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175-058
) ) FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AND GAS CONSERVAnONCO~SSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 21, 2005 Duane Vaagen Fairweather E&P Services 715 L Street Anchorage, AK 99501 Dear Mr. Vaagen: sr'l\NÌÌ\~Ff\ S E P ') ""', 7' I1r¡'h ~ ~r-!'ð ~" ,,~ '1 ~"3Mll,·;-) ~~~~: : ,r r-.fl t..~: .... tN L ,) We have reviewed the well files, which contain recommendations for tinallocation clearance for the following wells: Sag Delta Kuparuk River ST 1 (PTD 175-058) (PTD 169-042) We found field inspection reports in both of the above tiles recomn1ending Ünallocation clearance. The reports show the locations to be in c0111pliance 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. ren1ains liable if any problems occur in the future with either of the wells. Final location clearance is hereby approved for the above listed wells. If you have any questions or need further information, please contact Jim Regg 907-793- 1236. Sincerely, ~~Á4r John 1'forman t/ Chairman cc: Jason MoncrietT P.E. BPXA Steve Rossberg BPXA Steve Ñ1ctvlains 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 \ c, (~ Reference: Issuance of Permanent Closure Approval for Inactive Reserve Pits located at Sag Delta 1, Sag Delta 2/2A, and Milne Point N Pad \'15-05<6 ~AÇ,~ --;.-\.ì,1s DearMsSharp: . ."'~ ~~-OO~ The Alaska Department of Environme~~n~e~~ion (ADEC) h~? ~Ìn~à~ rèview 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 from 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, TllN, 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.akus cc: electronic only Harry Bader, ADNR, Fairbanks (Harry_Bader@dnr.state.ak.us) Tom Maunder, AOGCC, Anchorage (Tom_Maunder@admin.state.akus) Bruce Webb, ADNR, O&G Division, Anchorage (Bruce_ Webb@dnr.state.akus) Jack Winters, ADF&G, Fairbanks (Jack_ Winters@fishgame.state.akus) Kaye Laughlin, DGC, Anchorage (k1aughli@jpo.doi.gov) Linda Nuechterlein, ADEC, Anchorage (Linda_Nuechterlein@dec.state.ak.us) Terry Carpenter, COE, Anchorage (Terry.A.Carpenter@poa02.usace.army.mi1) e e Ms. Susan Sharp BP Exploration (Alaska) Inc. Louise Smith, USFWS, Fairbanks (Louise_Smith@fws.gov) Sheldon Adams, NSB, Barrow (She1don.Adams@north-s10pe.org) Rex A. Okakok, Sr. NSB, Barrow (Rex.Okakok@north-s10pe.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, P. I. Supervisor r/ÇfffY'/ P:X \Ofc;.--OJ- ,,,,,,,.."{. ij~?"\¡~~Er! 1".)1\~,,,,,nX~ J ~~ FROM: John Spaulding, Petroleum Inspector SUBJECT: Surface Abandonment's North Slope Multiple Locations AUQust 7 ,2002: 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 clëañ and did not have any standing water located over the area that was presumed to be the casing stub. I recommend this well for suñace location clearance. West Sak 25 (PTD 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 suñace location clearance until further remediation to the site has been done. ~"\- S S- Gwyder Bay South 1 (PTD ~): 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 (PTO 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 (PTD 175-058): The pad area is located on an old island that is washing away and going back to 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 & LOC_ATION __.~.~=A~C RF, PORT Sta.~e cf Alaska ALASKA 0iL & GA~ C-'~TSE~TATION CTMHISSION Ahn~ Da=e well haa~ :r=vi~e lc¢. . co~e. Harker ~oa= c= place: Locaclcn CLearance: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATIO,, COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED: ABANDONED: X SERVICE: 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 175-058 3. Address 8. APl Number P.O. Box 196612, 900 E. Benson Boulevard, Anchorage,, AK 99519-6612 ~l~,~x J~~ 50-029-20176~00 4. Location of well at surface ~~-- _'~'_~7,~ ...... ; 9. Unit or Lease Name 749'EWL, 100O'SNL, Sec4, T11N, R16E, UM, ASPX 733,543',AS~Y5,977,898~. ' ~'~ ! Prudhoe Bay Unit At Top Producing Interval ~I' ~, i ~i,.Z.~, ~Z 1 10. Well Numbsr NA ~ i i~'~J il Sag Delta No. 1 (33-12-16) At Total Depth '~'{. 11. Field and Pool NSL, 652' EWL, Sec 33, T12N, R16E, ua [~ ~ 911' 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designi~ IN{3. Wildcat I 32.2' RKB AMSL '42. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 2/3/1976 4/3/1976 3~29~2002I NA feet MSLI 0 17. Total Depth (MD+TVD)10,216, MD(9906' TVD) 18. Plug Back Depth (MD+TVD)14.7, Below MSL & Cut J 19' Directi°nal SurveY I 20' Depth where SSSV Setyes: No: X NA feet MD I21' Thickness °f Permafr°stNA 22. Type Electdc or Other Logs Run CCL/Tubing Punch (3/2102), GR/CBL/Temp (3/3/02), Plug Set/CCL/Tbg Punch (3/4/02), CCL/Tbg Punch (3/7/02), CCL/Tbg Jet Cut (3/9/02) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Structural Line Pipe 0 90' 24" To Surface 0 ..... 13 318" 72~ N-80 0 2731' 18 1/2" To Surface 0 9 5/5" 47# N-80 2063' 9132' 12 1/4" 5200' - 9132'12063' - 2731' 0 7" 29~ N-80 8613' 10214' 8 1/2" 8613' - 10214' 0 ~4. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE I DEPTH SET (MD) PACKER SET (MD) 4 1/2"I 9192' 9095' None, Well P&A'd. See attached well diagram. Tbg cut at 205' Below Pad Surface Tbg BP set at 7660' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7650' - 9000' 54.5 Bbls Class "G" (Balance P!ug) 6992' - 7640 30.0 Bbls Class "G" (Balance Plug) 1733' - 2265' 43.0 Bbls Arctic Set I (Balance Plug) Surface - 205' 25 Bbls Arctic Set I (Surface Plug) 27. PRODUCTION TEST ,, Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO NA TEST PERIOD --> 0 0 0 NAJ NA Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 0 0 24-HOUR RATE => 0 0 0 NA 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ^ncl~orago · 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. Anchorage 31. LIST OF ATTACHMENTS Wellbore schematic, Summary of Well Plug and Abandonment Operations, Log of tubing and casing punch and packer set, Photo's 32.Signed I hereby certi, thal ~~ct to the best of my knowledge~(~. ~~ Title ~~ Date 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- 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. Form 10-407 Item 28: If no cores taken, indicate "none". BP Exploration (Alaska) Inc. Prudhoe Bay Unit (Sag Delta No. 1) Well and P&A Procedure Information The Sag Delta No. I exploratory well was spudded fi.om a gravel pad on the Saganavirktok River Delta on February 3, 1976, and directionally drilled in a northerly direction to TD at 10,216' MD (9906' TVD) on April 3, 1976. The 13 3/8" surface casing is set at 2731' MD and cemented to surface. A 9 5/8" intermediate casing string is hung as a drilling liner at 2063' and cemented from the shoe at 9132' to approximately 5200' and the liner lap from 2063' - 2731' was squeeze cemented. A 7" liner was mn from 8613' - 10,214' and cemented over the full length. The well was tested through four sets of perforations. Three sets of perforations in the lower part of the wellbore fi.om 10,001' - 10,145', 9691'- 9821', and 9583' - 9627' were isolated by bridge plugs at 9674' and 9570'. Perforations were then shot from 9424' - 9555', the well was completed with 4 ½" tubing rrm to 9192' and a packer set at 9095'. The well was then flow tested prior to suspending the well in 1976. In 1985, the upper set of perforations fi.om 9424' - 9555' were retested. The well was then re- suspended with a blanking plug set in the "X" nipple in the tubing tail and a back pressure valve installed at surface. The well was in this suspended state until permanent Plug and Abandonment procedures were completed in March of 2002. The permanent abandonment work summary attached details: 1) cellar and wellhead preparation work 2) slickline operations used in attempt to gain access to the wellbore below the tubing packer and subsequent slickline fishing attempts, 3) pressure testing of the 4 ½" tubing and the annular area offered between the tubing and the 7" and 9 5/8" liners, and the 13 3/8" surface casing, 4) tubing punch records, 5) displacement of cement plugs above fish inside the 4 ½" tubing and in the 4 ½" X 7" & 4 ½" X 9 5/8" tubing/casing annulus and subsequent AOGCC witnessed pressure test and tag of TOC, 6) the tubing punch and placement of a second balanced plug across the drilling liner lap interval offered by the 4 ½" X 9 5/8" and 4 ½" X 13 3/8" annulus and id of the tubing and tagging operations to verify location of same, 7) tubing cutting operations, fluid displacement, bridge plug setting and surface cement plug placement operations, 8) severing casing strings 19' below base flange. 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 obtained during the P&A procedure and the summary of daily operations activities. Fairweather E&P Services, Inc. Sag Delta No. 1 P&A Summary Page 1 of 10 4/9/2OO2 r~-~ Final Abandoned Condition Pump and place 25 bbls Arcticset I cement plug fi'om bridge plug to sun. ace. Excavate and cut casing strings off 19' below basefiange, weld on ID marker plate over all casing strings. Excavation filled back in and all covered to surface. 