pressure testing purposes. Connect to 3" 5M flange on tubing valve and pressure test well tree and tubing to 2500 psi. for 30 minutes while monitoring for flow and transient pressures up the 3 ½" X 7" annulus. If OK, RD and connect to 4" 5M valve on 3 ½" X 7" annulus. Pressure test annulus to 2500 psi. for 30 minutes while monitoring tubing for pressure changes and transient flow. Also monitor for pressures and transient flows at valve on 7" X 9 5/8" annulus. Open SCSSV and repeat test procedure. If OK, RD and connect to 4" 5M valve on 7" X 9 5/8" Fairweather E & P Services, Inc. N-01B P&A Rev. 4.1 Page 1 of 7 1/9/2002 . o o 10. 13. 14. valve on annulus and pressure test annulus to 1500 for 30 minutes while monitoring 3 ½" X 7" annulus for pressures and transient flow. If pressure testing is satisfactory, proceed to step 7. If pressure testing is unsatisfactory, close well in until such time that a new plan of action can be developed. When well tree has been inspected and tested and casing strings pressure tested, move in and rig up slickline unit with lubricator on tubing spool, RIH with gauge ring to verify tubing ID is open. POOH, RIH with SSSV extraction tool and pull SSSV out of landing nipple and POOH. PU gauge ring and RIH with slickline to PXN plug at 3294 feet, and verify tubing is not collapsed or plugged. POOH, PU PXN plug extraction tool, RIH, pull PXN plug, POOH, rig down and release slickline unit. Give AOGCC 24 hour notice of intent to place cement plug and chance to witness same. RU cementing unit and connect to 3 ½" 5M master valve at surface. Pressure test lines and and break circulation using clean NaC1 brine solution. When circulation rate has been established, using the downsqueeze method, pump 150 ft3 of 15.8 ppg Class "G" cement (this figure includes 20% excess). This will fill the wellbore from 3964 feet to the base of the tubing tail at 3325 feet and effectively cover all perforations. Drop a tubing dart and displace with 27 bbls of brine. Close in wellhead and WOC. Give AOGCC 24 hour notice of intent to place cement plug and chance to witness same. RU wireline with lubricator on wellhead, tubing punch perforating gun and sinker bar. RIH to tag TOC plug, record location and let AOGCC witness tag. POOH to 2550' MD and perforate tubing with 6 (six) ¥2" holes at 6 spf. POOH, RU cementers, pressure test lines. Break circulation down tubing and displace out remaining diesel fuel in annulus to open top tank. 'Using displacement method, place balanced 200' (40 ft3) Arctic Set cement plug in 3 ½" tubing ID and in 3 ½" X 7" annulus from 2550' - 2350' MD. Drop tubing dart and displace cement with 20 bbls of brine. Close in wellhead and WOC. RU wireline with tubing cutter and sinker bar. With AOGCC witness present, RIH to tag TOC at 2350', record location and POOH to 310 feet. Sever tubing and pull wireline out of hole. Disassemble and remove 3" valves from 3" X 9 5/8" wellhead flange. Unbolt and remove flange to expose tubing slip bowl and tubing. Connect lifting sub to top of tubing and lift up on tubing with crane to verify successful cut. Set tubing back in seal and slip bowl assembly. RU Hot Oil truck and connect to 3 1/2" tubing and connect return lines between 4" 5M valve on 3 ½" X 7" annulus and vac truck. Begin Fairweather E & P Services, Inc. N-01B P&A Rev. 4.1 Page 2 of 7 1/9/2002 15. 16. 17. circulating hot brine down tubing to heat wellbore and Arctic Pack in 7" X 9 5/8" annulus. Have 2 vac trucks ready (one with brine, the other empty). Connect so trucks can alternate between drawing hot fluids from wellbore and discharging to the hot oil truck. Circulate for 4 hours. Disconnect Hot Oil truck, RU crane and pull tubing. RU wireline with gauge ring, RIH to top of severed tubing (310'). POOH with gauge ring, PU 7" Bridge Plug, RIH to 305' and set Bridge Plug, POOH. PU perforating gun (casing punch), RIH to top of packer, perforate the 7" casing with 6 (six) ¥2 inch holes at 6 spf. POOH with wireline. Re-install 3" X 9 5/8" flange, RU Hot Oil truck to 3" flange on 7" casing spool and establish circulation at high rate (do not exceed 1500 psi) down ID with returns up 7" x 9 5/8" annulus. When circulation has been established, release wireline from location. Circulate to open top tank until clean returns observed. Swap line and break circulation down annulus (connected to valves on both sides of casing head) with returns up casing to open top tank. Monitor returns until clean. Repeat circulation procedure twice to verify clean annulus. Give AOGCC 24 hour notice of intent to pump surface cement plug and give chance to witness same. RU cementers and connect to both annulus valves on well-head. Have return line connected between 3" 5M valve flange on 3" X 9 5/8" casing spool flange and open top tank Using displacement method, place 255' (91.5 ft3) Arctic Set cement plug from 45' - 300', filling annulus and wellbore to surface. Pump cement until cement returns are seen at surface. Close valves, disconnect and wash down cementing lines, release cementers from location. WOC. Give AOGCC chance to inspect cement plug at surface PU 1 inch pipe and RIH to tag TOC inside casing. Open annulus valves to inspect for cement. Using Excavator, remove cellar and excavate around wellbore to 6' below original ground level. Connect crane and safety lines to wellhead to stabilize assembly and prevent it from falling into excavated area while work is being performed. If guillotine saw is available, RU and sever casing strings 5' below original ground elevation. If not, cut window in 13 3/8" conductor to reveal cement sheath surrounding 9 5/8" casing. Break away cement to expose 9 5/8" casing and cut window in 9 5/8" casing to expose cement sheath surrounding 7" casing. Sever final casing string and remove severed casing and wellhead equipment, load into dumpster for backhaul. With AOGCC witness, inspect top of cement location. NOTE: Conduct safety meeting before proceeding with step No. 17. Fairweather E & P Services, Inc. N-01B P&A Rev. 4.1 Page 3 of 7 1/9/2002 19. 20. 21. Trim casing stubs and weld 30" X 30" X ½" steel plate across all casing strings. Insure proper well identification information has been bead welded to plate and give AOGCC chance to inspect. Backfill pit surrounding P&A'd well, RD and remove all associated P&A equipment from location, and clean site. Turn site over to pad remediation contractor. File new Form 10-407 with AOGCC describing final status of well. Attachment II is a proposed diagram of N-01B after the P&A procedure. Fairweather E & P Services, Inc. N-01B P&A Rev. 4.1 Page 4 of 7 1/9/2002 Proposed Present Condition ARI :TIC PACK TO ~2000' MD 13 3/8" 72# L-80 130' MD 9 5/8", 47# L-80 2496'MD(2496' TVD) iSCSSV 2009' MD Milne Point N-01B Milne Point Field, North Slope Alaska Size Wt. Grde Thrd Depth Sks/Cmt CONDUCTOR 13~ 72# L-80 130' SURFACE 95/8" 47# H-90 2496' INTERMEDIATE LINER PRODUCTION 7" 26# L-80 BUT 9193' 1100sks TUBING 3 1/2" 9.2# L-80 8 RD 3325' 85 bbl Diesel inside Tubing and 3 1/2" X 7" Annulus Perfs 12 spf 3601'- 3614' Perfs 12 spf 3636' - 3651' Perfs 12 spf 3668' - 3674' Perfs 12 spf 3749' - 3756' Perfs 12 spf 3794' - 3830' Perfs 12 spf 3874' - 3894' Description OD ID Depth Well currently Plugged and Suspended With Following Hardware in Hole EZSV Cement Retainer 7" 9020' EZSV Cement Retainer 7" 8800' EZSV Cement Retainer 7" 3964' Baker FHL Hyd Ret. Packer 7" 3258' PXN 3.5" 3294' Camco TRDP-1A SCSSV 2009' Tubing Packer 3258' MD PXN 3294' MD 3 1/2" 9.3# L-80 8RD Tubing 3325' perfs 4 spf 3330'-3332' perfs 4 spf 3354'-3388' perfs 4 spf 3395'-3464' ueezed perfs 4 spf 3498'-3500' ueezed perfs 4 spf 3720'- 3722 EZSV Cement Retainer 3964' MD (3585' TVD) perfs 4 spf 3980'- 3982' PTD: 84-13 APl: 029-21053 Spud Date: Dec. 17, 1983 Date Suspended: April 27, 1984 'Elev. (RKB) 54.50' (Flange Elevevation - ?' AMSL) All depths are RKB measured depths. EZSV Cement Retainer 8800' ATTACHMENT I Perfs 12 spf 8820'-8940 Perfs 12 spf 8985'-9015' 7" 26# L-80@ 9193' MD TD 9208' M D EZSV Cement Retainer 9020' Squeezed perfs 4 spf 9025'-9050' DRAWING NOT TO SCALE MILNE Pt. N-01B FA.~RWEATHER E&.P Rev. 03.1 Pcond / DHV SER V~CES INC. 22-Oct-01 ~--[ Proposed ['"~ Present Condition Cement to Surface (Displacement start at 300' Inside of tubing) Steel Plate W/Id Welded On Top Top -5 from original ground level. 13 3/8" 72# L-80 130' MD 10.2 9 5/8", 47# L-80 2496'M D(2496' 'IVD) M ilne Point N-01 B Milne Point Field, North Slope Alaska 7" perforated at 300', Arctic Pack displaced out with Cement. Tubing Severed 310' TOC @ - 2000' MD In 9 7/8" X 7" annulus Balanced cement plug 2350' - 2550' Tubing ID & AnnulusTubing perforated @ 2550 feet w/6 1/2" ho~es @ 6 spf. 3 112" 9.3# L-80 8RD Tubing 3325' Size Wt. Grde Thrd Depth Sks/Cmt CONDUCTOR ~3~- 72# L-80 130' SURFACE 95/8" 47# H-90 2496' INTEF~I EDIATE MNER PRODUCTION 7" 26# L-80 BUT 9193' 1100sks TUBING 31/2" 9.2# L-80 8 RD 3325' Squeezed 150 ft~ cement plug from 3964' - 3325' EZSV Cement Retainer Description OD ID Depth Well To Be P&A'd wl~ following Hardware In Hole EZSV Cement Retainer 7" 9020' EZSV Cement Retainer 7" 8800' EZSV Cement Retainer 7" 3964' Baker FHL Hyd Ret. Packer 7" 3258' PXN 3.5" 3294' 3964' MD (3585' 'IVD) ATTACHMENT III L PTD: 84-13 APl: 029-21053 Date: Dec. 17, 1983 EZSV CementRetal .... t8800' ~ ~ppril--~', 1984 [_~_ev. (RKB)~54_.50~e--~evevation - ?' AMSL) Tubing Packer 3258' MD PXN 3294' MD Squeezed perf~ 4 spf 3980'- 3982' Perle 12 spf 8820'-8940' Description Start Depth End Depth Proposed P&A Plug Location Referenced to RK~ 255 ft (91.5 ft3) Cmt Plug 45 300' 7" Bridge Plug 305' 200 ft (40 ft3) Cmt Plug 2350' 2550' 639 ft (150 ft3) Cmt Plug 3325' 3964' Perfs 12 apl 8985'-9015' Squeezed perfa 4 spf 9025'-9050' 7" 26# L-80 @ 9193' MD TD 9208' MD EZSV 9020' DRAWING NOT TO SCALE MILNE Pt. N-01B FAIRWEATHER E&P Rev. 04Prop / DHV SERVICES INC. 09-Nov-01 Fairweather E & P Services, Inc. N-01B P&A Rev. 4.1 Page 6 of 7 1/9/2002 Attachment II BP Exploration (Alaska) Inc. Milne Point N-01B Proposed Permanent Well Abandonment and Location Clearance DAYS Construct ice Road Access Estimated at I week Prior to mObilization for p&~ or previous well in program. Thaw wellhead and cellar, test and lubricate wellhead valves. RU test pump, pressure test all. Pu, sssv va~ve, pull PX. p~ug. Squeeze cement perforations below tubing packer. WOC Perforate tubing, place 2nd cementplug, WOC. tubing, set bridge plug, perforate casing, circ out Arctic Pack. Place Surface Cement plug. Remove wellhead Xmas tree. Excavate, remove cellar. Sever casing strings, weld on Id plate, backfill emavation. Demob back to Deadhorse. Contingency Day's: Weather & Equipment Fairweather E & P Services, Inc. N-01B P&A Rev. 4.1 Page 7 of 7 1/9/2002 BP EXPLORATION To: From: David W. Johnston Chairman Alaska Oil & Gas Commission Steve Herren, Drlg Mgr Shared Services Drilling ARCO Alaska, inc. s ~ ~OL~~ Date: Subject: ,,, Suspended wells Compliance with regulations in response to your letter dated August 15, 1994 regarding suspended wells attached are lists detailing well status and criteria for maintaining these wells in a suspended status. Plans for well inspections are in place for October 1 through October 3, 1994 as discussed with Blair Wondzell and John Spaulding. Updated reporting has been filed with the commission as listed. Yours Sincerely, Steve Horton Drilling Manager Bill Bredar Patrick Collins Jim Farnsworth Mike Miller Bruce Policky Scott Sigurdson Marian Sloan RECEIVED 0CT 1 4 1994 Alaska 0il & Gas Cons. Commission ~chor~a Suspended Wells, ReQuest to retain suspension status The following wells are listed as suspended by the AOGCC under 20 AAC 25.110. These wells are requested to remain suspended for the reason(s) as indicated. Site inspections should be conducted as soon as possible. MPA-01; 029-20376-00 79-/e'04 Potential recompletion in the Kuparuk C and/or B sand as a water injector. Decision hinges on 1994/95 development drilling results (E-13)in this area. MPB-02; 029-20662-00 81-/¢(142 This well is scheduled for initial completion in the Schrader Bluff late this year or early next year. MPA-03; 029-20891-00 83-~001 Future utility as a Schrader Bluff producer with producing utility when surface infrastructure is installed on A pad. MPN-01 B; 029-21053-02 84-0013 N-01 B is a usable well in the Schrader Bluff, with producing utility when surface infrastructure is installed on N pad. The well should be retained in a suspended status until that time. MPC-16; 029-21364-00 85-O 110 C-16 has recompletion potential in the Kuparuk "C" sand and/or the Schrader Bluff horizons. Although additional evaluation must be performed to quantify reserves and production potential, C-16 is believed to be a viable workover and/or sidetrack candidate. NWM#1; 029-22231-00 91-0145 Northwest Milne #1 should remain suspended until the Northwest Milne Point development is better defined. The wellbore is strategically located on a gravel island and may possess utility in either production or injection operations. DNR recently certified this well as capable of production. No Point #1; 029-22450-00 94-0027 No Point #1 will be utilized in the upcoming F- Pad development. Expectations are to complete the Kuparuk "A" zone and commence production 4Q95. Niakuk #4, 029-21217-00 84-0200 Niakuk #4 is requested to remain suspended until the viability of the well for monitoring is defined. Niakuk #5, 029-21290-00 85-0027 Niakuk #5 should remain suspended for observation purposes at this time. Sag Delta #33-12-16, 029-20176-00 75-0058 Area being drained by 1994 Alapah well NK-26 (HAW). Potential use as a monitor well for this new reservoir Would have to truck oil across winter ice road if resume production Produced 186 MBO in 1985 2 month production test. Sag Delta #5, 029-20527-00 80-0129 Area being drained by L5-26 (high gas well), L5-28, and L5-36 from south to west. Well tests indicated fairly tight, but productive rock; perhaps inadequate stimulation? Costs prohibitive for eventual tie-in to L5 (? via Heald Point). Potential for gas cap monitor well Sag Delta 31-11-16, 029-20011-00 69-0014 Area being drained by L4-36, 80 Acre offset to NW. Potential for service well (water injection?) Well is capable of production, but most Lisburne in water leg and costs likely prohibitive for tie-in to L4. Sag Delta #2A, 029-20234-01 77-0069 South of Sag Delta #1, in water leg of Alapah oil accumulation in NK-26 well. Remote potential for pressure monitoring of Alapah offtake and the effect on the Alapah aquifer; though, costs would likely be prohibitive. Sag Delta #8, 029-20519-00 80-0121 Z-32A, 029-21924-01 93-O 113 S-10A, 029-20765-01 91-0123 Sag Delta #8 should remain suspended until the development plan for the area is better defined. This well may possess utility for production or as an observation well. Z-32 was shut in due to high water production in 1992. In 1993 it was sidetracked to a new location. The oil column at the new location was. less than prognosed and was not considered economic and the well was suspended. There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. S-10 was sidetracked in 1992. Drilling difficulties were encountered while drilling through a