24" Hole 20"~90' cemented with 8 cu yds cement NaBr Brine (10 18 112" Hole 13 318" 72# N-80 ~ 2731'wl 4164 ft~ Permafrost II NaBr Brine Tubing Cutat 205' and pulled. Poor Boy bridge plug set at 205' on top of i, tubing stub. TOC tagged at 1733' inside tubing. Cement Plug #3 pumped 43 Bbls Arcticset I cement 5~8" PBR ~ 2063' 9 5/8" Liner Lap Squeezed Tubing Punch ~ 2263' - 2265' Drilling Mud TOC in 12 1/4# X 9 5/8' Annulus ~ 5,200' 12 114" Hole Baker EZDrill Bridge Plug in tubing ~ 7,666 1OC Tagged at 6,992' inside tubing. Cement Plug #2 Pumped 30 Bbls Class "G" Tubing Punch ~ 7638' - 7640' TOC in 4 1/2" X 9 5/8" Annulus ~ 7,650' Cement Plug #1 Pumped 54.5 Bbls Class 7" Liner Hanger 8613' Tubing Punch ~ 9010'-9012' Uner Lap tested · to 3000 psi Packer ~ 9095' 9 5/8" 47# N-80 ~ 9132' Pumped 1525 cuft Class G Otis 3(' Nipple 9164' 4 112" Tubing Tail ~ 9192' MD Sag Delta No. 1 t Prudhoe Bay BP Exploration (Alaska) Inc. Size VVt. Grde Depth Cmt Vol. CONDUCTOR 20" LP 90' 8 cu.yds SURFACE 13 3/8- 72# N-80 2731' 4164 cu.ff. INTERMEDIATE 9 5/8" 47# N-80 9132' 1525 cu.E UNER 7" 29# N-80 8613'-10214' 415cu.ft. PRODUCTION TUBING 4 1/2" 9192' Description OD ID Depth We///s p/ugged and abandoned with the following hardware in the hole. Tubing Packer 7 4 1/2 9095 Otis X-Nipple 4 1/2 a~3~ 9164 EZSV 7 9570 EZSV 7 9674 , ,, IPTD: '175-058 APl: 029-20'176 !Spud Date: Feb. 3, 1976 Date Suspended: April 28, 1976 Date Plugged and Abandoned: March 29, 2002 Elev. (RKB) 32.16 All depths are RKB measured depths. Perfs ~ 9424'~ 9555' Perfs ~ 9583' - (Crude) EZSV ~ 9674' Perfs ~ EZSV ~ 9570' Tubing and Wellbore below Packer filled with Well Fluids ATTACHMENT I 8 112" Hole 7" 29# N-80 ~ 10214' 415 cuff Class G '10 ~ 10216' MD (9906' TVD} DRAWING NOT TO SCALE Sag Delta No. 1 FAIRWEATHER E&P Final P&A / DHV SERVICES INC. 05-April-02 Fairweather E&P Services, Inc. Sag Delta No. 1 P&A Summary Page 2 of 10 4/9/2002 BP Exploration (Alaska) Inc. Sag Delta No. 1 P&A Operations Summary DATE/Time OPERATIONS 20-Feb-02 Mobilize equipment and crew across field from Milne Point N-01B project. Attend post job meetings at MPU base camp to discuss operations on N-01B. Attend pre-job meetings at MCC to discuss operations plan for Sag Delta No. 1 and work on methodology to coordinate P&Aactivities concurrently with gravel work being performed on site. 21-Feb-02 Finish mobilization of equipment to Sag Delta No. 1 well site, spot borrowed GNW forced air heater near well cellar and begin thawing operations while rigging up. Attend site-specific permit training session at MCC. 22-Feb-02 Mobilize rental heater to site, RU boiler and order out potable water for steaming operations. Notify AOGCC of intent to begin well work operations on Sag Delta No. 1. Fire boiler, main breaker switch on gen-set has broken so call and order out replacement. Arrange for delivery of portable well shelter and boom truck. Steam thaw cellar. Have melted the snow in cellar and all valves visible. Appears all valve handles have been removed. 23-Feb-02 Arrange for vac truck and call out well support tech's for valve inspection. Call Cooper Cameron for expertise on non-standard wellhead inspection, well has what appears to be a composite tree, with all 4" valves machined into one casting. No vac truck or others able to make it to site today as Doyon 14 is being moved on road and is blocking access for greater part of day. All hands back to camp early when informed have 60 minutes to get out ahead of rig module or will be stuck behind rig until midnight. 24-Feb-02 Vac truck on location, vac out 35 bbls cellar water and mud. Order out triplex pump, diesel and bleed tank for pressure testing wellhead equipment. All ice and snow removed. Obtain non-hazardous confined space work permit for cellar access. Place dunnage in cellar bottom to cover mud and walk on. Cooper Cameron on site, begin checking wellhead for pressures. All appears to be on vacuum. Mob in and set wellhouse, install warm air heaters. Valve inspection crew on site. Function test all valves, none seized. RU and install Back Pressure Valve extraction tool lubricator, pull back pressure valve. RU and install 2-way valve in hanger to pressure test valve tree. Attempt to pressure test tree assembly, test failed with cut O-ring on 4" Otis connector. Clean and replace O-ting, pressure test wellhead to 3300 psi, hold for 10 minutes with no pressure drop. Bleed off, pull 2-way valve, RD lubricator release valve crew and Cameron. Attempt to pressure test tubing, pump 12 barrels of diesel with test Fairweather E&P Services, Inc. Sag Delta No. 1 P&A Summary Page 3 of 10 4/9/2002 24-Feb Contd... : triplex, still taking fluid, suspend operations and order out Hot Oil and 140 barrels of diesel for following day to fill tubing and annulus and get pressure test. Order out slickline unit for following evening. Move Boiler and heater to site, hook up heater to cellar to begin thawing operations, boiler on standby until following day when vac trucks can show up. 25-Feb-02 Water on site for boiler, send to Sag 2A for boiler operations. Order 0630 - 1730 out 180 Barrel open top slop tank for well work. Hot Oil on site, RU, pressure test lines, begin pumping diesel to fill and test tubing. Displace 69 barrels of diesel to fill tubing. Pressure test to 2500 psi and hold for 15 minutes. Lose 40 psi in 15 minutes, OK. Bleed down pressure and swap lines to begin pumping down annulus. Seek variance in testing procedure through fax to AOGCC Anchorage to pressure test annulus to 1500 versus the planned 2500 psi with reasoning as follows: Have 7" X 9 5/8" liner lap and 9 5/8" X 13 3/8" drilling liner to surface casing lap and well was drilled in 1976 with no Arctic Pack freeze protect. Obtained verbal approval from Tom Maunder (AOGCC Anchorage) to pressure test annulus to 1500 psi with procedure for doing so in following step rates. Pump 18 barrels diesel to fill annulus. When full, pressure up to 500 psi with -2 barrels away, hold 10 minutes with no loss. Pressure up to 1000 psi with-1 barrel, away, hold 10 minutes with no loss. Pressure up to 1500 psi with N 1 barrel away, hold with 20 psi loss. Inspect and observe packing nuts leaking on tubing hanger lock-down stud. Bleed off, observe 2 barrels returned, and tighten nuts. Re-test by pressuring up to 1500 psi with - 2 barrels away. Close in valves and observe pressure for 20 minutes. No loss, call and report findings to Tom Maunder, AOGCC Anchorage. Receive approval to proceed with well work. RD and release Hot Oil. Cellar at Sag Delta 2A full so suspend operations there. Wait on Slickline, informed will not be on site until late evening. Crew returned to camp. Place tentative order for eline and cementers for following day should slickline operations be successful. 1830 - 2400 hrs. Recd. call slop tank had been delivered and needed representative on site to spot. Return to well site and spot tank. Slickline on site at 1945 hrs. Very windy, discuss work rules concerning crane operations in windy conditions. Vac track arrives on location, send to Sag 2A site to evac cellar and release. Decision made to RU slickline and begin well operations. RU and RIH with 3 ½" tubing swage for drift check and 2 ½" LIB to determine type PXN nipple present as records incomplete. 26-Feb-02 RIH with slick line when wind caught upper sheave on lubricator and 0000 - 2100 hrs spun around. Stop operations to reorient sheave with slickline spool. Continue to RIH and hit obstruction at 9042' slm. Tap down hard 2 times and POOH. Observe crescent shaped imprint on LIB, appears Fairweather E&P Services, Inc. Sag Delta No. 1 P&A Summary Page 4 of 10 4/9/2002 26-Feb Contd... to of caught edge of tubing or something. No record of anything in well records found to date. Call BP Anchorage and ask to pull records from off-site storage if available. Remove LIB and polish 3 ½" swage, RIH to tag up on obstruction. Beat down several times and POOH. Observe a 3.17" ring imprinted onto end of swage. Call and cancel eline and cementers until progress is made on obstruction. RIH with 2 ½" LIB and centralizer to investigate ID of blockage. POOH, no confirmation of anything when viewing LIB. RU 3.8" LIB and RIH with slickline again. Order out PDS, with CCL and gamma ray sensor to nm on slickline. Will try to verify if perhaps tubing tally is off and can see if tubing packer is above obstruction. If packer is above, will perforate tubing below packer and continue on with P&A operations as planned. RIH with LIB until it stopped due to some obstruction above 9042' slm. POOH and LD LIB. PU PDS logging tool, time sync tool and RIH. Tag obstruction, start log of time vs. depth to correlate with PDS tool and begin logging out of hole. Log from 9041' - 8200' slm, POOH download tool and print logs. CCL indicates collars to be evenly spaced with no indications of packer in string. This indicates we are still above the packer. PU 3.5" LIB and RIH. Block shows what appears to be 3.25" latch in profile. PU and RIH with latch in tool, apply 1000 psi to tubing latch in beat 10 minutes and shear out. POOH. Bleed off tubing, latch in tool sheared. Order and W/O 4 ½" sucker rod style equalizing prong. RIH with equalizing prong. 27-Feb-02 Contd.. RIH with 4 ½" equalizing prong, pressurize tubing to 1000 psi. Tag at 9042', work tool, pressure drops to 700 psi and then to 50 psi, POOH. PU 4 ½" GR, RIH and latch plug at 9042'. Beat 20 minutes, shear pin, POOH. LD GR and PU 2.125" pump bailer. RIH to 9042', work bailer and POOH. Empty bailer of what appears to be soupy cement? LD bailer and RIH with 4 ½" sucker rod style equalizing prong to 9042, work tool, POOH. No pressure change, just very sticky. LD prong and PU 4 ½" GS RIH to 9041', beat up 7 minutes, shear GR, POOH. RIH with 4 ½" GS w/FIT skirt to 9041', latch and beat up 1 hr with oil jars set to release at 1300#, shear off, POOH. Lay down tools and switch to .125" wire, PU and RIH with 4 ½" GS to 9030', latch and start beating up w/oil jars set at 1800#. Beat 1 hr, shear off, POOH. PU and RIH w/4 ½" GS to 9030'beat up 1 hr, tap down 10 min and shear, POOH. Slip line, re-pin same tool, RIH, latch and beat 1 hr. shear off, POOH. PU and RIH w/3.6" swage w/2' 1 3A" stem w/2.6" LIB to 9030. Tap down, POOH. No markings on LIB, LD assembly and PU 2.125" pump bailer while waiting on hydrostatic bailer. Work bailer, POOH and observe what looks like gray cement material. 28-Feb-02 Contd.. PU and RIH with 5' X 2 5/8" hydrostatic bailer to 9027' SLM. Pressure up tubing to 300 psi. Hit down one time and bailer stuck. Work tools, order out Kinley cutter, standby. Kinley Cutter Fairweather E&P Services, Inc. Sag Delta No. 1 P&A Summary Page 5 of 10 4/9/2002 28-Feb Contd... on location, RU, close BOP's and bleed down lubricator. Install battery in Kinley, open rams and drop cutter away. Cut line above downhole tools and POOH. OOH with wire, RD lubricator and boom truck in anticipation of rigging up braided line and heavier lubricator. Mob in and RU crane and large lubricator and braided line. Pressure test to 300 psi for 5 minutes, then to 1000 psi for 10 minutes, no leaks. RIH w/2 ½" RS and latch top of fish ~ 9012'. Beat up 2 times with oil jars firing at 2000#, shear off, POOH. Observe swab valve leaking on wellhead. Order out valve crew to service valves. Wait on valve crew. Have corresponded with AOGCC on tentative plan forward should slickline options fail to produce results. Will punch tubing above fish and lay in 500' balanced cement plug above fish in tubing and in tubing/casing annulus. Faxed request to Tom Maunder, Anchorage AOGCC office and received verbal OK to proceed with alternate cement plug placement scenario if all options for re-entry with slickline are used up. 01-Mar-02 Contd.. Service valves, bleed down well. PU and RIH w/2 ½" JDC inside of 3.6" bell guide and latch fish ~ 9012' BL, Beat up 2 hours with oil jars firing at 3500#, shear off, POOH. Re-pin and RIH with same, latch fish at 9012', beat 1 hour, tool releases. POOH and inspect. Skirt and 1 dog broken on JDC. LD and PU 3.62" overshot w/1 7/8" grapple and super G fishing neck. RIH, latch onto fish and beat up 45 minutes, oil jars not working, no movement, tap down 45 minutes to shear, POOH. Inspect, put oil in jars, RIH with 4 ½" GS to 9012', latch and beat up with jars firing at 3800# for 1 hr. Shear off and POOH. Inspect tools and re-pin, RIH w/same assembly, latch up and prematurely shear, POOH. Inspect, re-pin, RIH and latch on, beat up with oil jars firing at 3800# for 1 hr. Blow main reel drive chain on slickline truck. Shut down and repair same. Continue beating on fish 40 minutes until shear off, POOH. Inspect assembly, now have 2 fish in hole, bailer and overshot. Top of fish at 9012' MD, slm. Decide to cut losses, release Slickline and continue on with new plan forward submitted on day previous to AOGCC. Call vendors and notify of potential for perforating and cementing on following day. All off location for evening.. 02-Mar-02 Notify AOGCC of intent to place cement plug so they can witness tag and Pressure test on following day. Eline on location to punch holes in tubing above fish. Vac tracks with NaBr brine and warm fresh water for cement on site, no dirty vac. RU tubing punch and RIH. Tag top of fish at - 9015' eline depth. View CCL and punch tubing from 9010' - 9011' with 6 (six) .38" holes at 3 spf, POOH and RD eline. Noted 1200 psi surge in pressure at lubricator when tubing ptmch fired, pulled back into lubricator, closed valves and bled down down pressure. RU cementers, attempt to break circulation down tubing with returns up annulus to open top tank. Slowly pressure up to 2500 psi. with no observed fluid movement. Hold pressure and Fairweather E&P Services, Inc. Sag Delta No. 1 P&A Summary Page 6 of 10 4/9/2002 02-Mar Contd... observe, nothing moves. Close in and bleed down line pressure, swap lines to pump down annulus, open 4" 5M swab valve and 3" 5M 4 ½" X 13 3/8" annular valve. Observe flow back to tank from tubing. Break line on annulus and note suction, so well is u-tubing due to tubing filled with diesel and annulus primarily filled with brine. Let flow until approximately 35 bbls have been observed and tubing pressure has dropped to 300 psi. Close in valves and swap lines to pump down tubing again. Begin displacing down tubing and note 1:1 returns up annulus. Pump at 4 bpm with observed pressure at 2500 psi. Observe diesel returns at open top tank followed by heavy chunky drilling mud. Displace with brine until clean returns observed and displacement pressure has dropped to 1300 psi. Batch and begin displacement of cement to place balanced plug over top of packer and fish. Pump and displace 182 bbls brine, 5 bbls fresh water spacer, 54.5 bbls 15.8 ppg Class "G" cement, 5 bbls fresh water spacer and 118 barrels of brine to displace into place. Close valves, clean and drain all lines, release all from location with. 03-Mar-02 Eline, Vac tracks and AOGCC witness Chuck Scheve on location. Wait on cementers to pressure test cement job. Cementers arrive, RU and pressure test tubing to 2522 psi and held for 1 hour with 406 psi pressure drop. The pressure drop was attributed to bleed back of the -20 deg. diesel used for the testing. Tubing pressure test OK'd by Chuck. Swap lines and pressure up to annulus to 1451 psi. Hold pressure for 20 minutes and observed a 178 psi pressure drop. Again pressure drop attributed to -20 deg. diesel bleeding back through block valve into the pumping van. Annulus pressure test OK'd by Chuck. RD cement pump lines and RU eline w/lubricator to RIH with tubing punch to Tag TOC and pull up hole to shoot holes in tubing for 2nd balanced plug up hole. RIH to tag top of fish at 9015'. No cement found. Double check depths. POOH, order out SCMT cement bond logging tool to determine where cement went. Appears volumes were not tracked accurately when displacing and did not keep sufficient backpressure on system to prevent nmaway and cement was overdisplaced. Will wait for CBL for plan forward. CBL confirmed preliminary analysis, found TOC in tubing / casing annulus to be at 7650'. High quality cement bond inferred from 7650 ' - 7800', with good bonding inferred to be present from 8608' - 8725', 8648' - 8658' and from 8930' - 8950'. The remaining intervals in between appear to range between ratty to fair. Release cementers, eline and vac trucks from location while formulating plan forward. 04-Mar-02 Call and coordinate transmittal of'digital data to BPXA Anchorage for generating logs which can be forwarded to Tom Maunder (AOGCC) in Anchorage. Fax copy of findings and plan forward to Tom as well and standby for analysis. Decision made to place another balanced plug directly above the current cement plug in the Fairweather E&P Services, Inc. Sag Delta No. 1 P&A Summary Page 7 of 10 4/9/2002 04-Mar Contd... annulus, with request by AOGCC that we place a retainer just below the new tubing perforations, which are tentatively planned for shooting at -7645', or 5' above the cement in the annulus. This will insure no cement can fall out when placing remedial cement plug. Order out eline with bridge plug for 4 ½" tubing, cementers, and vac trucks. RU eline with lubricator and wireline BOP's. PU 3.75" gauge ring junk basket and RIH to insure no cement sticking to sides of tubing id. RIH to 7700', no obstruction so POOH and lay down gauge ring. PU bridge plug setting tool and bridge plug, RIH and set Baker EZDrill at 7660', POOH. LD setting tool and PU tubing punch, RIH and punch tubing from 7638' - 7640' with 6 (six) .38" holes at 3 spf, POOH and RD. RD eline and release. Cement and vac trucks ordered out for following AM. Order out another fluid storage tank as vac trucks are in tight supply and both injection disposal facilities are backed up. All back to camp for evening. 05-Mar-02 Cementing crew and equipment and vac trucks on location. Discharge 150 bbls of clean 10 ppg NaBr brine into open top tank for circulation and to insure uniform density fluid exists in both the tubing and tubing / casing annulus. Break circulation down tubing taking returns up annulus to slop tank. Observe - 70 bbls diesel returns followed by what appears to be drilling mud followed by brine. Determine need of more clean brine, standby and order out 150 bbls more 10 ppg NaBr brine. Brine arrives, break circulation and pump until clear brine returns observed. Pump 10 bbl fresh water spacer, 30 bbls of 15.8 ppg Class "G" cement, 2.4 bbls fresh spacer and displace with 104 bbls 10 ppg NaBr brine. While displacing cement and brine, backpressure was kept on annulus by choking back on annular returns with plug valve. Observe balanced plug (i.e. no pressure or flow from either tubing or annulus), close in valves, wash down pumps and lines, release all for evening. Manifest out vac tracks and all back to camp. 06-Mar-02 Schlumberger eline scheduled for morning tag and tubing punch has been rerouted to emergency job on coil rig so cancel cementers, AOGCC witness and vac trucks. Crew on Standby until further notice. 