fault in the Kingiak and the well was suspended. There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. The West Sak formation, a non unitized formation in the PBU license area, is reachable from this wellbore. Work in ongoing on a facility sharing agreement. In the case that a satisfactory agreement is reached, this wellbore could be used to access oil in this formation. Y-22A, 029-21558-01 88-0115 Y-22 was sidetracked in 1988. The sidetrack was suspended due to drilling difficulties. There is oil in the region that can be reached as a new sidetrack from this well. A location has not been worked on but we wish to retain this wellbore for a future sidetrack. U-01, 029-22244-00 92-0011 There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. PR 33-12-13, 029-20047-00 69-0104 The well penetrates The West Sak and Ugnu formations in the aquifer. Work in ongoing on a facility sharing agreement with subsequent appraisal of the formations. This well could be used to test the aquifer properties. These wells are listed as suspended, action items are detailed. Ak Island #1,289-20018-00 81-0119 Alaska Island #1 was abandoned in 1988. The completion notice has been refiled with AOGCC on 9/15/94. The site is ready for inspection (priority 1 ). Niakuk #lA, 029-20156-01 76-0028 Niakuk #lA was abandoned in 1991. A sundry application requesting status change was filed with AOGCC 9/20/94. A completion notice will follow when the sundry application is approved. The site is ready for inspection (priority 1). Niakuk #2A, 029-20180-01 76-0079 Niakuk #2A was abandoned in 1991. A sundry application requesting status change was filed with AOGCC 9/20/94. A completion notice will follow when the sundry application is approved. The site is ready for inspection (priority 1). PBU H-01, 029-20099-00 71-0015 The well was drilled in 1971 and hit a down thrown fault block with only 20ft of oil bearing Ivishak. This was not economic at the time. It was left suspended without tubing. Recent success in fraccing the Sag formation indicated that it might be an economic well. A rig workover was completed in April 1994 and the well was put on production 9/94. It is not necessary to inspect this site. Kemik Unit #1,223-20006-00 70-0060 Kemik Unit #1 is scheduled to be abandoned in the near future. Abandonment planning is now in progress. Site inspection will not be necessary at this time most likely should be scheduled for Spring of 1995. P2-59, 029-22096-00 90-0140 Arco Alaska Inc. is the operator of this well, they will be addressing the question of suspension. Sag Delta #3, 029-20233-00 79-OO8O Well plugged and abandoned March, 1991. Well completion notice will be refiled with the Commission. Sag Delta #4, 029-20245-00 77-0015 Well plugged and abandoned March, 1991. Well completion notice will be refiled with the Commission. The following wells are not under BP Exploration ownership. A letter requesting the owners to respond regarding their wishes for these wells was sent on 9/30/94. MP 03-10-12, 029-20483-00 80-0066 MP 33-11-12, 029-20504-00 80-0092 CHEV 18-11-12, 029-20511-00 80-0108 Term C 03-11-12, 029-20356-00 78-0102 MP 22-3 81-0010 MP 43-3 80-0139 MP 30-1 80-0152 1-11-13, 029-20545-00 1-11-13, 029-20536-00 1-13, 029-20546-00 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David~ DATE: October 2, 1994 Chairman THRU: Blair Wondzell, ..~r~~ FILE NO: 2991jbbd.doc P. I. Supervisor '~' / John Spaulding,Q~. Petroleum Insp. FROM: SUBJECT: Suspended Wells ,inspection North Slope, Alaska .Oct,ober 1,2&3, 1994: I accompanied Marian $1oan BPX representative on an inspection tour of BPX suspended wells at various North Slope locations. Travel was by pickup and helicopter. Marian Sloan Informed me that BPX is drafting a program with reasons for leaving wells listed below as suspended, this program will be available to the AOGCC in the very near future Oct. 1,1994 Y-22A / PBU / PTD 88-115; well head on configuration, no pressure on tubing or annulus, area very clean, well is located on a producing drillsite. S-10A / PBU / PTD 91-123; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. U-01 / PBU / PTD92-11; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. Z-32A / PBU / PTD 93-11_3; wellhead on configuration, no pressure on tubing, 750 psi on inner annulus, 0 pressure on outer annulus, area clean, well is located on producing drillsite. Chevron 18-11-12 / PTD 80-108; wellhead on configuration, no pressure on tubing or annulus, area clean. MP 22-31-11-13 / PTD 81-10; wellhead on configuration, no pressure on tubing or annulus, area clean, reserve pit is still open. MP 32-30-11-13 / PTD 80-152; wellhead on configuration, no pressure on tubing or annulus, area clean, reserve pit is still open. Oct. 2, 1994: A-01 / MPU / PTD 79-40; wellhead is removed with casing hanger still on, area clean, well is located on a active drillsite. A-03 / MPU / PTD 83-01; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a active drillsite. B-02 / MPU / PTD 81-142; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite, C-16 / MPU / PTD 85-116; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. N-01B / MPU / PTD 84-13;. wellhead on configuration, no pressure on tubing or annulus, area clean with timbers covering the cellar area and well guard around the wellhead. No Point #1 / MPU / PTD 94-27; wellhead on configuration, area clean, unable to land helicopter to check wellhead for pressures, No Point #1 is scheduled to become part of the F- pad construction at MPU. NW Milne #1 / MPU / PTD 91-145; wellhead on configuration, area clean, island is suffering from severe erosion on the North side. Oct. 3, 1994: Sa,q Delta 31-11-16 / PTD 69-14; wellhead on configuration, area clean, has wooden location marker, no pressure on tubing or annulus. Sag Delta #3 / PTD 76-80; wellhead on configuration, area clean no pressure on tubing or annulus. Sa.q Delta #4 / PTD 77-15; wellhead on configuration, area clean, no pressures on tubing or annulus. Sa.q Delta #2A / PTD 77-69;. wellhead on configuration, no pressures on tubing or annulus, timbers and cellar box material, reserve pit open. Sag Delta #5 / PTD 80-129; no wellhead; bell shaped affair was covering the supposed well surface location, area clean. Sa.q Delta #8 / PTD 80-121; wellhead on configuration, timbers and well guard, island is eroding. o Alaska Island #1 / PTD 81-119;. unable to land, area appeared clean from the air, marker post visible on South side of island. Niakuk ~ / PTD 84-200; wellhead on configuration, concrete river weights, cellars open, island eroding. · Niakuk #5 / PTD 85-27; wellhead on configuration, concrete river weights, cellars open, island eroding. Location Clearances; Niakuk #lA / PTD .76-28; area is clean, no visible marker post, island is eroding as planned. ~l.iakuk #2A / PTD 76--79;...area-is-clean;-.no-visible-marker--post; .island-is-eroding as planned. I recommend that the AOGCC consider Niakuk lA & 2A for final abandonment and location clearance. , Summary,: I inspected locations of 28 BPX suspended wells. I also inspected 2 wells for final abandonment and location clearances. ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 15, 1994 Steve Horton, Drlg Mgr BP Exploration (Alaska) Inc P O Box 196612 (MB12-1) Anchorage, AK 99519-6612 Re: Suspended Wells Compliance with regulations Dear Mr. Horton: BP Exploration and the predecessor Sohio companies have several suspended wells as shown on the attached lists: BP SUSPENDED W-~LLS PRIOR TO 1980 and BP SUSPENDED W~LLS SINCE 1980. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission, will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above, or advise as to your plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as suspended, as ~equir~d by 20 AAC 25.110(e), must have well site locations inspections ~ls y~~i~-~-to snow covering the . David W.(Johnston Chairman Attachments c: Blair Wondzell hew/1 lbp.~usp ~/!5/94 BP SUSPENDED WELLS SINCE 1980 PAGE ! AUGUST 1994 PEPd4IT 79-0040-0 80-0066-0 80-0092-0 80-0108-0 80-0121-0 80-0129-0 80-0139-0 80-0152-0 81-0010-0 81-0119-0 81-0142-0 83-0001-0 84-0013-0 84-0200-0 85-0027-0 85-0110-0 88-0115-0 90-0140-0 91-0123-0 91-0145-0 92-0011-0 93-0113-0 94-0027-0 API N-UMBER 029-20376-00 029-20483-00 029-20504-00 029-20511-00 029-20519-00 029-20527-00 029-20536-00 029-20546-00 029-20545-00 089-20018-00 029-20662-00 029-20891-00 029-21053-02 029-21217-00 029-21290-00 029-21364-00 029-21558-01 029-22096-00 029-20765-01 029-22231-00 029-22244-00 029-21924-01 029-22450-00 WELL WELL WELL NAME CLASS STATUS MILNE POINT UNIT A-01 EXP SUSP PRUDHOE BAY UNIT 3-10-12 DEV SUSP PBU MP 11-33-11-12 1 DEV SUSP PRUDHOE BAY UNIT TR 18-11-12 DEV SUSP SAG DELTA 8 EXP SUSP SAG DELTA 5 EXP SUSP PRUDHOE BaY UNIT 31-11-13 DEV SUSP PBU MP 32-30-11-13 1 DEV SUSP PBU MP 22-31-11-13 2 DEV SUSP ALASKA ISLAND i EXP SUSP MILNE POINT UNIT S-02 DEV SUSP MILNE POINT UNIT A-03 DEV SUSP MILNE POINT Lll~IT N-01B DEV SUSP NIAKUK 4 EXP SUSP NIAKUK 5 EXP SUSP MILNE POINT UNIT C-16 DEV SUSP PRUDHOE BaY UNIT W-22A DEY SUSP PT MCINTYRE P2-59 EXP SUSP PRUDHOE BaY UNIT S-10A DEV SUSP NORTHWEST MILNE 1 EXP SUSP PRUDHOE BaY UNIT U-01 DEY SUSP PRUDHOE BaY UNIT Z-32A DEV SUSP NO POINT i DEV SUSP STATUS DATE 4115180 10/lm/80 4/29/81 12/24/80 4/15/81 4/13/81 2/20/81 i/lS/81 2/i4/81 6/08/82 5/27/82 12/10/83 4/27/84 2/17/85 4/i8/@5 10/27/93 10/29/88 12/22/90 11/06/91 3/30/92 3/16/92 8/31/93 4/08/94 SECT 23 33 33 07 27 36 O5 3O 3O 11 19 23 3O 25 25 10 33 14 35 25 18 19 O6 TWP 13N llN llN llN 12N 12N 10N llN IIN 10N 13N 13N 13N 12N 12N 13N llN 12N 12N 14N 11N 11N 13N RinG 010E 012E 012E 012E 016E 015E 013E 013E 022E 011E 010E 010E 015E 01SE 010E 013E 014E 012E 009E 013E 012E 010E MER U U U U U U U U U U U U U U U U U U U U U U U /15/94 BP SUSPENDED WELLS PRIOR TO 1980 PAGE 1 AUGUST 1994 PERMIT 69-0014-0 69-0104-0 70-0060-0 71-0015-0 75-0058-0 76-0028-0 76-0079-0 76-0080-0 77-0015-0 77-0069-0 78-0102-0 API NUMBER 029-20011-00 029-20047-00 223-20006-00 029-20099-00 029-20176-00 029-20156-01 029-20180-01 029-20233-00 029-20245-00 029-20234-01 029-20356-00 WELL WELL WELL NAME CLASS STATUS SAG DELTA 31-11-16 EXP SUSP PRUDHOE BAY UNIT 33-12-13 DEV SUSP KEMIK UNIT I DEV SUSP PRUDHOE BaY UNIT H-01 DEV SUSP SAG DELTA 33-12-16 EXP SUSP NIAKUK 1-a EXP SUSP NIAKUK 2-A EXP SUSP SAG DELTA 3 EXP SUSP SAG DELTA 34633 4 EXP SUSP SAG DELTA 28337 2-A EXP SUSP PRUDHOE BAY I/NIT TEI~/~ C DEV SUSP STATUS DATE 4/28/69 12/20/69 6/17/72 6/22/71 4/28/76 4/30/76 3/30/77 3/23/77 3/22/78 12/27/77 4/25/79 SECT 31 33 17 21 O4 26 26 35 35 10 O3 T%qP lin 12N 01N I1N llN 12N 12N 12N !2N llN 11N RNG 016E 013E 020E 0!3E 016E 015E 01SE 016E 016E 016E 012E MER U U U U U U U U U U U STATE OF ALASKA Al. KA OIL AND GAS CONSERVATION C~__~.,vllSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon D Suspend I~ Operation Shutdown [] Re-enter suspencled well [] Alter casing [] Time extension [] Change approved program [] Plugging E3 Stimulate [] Pull tubing I"1 Amend order [] Perforate [] Other [] 2. Name of Operator CONOCO, INC. 3. Address Pouch 340045, Prudhoe Bay, Alaska .99734 4. Location of wellatsurface 2660' FSL, 1428' FEL, SEC. 30, T13N RIOE U.M. Attop of productiveinterval 2436' FSL, 1591' FEL, SEC. 30, T13N, RiOE, U.M. Ateffective depth 2276' FSi, 1705' FEL, SEC. 30, T13N, RIOE, U.M. Attotaldepth 1295' FNL, 4081' FEL, SEC. 31, T13N, RIOE, U.M. 5. Datum elevation(DF or KB) 54.5' KB 6. UnitorPropertyn~me Milne Point Unit 7. Well number N-lB 8. Permit number 84-13 9. APInumber 50-- 029-21053-02 lO. Pool Kuparuk River 11. Present well condition summary Total depth: measured true vertical 9208 ' RKB feet 6811 ' feet Effective depth: measured 3964' RKB feet true vertical 3858' feet 7" Float Collar @ 9112' RKB Plugs(measured) ~EZSV Retainer @ 9020' WLM Halliburt°n~EZSV-- Retainer @ 8800' WLM Junk(measured) ~EZS¥ Retainer @ 3964' WLM Not Applicable ' Casing Length Size Cemented Structural Conductor ± 95' 13-3/8" CMT to Surface Surface 2461 ' 9-5/8" 1750 SKS. Intermediate Production 9158' 7" 1100 SKS. Liner Perforation depth: measured 3601' - 3614' 3636' - 3651' 3668' - 3674' true vertical 3551' - 3562' 3581' - 3594' 3614' Tubing (size. grade and measured~e~h)- 3-1/2", 9.2 lb/ft, L-80,-3325~'_ RKB Packers and SSSV (type and measured depth) Baker "FHL" Hydraulic Retrievable Pkr. @ 3258' RKB. Measured depth ± 130'-RKB 2496' RKB 9193' RKB True Vertical depth ± 130' 2495' 6782' 3749' - 3756' 3794' - 3830' - RECEIVE 3678' - 3684' 3715' - 3722' 3781' ' 3798' S~P O~ i:io/ Naska Oil & Gas Cons. Commissi~ Anchorage Camco TRDP-1A SCSSV @ 2009' RKB 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch Not Applicable 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Not Applicable Date approved 15. I here/b~ tif ~t t(he~ ~or~g~ing is true and correct to the best of my knowledge Signed D. F. RAINWATER Title SENIOR FOREMAN Date 8/3/87 Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceJ '~ '~ -~7~./~/~ Approved by Form 10-403 Rev 12-1-85 Commissioner by order of the commission Date Submit in triFlicate feet August 31, 1987 Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 .~ -~ .c Mr. Russ Douglas Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Douglas RE: ~3fpension Applications for Milne Point Wells L-iL M-iA and N-lB Conoco requests a suspended status for the Milne Point Unit L-i, M-iA, and N-lB wells. Attached are 10-403 forms for these wells. A suspended status is necessary because production of these wells await design, delivery, and construction of production facilities. Conoco requests an exception to 20 AAC 25.110.(c) which states that the operator shall set a bridge plug between 200 and 300 feet below the casing head and cap with 100 linear feet of cement. The exception is requested due to anticipated development and production of these wells. The following information concerning each well further supports our exemption request. Milne Point Unit L-1 L-1 contains a PXN plug at 7012 feet, a SSSV at 2019 feet, a Packer at 6970 feet and a back pressure valve in the tree. Milne Point Unit M-iA M-iA contains a PXN plug at 9700 feet, a SSSV at 1908 feet, a Packer at 9663 feet, and a back pressure valve in the tree. Milne Point Unit N-lB N-lB contains a PXN plug at 3294 feet, a SSSV at 2009 feet, a Packer at 3258 feet, and a back pressure valve in the tree. Conoco believes that the wells as they are constructed provide adequate protection to ensure that hydrocarbons and freshwater are confined to their respective strata. Mr. Russ Douglas August 31, 1987 Page 2 Please contact Doug Frey or Jim Dosch at 659-6336 if you should have any questions. Yours very truly, D. F. Rainwater/E. L. Robinson DFR/JTD/pck File 4.25 - 1569/WP22 cc: w/attachments Field Superintendent - Anchorage Production Technician - MPOC P. J. Grimmer - Anchorage Safety & Compliance Coordinator - MPOC M. EMORANDUM TO: State of Alaska ALAoKA L AND GA~ CONSERVATION CO~,iISSION O. Vo ~~er~oII .. DATE: September 17, 1985 / Chai~~/ / THRU: Lonnie C. Smith Commissioner FROM: Bobby D. Foster'. Petroleum Inspector FILE NO: D. BDF. 95 TELEPHONE NO: SUBJECT: Location Inspection Conoco - tiPU-#N1-B Permit ¢ 84-13 Kuparuk River Field Thurs_da_Dy~ August 29, 1985: I met with Roy Robinson, Conoco Rep- z-~~-fa.t'i've an~ inspec(e--~ the following location: Milne Point Unit Well CN-IB, Permit No. 84-13 Attached to this report are pictures of the location and a copy of the suspended well report. Attachment 02 00IA(Rev. 10/79) Suspended Well and Location 20 AAC 25, ARTICLE 2 Report FILE INFORMATION: /~ ' ' " Date Suspended Surface L0-~tYOn ~f ~efi - ~ ....... ' ..... permi6 · -~'-T~ ~, R~O~, ~M. Unit or Lease Name~r~-~ Wel 1 ~o. ~%.