07-Mar-02 Standby until 1545 hrs, waiting on eline. Notify AOGCC of same so they might witness tag of cement plug when eline is available. Eline on site, RU and call AOGCC to notify of intent to tag TOC. AOGCC inspector John Crisp on site to witness tag. RIH and tag TOC at 6992' MD (anticipated tag depth at-7200' MD). Pick up and tag again to verify location, depth is same. OK'd by John Crisp. Cement appears to be firm. POOH to inspect tubing perforator bow spring, RIH with tubing punch and perforate tubing from 2263' - 2265' MD w/6 (six) .38" shots at 3 spf. POOH and release eline crew. RU cementers and vac trucks. Pressure test lines and valves and tubing to 2500 psi. All hold steady with no loss. Bleed down, configure Fairweather E&P Services, Inc. Sag Delta No. 1 P&A Summary Page 8 of 10 4/9/2002 07-Mar Contd... valves to break circulation down tubing with returns up tubing / casing annulus. Break circulation and observe rates and pressures are proper, observe clear brine at surface return line. Pump 10 bbl fresh water pre-flush, 43 bbls cement, 1.18 bbls fresh water spacer, and displace with 26.5 bbls of 10 ppg NaBr brine. Close valves, wash down pumps and lines, release all from location. Vac out all remaining wellbore fluids from two onsite slop tanks and manifest all for disposal. Release all from location for evening. 08-Mar-02 Schlumberger eline has been pulled to different job again. Cancel cement and water trucks. Order out crane and Cooper Cameron hand to help dismantle wellhead assembly. RU crane, disassemble wellhead and valves, remove Christmas tree assembly. Loosen tubing hanger lockdown bolts, lock hanger by retightening 4 locking bolts. PU and make up 4 ½" 8 Rd box X 4 ½" A-95 Hydril pin pony sub for lifting tubing when cut. RD crane and release from location. Standby wait on eline. All off location for evening. 09-Mar-02 Eline on site, RU eline with packoff on 4 ½ 8 Rd X 3 ½" Reg XO on pup joint. Called AOGCC and informed no witness needed for tag, and will not need to be on location again until we cut wellhead off, so they can verify cement in wellbore and proper P&A marker installation. RIH and tag TOC at 1733'. Tag twice to verify location, cement appears to be firm. POOH and lay down sinker bar. RU jet cutter to cut tubing, RIH and cut tubing 205' MD. POOH and RD eline, instruct to standby until cut is confirmed. Back out 4 remaining hanger lock down bolts and RU boom truck with elevators to pull tubing. Atternpt to pull tubing, discover the tips of 2 locking bolts are broken off and are causing interference, keeping hanger in place. Wait on and get hot work permit, cut out bolt tips with acetylene torch. Attempt to pull tubing again, successful, release eline from location. Reseat tubing and tubing hanger back in bowl and lock down with 2 bolts. RU compressor lines to tubing / casing annulus and return line from tubing to slop tank. Pressure up on annulus with 120 psi. air and blow down brine in annulus with returns up tubing ID to tank. Inject air until receive air returns. Stop, let well stabilize and inject air again. Remm very small amount of fluid followed by air again, indicating area in wellbore above tubing cut-off point has been evacuated of fluid. Pull tubing with boom track and lay out on ground, cutting into sections with band saw. Cementers and vac trucks on location. PU and attempt to RIH with poor boy bridge plug, notice false bowl in top of speed head causing interference. Cannot remove as still have tips of two broken lock down bolts holding in place. Instructed by site safety we need another hot work permit and need to pack wellbore with fireblankets before any torch work can take place. Standby while waiting on fireblankets and more acetylene. Fireblankets and acetylene on site, RU torch and cut out false bowl and interfering lockdown bolts. Measure out and mark Fairweather E&P Services, Inc. Sag Delta No. 1 P&A Summary Page 9 of 10 4/9/2O02 09-Mar Contd... depth reference on rope to be used for setting poor boy bridge plug in place. Lower bridge plug into wellbore and set directly on top of tubing stub. Verify correct depth by correlating depth reference on rope to top of base flange, OK, Drop rope in on top of plug. RU cementers, batch mix and dump 25 bbls of Arctic Set cement on top of plug with clean cement observed at the top of the bradenhead. Clean pumps and lines and RD cementers and release from location. ~ Manifest out vac truck and all return to camp for night. 10-Mar-02 RD all equipment and clean up work area and demob all from site. Will return at later date to cut off wellhead after dirt contractor has had a chance to remove gravel pad. Demob until later date... 28-Mar-02 Contractor has excavated around wellbore to depth of-9' below MSL. Surveyors have marked MSL depth on conductor and current plan is to cut 6 ½' below MSL. Original plan called for cutting conductor at 18 ½' below baseflange. After reviewing regulations, requested through Winton Aubert (AOGCC Anchorage) and received approval for cut at -5' below mud line. RU guillotine saw and cut at 6.5' below MSL, or 11.4' below the baseflange. AOGCC inspector John Crisp on site. Inspector voiced concerns about depth of cut. Call Tom Maunder (AOGCC Anchorage) and instructed, that due to location of well on flood plain, we would need to proceed as originally planned and cut off casing 18 1/2' below baseflange. Finish first cut and demobilize from site so gravel contractor can excavate deeper around conductor. 29-Mar-02 Back on site in afternoon. Contractor has excavated to depth of- 20'. RU guillotine saw and cut additional 7.6' of casing for f'mal cut length of 19' below baseflange or, a depth of 14.7' below MSL (per survey performed by Bell & Associates). Cut witnessed and inspected by John Crisp of AOGCC. Weld on P&A ID marker plate and release location to Great Northwest so they can backfill excavation and finish site clearance. Fairweather is done on Sag Delta No. 1 site. Fairweather E&P Services, Inc. Sag Delta No. 1 P&A Summary Page 10 of 10 4/9/2002 Sag Delta No. 1 Well P&A Photo's Winter 2002 BPXA P&A Program Fairweather E&P Services, Inc. Sag Delta No. 1 P&A Photo's Page 1 of 6 4/16/2002 Sag Delta N°:1 before p&A Operations Sag Delta No. 1 Wellhead Fairweather E&P Services, Inc. Sag Delta No. 1 P&A photo's Page 2 of 6 4/16/2002 S Fairweather E&P Services, Inc. Sag Delta No. I P&A Photo's Page 3 of 6 4/16/2002 Fa~rweather E&P Services~ Inc~ Sag Delta No~ 1 P&A Photo~s Page 4 of {¢ 4/16/2002 Cut aha Fairweaher E&P Services, Inc. Sag Delta No. 1 P&A Photo~s Page 5 of ¢ 4/16/20©2 Sag Delta No,. 1 b after final cut & ID of cut casing showing cement job. P&A Marker Plate as installed at cm offp°in/15 fl~ge. Fairweather E&P Services~ inc. Sag Delta No. 1 P&A Photo's Page 6 of 6 4/16/2002 E & P SERVIGES, 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) Sag Delta No. 1 (PTD 175-058) 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, Sag Delta No. 1 (33-12-16), 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 Sag Delta No. 1 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 RECEIVED Alaska 0il & Gas Cons. Commissior, Anchorage 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 ° FAX (281) 445-3388 MEMORANDUM TO: Camille O. TaylOr, ~'~ Chair THRU: Tom Maunder, -. P.I. Supervisor State of Alaska Alaska .Oil and Gas Conservation Commission FROM: John Crisp, SUBJECT: PetrOleum Inspector DATE: March 29, 2002 Plug & Abandon Sag Delta #1 PTD 175-058 March 29, 2002: I traveled to BP's Sag Delta #1 to witness casing cut 19' from base plate & 14.7' below Sea Level. All casing strings on Sag Delta #1 were cut 19' from base plate & 14.7' below Sea Level (as per AOGCC reviewed prOcedure). Casing strings were all cemented, to surface. I witnessed the well Marker Plate installed. Three pictures are attached. Summary: I witnessed the final P & A work on BP's Sag Delta #1. Attachment: Dsc 00038. jpg Dsc 00039. jpg Dsc 00040. jpg . NON-CONFIDENTIAL P & A Sag Delta .doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor, (j)'~ DATE: March 27, 2002 Chair Tom Maunder, P. I. Supervisor John Crisp, Petroleum Inspector THRU: FROM: SUBJECT: Plug & Abandon Sag Delta #1 March 27, 2002: I traveled to BP's Sag Delta #1 to witness casing cut 5' below mud line datum. BP Rep. Duane Vaagen contacted North Slope office to request a variance from the original proposal to cut all casing strings on Sag Delta #1 18.5' below base flange on well. I told Duane that I would like to drive out to evaluate his situation. When I arrived on Location Duane stated that he had