~-~-- -...- _.'-_-~- Condition of Pad ...~~ Well head - All outlets plugged No Well sign - Attached to well head Yes No Attached to well guard ~ No Attached to Information correct No Cellar - Opened ~ No Fi 1 led No Cove red Ye s No Rat Hole eton Yes ~ Fi 1 led Ye s No Covered Ye s No WaterWell - Plugged off Capped Open Explanation Photographs taken to verify above Conditions~ No Explanaton Work to be done to be acceptable This well and location is ~cceptabl_~9~ (unacceptable) to be classified as suspended f.or the period of~~_--__ l~thru ~__~__' ,~~ 19_~ _~_. Inspected by:~ ~~~/._. ~_: _.~~ .... Date:: _'~_ [_~- ~- Revised 8/24/82 John R. Kemp Manager of Alaskan Operations September 12, 1985 Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 Harold Hedland Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hedland, Attached are completed 10-403 forms for Milne Point A-3, D-i, N-lB, L-i, M-IA and Gwydyr Bay State #2A. Ail of the above are classified as suspended wells. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the wells is suspended. Please contact Jim Dosch at (907) 564-7649 if you should have any questions. Very truly yours, Manager of AlaSkan O~erations I ECEIVED Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OT~L AND GAS CONSERVATION COigFMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 84-13 3. Address 8. APl Number 3201C Street, Suite 200, Anchorage, Alaska 99503 50- 029-21053-02 4. Location of Well 2660' FSL, 1425' FEL, Section 30, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 54.5' KB 6. Lease Designation and Serial No. ADL 25517 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point N-lB 11. Field and Pool Kuparuk River 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension for a suspended well. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the well is suspended. This well will remain suspended pending engineering evaluation of development of the western portion of the Milne Point Unit. 14. I hereby certify that the foregoing is true and correct to thE; best of my knowledge. The space belo~ for Commission.~se Conditions of Approval, if any: _~,,,~, ~-~ ,~'/z,~/,','s .... IRIGIttAL SIGNED Approved by. !11f LON~IE C. SMITI~ Approved Copy Returned ~ .~. By Order of COMMISSIONER the Commission Date / O - '") ' ~.5' Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate November 6, 1984 Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 Mr. Jim Trimble Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble: Attached are completed 10-403 forms for Milne Point A-I, A-2, B-i, B-2, B-3, B-4A, B-5, C-l, C-2, C-3, D-I, L-I, M-iA, N-iB, and Gwydyr Bay State 2A. Ail of the above are classified suspended wells. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the wells are suspended. Please contact Jim Dosch at 279-0611 if you have any questions. Yours veery truly, //Tl'n/l"":JTD/ks Attachments RECEIVED NOV o 9 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASK-~_31L AND GAS CONSERVATION L_.,MMISSION ,, SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Naj;ne of Oper&tor 7. Permit No. uonoco Inc. 84-13 8. APl Number 3. A~ C Street, Suite 100, Anchorage, Alaska 99503 50- 029-21053-02 4, Location of Well 2660' FSL, ]425' FEL, Section 30, T13N, R10E, U.M. 5, Elevation in feet (indicate KB, DF, etc.) 54.5' KB 6. Lease Designation and Serial No. ADL 25517 9. Unit or Lease Name Milne Point Unit 10. Welt Number Milne Point N-lB 11. Field and Pool Kuparuk River 12. (Submit in Triplicate) Perforate [_] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [~X Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10~407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension for a suspended well. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the well is suspended. This well will remain suspended pending engineering evaluation of development of the western portion of the Milne Point Unit. 14. I hereb / ~:yc~t/ c ct to the best of my knowledge. Manager of Alaskan Operations Date 9-26-84 ]proval, if any: Approved by By Order of COMMISSIONER .the Commission Date // Form 10-403 Rev. 7-1 ~80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate M EMORAT, i DUM State of Alaska DATE: August 22, 1984 FILE NO: D. 3I. 52 ALASKA~IL_AND GAS CONSERVATION COMMISSION To: C. V ~ Ci/~er~on ChaiB~ THRU.. Lonnie C. Smith~~% Commis s loner TELEPHONE NO: FROM: Bobby Fos td~-~.. Petroleum Inspector SUBJECT: Inspect Suspended Wells and Locations at Conoco Sites. Thursday, August 16, 1984: I traveled this date to Prudhoe Bay and met With jerrY Fritch and Jim Dosch, Conoco representatives, to inspect the suspended drill Sites and wells listed below. Gwyder Bay .2A Milne Point N-lB Milne Point M-IA Milne Point L-1 Milne Point Pad A (4 wells) Milne Point Pad C (4 wells) Milne Point Pad B Milne Point Pad D I recommend to the Commission that these wells and drill sites be accepted as suspended. Pictures attached. 02-001A(Rev. 10/79) Suspended Well and Location Report 20 AAC 25, ARTICLE 2 0pe~a{'or~ [_.~/Gzp df%)_,. ' Date Suspended Surface ' Permit No.'~'9~3 Locatzon of Well, ~seC' ~ , T_/~ .~, R~~~ ,~ M. ~it"or Lease Name~/j~ ~/'~ - Wel 1 No. 'ffil l:~ _ Condition of Pi ts ~ {OF Well head - All outlets plugged Well sign - Attached to well head Attached to well guard Attached to Information correct < ~ No Ye s No No No Cellar - Opened Ye s Fil led Yes Covered ~ WaterWell - Plugged off No No No Capped Open Rat Hole oPan Yes No Fi 1 led Ye s No Covered ~ No Explanation Photographs taken to verify above conditions~ No Explanaton Work to be done to be acceptable This well and location is/~oce~(unacceDtable)to be classified as ! Ins~cted bYDate: ~--/~:~~- ~_ . _ Revised 8/24/82 STATE OF ALASKA /:Ur.Oi bAd ALASKA c, lL AND GAS CONSERVATIOND.~,4MISSION 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 Conoco Inc. 84-13 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50-029-21053-02 4. Location of well at surface 9. Unit or Lease Name 2660' FSL, 1428'.. FEL, Sec. 30, T13N, R10E, U.M. '~ Milne Point Unit At TopProdudir{g Interval ~ V~,',,F~'u 10. Well Number 2436' FSL, 1591' FEL, Sec. 30, T13N, R10E, U.M. ts~,r~.~i N-lB At Total Depth .~B H ~-, J 11. Field and Pool 1295' FNL, 4081' FEL, Sec. 31, T13N, R10E, U.M.~-"-~~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 54.5' (KB)J ADL 25517 12. Date Spudded 13. DateT. D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116- No. of Completions 01/19/84 01/27/84 04/27/84I N/A feet MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)/ 19. Directional Survey I 20. Depth whereSSSV set 21. Thickness of Permafrost 9208 (6816 'TVD) 3964' (3858' TV )~)ES ~X NO []I 2009' feet MD +1800I 22. Type Electric or Other Logs Run DIL-SFL, BHC Sonic, FDC-CNL-GR, NGT, CBL-VDL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13 3/8" 72 LB/Fi' L-80 Surface +130' 17~" See attachment None 9 5/8" 47 LB/JCl L-80 Surface 2496' 12¼" NO. IV None 7" 26 LB/Fi L-80 Surface 9193' 8½" None 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) MD LENGTH TVD l~", 9.2 LB/FT 3325' 3258' 3601' -3614' 13' 3551' -3562' 3636' -3651' 15' 3581 '-3594' 12 JSPF 3668'-3674' 6' 3609'-3614' EHS=0 91" 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 3749'-3756 7' 3678'-3684' Schl. Big Hole 3794'-3830' 36' 3715'-3722' unarg~: 3874' -3894' 20' 3781' -3798' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) See attachment No. III Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCr 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. RECEIVED None AUG 1 0 1984 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH .Upper Cretaceous KA MA NA OA Kuparuk Lower Kuparuk Unconformity Kuparuk Interval Laminated Zone LK1 LK2 3090 3346 3597 3792 8182 8600 8820 8997 9025 3082 3312 3548 3716 6226 6458 6584 6686 6702 31. LIST OF AT'TACHMENTS I' Directional Survey, ti' Well History, 32. 30. uuNh~DENTIAL INFORMATION -FuriId Con o0_ FORMATION TESTS Include interval Tested, pressure data, all fluids recovered and gravity, GOR, and tirne of each phase. See Attachment No. ][]]~] III Well Test Results, IV' Cementing Details, I hereby ce, lily that the foregoing is true and correct to the best of my knowledge V' As-Bui 1 t Survey 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 cement- ing 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 I% I L. NI:~ F:'T,, I...11",.I I T -, WIE]_.L. NO' N"- 1B '..:.'!; I GMA...--GYRO ,JOB NO: AO28Zt Z 02:q :[ ~.. ~l.~. ,,- ~ Nf"IF;.~]"H '-r";LL-IF:'E ? ~'-..d_~'...~.z,l'...A SI GMA-GYF,.'EI, O-'F.;'i~.._ hlI3, '.:;I IF,.'VEYOR: CEIRAM/._IAHN, DATE RIJN: O'F.~-FEB-84 :3IF'iMA 175 NO: 662-, F'Rr]BE NID: 064 I:::'I]RE'SIGHT '.:; :"-':4 ":' E SURVEY TAKEN FROM RIG FLOOR Fu,,,~hed By Conoco ~nc. ',:.;ERTI CAL '.':i;I:.CT I 01"-.t CAI_.r":ULAT RECORD OF SURVEY · R A D I I. I:: 0 F C l..I F..' V A T U R E M E T H OI_-I i!Li':.IE F'T,,, ~.T, WELL.. Nm: r.~-lB !:;Ir:;MA-RYRr] ,hqB ~: AO2A4Z02::~l TIME DATE "~ ~ .~ " .... "" ...... OONFIDENTIAL INFORMATION .... '=" ' '-' ~r] r.:;z T it'.-! 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GI"IA-.GYI::;~C~ dOB ~: AO2:E:4Z(')z::31 TIME DATE [l:::~l:-::"l' H :3t...OF:'E., ~cq.. r--':i::31<A 10: :3C): :5.4 1 5-MAR-':~:4 ...... TRUE . 'iE::~ciS;UFdED DR IF:'T DRIFT C:OIJR::;E' \;ERTIC:AI_ VERTIE:AL C;UB:!3EA R Er C: T A N G U L A R C: L O S U R E DOGLEG ...... '-' R~L.T InN '..:;EVER I ']" DE.:F'TI.~ AIq~qL..[.:: DIREr':TIFd',I LENGTH FiEF'TH SECTInN TVD O Fi IzI R D I N A 'T E .=, £1ISTANC:E ]:ii c~' _ ' FEET D h'l D Fl FE:ET FEET FEET FEET FEET FEET O I'1 I3G/1OC}F' ..!~::' I l',h.C'd.~ F:LOSLIF;,'IE .... D I R'EF:T I Fff:l: S :%3 DEtT.;S 5:2 I"1I 1',1:..-.-; 2:3 F:;EE:S ~^J l:l I S T F.~ N C E ',, 4/.. ,:".¢. R._. ,::,,_, s._ F E E T Furnished By Conoco inc. LOCATED IN THE APPENDIX WFL IPR LOG CALIPER SURVEY ~1 VOLAN I~ C~RVE DATA [~TRATIGRAPHIC HIGH RESOLUTION DIPMETER [21 OTHER: 'CON DENTIAL INFORMATION Furnished By Conoco Inc. MILNE POINT UNIT N-lB ATTACHMENT II 1-18 1-19 1-20 1-21 Circ. hole & POOH f/7940'. Re-pin plug catcher & TIH to 3948'. Mix, pump & displace 165 sks. Class "G" w/l% CaCi_, est. cmt. top 3600'. POOH, service plug catcher & TIH to. 3408'~ Mix, pump & displace 165 sks. Class "G" w/l% CaClo, est. cmt. top 3050'. POOH, service catcher & TIH to 2709'. ~{ix, pump & dis- place 170 cf "Cold Set 1", clear drill pipe & POOH. L/D excess drill pipe in derrick & L/D BHA. Cut & slip drlg. line. TIH w/slick assembly, tag @ 2270'. O.K.'d by AOGCC. Drlg. out cmt. f/2270'-2399'. Green cement. WOC. Continue dr].g, green cmt. f/2399'-2496'. WOC. Drlg. to 2585'. POOH. TIH w/Navidril & orient. Drlg. w/Navidril. Surveys: Survey Angle Direction 2625' 1.65° S34.8W 2719' 4.60° S29.1W 281.4' 7.70° S37.6W 2910' 10.65° S41.1W 3007' 13.45° S39.3W 3103' 16.10° S41.5W 3197' 18.50° S43.2W 3292' 20.55° $29.5W 3384' 22.50° S28.4W 3482' 25.05° S29.5W Navidrill & survey 3650' to 3806'. POOH, L/D Navidrill, M/U angle build BHA & TIH to 3520'. Wash & spot ream 3520' to 3806'. Drill & survey 3806'-5350'. Surveys: Survey Angle Direction 3578' 28.8° S31.6W 3673' 31.0° S33.0W 3747' 32.3° S36.2W 3916' 35.2° S35.5W 4075' 38.3° S35.8W 4232' 40.8° S36.5W 4391' 43.4° S36.9W 4551' 46.6° S37.6W 4711' 49.8° S37.6W 4869' 53.2° S37.6W 5028' 56.3° S36.9W 5188' 59.3° S37.2W Drill & survey to 5395'. POOH, M/U packed BHA & TIH. Drill & survey 5395'-6095'. Surveys: S~rve~ Angle 5347' 63.1° 5566' 63.5° 5758' 62.5° 6014' 63.5° tECEIVED Direction S37.2W S36.8W A JG 1 0 S36.2W S33.4W A!aska Oit & Gas Cons. Commission Anchorage -1- COI'"'IDENTIAL INFORMATION furnished By Conoco Ina. 1-22 1-23 -24 1-25 1-26 1-27 Drill & survey 6095'-7338'. Drop survey & POOH. Remove wear bushing & prepare to test BOP. Surveys: Survey Angle Direction 6142' 62.7c S33.4W 6332' 60.6° S32.7W 6587' 58.1° S32.7W 6841' 55.5° S32.0W 7095' 53.6° S31.3W 7287' 52.0° S31.3W Test BOPE, remove test plug & reinstall wear bushing. Repair top boot in drlg. nipple. M/U 50' building BHA. TIH to csg. shoe. Slip & cut drlg. line & finish TIH. Run single shot survey on wireline. Stacked out at 5600' est. top of ~DP. Drill & survey 7338' to 7714'. Run shorter survey tool on wireline & stacked out top of HWDP. Drop survey too]. & pump to bottom. POOH, retrieve survey tool. M/U packed BHA & TIH. Drill 7714' to 7749. Surveys: Suryey 7450' 7577' 7672' Angle Direction 53.9° S31.3W 56.6° S31.6W 58.6° S32.0W Drill & survey 7749'-8051'. Drop single shot survey & POOH. Change bit & TIH. 15' of soft fill, wash to bottom. Drill & survey 8051'-8457'. Pump pill & start POOH. Surveys: Survey Angle Direction 7827' 59.0° S31.3W 7984' 58.4° S31.3W 8143' 57.6° S31.6W 8397' 56.0° S33.4W Continue POOH & L/D Teleco tool. Change bit & TIH to csg. shoe. Slip & cut drlg. line. Continue TIH, 30' fill, wash to bottom. Drill f/8457'-8798'. Drill 8798' to 8831'. Drop single shot survey & POOH. Change bit & TIH, 30' fill, wash to bottom. Drill to 9017'. R/D. Air compressor failure:. Drill 9017'-9132'. Survey: Depth Dagrees Direction 8747' 55.5° S35.5W Drilling f/9132'-9157'. Circ. per geologist. POOH f/bit change. Tally pipe. TIH to 9115'; wash & ream f/9115'-9157'. Drill to 9208' & circ. per geologist. 20 std, short trip, no fill.. Circ. & cond. mud. POOH for logging. Survey: Depth Degrees Direction RECEIVED -2- Alaska Oil & Gas Cons, Commission Anchorage COIV 'DENTIAL INFORMATION F'drnished By Conoco inc. 1-28 1-19 1-30 1-31 2-1 2-2 2-4 2-6 2-6 2-7 Continue POOH. R/U Schlumberger. Run DIL/BHCS/GR f/9194'. 'Log run #2 - FDC/CNL/NGT. Unable to pass 7860'. POOH & add dummy DIL tool for added weight & centralizers. Unable to work past intervals 7750'-7860'. POOH & TIH for conditioning trip. TIH to csg. shoe & break circ. Cut & slip drlg. line. Continue TIH w/D.P., no fill. Circ. & cond. mud. POOH. Continue POOH w/D.P. TIH w/Schlumberger for FDC/CNL/NGT log up from 9186'. TIH w/dipmeter. Unable to work past 7860'. TIH w/D.P. Repair elec. problem w/drillers console. Continue TIH w/D.P, to 9166'. Tight @ 8310' & 8530'. Wash to 9208' & circ. to condition mud. POOH for logs. Continue POOH w/DP for logs. RIH w/Schlumberger for HDT. Unable to pass 8010'. Log'd up from 8010'. RIH to 9208'. Unable to pul.], off BTM due to packing off. Circ. & work pipe free. Pull to 9023' & wash & ream to BTM. Packing off occasionally. In- creased mud viscosity to 45 FV. Circ. viscous pill to sweep hole. Pull, 20 STD. Short trip, 3' fill. Circ. & condition mud. Increasing mud weight to 10.4 PPG. Conditioned mud to 10.4 ppg. Pulled 20 std. wiper trip, no fill. Circ. hole clean. POOH L/D drill pipe. R/U csg. tools. Changed to 7" pipe rams, pull wear ring & test BOP stack. TIH w/7" 26# csg. Continue TIH w/7" 26# csg. Wash last 78' to btm., shoe @ 9193' RKB. Circ. & cond. mud. Mix & pump 600 sks. 12% gel cement @ 12.8#/gal & 500 sks. Class "G" w/l% D-31, 0.2% R-5, 0.2% D-6, displaced w/350 bbls. 10.3#/gal. brine. N/D BOPE, set 7" csg. w/150,000# tension. Tested to 2600 psi, o.k. Prepare for Arctic Pak. Float shoe -9193', float collar - 9112', Lynes ECP 9020'. R/U B.J. Hughes. Test lines 3000#. Inject 200 bbls. water down 9-5/8"x7" annulus @ 6.12 bpm @ 1250#. Followed water w/16.5 bbls. Cold Set 1 cmt. @ 15.3 ppg. Displaced cmt. w/50 bbls. Arctic Pak @ 4.6 bpm. Final. pressure 700 psi. Closed annulus w/700 psi, RDMO B.J. Hughes. N/U blind flange & cleaned mud pits. Release rig @ 11:00 a.m. on 2-2-84. Preparing to set deadman anchors when complexes off N-Pad. Temporarily suspend N-lB from report. Roll'n crew arrived Sunday P.M. Digging out equipment & prepare for rig move today. Test system is spotted & awaiting arrival of crew (delayed due to weather). Anchor holes dug & waiting on cement. Lay matting, move & set up substructure; spot & raise derrick (half mast). Spot mud tank, pumps, boilers & Tioga. Hooking up misc. equipment. Install wind walls & doghouse. Raise upper section of derrick. RECEIVED -3- AUG 1 0 4.!~ska 0il & Gas Cons. Commission 2-8 2-9 2-11 2-12 2-13 2-14 2-15 2-16 2-17 CON[._ )ENTIAL INFORMATION Furnished By Conoco Inc, Continue hooking up misc. equip. Remove blind flange, install spool & BOP. Test BOP, Hydril & surface equip, to 1500 psi. R/U Schlumberger Continue rigging up Schlumberger. Cased hole logging - all logging tools set down @ 9023', 2' above the top of the proposed perforations. 0700 - 0815 hours - First GR/CCL Correlation Log - Tool failed 0830 - 1100 hours - Successful GR/CCL Correlation Log 1145 - 1430 hours - Junk Basket/Gauge Ring (6.00") Run 1500 - 2000 hours - Gyro Survey R/D Schlumberger. R/U for scraper/bit run. TIH w/6.125" bit & 7" 26 lb/ft csg. scraper. Continue TIH w/bit & scraper on 3~" tbg. Long trip=in time is due to cold weather, cold equipment, & new tubing & collars. Continue TIH w/bit & scraper on 3~" tbg. Bit on bottom (9063') & R/U to circ. Circ. out fill to 9082'. Rev. circ. out fill to 9086'. POOH w/bit & scraper. R/U Schlumberger. Perf. f/9025' to 9059' WLM w/12 jpf - Hyper II charges. TIH w/EZSV pkr. & set @ 9020' WLM (middle element). R/D Schlumberger. M/U DST assembly & TIH w/same on 3~" tbg. R/U Otis wireline & surface equipment. PBTD was tagged @ 9067' TIH w/Otis shut-in tool, H.P. gauge on E-Line and locate in locking mandrel @ 8956'. Attempt to flow well. Test tools failed, tbg. loaded w/brine to surface. Well dead. POOH w/shut- in tool - H.P. gauge. R/D wireline unit & surface test equipment. Open APR circ. valve & rev. circ. tbg. POOH w/DST assembly. L/D DST assembly & P/U new DST assembly. TIH w/DST assembly. R/U Otis wireline & surface test equipment. TIH w/shut-in tool & H.P. gauge on Otis E-line. LPR ball valve leaking. POOH w/shut-in tool-H.P. Prepare surface test equipment & flow well. Well started making 50% oil but water cut increased to 100% within 7 hours. Average rate approx. 170 BPD, total produced fluid = 90 bbl., including a 9 bbl. cushion. Well shut-in for build-up. Ran a build-up test on LK?. Attempt to release HP tool. Could not pull-out of lo~king mandrel. R/U & pump down tubing. HP came loose with 900± psi. POOH w/HP. Stopped at 900', could not move tool up or down. Pressure-up on backside to open APR circ. valve & circ. Found broken strand on electric cable. R/D lubricator & splice cable. POOH w/HP gauge & DST assembly. POOH w/DST assembly. L/D DST assembly. TIH w/EZSV stinger & plug catcher. Mix-up 200 bbl. of 10.1 ppg brine (cleaned pits out early that day). R/U & pump 110 sacks of cmt. (22 bbls). Initial Inj. Press = 2700 psi @ 3 bpm. Final Inj. Press = 3200 psi @ 2 bpm. R/D cementing equip. & POOH. REC[IV[D -4- ^UG l 0 i984 Oas Cons. Commission 2-18 2-19 2-20 2-21 2-22 2-23 2-24 COL ,DENTIAL INFORMATION Furnished By Conoco Ino. Finish POOH w/DST assembly. R/U Schlumberger. TIH w/20' 5~" csg. gun @ perf. 9015'-8995'. POOH to find that gun was loaded at 4 spf. P/U 10' x 5~" gun & perf. 9015'-9005' @ 12 spf. P/U 20' x 5~" gun & perf. 9005'-8985' @ 12 spf. R/D wireline. R/U & TIH w/DST assembly. R/U Otis w/H.P. & downhole shut-in tool. Could not get past 5364' when tool failed. POOH. Change out H.P. & re-run, hung-up @ 5360'. Pump 6.1 bbls. of diesel, to help tool slide down. Worked tool. past dog-leg & sting into "XN" nipple @ 8854' M.D. (6598' TVD). R/U to test LK . Test the LK. formation: 27 min. i initial flow, 90 min. initia~ shut-in, 13 hour final flow, 1 hour into final build-up. Average rate = 210 BOPD, water cut = 0%, gravity = 19° @ 60°. Continue final build-up test. Finish downhole build-up test. Close "LPR" and fill tbg. w/diesel (15.8 bbls. Attempt to release H.P. tool. After numerous attempts at equalizing and pressuring-up, tool is released. POOH. R/D Otis. R/U Schlumberger. TIH to 8785'. Flow 15 bbls. of fluid. Rat hole volume below tool = 4 bbls. Catch fluid sample (Pbh = 2653 psia). POOH. TIH to 8785' & caught second sa=~e (Pbh= 3260 psi). POOH. R/D Schlumberger. Open APR circ. valve. Rev. out tbg. POOH w/DST assembly. L/D DST assembly & P/U Halliburton's retrievable bridge plug. W.O.O. TIH w/Halliburton's retrievable bridge plug on 3~" tbg. Set bridge plug @ 8963' (top). Pump 3 sks. (300#) 12-20 gravel down tbg. & chase w/70 bbls. of brine. Estimated PBTD = 8949'. Allow sand to settle out. Tag fill. @ 8953', pressure test to 1000 psi. Pressure bleeding off downhole @ ±500 psi/4 min. Mixing up 250 bbls. of brine in preparation of reversing out sand. Finish mixing 250 bbls. NaC1-NaBr brine. Roll brine in mud pits & pressure test bridge plug again. Bridge plug would not hold pressure. Circ. sand off of bridge plug. Latch onto Halliburton bridge plug, release, pull up hole 8' (top @ 8952') & set bridge plug. Pressure tested to 2000 psi & held. Released bridge plug, lowered 21' (top @ 8973') and pressure tested to 2000 psi with no leak off. Dumped 2 sxs. (200 lbs) of sand down tbg. & chased with 70 bbls. of brine. POOH w/setting tool & 3~" tbg. M/U tbg. conveyed perforating assembly. TIH w/perforating assembly on 3~" tbg. R/U Schlumberger & TIH for G.R. correlation log. Continue running G.R. correlation log. POOH & R/D Schlumberger. Space out tbg. out tbg. Circ. 80 bbls. of diesel down tbg. & set pkr. Detonate perf. guns (8940' to 8820') &. flow well for ½ hr. to clean perforations. Produced back 4.6 bbls. @ a constant FTP= 12 psig w/24/64" choke. Rev. circ. diesel & oil (& gas) out of tbg. w/brine. POOH w/perforating assembly. L/D perf. assembly & P/U DST assembly. TIH w/DST assembly & ~e~p~.~ 8757'. R/U Otis wireline to run H.P./shut-in tool.~~ ~ ~ -5- A JG I 0 Oil & Gas Cons, commissior~ CONFtDE.. TIAL INFORMATION Furnished By Conoco Inc. 2-25 Continue TIH w/Otis H.P. gauge/shut-in device & locate in the locking mandrel @ 8670', H.P. gauge @ 8663' (6492' TVD). Monitor BHP & open LPR ball valve. Initial Hydrostatic=186 psia, initial shut-in pressure=3163 psia. Open wireline shut-in device for 20-min. initial flow. BHFP decreased f/3262 psia to 731 psia. Close wireline shut-in device for 60-min. pressure build-up survey. Final BHSIP-3127 psia. Attempt to open wireline shut-in device for final flow period with no success. Load tbg. w/diesel & attempt to pull the shut-in device out of the locking mandrel with no success. With the wireline shut-in device now open, the well was allowed to flow for the final flow period. 65 bbls. of diesel rec. (tbg. & rathole vol = 78 bbls. to top perf.). Well open but not flowing at surface. BHP increasing. Date 2-25 2-26 Time Oil Emul H 0 BS C1 °API 1730 4'0% 46% ~ ~ 125,0---00 ppm 0500 73% 18% 9% TR 29,600 ppm 19 (est) 2-26 Continue to watch well for flow & monitor BHFP. Only slight gas blows & small surges of diesel seen periodically. POOH w/Otis wireline shut-in too]. & H.P. gauge. R/D Otis & R/U swabbing equipment. Swab in well, 29 swab runs made, stabilized fluid level approx. 4000'. Total fluid produced in past 24 hrs=212 bbls., Cum.prod.fluid=277 bbls., vol of fluid swabbed = 211 bbls. 2-27 Continue to swab in well. Stabilized fluid level @ ± 4000'. The total number of swab runs was 41. R/D swabbing equip. & R/U Otis wireline. TIH w/Otis shut-in device/H.P, gauge & latch into locking mandrel @ 8670'. BHFP=2320 psia. Monitor BHP & maintain open well status. First oil to surface @ 2200 hrs.. Monitor surface flow rates. Cum. Vol. Produced Fluids = 439 bbls. Volume Produced Fluid in past 24 hrs. = 162 bbls. Volume Produced Fluids Rec. by Swabbing = 331.5 bbls. 2-28 Continue to flow well to production tanks. Monitoring prod. rates & BHP. Shut well in at Otis wireline shut-in tool (8670' WLM) & at surface wing valve for final pressure. Build-up survey. Monitoring BHP. BHP @ time of shut-in (1000) = 2320 psia. BHP @ Report Time = 3228 psi. Cumulative volume of fluids produced = 467 bbls Volume of fluids produced during last 24-hours = 28 bbls (ali. in last 12 hrs) Final Sample Cut: 90% oil, 9.5% emul, 0.5% wtr., 0.0% solids Final Oil Gravity = 18.4° 2-29 Continue to monitor bottomhole shut-in pressures for final pressure buildup survey. BHP @ report time = 3242.03 psia. 3-1 RECEI AUG 1 0 i984 Continue to monitor bottomhole shut-in pressures for final pressure build-up survey. Final BHP=3243 psia. Unseat wireline, shut-in device from locking mandrel & POOH w/Otis shut-in device/H.P, gauge & R/D Otis. R/U Schlumberger. TIH w/fluid sampler, H.P. pressure gauge, temperature gauge, Gamma Ray, CCL, and Gradiomanometer. Tie into DIL log depth & drop tool to 8650' ~las~a 0Il & Gas Cons. C0mmi~;~.'(6484' TVD). Open LPR ball valve & surface valves to allow well to flow. No fluid to surface at report time. BHFP increasing. BHFP @ 0600 hrs = 2950 psia. CONFI[._ TtAL INFORMATION Furnished By Gonoc, o Ino. 3-2 3-3 3-4 3-5 3-24 3-25 3-26 Flow well to production tanks. Logged pressure gradients from 8640' to 8200'. Sampler positioned @ 8650' & opened. Bottomhole sample pressure & temp = 2802.8 psia & 158.9°F. The well was shut-in at surface. Fluid recovered at surface = 18 bbls. POOH w/sample #1. Unsuccessfully attempted to TIH w/second sampler. Sampler tool would not fall past 80' (WLM) due to cold viscous oil in the tbg. POOH w/sampler. R/D Schlumberger, reverse circ. Unseat pkr. & POOH. L/D DST assembly. TIH w/retriving tool for Halliburton's bridge plug on 3~" tbg. Continue TIH w/bridge plug retrieval too].. Tag fill & rev. circ. sand & debris off of retrievable bridge plug. Release bridge plug @ 8973' & POOH. TIH w/EZSV retainer & set @ 8800'. Set 30,000 lbs. on top, tested o.k. Pressure up 1500 psi on top & held for 15 min., o.k. Witnessed by AOGCC. Displace tbg. with treated (oxygen-corrosion inhibitor) brine. POOH w~setting tool, L/D 3~" tbg. TIH w/75 j ts. of 3~", 9.3#/ft, L-80 8~- tbg. Land 3~" tbg. in spool. Bottom of tbg. (open-ended) is @ 2369' (WLM). N/D BOPE & N/U wellhead equipment. Rev. circ. tbg. & annulus from surface to 2369' with diesel. Pressure test wellhead seals, no test. N/D wellhead. P/U tbg. hanger & replace seals. Land tbg. & N/U wellhead. Pressure tested wellhead seals to 5000 psi & valves to 1500 psig. Pressure test Arctic Pack in 7" x 9-5/8" annulus to 1000 psig. for 30 minutes, no bleed off. Install back pressure valve. Mix NaC1-NaBr brine for MPU M-lA. Continue to mix NaC1-NaBr brine for MPU M-iA. Roll's #4 rig released at 1800 hours. FINAL REPORT. Well Status: SUSPENDED. Estimated Final Cost: $5,550,000. Roll'n rig accepted @ 2300 hrs on 3-22-84. R/U Pulled BPV. N/U BOP. Pulled tbg. hanger & R/U to circ. diesel out of hole. P/U & TIH w/3~" buttress workstring to 4160'. Circ. hole to 9.3 ppg. sodium chloride brine. Preparing to POOH with workstring. POOH w/3~" workstring. R/U Schlumberger. Run CBL/VDL/XY. Found no cmt. bond. TIH w/squeeze perforator. Shot squeeze perfs 4 spf: 3980'-3982' and 3720'-3722'__ R/D Schlumberger. P/U Hal].iburton EZSV & set @ 3964' (WLM). R/U BJ for squeeze cementing. Wait on Conoco representative. Wait on water truck & vac. truck. R/U B.J. for squeeze cementing. Waiting on water truck. Squeeze bottom perfs (3980'-3982') through retainer. (250 sks. Cold Set I) 2000 psi. P/U out of retainer. Circ. to remove cmt. above retainer. POOH & remove stinger. TIH open ended w/3~" tbg. Squeeze #2: 250 sks. squeezed into perfs at 3720'-3722' @ 600 psi. Bled off tbg. press. Opened backside. Equalized a plug up to 3580' (5 bbl). Pulled up to 3580'. Circ. around backside. Squeezed 2 bbls. of brine @ 200 psi. Pulled 10 stands out of the hole. WOC holding 500 psi. -7- 3-27 3-28 3-29 3-30 3-31 4-1 4-2 CONFtE;._ iTIAL INFORMATION Furnished By Cono Inc. Continue WOC. TIH, tag cmt. @ 3531'. POOH w/3~" tbg. R/U Schlumberger. TIH w/2' perforating gun & perforate csg. f/3498' to 3500' w/4 jspf. POOH, R/D Schlumberger. TIH w/open-ended 3~" tbg. to 3493'. R/U B.J. Squeeze 290 sks. (52 bbls.) of Coldset I cmt. & allow to equalize. Squeezed away @ 4 bpm & 1100 psi. Pulled 3 stds., rev. circ & pulled another 15 stds. Downsqueeze 4 bbls. @ 1050 psig. WOC. Continue WOC. TIH, tag soft cmt. @ 3429' (WLM). POOH w/3½" tbg. R/U Schlumberger. TIH w/2' perforating gun. Csg. perforated f/3330~ to 3332' w/4 spf. TIH w/3~" workstring open- ended to 3320'. Establish inj. rate of 3 bpm @ 800 psig. Mix & pump 392 sks. of Coldset I (52 bbls.) and then displace. Final squeeze pressure = 800 psig @ 3 bpm. Pull 4 stands, rev. circ. & pull additional i5 stds. Downsqueeze 5~ bbls. Final downsqueeze pressure = 1450 psig. WOC. TIH w/open-ended 3~" tbg. & tag hard cmt. @ 3281'. POOH w/3~" tbg. TIH w/6~" bit & 7" scraper on 3½" tbg. to 3129'. Drill through cmt. stringers to 3216'. P/U Kelly & drill out cmt. f/3216' to 3394', Pressure test squeeze perforations and circ. hole clean. Pressure leakoff from 700 psig to 625 psig in 20 minutes. Decided to re-squeeze.' L/D Kelly & POOH w/drilling assembly. TIH w/open-ended tbg. 