permission from AOGCC office to cut casing 11' below base flange on well, which would be approximately 6' below sea level. After evaluating much more information than was supplied to our Anchorage Office when BP acquired permission to cut casing strings 11' below base flange, & relaying this added info to P.I. Supervisor Tom Maunder it was decided not to allow BP to cut @ 11'. Duane stated he would dig out to cut @ least 19' below base flange & 14' below sea level. I told Duane Myself or another Inspector would like to see final cut & witness cmt. to surface on all casing strings. Summary: BP was not allowed to cut Sag Delta #1 11' below base flange on well. Inspection will be made of last cut & cement to surface. NON-CONFIDENTIAL P & A Sag Delta 1.doc Tn' Trim M~nnder P F ~NI']CF' Date: 4-Mar-02 Fax #: 276-7542 From: Duane Vaagen Fairweather E&P Services, Inc. Re: Sag Delta No. 1, Plan Forward: Procedure to remedy improperly placed cement plug. Mr. Tom Maunder: On 03-Mar-2002, we punched the tubing on Sag Delta No. 1 from 9010' 9011' (Schlumberger depth)with 6 shots at 3 spf. This is directly above the fish located at 9012' (Slickline Depth). This was, per our earlier procedure change request, submitted and discussed on 28th March. On 02-Mar-02 we displaced our cement plug, pumping -54 bbls of cement, which was of sufficient volume to fill the 4 ½" tubing and the 4 ½" X 7" romulus from 9011: to the top of the 7" liner at 8613' (398 fl. column of cement below the liner) and of sufficient volume to place a 500 fl column of cement above the 7" liner hanger in the 4 ½" X 9 5/8" annulus in the 4 ½"tubing and from 8100' to 8613'. This would o£1eft a 900' plug of cement above the packer. During the cement placemem procedure, it appears that our cement got away from us and u-tubed up the annulus. On 03-Mar-02, Chuck Scheve, the local AOGCC inspector was on site to witness the plug integrity. We pressure tested the tubing to 2522 psi. with the romulus open to monitor for flow. We held pressure for ~ 1 hour and noticed a 406 psi pressure drop. This pressure drop was attributed to bleed back of the -20 deg. Diesel through the block valve back into the pumping van. No flow was observed out the romulus. Tiffs test was witnessed and aPProved by Chuck. We then connected to the tubing annular valve and opened the tubing to monitor for flow. We pressured up the 4 ½" X 13 3/8" atmulus to 1451 psi. We held pressure for~ 20 minut.~s and observed a. 178 psi pressure drop. Again, this pr~ssur~ drop was a.tl. rihuted to bleed back of the -20 deg. diesel through the block valve back into the pumping van. This test was witnessed and approved by Chuck. We then rigged down Schlumberger cementers and rigged up Schlumberger wireline and ran in the hole to tag the top of the cement and verifY the location. We were not able to tag the top of the cement and ended up tagging the top of the fish we were attempting to cement over. At this time it was decided to run a CBL to determine the exact location of and characteristics of the cement in the tubing / casing romulus. TOC was indicated to be located at 7650'. It would appear that the interval from 7650' - 7800' possesses a high quality cemented interval. The intervals from 8608' - 8725', 8648' - 8656', 8930'-- 3/4/2002 11:02/~, FROM: Fax BPXA TO: +1 (907) 276-7542 P~c 002 OF 002 8950' also appem' to offer good bonding. The intervals in between appem' to rm~ge between ratty and fair. Logging operations were finished at 11:30 PM on the 3-Mar-02. PLAN FORWARD The data foe the Bo~ad logs was tea, smitted to Anchorage last nite and is currently being printed up and evaluated by Schlumberger's Sales Engineer, Gary Ehnore. As soon as the printing and analysis process is finished, I will have a copy sent to your office for review. Bill Penrose indicated he could help me out on this and will probably bring the copy by when it is ready. Since we have verified the pressure integrity of the plug in the a~mulus, we v~ottld like to proceed as follows: ~c~>~*--a:,,~. ea,e.o,~~~\~ ,,~a'~%-~ ~r%,ee ~,~\1~[~2>~"~ Cr~ co, ~'~'> 1. We aould like to punch the tubing at ~7645, right above the ammlar cement lop · indicated on the CB[, as being at roughly 7650' and displace in a 400' balanced plug from 7645' to 7245' in both the tubing and tubing / casing annulus. . Prior to per,brining ~his procedure we will roll ~he ~luids in thc hole to inmre our brine density is uniform and to remove the remaining diesel in the anlmlar area. We will also utilize a valve on the return side to insure our plug placement is correct and there is no chance of it u-tubing on us. We f3el that the pressure tests prove there is indeed a sufficient barrier to prevent any possible movement of fluids in the tubing / casing annulus. The Cement Bond log backs up this finding that there is an impermeable barrier in place. We also feel that the placement of a 400 foot plug in the tubing and tubing / casing annulus above 7650' will be sufficient to effectively seal the lower wellbore from the upper pem~anently. Please call me at 943-5027, or 240-1107 at your convenience. Thank You, Duane Vaagen Fairweather E&P Services, Inc. . MEMORANDUM TO: Cammy 0 Taylor cJ.' Commissioner ~ THRU: Tom Maunder *-rrft.# ~ P.I. Supervisor ~ö-ç'\ \ . State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 3, 2002 SUBJECT: Plug & Abandonement Sag Delta #1 (33-12-'16) BPX Exploration 175-058 FROM: Chuck Scheve Petroleum Inspector CONFIDENTIAL Township: 11 N Drilling Rig: N/A Meridian: Umiat Total Depth: 10216 Section: 04 Lease No.: Operator Rep.: Duane Vaagen Range: 16E Rig Elevation: 32.18 Casing/Tubing Data: Conductor: _20" 0.0. Shoe@ 90 Surface: 133/8 0.0. Shoe@ 2731 Intermediate: 95/8 0.0. Shoe@ 9132 Production: N/A 0.0. Shoe@ Liner: 7" 0.0. Shoe@ 10214 Tubing: 41/2 0.0. Tail@ 9192 Casing Removal: Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Type Plu~ Founded on (bottom up) perforation Packer Bottom of Cement 9010 Plugging Data: Top of Cement Depth Verified? 8100 Failed Mud Weight Pressure above plug Test Applied 10.2 2500 Type Plug Open Hole Perforation Annulus Casing Stub Surface I traveled to BPXs Sag Delta#1 exploration location in the PBU to witness integrity tests of the bottom cement plug in this well. This well was drilled and completed in 1976. An obstruction in the tubing prevented squeezing the perforations and a plan was approved to perforate the tubing above the packer (9095) and spot a balanced cement plug. The tubing was perforated at 9010' and a 50bbl balanced cement plug spotted placing the esttop of cement at 8100'. The top of the 7" liner is at 8613'. The tubing was pressure tested to 2500 psi with the annulus open to atmosphere and the casing tested to 1500 psi. Wire line was then run into the hole to tag the top of cement in the tubing. This proved unsuccessful as no cement was found in the tubing. I requested cement location in the casing be verified with logs and a foward plan approved prior to any further plugging operations. " ~ ~ '-\\.- ~ ~ ~~~ ~~\~\~~~ ,~>~~<.-tt.J \ \\~~~<-c:..ð\.\')~'" ~(,).S. C~~~Q\c.x~~ 1 Attachments: ":>C:> \> \~ ~~"> "~~\>\~ tl <YtY1 l:r£ '( ~{,--od- Distribution: orig - Well File c - Operator c - DNRIDOG c - Database c - Rpt File c - Inspector Rev.:5/28/00 by L.R.G. Founded on: Bottom Bridge plug Balanced Retainer Verified? Drillpipe tag Wireline tag C.T. Tag No SCANNED NIl\! 0 5 2001.~ ~ 020305-P&A Plug Sag Delta .xls 3/7/02 2/25/2002 12:13,~ROM: Fax BPXA TO: +l (907) 276-7542 P~';' 001 OF 00l To: Tom Maunder AOGCC Fax #: 276-7542 From: Duane Vaagen Fairweather E&P Services, Inc. Re: Sag Delta No. 1, annular pressure test. Tom: As per our conversation, we are currently at the following point in our procedure on the Sag Delta No. 1 P&A. In step number 7, we have tested the tubing to 2500 psi for 15 minutes. We detected a 40 pSi loss over the 15 minute test period and will call that sufficient for the.proposed well P&A procedure. We are Preparing to pressure test the 4 ½" X 9 5/8" and the 4 1/2" X 13 3/8" annulus (two liner laps here). The approved Procedure indicated testing this to 50% of the lowest rated component, which in this case is the wellhead and the 13 3/8" casing. This would require pre,s,mring up t9 2~00 psi, We woul~l like ~ waiver on thi,s and pr~,s,sure te~ th~ annular area to 1500 psi Only. Our reason for this is concern about the two liner laps and the fact that the surface was never freeze protected with Arctic Pack or equivalent. We do not want to cause a leak. As per our procedure, the only pressures to be applied during the P&A will be during the bullhead squeeze to cover the lower perforation. The plugs in the mmular area will be balanced plugs so pressure will be minimal. Also, we have no way of introducing a tubing dart for the first (lowermost) cementing procedure so will not run one. Will notif? the NS inspectors and test as indicated though in the procedure. Please call me at 943-5027, or 240-1107 if this is acceptable. Duane Vaagen Fairweather E&P Services, Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: . . 