'to 3321'. R/U B.J. Hughes. Est. Inj. Rate - 2 bpm @ 1200 psig. Pumped 100 sks. Class "C" w/2% CaCl (20 bbls.). Spotted plug, pulled 12 stands & down squeezed 15~ bbls. in 5 stages. WOC. Contine WOC. POOH w/3~" tbg. TIH w/bit & csg. scraper. Top of cmt. tagged @ 3208'. Drill out cmt. to 3424'. Dropped through cmt. plug. Pressure test squeeze perforations (3330' to 3332') to 700 psig. 15 minutes. TIH to 3440' & drill out cmt. plug to 3567'. Drill out cmt. to 3597' & circ. hole clean. Pressure test squeeze perforations. No test. POOH w/drilling assembly. TIH w/3~" open-ended tbg. to 3494'. R/U to squeeze cmt. into perforations @ 3498' to 3500'. Could not establish an injection rate @ 700 psig. Squeeze procedure was abandoned. POOH w/opened tbg. & TIH w/6-1/8" bit & csg. scraper. Cmt. tagged @ 3593'. Drill out firm cmt. f/3593' to 3964'. Rev. circ. the hole clean. Cleaning mod pits. Continue cleaning mud pits. Mix 400 bbls. of 9.3 ppg. NaC] circ. brine. Ship brine f/mud pits to brine tanks. Mix another 400 bbls. of 9.3 ppg NaC1 brine for completion fluid. Filter completion fluid. Continue filtering brine. Rev. out & dispose of cmt. contaminated brine using filtered 9.3 ppg. NaC1 br~.ne for displacement. POOH w/3½" tbg. R/U Schlumberger & run cmt. bond log & the cmt. evaluation tool f/3951'-2500'. TIH w/gauge ring, junk basket to 3951' & POOH. R/U lubricator. TIH w/5~" gun & perforate interval 3874'-3894' w/12 jspf. Perforate interval 3810'-3830' w/12 jspf. Perforate interval 3794' to 3810' w/12 jspf. Note: The well went on a vacuum when this interval was perforated. -8- 4-3 4-4 4-5 4-6 4-7 4-8 4-9 CON JENTIAL INFORMATION Furnished By Con Inc, TIH w/Schlumberger 5~" hollow carrier gun & perforate f/3749' to 3756' @ 12 jspf. The well went a a slight vacuum after perforating. TIH w/Baker "Retrieva-D" packer/seal bore on wire- ].ine & set @ 3730' WLM (top). Change pipe rams & pressure test BOPE to 1000 psig. P/U seal assemblies, bundle carrier, & perforated pup & TIH on 4~" btrs. tbg. Space out & ].and the 4~" tbg. 4' above the neutral point. R/U & TIH w/2-7/8" CS Hydril tbg. Note: 6.5 bbls. brine lost during perforating. Finish TIH w/2-7/8" test string. Locate in the 3.25" seal bore, then space out to set 4.0' above the neutral point. Displace the 2-7/8" w/diesel. Circ. heated brine down the 2-7/8" x 4~" & up the 4~" x 7" annulus. Flow test the "0" sands. Well. flowed back diesel until 1530 hours. At 1607 hrs., began swabbing. Well started flowing on its own at 1900 hrs. Had to swab intermit- tantly to keep well flowing. Since 2330 hrs., the we].], has been flowing at 240+ BOPD with a surface pressure of 10+ psi. No GOR available (bypassing .separator). The water cut stable @ 2.5+% w/0.5% B.S. Finish running the flow test for the "O" sands. Running a build- up test. Test scheduled to terminate @ 0800 hrs. Finish the build-up test for the "O" sands. R/U Schlumberger. TIH w/gradiometer, HP gauge, temperature gauge & sample tool. Gradiometer failed, sampler set @ 3650' (60' above packer). Attempted to bring well in. Could not bring in well & keeep BHP above 1400 psi. Caught 1st sample (BHP=1424, BHT=71°). TIH & caught 2nd sample (BHP-1526, BHT=66°). Reverse-out the 2-7/8" & POOH w/2-7/8" tbg. Change rams, & POOH w/4~" tbg. TIH w/4~" & catch pkr. POOH. Finish POOH w/test packer. R/U Schlumberger. TIH w/Halliburton EZ drill & set @ 3709' WLM. P/U 5½" csg. guns. Perf. the "N" sands, 3668' to 3674', 3636' to 3651' 3601' to 3614'. P/U "Retrieva-D" test: packer & set on ~ireline @ 3580'. R/D Schlumberger. R/U & TIH w/4~" tbg. Space-out 4' above neutral; test hanger to 500 psi & change rams. TIH w/2-7/8" tbg. R/U to flow test. Swabbed out brine, then tagged formation fluid w/swab cups. Swab cups falling very slow. Attempt to swab heavy fluid. Surface sample of fluid was low gravity oil w/extremely high sand content. Shut well in @ wellhead to observe pressure build-up. Bleed-off pressure & ran in w/swab to tag fluid @ 650'±. Swabbed well in slowly, taking 200'± of fluid per swab. Well flowing. Observe & monitor. BS content fell-off quickly to 2%, avg. rate of 80 BOPD. SI @ wellhead & TIH w/"XX" plug. After 2 hrs., plug was @ 1200'. With well still SI, POOH & R/D wireline. SI @ wellhead for build-up. Build-up test for "N" sands. -9- 4-10 4-11 4-12 4-13 4-14 CONFI TIAL INFORMATION Furnished By Conoco Inc. Finish build-up test for "N" sands. TIH w/downhole sampler, HP gauges, gradio, temperature, CCL & GR. Could not get past 3100' (tool fell extremely slow). Took sample @ 3029'; pressure = 1129 psi, temperature = 55°. POOH w/sample. R/D Schlumberger. Reverse out 2-7/8" tbg. w/9.3 ppg. brine. POOH w/2-7/8" tbg. & L/D seal assembly. Change rams. POOH w/4½" tbg. & L/D seal assemblies. TIH w/4½" tbg. & pkr. retrieval tool. Retrieve packer @ 4580' on 4½" tbg. & POOH. Rig up Schlumberger & RIH w/GR-CCL to determine fill depth. The top of the fill was measured at 3599' (WLM). POOH. RIH w/6.1" O.D. gauge ring/junk basket to 3580'. POOH. The decision was made to re-test the "N" sand. Rig down Schlumberger and change pipe rams to 2-7/8". RIH with 2-7/8" tubing open ended. Build up brine volume. Wash out sand fill from 3600' to EZSY retainer @ 3709'. POOH w/2-7/8" tubing. Rig up Schlumberger. Run in and set a Baker-model "Retrieva-D" packer @ 3580'. R.D. Schl. RIH w/4~" tbg. Run 4½ tubing, latched into Retrieva D packer at 3580'. Run 2-7/8" tubing, loaded it w/20 bbls diesel and latched into seal. nipple in 4½" tbg. Established hot water circulation down 4½ x 2-7/8 annulus and out the 7" x 4½ annulus. Opened well to flow. Recovered 12 bbls diesel and noted drop in casing pressure and fluid level. Pumped down back side without pressure and no return. Pull tubing strings and re-run 2-7/8" with retrievable packer to check squeeze perf. - held o.k. - tagged 20' sand fill on retainer at 3709. Now coming out of hole w/packer, prep. to run in open ended and circulate out sand. Finished coming out of hole w/packer & bridge plug. RIH w/open-ended 2-7/8" tubing and wash out fill from 3685' to 3709' (top of EZSV retainer). POOH w/2-7/8". R.U. Schlumberger & RIH w/"Retrieva-D" packer on wireline & set at 3467' (top). POOH and R.D. Schl. Made up 4½" seal assembly. Discovered bad 2-3/8" Hydril crossover thread. Wait on tristate to cut new crossover. Made up, 2-3/8" tail pipe, seal assembly, bundle carrier, sea]. bore, perforated pup joint and RIH on 4½" tbg. Landed 4½" tubing 4' above the neutral point. Made up 2-7/8" seal assembly and "X" nipple and RIH on 2-7/8" tbg. Space out 2-7/8" tbg. Displace tbg. w/19 bbls. diesel & ].and tbg. Pressure test annulus to 200 psi, no apparent communication w/2-7/8" tbg. Start circ. of hot brine down 2-7/8" x 4½" annulus, returning up 4½" x 7" annulus. Temp.in = 135°F, temp.out = 125°F. Open well to flowo Initial WHP = 180 psig. Well flowed for ±15 minutes & died off. Total rec. = ±2 bbls. R/U & swab down 2-7/8" tbg. w/200' pulls to a depth no greater than 575'. Total 42 bbls. of brine & diesel rec. Pressure tests & loss of circ. brine indicate communication between circ. string & production tbg. Pressure test annulus with both 2-7/8" & 4~" seal assembly in different positions. No change in communication. Mix 150 bbls. of 9.3 ppg. brine. R/U Otis slickline to run 2-7/8" tbg. plug. -10- 4-15 4-16 4-17 4-18 4-19 4-20 CONFIDt_.. rIAL INFORMATION Furnished By Conoco In=. TIH w/Otis 2-7/8" tbg. plug & set in "XN" nipple @ 3231'. POOH w/slickline. Pressure test 2-7/8" tbg. to 2500 psig. No leaks. TIH w/Otis plug retrieving tool & retrieve the 2-7/8" tbg. plug @ 3231'. POOH w/2-7/8" tbg. & seal assembly. POOH w/4~" tbg. & seal assembly. Pressure test all bottomhole 4-15 assem- blies to 1500 psig, no leaks apparent. TIH w/pkr. (cont'd) retrieving too]. on 2-7/8" tbg. & pull the "Retrieva-D" pkr. @ 3467'. TIH w/pkru on wireline, tag fill. @ 3653'. Pull up & set pkr. @ 3309' (top). POOH. TIH w/5' of seal assembly on 2-7/8" tbg. Locate in seal bore & pressure test backside to 2500 psig. POOH w/seal assembly & 2-7/8" tbg. TIH w/14 its. of 2-3/8" tbg. tail on 2-7/8"tbg. Tag fill @ 3666'. Circ. out fill to 3709~ & POOH w/tbg. P/U 9 j ts. of 2-3/8" CS Hydril tbg., seal assembly, bundle carrier, seal bore & perforate 4~" pup joints. TIH on 4~" tbg. Spaced out & landed 4~" tbg., end of tbg. @ 3603'. P/U seal assembly & Otis 2-7/8" "XN" nipple. TIH on 2-7/8" tbg. Displace 2-7/8" & 2-3/8" tbg. string w/diesel (20 bbls.) Pressure test annulus to 1600 psig, no leakoff. Begin circ. of brine down 2-7/8" x 4~" annulus & return- ing up 4½" x 7" annulus. Temp in = 128°F, temp. out = lll°F. Open well to flow. Initial tbg. pressure = 240 psig, tbg. pressure dropped 'to 0 in 10 min. through 1/4" choke. Swab down 2-7/8" tbg. pulling no more than 200'run & no deeper than 500'. Produced back all diesel. Producing brine. Total volume produced as of report time = 30.5 bbls. Continue to swab down 2-7/8" tbg. Maximum depth of pull = 500'. Continue swabbing, maximum depth of pull = 800'. Continue swabbing, maximum depth of pull = 1000'. Continue swabbing, maxJ~mum, depth of pull = 1200'. Well quit making fluid. TIH w/o swab cups & tag @ 3240' (3260'± WLM). Wait for fluid level to raise. Total fluids produced = 149 bbls. brine, Tr sand, Tr oil. WOO. R/U & POOH w/2-7/8" tbg. string. R/U & POOH w/4~" tbg. P/U pkr. plucker & TIH. Tag pkr. & pull 5000± lbs. to release pkr. POOH w/test pkr. P/U retrievable bridge plug. Set bridge plug @ 3535'± (WLM). POOH w/4½" tbg. R/U Schlumberger to perforate. Perforate the "M" formation f/3395'-3464' w/12 spf & f/3354'-3388' w/12 spf. Set "Retrieva-D" pkr. @ 3320'. R/D Schlumberger. TIH w/4~" btrs. & locate in pkr. 4' above neutral point. Change rams. TIH w/2-7/8" Hydril & locate in upper seal bore. Pressure test backside. Space-out 2-7/8" & R/U to swab. Swab brine out of the 2-7/8". Swab the "M" formation. Tried to bring well on slow by pulling only 200' of fluid/pull. After 12 pulls, fluid influx slowed down. Pulled 3 more swabs, then the fluid level was down to 700'. Quit swabbing to allow fluid level to rise. Fluid rose to. 475' within one hr. Began swabbing w/100' bites (fluid level stable @ 500'). At 1630 hrs. fluid level began to drop (swabbing one run every 1/2 hr.). At 2200 hrs. fluid level down to 875'. SD swabbing. At 0230 hrs. fluid level still @ 875'. Began swabbing (200' fluid per pull). Total fluid = approx. 40 bbls. -11- 4-21 4-22 4-23 4-24 4-25 4-26 CONFIDL-, TIAL INFORMATION Furnished By Conoco Inc. Attempt to swab the "M" formation. Fluid level dropped to 1935 by 1000 hrs. Suspended swabbing & monitored fluid level. Fluid to 1500' @ 1200 hrs. @ 1500 hrs. pulled swab from 2000' & diverted flow into sample barrels. Pulled from 1800' into sample bbls. Pulled final swab for samples, then R/U to reverse out. Reversed out tbg. string ~nto sample barrels. 50% BS in samples. POOH w/2-7/8" tbg. POOH w/4~" tbg. Total samples = ~ bbl. Chevron, 8 bbl. ARCO, 2 bbl. Conoco. Finish POOH w/4~" tbg. R/U & TIH w/3~" tbg. Grabbed the test pkr, pkr. set @ 3320' WLM. POOH w/test pkr. TIH w/pulling tool for bridge plug. Tag fill @ approx. 3355' (165' of fill). R/U & wash down to bridge plug. Release bridge plug & circ. (Pipe & BP free.) R/U to POOH. Bridge plug stuck. Could not release B.P. so release pulling tool & PU. Build-up additional brine volume. Wash down; grab BP (20' fill). BP & pipe free. R/U to POOH. Bridge plug & pipe stuck. Rev. w/700 psi (no ret). Pressure-up on tbg. to 3000 psi w/no bleed-up. Pulled max. of 90,000 lbs. TIH w/S.L. Tag depth indicates 30'-40' of fill in tbg. R/U Camco. TIH w/2-1/8" bailer. Tagged-up @ 3495'± slickline measurement. Made three runs w/bailer. Rec. only a cup of sand. R/D Camco. R/U & try to circ. & rotate (3000 ft-lbs.) with no success. Work pipe (190,000 lbs. max. pull). R/U Gearhart & perf. tbg. just above pulling tool. Broke circ. w/1000 psi @ 2 bpm. Work pipe but no movement. T!H w/2" jet cutter. Cut tbg. 1~ joints above pulling too]. (40' of 3~" tbg. left in hole). POOH w/3470'± of 3~" tbg. TIH open-ended to 3420'. R/U B.J. to cmt. Cmt. the "M" formation w/200 sks. of Class "G" + 2% CaC12. P/U to 2460' & rev. circ. WOC. Continue to wait on cmt. POOH w/open-ended 3~" tbg. TIH w/6" bit, csg. scraper. Gel up mud and tag cmt. @ 2786'. Drill out cmt. f/2786'-3325'. Continue drilling out cmt. to the top of the fish @ 3463'. Note: Hole standing full w/9.3 ppg mud. Circ. hole clean. POOH w/bit & scraper. TIH w/washover assembly & tag top of fish @ 3456'. Tag restriction @ 3485'; circ. hole clean. Rotate easily through restriction to the bottom of the bridge plug retrieving tool. Bridge plug is being pushed downhole ahead of washover tool. Circ. hole clean. POOH w/washover assembly. P/U overshot assembly & TIH on 3~" tbg. Bridge plug fell. to 3522'. Stab over fish; P/U fish w/50,000 lbs. over string weight. Circ. not possible. Pull 3~ stands wet. Fish is pulling hard; fish stuck @ 3361'. Attempt to free stuck fish. The B.P. retrieving tool was released from the B.P. POOH w/shot off tbg. & B.P. retrieving tool. L/D fish & fishing tools. P/U & TIH w/B.P. retrieving tool on 3~" tbg. & wash down to 3347'. Latch onto bridge plug & POOH. P/U & TIH w/6" bit, X.O. & six 4-3/4" D.C. P/U Kelly & circ. out sand from 3511' to 3566'. -12- 4-27 4-28 CONFIDE--rIAL INFORMATION Furnished By Conoco Inc. Circ. out fill f/3566' to 3709'. Drill out EZSV retainer @ 3709' & TIH to 3959'. Circ. hole clean, L/D Kelly & POOH. TIH w/csg, scraper to 3354'. POOH. M/U pkr. assembly & TIH on tbg. M/U SSSV & continue TIH on 3~" tbg. Continue to TIH w/3~" completion string & ¼" SSSV control line. Install tbg. hanger, pressure test SSSV to 5000 psig & land tbg. N/D BOP & N/U wellhead. Pressure test seals to 5000 psig, o.k. Displace annulus w/85 bbls. of diesel. U-tube diesel into tbg. Drop tbg. plug prong down tbgo & chase w/slickline blind box. Tap prong into plug body & POOH w/slickline. Pressure up on tbg. to 2500 psig setting pkr. @ 3258' & pressure test tbg., no leakoff. Install Cameron back pressure valve & secure wellhead. Clean mud pits. RIG RELEASED @ 2400 hrs. AUG 1 0 Alask~ Oil & Ga.s Cons. commission -13- CONFIDENTIAL INFORI 71ON Furnished By Conoco ATTACHMENT NO. III MILNE POINT UNIT N NO. 1 B PRODUCTION TEST DATA Interval Tested: Date of Test: Method of Operation: Hours Flow Tested: Wellhead Flowing Tbg. Pressure Gauge Depth (MDKB): Oil Produced (bbls): Gas Produced (MSCF): Water Produced (bbls): GOR (MCF/bbl): Choke Size: Flowing Bottomhole Pressure * (PSIA): Final. Build-Up Pressure * (PSIA): Average Rates: BOPD MSCFPD BWPD Oil. Gravity: Production Test No. 1 9025'-9050' 02/14-16/84 D.S.T. 14 20 8956' Nil 105. 82. NA 1.25" 2902 3320 <5 7.5 170 NA Production Test No. 2 8985' - 9015' 02/19-21/84 D.S.T. 13.5 45 8854' 70 85O 0.300 2" 2300 3312 210 63 0 19° Production Test No. 3 8820'-8940' 02/23-28/84 D.S.T. 12 0 to 10 8663' 61 NA NA 2" 2320 3243 122 NA 0 18.4° * As recorded at gauge depth. CONFIDENTIAL INFORMA N Furnished By Conoco ATTACHMENT NO. III MILNE POINT UNIT N NO. 1B PRODUCTION TEST DATA Interva]~ Tested: Production Test No. 4 3749'-3756' 3794'-3830' 3874'-3894' Date of Test: Method of Operation: Hours Flow Tested: 19 Wellhead Flowing Tbg. Pressure (PSIG): 5 Gauge Depth (MDKB): Oil Produced (bbls): 143 Gas Produced (MSCF): NA Formation Water Produced (bbls): NIL GOR (MCF/bbl): NA Choke Size: 2" FI. owing Bottomhole Pressure *(PSIA): 1030 Final Build-Up Pressure *(PSIA): 1562 Average Rates: BOPD 200 MSCFPD NA BWPD <5 Oil. Gravity: NOTE: 04/3-4/84 D.S.T. 3726' 18.9° Production Test No. 5 3601'-3614' 3636'-3651' 3668'-3674' 04/7-8/84 D.S.T. 9.25 <5 3551' NA NA NIL NA 2" 1390 1543 8O NA 0 16.8 Well Sanded Up NOTE: Production Test Nos. 6 and 7 were unsuccessful. Production Test No. 8 3354'-3388' 3394'-3464' 04/19-20/84 D. S. T. /Swab 35 <5 3284' 15 NA NIL NA 2" 1200-1400 NA NA NA 0 Well Sanded Up * As recorded at gauge depth. CONFIDENTIAL INFORMA'rtdN Furnished By Conoco ATTACHMENT NO. IV MILNE POINT UNIT N NO. lB CEMENTING RECORD Primary Cement: 13-3/8" Casing - cemented to surface. 9-5/8" Casing - cemented with 1000 sks. of Cold Set III cement followed by 750 sks. of Cold Set II cement. 7" Casing - Cemented with 600 sks. of 12% Gel cement (@ 12.8 PPG) followed by 500 sks. of Class "G" cement w/l% D-31 (friction reducer), 0.2% R-5 (retarder), and 0.2% D-6 (defoamer). Secondar~ Cement: Squeeze No. 1: 3980' to 3982' and 3720' to 3722' - circulated 250 sks. Cold Set II through bottom set of perforations. Squeeze No. 2: 3720' to 3722' - squeezed 250 sks. of Cold Set I cement. Squeeze No. 3: 3498' to 3500' - squeezed 290 sks. of Cold Set I cement. Squeeze No. 4: 3330' to 3332' - squeezed 390 sks. of Cold Set I cement. Squeeze No. 5: Resqueeze 3330' to 3332' - squeezed 100 sks. Class "C" cement w/2% CaCi^. Squeeze No. 6: 3395' to 3464' and 3~54' to 3388' (production perforations) - squeezed 200 sks. of Class "G" w/2% CaC12· . . (n' (f' ° Suggested fom to be inserted in each "Active" vicll folder to d1eck for timely compliance with our regulations. ~ 11 ~ (: tr !vJ I / úP fr¿Ú11--1Y - lB- f:erator, \vell Narœ and Numœr . Reports and Materials to be received by: \~ ~7-11f Date Re:quired Canpletion Rep:>rt Yes Well HistoIy Yes ~ _Samples ,Mud Log Date Received Re¡;¡arks 8-/tJ- ~fe 0' . . o. - ~ Core Chips Core Description Registered Survey Plat Inclination Survey Directional SUrvey Drill Stem Te~t Reports Prcx:h!ctiðn Tes t RefOrts ð ~ 4f~ -- .. ~ eft ._"'" -/ó-~ Logs Run . Yes s ~-¡ 7- ~'II'-?" ' S~/7- ~'f t, - I ~- 8'<1 Digitized Data IJ'fM ë:/-e,y ye.s <~_._---- , -~ <e- N 0 R T H n I I ~'~UI II'IF_.INI I I~IU. V VICINITY MAP AS-BUILT PAD N SECTION 30, TI3N, RIOE~ UMIAT MERIDIAN LOCATION IN SECTION WELL : FROM NORTH LINE : FROM EAST LINE I : ! : .. , : · ,; : : .: ; : ' STATE PLANE COORDINATES WELL NORTH INGS .: EAST I N G S · : I 6~ 015,002.1 : 543,$30.0 : t · · · : ZONE 4 GEODETIC POSITIONS WELL i LATITUDE : LONGITUDE : · I ~ 70° 27'07" i 14 9° 38'47" ; · : CERTIFICATE OF SURVEYOR: I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA ~D ...... :~ THIS PLAT REPRESENTS A LOCATION SURVEY II MADE BY ME OR UN'DER MY SUPERVISION, AND __,, II THAT ALL D~ENS~ONS AND OTH~. DETA~LS 3340 Arctic Boulevard, Suite 201, Anchorage Alaska 99503 Ils~Le I": 2~'~r~ge ' July 18, 1984 Mr. H. D. Haley Manager of Alaskan Operations Conoco Inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503-2689 Dear Mr. Haley: Enclosed with this letter is a copy of our letter to you dated May 18, 1984. Since our records show no response to the ~a¥ 1984 correspon- dence, the possibility of non-receipt can be accepted. However, in spite of postal difficulties, the regulations remain in effect and the data on the Mi!ne Point Unit Wells M-l, M-lA, N-l, N-lA, and N-lB are past due. Please submit the required data and reports at this time. Yours very truly, Horry W. Kugler Commissioner b e: ]. !IWK. H Enclosure ~,'F'A <?'~ ~ J'~~t..~ t~N'é<;li~\{ Arrot! <:ÖJ"]J" Fcom ,", '" rot'.- c . ) t'- -:- 1) \ V {- l"\' ,- J ~ ~ c.,:- '-,' -:> N e ~,o \.2.... ~~ (.." t....' ,-"{ t ;~c') -~ Oecord of Shipment of "'1 Confidential Information Date CJ (,/ l C);f\4- "t I I (L~ KCi\,"') T.^\C:. ' ?:~-=;75 Co. -;:") T72..F- ¿T - ~o .ï-E lCO t4-N ("' H-() p, ¡.:.\.{:,., ,¡;:. ~~ K c; cr '3"(\ -..::;, . - canace (,~onoco Inc. Geophysical Section ~~Iosed 0 Under Separate Cover ~~t-I"h Dr:=-Cl vEi2...-E.:ñ Subject Tl-hS i KÇ'.c:¥,YI\4TlC:)/'ï (,Jt-î-S ('tor /4'-tt!-llLI4Bct:- ("J ~E:\('-\ìHE C,-¡-"Hf;\i? G1::Jt='={'~ HéI c¿- lo{-;,~~) t..Jeí2-.E -f"P,y~,)'tsf""'\lIT¿-Ö. HI.S Sf-K.')LI,-,Ù êC.l'.,-\YCeTtC; TH£ "56T OF hip(( LI..'(""'~"::> ç'p,,(\¡---\ Quantity Contents tv",! LI'--( b 1'0 I J'-\ ì UK \ I" N -\1::> /'1\ (L"t-Ç. -:PC) \ )--l T , I Uì'\~T N -lB VI P'MeT~:~-~C:SuLT~ '--"~--"-"--'-'-- -'--,..,"-'-,.."._----'-".._--,--------------,-----------------.' -- -- ----------,--- Oi'If:: 'DI.'7 jYI f:. T~¥-, LL_U~~l-E~ é_" -=:::>', I Ì'\. G- ON(., C) I'l E~ '1)~-Pì"'--l E,:TE:ô/~ Dt 7 1'-\ E~ TC:=Q~ /\ LC,(JST(::,K ---_OJ:) I Lé") T--'- '-[3L.() E,L-\ ï--\E: ---p~ l f--\.-r- --YCO r - ~t?14 ----PP~ 1 hT- (~L C¡S -r~~¡¿, "-"J ~, L E'l¥::£= I\i c' T E~:' '1'(-( (J'+1- "'((í (~ ÔA'7-(i (, 1<-- "" :-""-- ",il' ~ ----c/ !'{. ~ ( t::r¿~'l'--\l [ f"~ (--- '---,---,,_.."...~ ~.. ""_._.~--._-,-,- ~ ,~.,¡}¡}~E~E~ £l i./" '" ~v~r:;6e,~- U'V-'-, v' , ',/L{jJ? /1../ / J U 1 1984 1/"-- . 8 Alaska Oil & Gas Cons. Commission Anchorage SiÇ)fiüci By ß Ell- Date ledçw receipt promptly by siç¡ninq and rd Irni ~1 carbon copy. Date -,_.._--- ---- Transmittal Copy Only To -"'----------- ~----------------.. 13-98 PCXJ, 7-79 ~,I()RICK OKLA. CITY PR INTED IN U.S,A. May 18, 1984 Mr. H.D. Haley Conoco, Inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503 Re: Milne Point Unit Wells A-3, M-I, M-IA, N-i, N-IA, N-lB Dear Mr. Haley: Available evidence indicates the referenced wells have either been suspended, abandoned, or completed. Our regulations require the submission of well completion reports, deviation surveys, logs, and other data within 30 days of the suspension, abandonment or completion of the well, whichever comes first. Please submit the required reports and data at this time. Sincerely yours A, Harry W. Kugler Commissioner lc:B.lg.8 To 'onoco Inc. Geophysical Section ~001 -r'oC, e_cd'Pr z"-~ 6_., ;ecord of Shipment of Confidential Information oat [] Under Separate Cover [~Enclosed Via Quantity Contents Qow ¢. .... ' - , - I~uctions: PIc'ase acknoIledq,~ receipt prx)mptly by signing, and t ~turning carbonDateCOpV. Transmitt;fl Copy ()~fly 1;) 13-98 PCXt, 7-79 AlasKa Oil-''~-'',~,,,o ....... Cons~ Commission -- · ~K,~h.*~ ~,c* NORiCK OKLA. CITY PRINTED tN STATE OF ALASKA ALASK~_.)IL AND GAS CONSERVATION (._. MMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator Conoco ]:nc. OTHER~j)( 7. Permit No. ~ 84-13 ~ 3. Address 2525 6 Street, Suite 100, ^nchoraqe, Alaska 99503 4. Location of Well 2660' FSL, 1425' FEL, Section 30, T13N, RIOE, U.M. 8. APl Number 5o-029_21053_02 9. Unit or Lease Name Milne Point 10. Well Number N-lB ! 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 54,5 KB J ^DL 25517 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Upper Cretaceous~. Formations NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing Stimulate L~ Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The N-lB well (second sidetrack of N-1 well) was drilled to a total depth of 9208' MD (6810' TVD) with a maximum hole angle of 64° at 5500' MD. After testing the two lobes of the "Lower Kuparuk" and then the laminated zone the well was suspended by setting an EZSV retainer at 8973' MD then hanging-off 2396' of 3½" tubing. It is now proposed that the shallow oil sands be tested. The recommended test procedure calls for three seperate tests using a 2 7/8" x 4½" concentric test assembly. While producing up the 2 7/8" tubing, heated fluid will be circulated between the two annuluses. Each test will involve downhole pressure gauges, a flow period of approximately 24 hours, a shut-in period for build-up of one and a half times the flow period and bottomhole samples. In the first two tests a gradiometer and spinner are proposed for determining the distri- bution of the production. Proposed Perforations Test No. I Test No. 2 Test No. 3 ("0" Sands) ("N" Sands) ("M" Sands) - 3756 - 3830 - 3894 - 4O08 - 4065 - 4080 3749 3794 3874 3998 4060 4075 (7') (36') (20') (10') (5') (5_3 3601' - 3614' (13') 3354' - 3388' (34') 3636' - 3651' (15') 3395' - 3464' (69') 3668' - 3674' (6') 14. I hereby c~e_.r_~fy that the,foregoing is true and correct to the best of my knowledge. Signed ..~~~--~_~~~ Title Production Engineer The space below for Commission use -OVER- Date March 22, 1984 Conditions of Approval, if any: ORIGTf, IAL SIGHED BY H,A4tRY W. KDGLEll Approved by COMMISSIONER ~pproved Copy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~ STATE OF ALASKA O~~./ ALASK/ 'IL AND GAS CONSERVATION ¢ /IMISSION MONTHLY REPORT F DRILLING AND woRKOVER OPERATI .... 1. Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. ~ 3. Address 8, APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50-029-21053 Location of Well atsurface 2660' FSL, 1425' FEL, Section 30, T13N, RIOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 56' KB ADL 25517 9. Unit or Lease Name Milne Point Unit 10. Well No. N-lB 11. Field and Pool Kuparuk For the Month of. February ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Rig was released on 2-2-84. Final TD of N-lB 9208'. 13. Casing or liner run and quantities of cement, results of pressure tests Si ze Wt. Type From To 7" 26# L-80 Butt. O' 9193' Cement 600 sks. 12% gel. Cmt., 500 sks. Class G 14. Coring resume and brief description 15. Logs run and depth where run 6. DST data, perforating data, shows of H2S, miscellaneous data Completion rig has moved on location, 2-7-84, to test the well. on Completion report. Results to follow 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is 'r-"/~l~lred for each calendar month, regardless o. the status o ns, and must b~ filed in duplico~= v, ith t,,= Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 STATE OF ALASKA ALASI~ ,.'.31LAND GAS CONSERVATION MMISSION MONTHLY REPOR'i"OF DRILLING AND WO' KOVER OPERATIONS · Drilling well Workover operation [] 2. Name of operator Conoco Inc. 3. Address 2525 C Street, Suite 100, Anchorage, Alaska 99503 4. Location of Well at surface 2660' FSL, 1425' FEL, Section 30, T13N, RiOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) ~6' KB 7. Permit No. 8. APl Number 50-029-21053--- 9. Unit or Lease Name Milne Point Unit 10. Well No. N- lA, k.N- 1B_B./' 1 1. Field and Po~O't'~ Kuparuk 6. Lease Designation and Serial No. ADL 25517 For the Month of January ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks N-1 (TD 7650') and N-lA (TD 8634') were both plugged back. N-lB was kicked off at 2586' and drilled to a T.D. of 9208'. Preparing to run 7" casing in N-lB at months end. 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description Sidewall cores were taken at selected intervals in both N-lA and N-lB. 15. Logs run and depth where run Log N-1 From To DIL/BHCS 7645' 2504' FDC/CNL/NGT 7645' 2504' HDT 7645' 2504' Velocity Survey 7645' 500' Log N-lA From To Log N-lB DIL/BHCS 8634' 2504' DIL/BHCS FDC/CNL/NGT 8634' 2504' FDC/CNL/NGT HDT 8634' 2504' HDT From To 9194' 2504' 9186' 2504' 8010' 2504' 6. DST data, perforating data, shows of H2S, miscellaneous data N-1 P1 u,gs Cement N-lA P1 uqs 6776' 230 sks. Class G 7947' 3600' 120 sks. Class G 7827' 3150' 186 sks. Class G 3050' 2400' 215 sks. Cold Set I 2270' Cement 182 sks. Class G 50 sks. Class G 165 sks. Class G 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ¢~ , . . ~ regardles'~of - NOTE-.-Report on this form is required for e~6ch calendar month, s, Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 AFE 1039 AOGCC(2) AEH Well file n_.. ~ ~ ~,~ ~ · and must be filed. in duldlicate with the Alaska Submit in duplicate March 1/1984 Received from the ANALYSTS, Inc. two(2) blue line copies and two (2) sepia copies for each of the follwoing wells CONOCO CONOCO CONOCO Milne Pt. fiN-1 Milne Pt ~,~N- lA Milne Pt. fiN-lB (signature) ALASKA OIL & GAS COMMISSION MEMORANDUM State .of Alaska ALAS}24~'QIL._A1]D GAS CONSERVATION COmmISSION TO: CC{la~~~a~ t on DATE: ~arch 12, 1984 ., . -~-¢/.i "~ ~" FILE NO: THRU: Lonnie C. Smith Co~issioner TELEPHONE FROM: Harold R. Hawkins .~.,/~i~/~/*' SUBJECT: Petroleum Inspec to .r~'~'?~// Witness Plugging of Well for Suspension, Conoco, Inc., Milne Point Unit N-lB Well, Sec. 30, T13N,R10E,~-I Permit No. 84a13. Friday., March 2, 19.84: I left Unions Leffingwell No. 1, subject of another report, to Conoco, Inc., Milne Point Well No. N-lB. Purpose of trip to witness the plugging of the well above the hydrocarbons for suspension. I filled out an A.O.G.C.C. well schematic which is attached and received a schematic o~ well proposal from Conoco of the retainer I witnessed set and tested. In summary, i witnessed the successful setting of the 7" retainer and pressure testing of same for Conoco, Inc. Attachments 02-O01A(P, ev. 70/79) '!_ N 8fiqo' - -- ~¢FOg.~P,'TtO H5 'T'b-- fi ~Ofi' o$/o~./~ PROFb.GEP Ac'P, JA L STATE OF ALASKA ALASKA--OIL AND GAS CONSERVATION O=rMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] OTHER [] · 2. Name of Operator Conoco Inc. 3. Address 2525 C Street, Suite 100, Anchorage, Alaska 99503 4. Location of Well 2660' FSL, 1425' FEL, Section 30, T13N, RIOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 54,5 KB 12. I 6 . Lease Designation and Serial No. ADL 25517 7, Permit No. 84-13 8. APl Number 5o-029-21053-02 9. Unit or Lease Name Milne Point Unit 10. Well Number N-lB '"i '1. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon .?"' [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~,~.?~ ~.~,. X Pulling Tubing SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The N-lB well was drilled to a TD of 9209' on January 27, 1984. After running 7" casing to 9196' the drilling rig was released. A completion rig was moved on the well and the well was tested as follows' Perforations' Lower Kuparuk (2) Lower Kuparuk (1) Laminated Zone (Depths based on DIL/GR run on 1-28-84) Procedure- 9025' - 9050' (25') 8985' - 9015' (30') 8820' - 8940' (120') 1) Perforated the Lower Kuparuk (2) zone, then was tested thru an EZSV Packer set @ 9020' The perfs were then squeeze cemented off w/110 sacks of class "G" cement. 2) 'Perforated the Lower Kuparuk (1). Zone was tested using conventional D.S.T. tools. 3) A retrievable bridge plug was set above the Lower Kuparuk (1) @ 8973' and laminated zone was perforated and tested using conventional D.S.T. tools. Retrievable bridge plug was the removed. Proposed suspension of well: 1) Set EZ drill bridge plug @8800'. 2) RIH w/ 3½" 9.3# tubing to 2300' to diesel.(Tubing to remain in well for a kill string). 3! Land 3½" tubing and install 3½" 5000 psi tree and back pressure valve. ~4).1 h~Vi~oVyecer~i~/~'th~t~t~ge ~~li¢t~ a'~l~"(~t~ the best of my knowledge. Signed Title Senior Dri 11 inq Foreman Date The space bel/Jw for Commission use Procedure- (500' below permafrost). Cahnge top 2300' of well over 2-29-84 Conditions of Approval, if any: Approved by ~ By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in 'F~'iplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA, ,L AND GAS CONSERVATION C IMISSION SUNDRY i 'OTICES AND REPORT,, ON WELLS DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 84-13 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 5o-029-21053-02 4. Location of Well 2660' FSL, 1425' FEL, Section 30, T13N, RIOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 54.5 KB I6. Lease Designation and Serial No. ADL 25517 12. 9. Unit or Lease Name Milne Point Unit 10. Well Number N-lB 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate J~ Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing ~_~1 Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-17(;)). The N-lB well was dril to 9196' the drilling be moved onto the well .Proposed Perforations: Lower Kuparuk (1) Lower Kuparuk (2) (Depths based on General Procedure: 1. 2. 3. 4. 5. led to a T.D. of 9209' on January 27, 1984, After running 7" casin¢ rig was released. It is proposed that the Roll'n IV completion rig and the well tested as follows; 8985' - 9015' (30') 9025' - 9050' (25') DIL-GR run on 1-28-84) Perforate the L. K. (2) then set an EZSV packer at 9020'. Test the L. K. (2). Squeeze-off the L. K. (2) if wet. Perforate the L. K. (1). Run completion string. Swab the well in, then release the rig. Test the L. K. (1), then set a downhole plug, close SSSV and set a BPV. (refer to attached procedure for details). 14. I h~ee4a~ certify that tile foregoing is true and correct to the best of my knowledge. Signed_~___.