12. [ X] Abandon [ ] Alter Casing [ ] Change Approved Program Name of Operator BP Exploration (Alaska) Inc. Address 900 E. Benson Blvd. Ancl~ora~le, AlaSKa f~YbUU Location of well at surface 1000' SNL, 749' EWL, Sec. 4, T11N, R16E, UM At top of productive interval [ ] Suspend [ X ] Plugging [ ] Repair Well [ ] Pull Tubing [ ] Operation Shutdown [ X ] Re- Enter Suspended Well 5. Type of well: [ ] Development [ X ] Exploratory [ ] Stratigraphic [ ] Service ASPX = 733,543', ASPY = 5,977,898' At effective depth At total depth 911' NSL, 652' EWL, Sec. 33, T12N, R16E, UM Present well condition summary Suspended Total depth: measured 10216' feet true vertical 9906' feet Effective depth: measured 9570' feet true vertical 9276' feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 7023' 1601' 20" 13 3/8" 9 5/8" Plugs (measured) Junk (measured) ] Time Extension [ ] Perforate ] Variance [ ] Other Stimulate 6. Datum ElevatiOn (DF or KB) 32.16' AMSL KBE 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number Sag Delta No. 1 (33-12-16) 19._EP, m~it Number 50-029-20_176 11. Field and Pool IWi~dcat 7" EZ Drill Bddge Plug 9570' 7" EZ Ddll Bddge Plug 9674' Plug in Packer Tailpipe Cemented MD TVD 8 Cu. Yds 90' 90' 4164 Cu. Ft. Permafrost Ii 2731' 1525 Cu. Ft. Class G 2019' - 9132' MD(Drilling Liner) 7" 415 Cu. Ft. Class G 8613'- 10214' MD Perforation depth: measured True vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 9424' - 9555', 9583' - 9627', 9691' - 9726', 9781' - 9821', 10001' - 10009', 10021' - 10033' 10040'- 10048', 10054'- 10068', 10086'- 10113', 10117'- 10127', 10129'- 10145' MD 4 1/2" 12.75 lb/ff. N-80 @ 9192' MD Tubing Packer 9095' 13. Attachments [ ] Description of Sumary Proposal 14. Estimated date for commencing operation 8-Feb-02 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Date Approved X] Detailed Operations Program [ ] BOP Sketch 15. Status of well classification as: [ ] Oil [ ] Gas [ X ] Suspended Service i Prepared By Name/Number: Duane Vaagen / 258-3446 17. I hereby cerJify ~at the foregoin~ is true and correct to the b~st of my knowledge Signe~,.~~/~~ Title Commission Use Only Conditions of Approval: Notify Commissi,o~ so representative may witness Plug integrity ~ BOP Test Date IApproval No..~:Zj~_' Mechanical Integrity Test Approved by order of the Commission Form '10-403 Rev. 06/15/88 Original Signed By · , .... b~llllll~ u~~''~''' Location Clearance Subsequent form required 10- Commissioner RECeiveD Date Sub~itI In TriPlicate O !G NA.L JAN 2 5 ZOO?_ Alaska Oil & Gas Cons. Commission BP Exploration (Alaska) Inc. (BPXA) Proposed Permanent Well Abandonment and Location Clearance Sag Delta No. 1 (33-12-16) PTD 175-058 APl# 029-20176 1.0 Background Information and Present Condition The Sag Delta No. 1 (33-12-16) exploratory well/was spudded from a gravel pad on the Saganavirktok River Delta on February 3, 1976, and directionally drilled in a northerly direction to TD at 10,216' MD (9906' TVD) on April 3, 1976. All depths reference original RKB depths. Original RKB elevation is recorded as being 32.16' AMSL. Base flange elevation is indicated to be 8.5' AMSL and original ground level is recorded at 2' AMSL. The 13 3/8" surface casing is set at 2731' MD and cemented to surface. A 9- 5/8" intermediate casing string is hung as a drilling liner at 2063' and cemented from the shoe at 9132' to approximately 5200' and the liner lap from 2063' - 2731' was squeeze cemented. A 7" liner was run from 8613' - 10,214' and cemented over the full length. The well was tested through four sets of perforations, then completed as a suspended oil well with 4-1/2" tubing run to 9192' and a packer set at 9095'. Three sets of perforations in the lower part of the wellbore from 10,001' - 10,145', 9691' - 9821', and 9583' - 9627' were isolated by bridge plugs at 9674' and 9570' before the well was suspended in 1976. In 1985, the upper set of perforations from 9424' - 9555' were retested. The well was then re-suspended with a blanking plug set in the "X" nipple in the tubing tail and a back pressure valve installed at surface. Other than the aforementioned bridge and tubing plugs, there are no other plugs, either cement or mechanical present in the well. During suspension procedures, the a.,6nular space above the packer was reportedly filled with "kill weight" CaCh brine to 100 ft. from the surface. The top 100 ft. of the annulus is filled with diesel Attachment I shows the present condition of the Sag Delta No. 1 (33-12-16) well (as of December 10, 2000). This well has been maintained in suspended status as a potential observation well for the Endicott and Lisbume reservoirs. The well is no longer being evaluated for these purposes, and BPXA plans to permanently abandon the well during the 2001-2002 winter season. The Sag Delta No. 1 (33-12-16) well is located on a large gravel pad constructed on an island at the north end of the Sagavanirktok River Delta. The well is not accessible by gravel road. Access is by helicopter, ice road or rolligon only. The well location includes a large reserve pit and test pit which are enclosed by dikes. The pits do not contain any exposed debris. A detailed characterization of the pits is currently being done by BPXA as part of ongoing planning for f'mal pit closure. A large mound of gravel has been stockpiled on the gravel pad since the well was drilled. Presumably this gravel Fairweather E & P Services inc. Sag Delta No. I Rev. 4 Page 1 of 9 1/16/2002 2.0 can be utilized in pit closure and f'mal site re-grading sometime in the future, once the well is permanently abandoned. At this time, configuration and condition of wellhead and associated hardware is not fully known. During an inspection trip, only the top valves of the wellhead were visible and sticking above the timbers and planks coveting the cellar. As the cellar was full of snow and ice, further investigation could not be pursued. Summary of Proposed Well Work In order to permanently abandon the Sag Delta No. 1 (33-12-16) well in accordance with Alaska Oil and Gas Conservation Commission (AOGCC) regulations, the following tasks must be completed: 3.0 2. Place a cement plug suffic~nt to cover open perforations and fill wellbore fi.om 9095' - 9570' MD.~ Displace out 100' diesel column in 4 ½" X 13 3/8" annulus. . . o Place a balanced cement plug in the 4 ½" tubing and in the 4 ½" X 9 5/8" annulus across the surface casing shoe interval from 1863' - 2263'. ~'~ Cut and recover 4-1/2" tubing from surface to approximately 175'. Set minimum 150' cement plug in 13-3/8" casing with top at or slightly below final casing cut off depth. 6. Excavate and remove well cellar. . Cutoff all casing strings approximately 10' below mudline datum (Sag River Channel depth). 8. Backfill cellar excavation and regrade pad surface. 9. Pickup any remaining debris on the location. The above work is required by various sections of 20AAC 25.105 - 20AAC 25.172 (Abandonment and Plugging). Attachment II presents a schedule of activities for completing the abandonment. The following well program (Section 3 below) does not include any specific activities directed toward reserve pit or flare pit closure. Proposed Operations Program Fairweather E & P Services Inc. Sag Delta No. 1 Rev. 4 Page 2 of 9 1/16/2002 The following Operations Program addresses the well P&A work only, and is based on a winter operation using an ice road for access. . Obtain all required permits and regulatory approvals before starting job. Fairweather proposes to secure all permits for the project on behalf of BPXA. Anticipated permits include the following: Application for Sundry Approvals, Form 10-403 (AOGCC); · North Slope Borough Administrative Approval. · BPXA's Authorization To Proceed . Mobilize all required personnel and equipment to the Sag Delta No.1 (33-12-16) location on an as needed basis via ice road. The proposed personnel and equipment spread is as follows: Personnel Working Supervisor (1) Mechanic (1) Welder (1) Roustabouts (3) EMT III/Environmental Tech/Expeditor (1) Wireline Operators (3) Cementers (3) Wellhead Technician (1) Bear Patrol (1) Hot Oil Crew (2) Equipment Operators (2) Equipment Steam Skid 200' of 1" steel pipe 200' of 2 3/8" tubing 966 Loader or equivalent Hitachi 400 Excavator or equivalent 1000 gallon fuel tank Fuel Truck as needed Vac / Supersucker Trucks as needed 125KW GenSet Water Truck as needed Mechanics Shop (Weld/CutIMaintenancedEtc.) Assortment of valve handles for wellhead Cementing Unit Boom Truck Wireline Unit Cement Silo Brine 1 Lot Valves, Fittings, Gauges, Tools, Etc. 1 Lot Oil Spill Contingency Equipment Fairweather E & P Services Inc. Sag Delta No. I Rev. 4 Page 3 of g 1/16/2002 Hot Air Heaters (2) 1 Prefab Wellhead Warm-up Shelter with Ceiling Port 1 Crew warm-up building trailer Cellular Telephones 100 Bbl Open Top Tanks (2) (for wellbore fluids) Air Monitor 2 Trash Dumpsters (1 metal waste, 1 general) Test Pump, Triplex . . Notify AOGCC and BPXA of intent to begin P&A operations on well. Hold safety meeting before starting work on the well. This is potentially a live well. o Remove guard rails, timbers and planks coveting cellar. At this time full details such as depth, and conditions of cellar are unknown. Cellar may have gravel and or ice fill. Steam thaw and excavate or evacuate as necessary to gain full access to all wellhead components. . Erect prefab shelter over well and apply heat to wellhead and cellar with hot air heaters. Function test, lubricate and service valves as necessary. Preliminar~ investigation indicates all valve handles were removed at time of well suspension. An assortment should be brought to well site to expedite the opening and closing of valves during P&A operations. Open back pressure valve at surface, check pressures on 4-1/2" tubing and 4-1/2" X 13-3/8" annulus. Rig up test pump, alternately pressure test 4 ½" tubing and 4 ½" X 13 3/8" annulus to 50% of lowest rated component exposed to test pressure. If ~'llhead, casing or tubing fail to pressure test properly, work will be suspended until such time that a viable solution can be found to remediate the problem and work can continue. . . Hold safety meeting to discuss hazards associated with wireline perforating operations and cementing operation,~with emphasis on working with explosives and high pressure lines. RU wirelin'e BOP and lubricator on wellhead, pic~k up gauge ting on wireline (for checking 4 ½" tubing I.D.) and RIH to 9164' tO verify tubing is not collapsed. POOI~ lay down gauge ring and PU tubing punch perforating gun:/RIH to 9100' (5 feet below tubing packer set at 9095') and perforate tubing~with 6 (six) ½" holes at 6 spf. POOH with wireline, rig down BOP and lubricator and standby. Give AOGCC 24 hour notice of intent to place cement plug and chance to witness same. RU cementers and pressure test lines. Break circulation using clean CaC12 brine down tu/bing. When circulation rate has be~,exl~established, using the downsqueeze method, displace 122.5 fi3 (107 sacks) of Class G cement into perforations and wellbore area beneath tubing packer. As soon as cement volume has been pumped, drop dart and displace cement in tub, b/ing with 137 bbls of CaC12 brine. The cement volume calculated includes 20% excess to insure sufficient Fairweather E & P Services Inc. Sag Delta No. 1 Rev. 4 Page 4 of 9 1/16/2002 . 10. 11. 12. 13. 14. 15. cement has been squeezed into perforations and wellbore beneath packer is adequately filled. WOC. Check pressures at wellhead to insure well is dead. RU lubricator and wireline with sinker bar and tubing punch perforating gun. W,/ith AOGCC witness, RIH to tag TOC plug and verify location. POOH to 2263', perforate 4 ½" tubing with 6 (six) ½" holes at 6 spf. POOH, rig down and standby. RU cementers, pressure test lines, hook up to 4 ½ inch tubing and displace out diesel 100' diesel column (12.8 bbls) in 1323/8" X 4 ~A" annulus. Using displacement method, place-2Z3q~3 (-.,~,~ sack~cement plug from 1863' to 2263' in tubing and tubing casing a~ius. ~as~ment with tubing dart and displace with 28 bbls CaC12 down tubing ID. WOC. RU wireline with lubricator, tubing cutter and sinker bar. RIH to tag and verify location of TOC plug. POOH to 175' below pad surface (198' original RKB), sever tubing, POOH, RD and as soon as cut is verified by lifting on tubing, release wireline from location. Give AOGCC notice of intent to place final cement plug at surface, and chance to witness same. Nipple down wellhead valves and tubing bonnet, using boom truck, pull severed section of tubing. RIH and place poor boy bridge plug on top of tubing. RIH with 175' of 2 3/8" tubing, rig up cement batch mixer~eement can be displaced with centrifugal pump here) and displace 145.5 ft3 ~f Arctic Set cement to fill casing id to surface. Release cementers. WOC. Excavate and remove well cellar box. Continue to excavate below cellar box to expose 20" conductor at a point greater than 10' below the bottom of the adjacent Sag River Channel (approximately 18.5' below base flange). Rig up safety lines on wellhead to prevent wellhead from falling into excavated area as cutting procedure is initiated. If guillotine saw is available, RU and cut all casing strings 9' below bottom of adjacent Sag River Channel. If saw is not available, proceed as follows. Using torch, cut and remove segment of 20" conductor to expose cement sheath surrounding 9 5/8" casing string. Break away cement to expose 9 5/8" casing. Break out cement from behind 20" conductor to expose 13-3/8" casing. NOTE: Conduct safety meeting prior to initiating Steps 13 and 14. Cut 13-3/8" casing and remove wellhead for backhaul. Trim up casing stubs and weld a 30" X 30" X 56" steel marker plate identifying well on 20" conductor at approximately 9' below base of river channel. Backfill excavation to avoid fall hazard. Attachment HI shows the post- abandonment condition of the wellbore. Fairweather E & P Services Inc. Sag Delta No. I Rev. 4 Page 5 of 9 1/16/2002 4.0 $o0 16. Pick up any debris on location, mm location over to pad reclamation contractor and move to next well in P&A program 17. File new Form 10407 with AOGCC referencing the new P&A well status. 18. Remm to Sag Delta No.1 (33-12-16) location the following summer to pickup any minor remaining debris exposed after snow melts and to conduct a final location inspection with the AOGCC and DNR. Waste Disposal and Responsibilities for Waste All liquid wastes recovered and generated in the abando, ptnent program will be transported in vac trucks to a BPXA designated injection facility. Fairweather will utilize BPXA contract hauler's for the recovery and transportation of these wastes. All fluid handling will be managed in a manner satisfactory to BPXA. Fairweather will handle transport paperwork if requested. . Solid waste (i.e. cellar box, wellhead, casing sections, etc.) will be transported to the North Slope Borough Solid Waste Disposal Site for disposal. This will be accomplished by Fairweather. . In the event that any hydrocarbon contaminated gravel and soil is identified during excavation, the materials will be segregated and staged on location. Sampling, transport and disposal of such materials will be at the direction of BPXA and costs for such will be in addition to any fixed price well abandonment bid. Reporting and BPX Oversight o BPXA will receive daily progress reports faxed to the Anchorage BPXA office and to the designated recipient on the North Slope during the term of the project. During any periods when a BPXA representative is not on site, the faxed reports will be followed up by a phone call to the designated BPXA contact in Anchorage or on the North Slope. . The amount of direct BPXA oversight of field operations is entirely at the discretion of BPXA. Transportation and camp space (if required) will be provided for the BPXA representative. Fairweather E & P Services Inc. Sag Delta No. 1 Rev. 4 Page 6 of 9 1/16/2002 24" Hole 20"~90' cemented with 8 cu yds cement 18 112" Hole Proposed Present Condition Cameron Back Pressure Valve at Surface Diesel in 4 112" X 13 318" Annulus to -100' Brine (kill wt) Sag Delta No. 1 Prudhoe Bay BP Exploration (Alaska) Inc. Size Wt. Grde Depth, Cmt Vol. CONDUCTOR 20" LP 90' 8 cu.yds SURFACE 13 3/8" 72# N-80 2731' 4164 cu.tt. INTERMEDIATE 9 5/8" 47# N-80 9132' 1525 cu.fl. UNER 7'' 29# N-80 8613'-10214' 415 cu.E. PRODUCTION TUBING 41/2" 9192' 13 318" 72# N-80 ~ 2731'w/ 4164 It= Permafrost II 12 114" Hole 7" Liner Hanger 8613' 9 518" 47# N-80 ~ 9132' Pumped 1525 cuff Class G Perfs ~ 9424'- 9555' Perfs ~ 9583'- Perfs ~ 9691' - 9821' 7" 29# N-80 ~ 10214' 415 cu It Class G ) 9 818" PBR ~ 2063' 9 518" Uner Lap Squeezed Tubing and Wellbore below Packer filled with Well Fluids (Crude) Drilling Mud TOC in 12 1/4" X 9 518" Annulus ~ 5,200' Liner Lap tested to 3000 psi Packer ~ 9095' Olis 'X' Nipple 9164' 4 112" Tubing Tall ~ 9192' MD EZSV ~ 9570' Tubing and Wellbore below Packer filled with Well Fluids (Crude) EZSV ~ 9674' 112" Hole 10216' MD (9906' 1VD) Description Well is currently suspended with the following hardware. Cameron Back Press Valve Tubing Packer Otis X-Nipple EZSV EZSV PTD: 175-058 APl: 029-20176 Spud Date: Feb. 3, 1976 Date Suspended: April 28, 1976 Elev. (RKB) 32.16 (Flange Elevevation ,,, 8.5' AMSL) All depths are RKB measured depths. ATTACHMENT I DRAWING NOT TO sCALE Sag Delta No. 1 FAIRWEATHER E&P Rev. 04asis / DHV SER VICES INC. 16-Oct-01 Fairweather E & P Services Inc. Sag Delta No. 1 Rev. 4 Page 7 of 9 1/16/2002 ~--~ Proposed ~ Present Contifion Casing to be severed 10 feet below original mudline datum (Sag River Channel Deplh) after pumping cement to surface. Steel Plate W ! Id welded on top of casing. Drilling Mud t 2 114" Hole 24" Hole 20"~90~ cemented with 8 cu yds cement 18 112" Hole Tubing Dart to 0050' Top 7" Uner Hanger 8613' 9 518" 47# N-80 ~ 9132' Pumped 1525 cu It Class G Top of Squeezed Cement Plug ~ 9100'(116 It3) Dement Plug: 23' to 198' (130 f~) Poor Boy Bridge Plug 198' Tubing severed at 198' Below Pad Surface Balanced Cement Plug 4 112' TBG and lbg Casing from1863' - 2263' (237 It3 cmt) Top 9 518" PBR ~ 2063' 9 518" Liner Lap Squeezed Sag Delta No. 1 Prudhoe Bay BP Exploration (Alaska) Inc. , , Size VVt. Grde Depth Cmt Vol. CONDUCTOR 20'' LP 90' 8 cu.yds SURFACE 13 3/8" 72# N-80 2731' 4164 cu.ff. INTERMEDIAT 95~8" 47# N-80 9132' 1525cu.ff. 30 ~) E RKB LINER 7" 29~ N-80 8613'-10214' 415 cu.ff. PRODUCTION in / TUBING 4 1/2" 9192' ~ing ,.83' Description OD ID Depth Well will be P&A'd with :ed following hardware in place. Tubing Packer 7 4 1/2 9095 Otis X-Nipple 41/2 3.