~~''~ ~t~0~. Title Production Engineer The space below for Commission use Date 2-7-84 Conditions of Approval, if any: Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate I.IILNE POINT UNIT WELL N-lB COMPLETION/TEST PROCEDURE February 7, 1984 Introduction: The N-lB well (the second redrill of the N-1 well) was drilled as a slant hole in a S35°W direction with a maximum hole angle of 63.5° at 6000'±. The well reached a total depth of 9208' MD (6796' TVD) on January 27, 1984. Casing was run with the Nabors #27-E rig, then the well was suspended. While the Nabors #27-E was moved to the "M" pad and the Roll'n IV completion rig was moved in for testing and completing. A DST assembly will be run for testing the bottom 25' of the Lower Kuparuk, then the top 30' of the Lower Kuparuk will be tested after completing the well and releasing the rig. Well Data: Total Depth: 9209' MD (6796' TVD~H Production Casing: 7" 26 lb/ft L-80 8-- and Buttress PBTD: 9112' MD External Casing Packer: 9020' MD Completion Fluid: 10.3 ppg NaC1-NaBr Brine (10°F C.P.) Note: Chevron will be sending a Production Engineer to witness the DST's and coordinate the samples. Notify Ron Thomas at 786-6600. Procedure: 1. RU the Roll'n IV completion rig. Mix up 250± bbl. of 10.2 ppg NaC1-NaBr (sodium chloride-sodium bromide) brine with a 10°F crystallization point. Note: Notify the State prior to the BOP test. 2. Rig up electric line and run a gauge ring and junk basket to PBTD. Run a Gyro survey to PBTD. 3. PU and RIH with 5" 12 SPF casing gun, CCL and GR. Perforate the lower lobe of the Lower Kuparuk from 9050' to 9025' (based on DIL/GR 1-28-84). 4. RIH with a 7" EZSV packer on wireline and set at 9020' (WLM). 5. RU and RIH with the following DST assembly (refer to attached schematic): a. 1.25" I.D. EZSV stinger b. Hydraulic Bypass Valve c. 3½" IF "APR" Valve (2.25" I.D.) d. 3½" IF "APR" Circulating Valve e. 3~" IF Pump out Su~(2.25" I.D.) f. 3~" IF Pin x 3~" 8r~ Box ~ossover g. 30'+ 3~" 9.3 lb/ft L-80 8r~ Tubing h. 3~" 8r~ "XN" Nipple (2.75" N~Q-Go) w/Locking Mandrel in Place i. 8975'+ 3~" 9.3 lb/ft L-80 8ra Tubing . While RIH, fill the bottom 1000' of tubing with diesel. Finish RIH with the proposed DST assembly and locate in the EZSV at 9020'. Slack-off 15,000 lbs. on the packer. Put a TIW valve on the top joint. 0 Close the pipe rams and tie-in to the test separator with a data header on the rig floor. . Pressure-up on the back-side to 500 psi to ensure that the stinger is located in the packer (use a bubble tube to ensure that the APR valve is still closed). e Open all lines to the heater and bypass to the holding tank. Pressure-up on the annulus to 1500 psi to open the APR valve (maintain this pressure through the test). 10. Allow the well to flow until cleaned-up (flow approximately 50 bbl. of formation fluid plus the cushion). 11. RU Otis wireline and RIH with HP gauge and downhole shut-in tool (0.7854 in.m flow area). Locate in the locking mandrel at 8975'. Set-up for test. 12. Test the formation as follows: A) ~) Initial Flow Period I. 20-minute Initial Flow Period II. 60-minute Initial Shut-in (Three times initial flow) Final Flow Period I. 12-hour Final Flow Period II. 24-hour Final Shut-in (Twice the final flow) NOTE: Near the end of the final flow period obtain the following samples: a) b) c) (Two) 1000 cc oil samples (One) quart produced water (Two) 5 gallon samples of separator gas * Be certain to purge the cans befor~ catching gas samples. 13. Release the annular pressure to close the APR valve. POOH with the HP gauge. 14. Rig-up Schlumberger. RIH with a fluid sampler and an HP gauge to the locking mandrel at 8975'+-' !i{i~iii~iii~ii~!'~:~i~ij -2- 15. With the well shut-in at the separator choke, open the APR valve. Open the surface choke slowly, maintaining a downhole pressure at the sampling tool of at least 2350 psi. Flow the well to bring in formation fluid above the bubble point. 16. Shut the well in at the surface and obtain (two) bottom hole samples. POOH and RD Schlumberger. 17. Pressure-up on the annulus to open the APR circulating valve. Reverse circulate to clean-up the tubing. POOH with the DST assembly. NOTE: Consult with Anchorage office on whether to squeeze-off the formation. 18. If it is proposed to squeeze off the formation, RIH with the EZSV stinger and a plug catcher on 3½" tubing. Locate in the EZSV and establish injection pressure. RU to cement. 19. Pump 100 sacks of Class "G" cement with friction reducer and retarder (for three hours pump time). Pump five barrels of fresh water ahead and behind the cement and use a top wiper plug. Bump the plug, then POOH. Test No. 2: 20. RU electric line unit. RIH with 30' of 5" 12 SPF casing gun, CCL and GR. Perforate the Lower Kuparuk from 9015' to 8985' (based on DIL/GR 1-28-84). 21. RU and RIH with the following assembly (refer to attached schematic): a) Hydraulic shear-sub b) 30'+ 3~", 9.3 lb/ft, L-80 8rd tubing c) 3~" "XN" Nipple (2.75" No-Go~ - 8ra pin x pin d) 30'+ 3~", 9.3 lb/ft.~L-80 8~u tubing ,, ra ~ ,, ra e) 3½ 8 pin x 4M 8 box crossover f) Baker "SAB" Hydraulic set permanent packer w/4~" mill-out ra extension (8 pin down) g) PBR Seal Assembly (made-up on_ghe "SAB" packer) w/8rd box on top h) 7000'+ 3!~", 9.3 lb/ft, L-80 8r~ t_u~ing i) 3~" CAMCO "TRDP" Safety Valve_~ 8£~ pin x pin j) 1850'_+ 3½", 9.3 lb/ft, L-80 8~u tubing 24. Finish RIH with the 3~" tubing, strapping the ¼" control line above and below each coupling. Space-out to locate the packer at 8850'±. 8rd 25. Install the tubing hanger (buttress box down x box up) and connect the control line. Rig-up to reverse circulate. Pressure-up on the control line to 4500 psi, then with the accumulator pressure reduced to a minimum, close the Hydril. 26. Reverse circulate to spot 750' (20 barrels) of diesel in the annulus. Close the safety valve, then open the Hydril and land the -3- 27. Drop the setting ball and set the packer, then shear-out the ball. Test the backside to 1500 psi. Back-out the landing joint and set a BPV. 28. Install and test the production tree. Pull the BPV. RU to swab. 29. Swab the tubing until the well is flowing. Cleaned-up, release the rig crews. Once the well is 30. RU a slick-line unit, then shut-in the well at the wing valve. RIH and set a locking mandrel in the "XN" nipple at 8900'~. POOH and RD. 31. RU Otis electric line unit and RIH w/an HP gauge and downhole shut-in tool. Locate in the locking mandrel and set-up to test. 32. Test the formation and obtain fluid/gas samples as per Step No. 12. 33. Release the HP tool and POOH. 34. RU Schlumberger, then with the well shut-in at the wing valve, RIH with the sampler and HP gauge to 10'± above the locking mandrel. Flow the well while maintaining a downhole pressure at the sampler of at ].east 2350 psi. Flow 10 to 20 barrels, then SI and catch two fluid samples. RD Schlumberger. 35. Bullhead 20± bbls. of diesel down the tubing, then rig-up a slick line unit and set a "PX" plug in the locking mandrel at 8900'±. 36. POOH, then bleed-off any surface pressure. Close the safety valve and install a BPV. Close all valves on the tree. Submit a final well report. D. R. Girdler Production Engineer kr -4- : I , , ,. !':::- ::.:;::: :' .:' :. ::: : . '. ::,-._,.: .~: ..: DST No.. ;1.:: :::_ :.:. _~:: ::--::~:~ [~..:~:~:~ :': .:~":: --;. ' ; .... ~ ~ ,.. i---:-.-~-- ~--~ -~-.-~ ; --t---t--.: '-77~:-I'~:'7"~':' ............. : ..... ::.: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::.;:::~ :~ ::. ::..', '; ~Zj. r.[:" ::::::::::::::::::::::::::::::::::::_:-::~::.::_1::-::::::~?:::t::-::::. :::~::"~:":~:~: ~ '' ~ .... ~ ..................~~[.i .... i.~ ~ .......................... i ........ i ..... :- ':' :'" :: :- : '1'~-:': ::::T~~ft:, L-80, 8 ......... ~ ....... ::- '::: : ~: : ':. '. '/:':~ .': .... Packe~ F]u~d:-lO.g'p~g NaC] ~'NaBrBr~ne::i:::~': ;-:: .............. ' : .... · ' , ., ~ ~ '': i .... ; , ' - - , .,: ....... Minimum Res~r]ct]on--~Downhole~shut, ln.~ool- 2 25": ...... ~ ..... -.-:'--::~-::'i:' ' - : -:'- :::::::::::::::::::::::::::::::::::::::::::: :-::-'t--:z:: ::::':-: ........ ~ .............. ,:'"~': ........... -"--~ ' --:-- :J: :--::::'-~-'-7--~ ..... ~ .......... t--':-] .... ~'-'T-t-~-: ..... L' ....... ~~'''2 .... '::-:~':::' :;:: :1.". ..... :'-'!:- -~"-- :'::::T:-:-:~-:~::-:-~-.-:'~:;--================================================ ' ' ~-- -- ',"- ; ...... I I .... ..-.~ .... ::.~. : ~- . .' ' 'i_' ::':~:_::-L~:~.::_.:~---::-_~z-~::::_'~:~z-~::-:~: ::::: :.::.: ::-:-i ' ::: ::.: '- ~'- -~ .... / ~- ~ :" ' ~ .... i .... ~ '--1 ........ ~ ..... i ....... i ...... ~ ......... t'-' ~"' ; ...... ; ...... ~~~ ............. ~--'~ -- ~ ' ' ' ~ i ~ ~ ~~~--' · ' t , I ' , r , i ......... ...... ~. ~ ..~ ~. '' ~-': .... _ ': : __:-t"-~_:~:~::-.:-.:~''::;': I' "~ ':' :-' :': :'::'1 ,'..-' i .... ' · -~ .--' .. ''---~ ...... - ;'--.: .... ~''" ~':---~' --i ...... ~ ...... 4 '~ i~-~ ' ' [ ; .... I ' ' ~ ~ .... ' ' I'1I II II ..... ~ II - · - i ....... ~ -. :: .~. ~-.:~:_ 8970 ': :i~.~.xm~i:'- :-.otis ~_- .... X~ ~pp]e~(2..:75i ~O-GO):.;.:.:i.:::;:- .t:.-:.~ . ~ . ~. ~ :, :--~: 3~~~__ .,. ' .;' ::.~' .:.:~-::::~ .... :_:i' : '[':" :.i i'~:'[~:' :~_]:~: ~-~::i~]~-::-~~ -..:'~_:' :'::-:;': ' IR.VJ ~3~ I~Pu~p~ Reve~sing.~ve-:.i :.:- '~'..-- ~-~ -i 'm ..... ~~-- - ' '. ' ' - ........ ~ ..... ~ '. ' - , ' , · -I~~- ~- , : , , ~ ~ ' ' ~ '~ ' ~ " ~ ...... ~ ..... ~ ...... ~ .......... ;'- - t ........ .......................... I-IF ............... ' - ' .................. ~:..:: . , -.: :.:~. ~'~-:--:.--~ ~--IF Hydraul_~c Bypass. Valve:-:-: :. I:: ~::,; ' :. ~ I ..... : ~-':~c~/ c~',~'~' ~b~::~J':.:~::::~:::_i::.::: :. '_.~': ::j: _~ ::: ':': ::.:~: ',-.I.:': .' =='. i::'--t :::-~'::-:~- Pr6poSed Perfo~ati6~:-~9025~ 9050:" (WLM) . .. [ .... ~ ..... ~-.- ~. - ..~ ........ i .... ~ ................. ~ : ~ ~ ; ~ , ,[ ..... , , , . ~ , ~ , , ~ , ' :: ::: ' .~':: I'. ;' :-: :-:: .... -::'- :'-::-':'~:-::-[--:-::--' ~:-'-::::::::::::::::::::::::::::::::::::::::::::::: :--:. :::. ::::?:::-:~:-:: ...................... 7..Cas~n .. PBTD at.9t12 ~ MDt--::~-:-..:!:-":.~i~-:~:~:: ~ ..~ .. ! . ~".:~--:,. ::: ! .... :: ::,':::-~-.::~:::--~-:::-:; :::::::::::::::::::::::::::::::::::::::::::::::::::: '' '. '-, .'' ~ .... ~---.'."~'-.t' '-. ........ ~:.'.-. - ..... :- ...... ~-'::.! .... ~'-:-, ;::'- :'1.::' ~-":! .... .) - ..~. ,. . . , , .'~:]~T~-~,'t~ ~: ~:" '-~ ~ ~. ~{-:~: ::7'co~pletio'n:-s'tri~ng:~3~,.,~:9:~-'1~/f~;'~:80:,'~ - ............... - . . : ......... , .... : .... }_.'._~'.'. ..... ~_..q..,: ..... t .................... ::.::-:' ,::::;:::' :::~::. '" :t :=1:" :::-.Packer.fluid':. (;Sur. face go..7~)~dlesel[.-.~ .... ....... r ..... ~- ' :' .,~-~ '- ...... ~ * .... ~ .... t ~ ~ .... t ........ ~' '~ ............. .......... I ' , ~,'- ........ ~ '' ' _ '~ .... t ' , , :::::::::::::::::::::::::: ::~'::::~: :.:-.::;:/:-lx:lzi:..: ............ ~-*~ ..... ~ ...... ~ ..... ~ .... =----b--=~ .... ~ ..... ~ .............. t ........... ~ ....... [ .... .................. .' .. - '-'. :t" ,. , ~_ ~ . ' ' ~ ' ~ '~ ' . . _: __ -: ................................... ~" * ~ ~ 7'~ .................. ~ ...... 1 ~ ~ ~ T ~ , -I ................ ] ............................... 1 ..... , } ............ , - · ,.. ..... ' .................... I ..... : ' · -- F -- 1 ..................... ~ ..................... 1 ...... '" :~ ~. .~ ' :~'..'. -- ~- . .... ' ; -.:,, ,, ." .~ ...... ~,,, nd ' I' * ' ' ' :n ion ..... ::.:-:.: - ~ ~ ..... ,.. ~- -..Baker:-SAB Packe~ w/4~_ 8~-Mlll~-out exte s I ..... :" ' ~ ' I '' ' t , ~ . j ~--_ ~ ....... ~ ........ j- - : . ~ t , ~ .......... - , . ~ .. ~ ·~ - ~ -- . ~ .... ~ ' ": ] ...... I '~ ..... _ _ .:~ ...... :~ ~ ...... :.] ...... ~__~__:~ .... ~0_I_~ _3~'_'i 8rd _T~b_ing::?~/:' ~ '__~__ :': :' ~ '_: ~_;___ ~_~ ..... ~ ~'--7 ' ' I ; I:~ ......... ~ ' ~' '~- ' : ' ' 'l' . ; :' ' -.:. . : ..... ·// ' O~s "XN" N~pp~e (2.75" NO.~O) * 8r~ P~n x P~n~: - '- -~ -* ' ~ ! I .... ~ ...... : .; ..... ' .... } , - ~ ~ : ~ .r ' - ._ ~ I ~._ ~ X ~__~!-~_74 ~ ~~ , . :~ -- ~ · --~ : . I ~ '. : :~ ,' ...-~-.-c-h~-~-~b'.'i .... .1 ~ t ~ i ..... · , . ~ : .- ~ ~ ~ ~ '~ '-~ ..... -1 ......... ~-'' ~ ''-! ...... ' ''' ..... ............................... , , , 1 I .... , ~ '' ~. . . · : .. ~--. ~ .... ~ ..... ~ ~ ...... .--, ~ -~....., ':- · : ...... , ~ ~. ~ -- · ' ~' t .... : : t I ' ........ ~ .... t ::' -., :: ......... Lo~r ~par~k (~)~:_.8~85:_:::-:~90~5 .... (20.) : : ....... q .... ~ ......... ~ ~ . ~ ~ ~. . ~ ....... ~ .... ~ .... ; ; ...; ..... ' :~ t' ~' 9020" ~'--".EZSV S~ueeze Pack~r:-::!:-:.:-:~-':--:r::::~ .: :::::::::::::::::::::::: ':"' :: '~:'~ ~- ..... ~ ...... Lower-~Kuparuk (.2) ...... 9Q2:5--:.-:9050.:: (25::):i.:::-:::: ' ' ; ' ' , '. ...... ' ' I . ' ~ ~~- _ I . , ', . .~. ~ ~ ;, , ..................... ;--- . ._~ ..... ~ ........ ~ ................ ,~ ............ I?~W; rine i MILNE POINT U '-"--"~ ~ PROPOSED PERF ..... FEBRUARY 7 1 · ~... , , ,, ,, I i- NIT WE' 1984 8985 15' 9025' 9050' ~,00 :i ' , N-lB TEST NO. 2 TEST No. I January 19, !98fi Mr. Don Girdler Production Engineer Conoco Inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503 Mllne Point Unit ~Io. ~-IB Conoco !nc. Permit No. 84-~3 Sur. Loc. 2660'FSL, 'FEL, Sec. 932'F~,~ Sec 31' T!3M, R10E, Btmhole Loc. 1460 'F~rL, , , Dear ~{r. Girdler: Enclosed i~ the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chid from each foot of recovered core is required. Samples of well cuttings and a log are not required. A continuous direct~ona! surx, ey is required as per 20 AAC Pi.050(b)(5). If available, a tape containing the digitized log information shall be submitted on. all logs for copying except experimental logs, velocity and d~pmeter surveys. Many rivers ~n Alaska and their drainage systems have been classified as important for the spa~fng or mlgrat~on of anadromous fish. Operations in these areas are ~ubJect to AS 1.6.05.870 and the regulations promulgated thereunder (Title 5/ Alaska Adm~nfstrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Off~ee, Department of Fish and Came. Pollution of mny w~ters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Titla 18, Alaska Administrative Code, Chapter 70) and by th~ Federal Water Pollution Control Act, as ammnded. ~Prior commencing operations you mmy be contacted by a representative of the Department of Env.~ronmental Conservation. To aid ns in schedu!~ng f.te!d work, please notify this hours prior to comme~,.c~ng in~tallation of the blowout prevention Don Girdler !ne PointF~ ~n.t January !9, 1984 'present to ~-~.t~ess te~t~.n.g of the equ~,pment before the ~urf~e~ ca~in~ shoe ~n drilled %~re a d~v~rter svste~ is re~u~red, c~:fice 74 hours prior to co~eucin~ pl.e~se ~].~o not~V this = equ!pme~t instat!~tion so that the Co~ission may ~¢itne~ test~ng before dr!Il inK below th~ shoe of the conductor pipe. In the event of suspansion or abandonment, p!ea~e give th~s o.~ .... ~ce adc~uate ~dv~nce notification so th.stw,~.~, m~.v have a witness presort. Vmrv truly yours, , C. V. Chatterton Alaska Oil and Cas Consolation Co~J~ssion sure Department of Fish & Gsme, Habitat Section w/o encl. Department of Environmental Con~er~at~on STATE OF ALASKA ALASKA tr.;"L AND GAS CONSERVATION CO;.~,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Conoco ]]nc. 3. Address 2525 C Street, Suite 100, Anchorage, Alaska 99503 . 4. Location of well at surface 2660' FSL, 1425' FEL, Secti0n 30, T13N, R10E, U.M. At top of proposed producing interval 1080' FNL, 1200' FWL, Section 31, T13N, R10E, U.M. At total depth ~j ~ 1460' F~Ltt 932' FWL, Section 31, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. 54.5' KB ADL 25517 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15-54 -~31 ~is~ance and di~e~io-n-f~)-m ne~]r-e~-t~)¥~-- 14. Distance to nearest property or lease line Northwest 35 miles 7000 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 9588' MD (7050' TVD) feet 2555 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 2550edt. MAXIMUM HOLE ANGLE 57 oI (see 20 AAC 25.035 (c) (2) 21 Proposed Casing, Liner and Cementing Program _Si2E ' CASING AND LINER [ Hole .... Casing-' 'Weight Grade Coupling ~-4"t'13 3/_8_ L__72# K-55 ~C~TRS ~~9 5_/_8_'___47# L-80 I BTRS ~~__8~:_~1 7I" _ 29# L-80 ] BTRSJ____ 22. Describe proposed program' Length 8O 2496' 8634' 9. Unit or lease name Milne Point Unit 10. Well number N-lB 11. Field and pool Kuparuk River Amount $200,000.00 15. Distance to nearest drilling or completed welt 8000 feet 18. Approximate spud date January 20, 1984 750 psig@____ Surface _~3Z].,50 psig@ 7tiROl ft. TD (TVD) SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD MD BOTTOM TVD 2496' i 2496' 9588' I 7050' (include stage data) in place in place 1400± sacks (3 stages The Milne Point Unit N-lB well is the second proposed redrill of the MPU N-1 well that was drilled to a T.D. of 7650' MD (7244' TVD). The first redrill (N-lA) was drilled to the southeast of the original BHL. N-lB is proposed to be drilled to the southwest of the original BHL. The N-lA well is to be plugged-back to 2300'. See supplemental data sheet proposed directional plat and BOP sketches. ---~-.Tin'¥~l~-~ 'c~rti¥; ~t~t' th~'~0regc~ing ik {~de and correct to the best of my knowledge The space ~eiow for Commission use Alaska Oil & Gas Cons, Commls: DATE January 18, 1 CONDITIONS OF APPROVAL .. Samples required ......... ! Mud log required Directional Survey required [~YES []NO APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE January 19, 1984 by order of the Commission Submit in triplicate ~84 SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al - Milne Point No. N-lB Conoco Inc. 2525 "C" Street, Suite 100 Anchorage, Alaska 99503 I. CEMENTING PROGRAM A, The 13 3/8" conductor was set at 80' below the surface 115' K. B., then cemented to the surface with high yield permafrost cement. B. The 9 5/8" surface casing was cemented with 1000~ sacks of high yield cement followed by 750 sacks of standard permafrost cement. This cement volume provided 68 bb]s. excess; calculated AHS is 17". C. The 7" production casing will be cemented in three stages. The first two stages will consist of 700± sacks of high yield followed by 700~ sacks of class "G" cement pumped around the casing shoe (estimated 4500~' of annular cement, assuming an AHS=ll"). The secondary cement job will consist of 100± sacks of permafrost type "C" cement followed by 50± barrels of Arctic Pack, pumped down the 7" x 9 5/8" annulus. II. ANTICIPATED GEOLOGY 2500' - 4000' Predominantly clay and siltstone with numerous sand sequences. 4000' - TD Predominately shale until the Kuparuk sands - expected at 6700~ TVD. III. FORMATION EVALUATION A. Standard mud logging equipment with a IDEL Plot. B. Sidewall cores to be taken as determined by onsight geologist. C. Wireline logs for the 8~" hole from T.D. to the 9 5/8" shoe will include: Dual induction laterolog; borehole compensated sonic-gamma ray; formation compensated density with CNL and GR-caliper, Dipmetero IV. DRILLING FLUID Low solids non-dispersed mud system Low solids lightly dispersed mud system 2450' - 6500' 6500' - TD V. DIRECTIONAL PROGRAM The N-1 well had a KOP of 3837' and built angle in a predominantly S3.5°E direction with a maximum angle of 35.9° at 5600' (MD). The N-lA well kicked-off at 2550' (MD) and angle was built a predominantly S14.5°E direction to a maximum angle of 50°. The proposed N-lB well is to be kicked-off at 2550' then drilled in a S35°W direction with a maximum hole angle of 57°. A Teleco tool is to be run while drilling below the KOP for directional control. i ' ' i ~ ' '' ~ i ' ' I ~ i : ~ : , .......... . . , ............. ; --+ ......... , ._ _ : -, -AVER ...... TAROET - J II 1=9034--DEP, _ ! , ! : -'HILNE PT?UN ' j .... 5000 ..... . . ...... ; ..... , ~.- ~ ~__,6000.__ - i - i.... "~ ...... i'!.' ..... ::. :_: .: :_-._ _-..-:-:_.:-:--::::-: ::::::::::::::::::::::::::::::: .... ~ ........ i .... i- :":< ?~.: i..,__:?~ ~':~i"".~,::~:? -'~ ..... ', .... i ! ,-f ........... ~ ~ ' ...... 1 ............ " ......... ) ............. ..... ' .......... i .......... i ..... : ........ ; .... , - ' -~. ,.~,~:i-~ ...... i -' : · · I ........ ; ..... -' ......... , ........... ~ ......... : '. ~-' '~ -'~' - - .......... ..... , -- .~ ., ..... ~ . _, .........,, , , - - ~ ...... ~ .... . ................ ~ .... I ~ · J ................................... ~ ....... ~ ~ -~ -- ~ ................. ... , .... ~. --_~-.-:__~_------:- ._ ...: ....... ~ .... ~ ............ , -. ~ ........ ~ ............ ; _ . .~ .............. _500 .... _ ~. - .i -,: 1 1 ..... ' t : ........... '-? ~ { NORTH SLOPE.- .ALASKA · , ~ .... ~ 'EASTMAN -WHIPSTOCK.--~INC~ .:.' i:.-:-i I ':500 .... ~ FRO~ MUD PUMP KILL MANIFOLD · FROld REMOTE HISH.__. ~ ~ ~ REMOTE PRESSURE: GAGE PRESSURE PUMP '----LLi ~ NOTE: ' ' ~ HYDRAULI~ CONTROLLED L H~RAULIC CONTEL SYSTEW fOR e~ ~ACE & CHO~ ~ REMOTE OPERATED UANtFOLO TO INCLUDE (5)STAT~ CONIR~ MANIF~ L~TEO REMOTELY ~lTN 3~0 PS! ACCU~ATOR 8 %/ · ~ 6~. RESE~R 8 AUZ. ENERGY SOURCE, (Si S~ ~ROL aANIF~ PLUS ~R~AB~ CHOKE ~NT~L TO BE ~CATED ON RIG FLOOR, ~ DRILLING Z KtL 8 CNO~ MANIFOLDS ~ MEET ~ RP53 ~. ~( )1 5~ s~s. . ~ ..... 3. m~ ~NIF~O S~ZE- RAT~NQ Z'- 5~ ( CHO~E MANIFO~ SIZE- RATIN6 3'- 5~ ~ ~ ~ SHAKER BL~D LINE TO ATMOSPHERIC TO PiT MUD/GAS SEPARATOR CHOKE a KiLL ~ANIFOLDS FOR ~s/8" a 7" OD CASING BOP STACK BOP MANIFOLD LAYOUT- CONO , INC. -. .... ; ,, , ' , ,; ............ "~ BOP S TACK AIO T~ ' __ ~ .FL OlU' L IAI~ t3 5 8" i' A TST. PR.- ,5500 §000 PS1 : ~.. 135 8" 5000 PSI-' 3//- $000 ,SIDE OUTL £T$ 1358" ~POOL . C O N DUC TOt~ (/.) ~.O. iE'. GTACK ~/Z~ /~'A7'IAI6 h'/EETS AP/ rfp 5...'3 t~ SPEC GA FOg k/1T1-/ CZ.A/#= ~ /-/UB COIVAIE'CT'O/gS AI_L /..4Y"D/~'AUI_/CAL./..Y OPEI~A TED. 7/{'IP / Pte£~SLII~ TESTED TST. PR.=5000 4'4.) I~AId 'TYPE ~ OP TO IIdCLtlDE A MItIII4Utd . ,.gET~ OF' APP~OBt~I,~TE P/BE RAI4,,e. ,.~EP/i~ATEL ~ TO i~qEET tiP/ SPI i~EC~tlIIeEt~IEAITS. -~ CAS/tdG ,.~POOt : I~ 13~'"- 5O00 X I$~~- "-- 5OOO W/Ti-/ ~ ~"- ~000 S/Z~E OUTLET~ / VALVE~. TST. PR.= 5000 :Ii dELLt~ WALL CONOCO~ ~ ~/ - 14iLltH POINT L~OPE FO~ IdE ~ _°% Proposed N-1 Location ¢-,~- EXISTG. GRND. TYPICAL SECTION , ,, i i i (cOho, co) N PAD CONSTRUCTION DETAILS S30, TI3N, RIOE, U. M.~, ALASKA- KUPARUK FIELD OCTOBER 12, 1983 FILE NO: ELEVEN-I OWG. NO: N-83-001 ii lilt [ '.. AL, xa OiJ & Gas Cons, Anchorage.. / Company ~ Î1 flA (\J-Iß Lease & Well No. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee 5Zvt..- /-/--8-( 1. (2) Loc n",- I"~"¡'f 2. ~ 8) - 3. 4. 5. 6. 7. "- 8. ..( J/J¡/ /-/3-$1 . (8) (3) Admin (J~ /-II-ð r (1"t"hru 11) /lv}l /-/$"i'/ (10 and 11) (4) Casg /1;-# /-/%-31 (12 thru 20) (5) BOPE JlJ¡j ¡ -/S...Fri (21 thru 24) ( 6) Add: jf:rf/ I-I 1-71 YES NO REMARKS Is the permit fee attached Is well to be located in a Is well located proper distance from property line.... .-. . . . . . . . . . . . . Is well located proper distance from other wells .................... Is sufficient undedicated.acreage available in this pool............ Is well to be deviated and is well bore plat included ............... Is operator the only affected party................................. Can permit be approved before ten-day wait .......................... 9. 10. 11. Does operator have a bond in force ..................................~--- Is a conservation order needed ...................................... ~ Is administrative approval needed ................................... ~~ 12. 13. 14. 15. 16. 17. 18. 19. 20. Is conductor string provided ........................................ 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 surface casing protect freshwater zones ....................... vall 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 well bore separation proposed ........................... I!J1f --- -Lf)J f L IJ (!. £: J:1J1f J N P J.. A-~ E ~~1= ¡UJf ~--- 7lllf --- H,T)f IN f)'f/'E. 21. 22. 23. 24. Is a di verter system required....................................... ---.- )/Æl:I StJRFIfC.E c.Jt~/JW5 I}J PJ..I}c.E Are necessary diagrams of diverter and BOP equipment attached....... /:lillI --- Does BOPE - have sufficient pressure rating - Test to $./ t'Tt> psig.. 'llilf --- Does the choke manifold comply w IAPI RP-53 (Feb. 78). . . . . . . . . . . . . . . . .. -&111 --- 25. Additional requi~ements .............................................. --- ./iJfI Additional Remarks: ~ .~ fJ,¡.JL r.A/ '- y, ~ I ~ J '- ,;, -tÌ ~- - c... ,~ INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Clf ¡)IQ V O'~ r -"\),'J 8'~ ~ ~)J . <""J' ~ 0 1-3 ::X:Z HO 001-3 ~~ >H n1-3 t:rjt:rj H Z ".--'" t.:<- 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 APPEN. DIX. No special'effort has been made to chronologically organize this category of information. .o CONFIDENTIAL INFORMATIO~ ~Furnished By .Conoco lno, 'RECEIVED JUN ! 8 lg~ Alaska OJt& Gas Cons, commission Anchorage © © 24I ~.~ --~ .~ © © © . ~ ~ '~ . · © 0 © © ? I © © C C © © CD © © © 0 © 0 0 © © © © ~ © © . ~ © © © © © ~r © © © © 213 - 0 0 0 0 ¢~-. ~ -~-, © © ~ ~- ~-~ ~ . . . ~,. . © © © © © © © © © © © © © © © © © © © © © C © ,{ © © © © -© © , © ~., ' . . © © © © © 0 0 © © 0 © © © © © © © © © © CD © © © © © ,! © © CD CD 0 0 © © ~ 77'" 0 0 © © © © 'OUl ~oa'oo ~g pm,p!uJn~ NOI.LVI61'dO-'INI 'IVI.LN'-JOI--INO0 {m~m~mmmm~mmmm{~m{~mm{ Conoco Ino, [!,E N~M~ :EDTT .OD1. Furnished ~y Conoco ino, HNTT 'I'YDE CA?E SI~E ODDE ohO 000 014 065 0~0 000 0~1 065 OhO 000 008 065 000 OhO 004 065 000 000 004 065 000 000 002 065 000 O00 OOP 065 000 000 006 065 000 000 0~4 0~5 POINT FT 0 OHMI~ 7 ~ I t, nil uV 7 ~ 0 0 n ~IT, CAP] 7 3~, ]2 0 n nH~ USIF 60 68 6m 6m 6m 6R 6~ :PT i , ~! [j :VT ~NI, ;D -o9q.7500 5~.0570 !3R.8000 36~4~7 7! .q375 · -~.~OOO 3o.~4~4 ~2~,.~000 ~..7~0 31.~477 n3B.SOnO 50.Z9~8 16.~4~8 800n. O000 -~.~0~0 3~.~6al 74.~Sn0 sF!r,u ?HOR ~R ~ALI '?HOR r~RHO THOR 'Y'HOR ~R THOR 0996 90.6250 DT. ~6.~4~7 0.1372 1. n. D7~4 ln.187~ Ro.~7~O 45.5000 0.021~ qHnn ~.4219 ~R~T ~.7461 t!R~N ?R.dO00 mT. 0.0269 10,.9500 ~P6~? TI, D -o90.2500 go.6875 !.~474 90.7~00 ?.~171 1.n654 1~.~q4 0.49~1 ~'.o5n8 DO~A TI,l~ ~R T DO'PA g~. ~242 ~.,s2~3 go.62~0 606.5000 4 ~TSg · 4.~8~0 81. 2~0 ~OOS.OOAO ~.~4~4 16.2969 45.5000 2774.0000 9.9707 0.9766 7s~oooo 240~,o0000 !.0215 1.66n2 1~.~734 . n. o30~ 14.6172 3~, ~000 ~.6875 1.37.~7~0 ! .9O33 ~.oooo ~.q375 133.~500 1 ]. 0000 O. 14~4 ~ .q6~7 !0S.5000 1~6.5000 ~' 4316 ~ ]: 602 !0~ -08oo .6~75 ~ .67~8 ?.04~q ~ 1 2. 3750 ~.. ~7~4 ~0~.~695 4.4~48 !00.5675 4.07d~ ,3t45 2064,0000 2.9785 ~.4~402 . Y34~ ~,. 9402 s, 3.0762 ! 26,. 0000 1.686.0000 4.2930 2.1875 113.0000 IU3~.O000 4..1484 ].1250 105.5000 1.682.0000 4.3594 4.0508 201.5000 178~.0000 4.1875 34.1707 9~,.4375 ? -63.~0o0 61~.~000 770~.~000 SFT,U 664,.~0oo ~0~000 -Ta.00n0 72~.~0~0 ~,I 10~.~7~0 THn~ -84.n000 3n.?0~1 nR~O ~17.~695 ~HnR 0~.9500 7~on.nono n.~266 4.6004 1R4.~000 o ~50o 7~.6250 1.0.35g4 !¸0 n,.01~7 a. O000 11.4483 n..o2~q 10.796q 17.1280 I03.n7~0 t05.t875 n.0269 I17.~6P5 ~0~.~5~0 1!.o2!g T b~ ~T~ ~HnB ~R A T TLr,/ l~Hng nR~N Tl,n -. 3. O 080 ,61.01 ~ .0277 9~.6~50 ,2852 .0695 3.a4~3 Sg.5695 9.3867 I .6357 9~.~000 3.1465 ?.~070 ~.O07g g6.37~0 TL~ C~L ~R ~tCNL ~.N~ g TLM ~R nN~A PO~'A OR NCNL nN~A 3.. 2043. 0000 8~-TM 2348.0000 72.62~0 ,0000 103'12~0 2~ga.oooo }.~0~? ?10'2.9375 21t0.0000 8~9 104.5000 2~$4 3:871 }.{494 2.014! 2{44,~0~0 ~,4~02 {0},~500 2094.0000 7~T ~'I CDT ~T !TRIN 3.2754 ]. 0176 2074. ,!.0 0 3.076~ 97.3125 . a99,,2 7500: 2039.0000 9.a902 9.9992 8S.~195 209g.0000 3.4~44 3.~246 2076.0000 9.14~4 3.2949 8~.6250 3.6563 3.92a6 7p.oooo 6>on:. oooo 91 .oono 6 ~ o~' oooo .4F..cO~e 37, ~ 094 9~,~7~0 600~:.~000 -50,6875 ~.~7~0 5~oo,nono 3~.~1~8 ~..n0o0 I03.12c0 ~7.I?~0 ~4-~. non() ~On.;~5 ~G~ ?HOR DR~O THOR gFT,U ~FT, Lt CALl THDR cFI,ti DR~O *HnR ~Y,It DRHO THDR g9 ,,, ~ 0 0 0 12'0000 no00 1 ~.. 0000 ,. n. 061 5 1 1. ~4~2 t?.67~7 Oq. 1~.~438 ~.5ono 0.0249 1 1.91~7 ~0~.~250 ~,27K4 O~.P7~O n.030e TLn 3750 .6045 ~ i, 40.6.3 q9,0~25 3.2t6e I.~506 3..3~$ 10~.I~0 2,3945 3.345'1 !.7764 3.4414 ~o9.5000 ?.37~1 1.g%g4 ~.4473 106.75o0 DD?A ~R nR NCNL DO~A Th~ ~R 218~.oono ' 5 ! ~5 9~.5000 21o~.00~o .5808..-~7~5 ~.o2,oooo 2074.0000 ~.44~4 3.6094 ~00.0000 9~0 1.6201 8;.~000 ~n7~.O000 3.7461 9.~q49 3.3008 g?.12~0 202~.0000 ?.3976 94,R7K0 2n3~.OOnO 5900~nono -78.nOnO q~.~O00 7?.0375 S~On~noo0 -71.12~0 Rlm.~ono 7o.1875 ~05.~ono 9~.~2K0 g~ LU ~.8789 0.0301 ?'. 4'766 17.,664l I 0'~. 62.!;0 n.o1.71 7~.~7F0 17.9656 ln.~5?e n.n2or 19.42Q7 ~.~707 '~!RA T _ 3.2363 J O~ · '~ 50,0 1.75~9 9.?049 106.q375 1.91~9 !00.6875 3.4699 ~..~R40 ~.~406 ! ~R TL~ WC~L ~N{~A ?L~ 105 ! m3 ~- 9160 8.0.,. 2o56.oono 3 ~6 090 3,.05~7 7~.W7~0 ].7734 ?.09~6 2.9972 8~.!875 9.0508 7°', 4*ooLoooo ' 30,' ~000 ,: 96.62~;0 · 1 .$0J 6 DOTA :! ,~, ~. 3~64 OO?A 1.07 9~.! 973 :: , 7.7344 g 1 ~. 4 ,,~ 75 1 ~ ~,, 0 O0 0 10!4.0000 4.3008 ~.~4m4 7¢.T500 2150.0000 ~.0906 3.6836 1~7~.0000 4.46m9 1 .qoa3 ~. !.367 101.6875 lV~!.oono C A ~HOR 7&.~875 .~.~6~o a~:. ~0oo 80.~175 THOR 4000' 310n,nOnO 4~.7734 ]~oo nolo 60~.0000 ~I.,I 7~. 0195 ~H~R: .3700 ~ 0000 -6~ .7500 67 .fl195 3~on. nono ~ U 60.~7~0 SG~ -70.9500 30.. 37~g 47o.7500 ~ll I 109 3~on.nono ~VT,II 104.~000 9,,. 94a6 soon 03~;6 I~.445] .6406 74.0375 ';,6016 n.0166 q... 03o1 1 t ~ 4600 70.7500 O. ~500 7n.~95 10.4063 7~. 1 ~KO o.n34~ 7,oooo 7~.~mo g'.~672 o~.o175 I 1. ~203 ~09.58¢5 ! L'B ! 17. 0000 1.9734 14.,I 484 3..~773 9.0039 9.1777 ~.7559 ~ .9707 7.7966 39. 0000 9.195] J .4894 6.9617 9.~6~7 3.4191 mOTA 7~' $000 ,, 7:oooo 0ooo 1..7578 66.!8';'5 270g. O000 7.~500 1~04.0000 1.R5~5 70,7500 2140.0000 1.7090 lOlq.O000 6.{797 6{.m125 177~.0000 4.1914 5.7031 91.9~75 169g.00~0 70.0000 Conoco Inc. 390~n000 -~4.0000 451,~500 rAI,I 6~.~7~0 9000 31°°'75o6 4~.~637 DR~O a81,~0~0 cai,! fi~.~3!3 ~ooo~nooo 47,6563 6K.g750 2n0o.o0n0 ~FLU 45.~496 6~..~2K0 2~On~OO00 -8,.~000 36a.0000 6n.~313 27o~,oooo ~FI,U 4~.,~Bol a4~,~500 ~aLI 61.9~13 to.70~1 4~.46~mR .~.4219 ,0459 .~tOt6 7~-3300 64.~2~0 ~8~0 8~.~0~0 0.7266 n.4531 0.0166 1!.406] &.n2O3 6m.62~0 43.46~R 1~,7109 6n.~313 54.4375 ~,.0566 19.04~9 ~.~701 ~RAT 'q[~RAN 36. o0~0 ~. ].4434 ~' 6 ~ tm'7 I~.7266 -0.144 0.404g 6.660~ 131.~750 135.7500 9.0605 0.~730 ~.4492 ~46.7500 9.0~03 3 9414 124.3750 9.0664 n.O002 ~R NCNb ~NI~A 1DC)'rA ~R ~NPA {L~ ~R ~lC~b DOTA POmA .C~L 30.?031 2960. 0000 . ~ :7:~: ~: 1786,0000 I. 6602 11.6016 59, 81~5 t t~ 7~.. 000'0 4.~602 1.80F6 6 2014. 0000 4; i. ! .4160 8~.~000 I ~5~. 000 4.30~6 9 l~S I .5137 43.4688 157~.0000 a,~i64 ~ ,6172 54.4]~5 1520.0000 4.38?8 1,8066 :PVTCr ~AUE :~DTT ~TGTN :69~8 :YT TBP~,~AuF: { )~TTNIIATY~N t .~soo '09~.91~0 ~;146 TL~ POmA ~-..17~9 11.1719 t60,. 0000 , Furnished By Conoco Inc.