~37 9164 EZSV 7 9570 EZSV 7 9674 Description Start Depth End Depth Proposed P&A Plug Location Referenced to Original Rig RKB 175 ft (130 ft3) cmt plug 23' 198' Poor Boy Bridge plug 198' 400 ft(237ft3) cmt plug 1863' 2263' Existing Tubing Packer 9095' 470 ft(115 ft3) cmt plug 9100' 9570' Existing EZSV 9570' , 'lOC in 12 114" X 9 618' ~ - 5,200' Liner Lap tested to 3000 psi 9095' Tubing Perforated ~ 9100' Otis ~(' Nipple 9184' 4 1/2" Tubing Tail ~ 9192' MD Perfs~9424~9555' EZSV~9570' Perfs~ 9683'- 9627' EZSV~9674' Perfs~9691'-9821' PTD: 175-058 APl: 029-20176 Spud Date: Feb. 3, 1976 Date Suspended: April 28, 1976 Elev. (RKB) 32.16 (Flange Elevevation-8.5' AMSL) All depths are RKB measured depths. ATTACHMENT III DRAWING NOT TO SCALE Sag Delta No. 1 FAIRWEATHER E&P Rev. 04prop / DHV SER VICEE INC. 07 - No v-01 7" 29# N-80 ~ 10214' 415 cu It Class G r~. I [~*/'' Perfe ~ 10,001'- 10,145' 8 112" Hole 'ID ~ 10216' MD (9906' T~/D) Fairweather E & P Services Inc. Sag Delta No. I Rev. 4 Page 8 of 9 1/16/2002 Attachment II BP Exploration (Alaska) Inc. Sag Delta No. 1 Proposed Permanent Well Abandonment and Location Clearance ,, Construct Ice Road Access Estimated at I week prior to mobilization for I~&A. Mobilize Equipment from Deadhorse or previous well in program. Thawwellhead and cellar, test and lubricate wellhead, open back I pressure valve, Pressure test. RIH wireline gauge ring, Perforate,place cement plug #1. WOC. Test TOC. Test TOC plug #1, Perf tubing, cement plug #2. VVOC. 1~ wellhead. Test TOC plug #2, Sever & pull tubing, place surface cmt plug. Remove cellar, excavat wellhead. r Sever casing strings, weld on ID )late, backfill excavaton. Demob to next P&A well Contingency Days: Weather and Equipment r Fairweather E & P Services Inc. Sag Delta No. 1 Rev. 4 Page 9 of 9 1/16~2002 15-Jan-02 Ms. Cammy Oechsli-Taylor 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) Sag Delta No. 1 Dear Commissioner Oechsli-Taylor: BP Exploration (Alaska) Inc.. (BPXA) hereby applies for Sundry Approval of its plan to plug and abandon the Sag Delta No. 1 Well. '/ The anticipated commencement date of this work is February 8, 2002. The well will be permanently plugged and abandoned by squeezing off and cementing over open perforations below. Jhe 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 t.h/e surface casing shoe and tubing annulus. The tubing will then be cut and a poor boy bridge ~lug will be set over the top of the tubing stub2~A cement plug will then be placed from the top of the bridge plug to surface (150 foot mimmum). The cellar will be removed, and all casing strin~'ll 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 Sag Delta No. 1, with schematics showing current and proposed condition of the wellbore. If you have any questions or concems, please contact Duane Vaagen at 258-3446. Thank you for your help. Ms. Cammy Oechsli-Taylor Page 2 Sincerely, Steve Rossberg BP Exploration (Alaska) Inc. Attachmems Cc: Jason Moncrieff P.E., BPXA Duane Vaagen (Fairweather) Re: Question on Sag Delta Subject: Re: Question on Sag Delta # 1 Date: Wed, 26 Jan 2000 14:05:41 -0900 From: Blair Wondzell <blair_wondzell~admin. state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "'Peterson, Judd"' <rjpeters~envircon. state.ak.us> CC: "Griffiths, Leslie A" <GriffiLA@BP.com> Judd, I certainly agree, they are same well. Blair "Griffiths, Leslie A" wrote: Blair and Judd - In our database, it does indicate that Sag Delta #1 and Sag Delta 33-12-16 are in fact the same site. (API Number 500292017600). Leslie > > From: Peterson, Judd[SMTP:RJPetersSenvircon.state.ak.us] > Sent: Wednesday, January 26, 2000 11:02 AM > To: 'Wondzell, Blair' > Cc: 'Griffiths, Leslie' > Subject: Question on Sag Delta # 1 > > Dear Blair, > I am working on a reserve pit closure file for Sag Delta #1, a BP well and > have a question. Sag Delta #1, (API# 50-029-20003-00) on the AGOCC > listing > was never drilled and is an expired permit. On the north slope maps I > have, > there is a well labeled Sag Delta # 1 and it is plotted on the maps in > Section 4, liN, 16E UM. This is the location on the ground that I have > visited a few times and the well was drilled. The well name on the well > marker was only painted and has rusted away. The only well in the AGOCC > listing with 'this surface location is Sag Delta 33-12-16. > > Do you know if Sag Delta 33-12-16 is also know as Sag Delta # 17 > > Thanks for your help. > Judd > 1 of 1 1/26/00 2:06 PM BP EXPLORATION To: David W. Johnston Chairman Alaska Oil & Gas Commission From: Steve Herren, Drlg Mgr Shared Services Drilling ARCO Alaska, inc. Date' ~LE Subject: Sus.~ended 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 Herren Drilling Manager Bill Bredar Patrick Collins Jim Farnsworth Mike Miller Bruce Policky Scott Sigurdson Marian Sloan RECEIVED ' OCT 1 4 1994 Alaska Oil & Gas Cons. Commission Anchor~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-/¢'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-01B 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 85-0110 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-O200 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 93-0113 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 PR 33-12-13, 029-20047-00 69-0104 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 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 7O-O060 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 90-01 4O Arco Alaska Inc. is the operator of this well, they will be addressing the question of suspension. Sag Delta #3, 029-20233-00 79-0080 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 80-0O66 MP 33ol 1-12, 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 22-31-11-13, 029-20545-00 81-0010 MP 43-31-11-13, 029-20536-00 80-0139 MP 30-11-13, 029-20546-00 80-0152 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 WELLS PRIOR TO 1980 and BP SUSPENDED WELLS 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 _~quire~_20 AAC 25.110(e), must have well site inspections is ye -Qr~t@ snow covering the locations. David W. ,Johnston ~ - Chairman ..... ~.~, ~ Attachments c: Blair Wondzell bew/llbpsusp '15/94 BP SUSPENDED WELLS SINCE 1980 PAGE 1 AUGUST 1994 PERMIT 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 NUMBER 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 I 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 I DEV SUSP PBU MP 22-31-11-13 2 DEV SUSP ALASKA ISLAND i EXP SUSP MILNE POINT UNIT B-02 DEV SUSP MILNE POINT TJl~IT A-03 DEV SUSP MILNE POINT UNIT N-01B DEV SUSP NIAKUK 4 EXP SUSP NIAKUK 5 EXP SUSP MILNE POINT UNIT C-16 DEV SUSP PRUDHOE BAY UNIT Y-22A DEV SUSP PT MCINTYRE' P2-59 EXP SUSP PRUDHOE BAY UNIT S-10A DEV SUSP NORTHWEST MILNE I EXP SUSP PRUDHOE BAY I/NIT U-01 DEV SUSP PRUDHOE BAY UNIT Z-32A DEV SUSP NO POINT I DEV SUSP STATUS DATE 4/15/80 10/11/80 4/29/81 12/24/80 4/15/81 4/13/81 2/20/81 1/18/81 2/14/81 6/08/82 5/27/82 12/10/83 4/27/84 2/17/85 4/18/85 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 05 30 30 11 19 23 30 25 25 10 33 14 35 25 18 19 O6 TWP 13N 11N 11N 11N 12N 12N 10N 11N 11N 101~ 13N 13N 13N 12N 12N 13N 11N 12N 12N 14N 11N 11N 13N 010E 012E 012E 012E 016E 015E 013E 013E 013E 022E 011E 010E 010E 015E 015E 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 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 BP SUSPENDED WELLS PRIOR TO 1980 AUGUST 1994 WELL WELL WELL NAME CLASS STATUS SAG DELTA 31-11-16 EXP SUSP PRUDHOE BAY U~IT 33-12-13 DEV SUSP KEMIK I/NIT I DEV SUSP PRUDHOE BAY I/NIT 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 TER~ 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 04 26 26 35 35 10 03 TWP llN 12N 01N 11N 11N 12N 12N 12N 12N 11N 11N P~NG 016E 013E 020E 013E 016E 015E 01SE 016E 016E 016E 012E PAGE MER U U U U U U U U U U U BP EXPLORATION January 11,1991 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: 900 East Benson Boulevl~d~,/-~. ,.o. ,ox ~ Anchorage, Alaska 99519-661~1~.(_ ~~ (907) 561-5111 . :,~ ~ c ~o~~1 BP Exploration respectfully requests a waiver to Alaska Administrative Code 20 AAC 25.240 section (b) for Sag Delta North Wells 1,2 and 3 in order to continue the long term production test of Sag Delta North for the purpose of acquiring pool performance data to determine an optimum reservoir management program per Alaska Administrative Code 20 AAC 25.240 section (c.3). A waiver was requested and granted on June 28, 1989 for the pool discovery well Sag Delta 9. The request and waiver are attached. BP Exploration plans to begin discussions with the AOGCC within the next month to develop Pool Rules for the Sag Delta North accumulation. Reservoir Simulation studies are underway to aid in determining an optimum reservoir management program and continued production will provide information for these studies. Please direct any questions regarding this request to Herman Hellman at 564-4785. B.~j. ~ ../Sincerely~/~ BJP/HLH RECEIVED 'JAN 1 ~ 1991 Gas Co. . ', Ntchorage ALASKA OIL AND GAS CONSERVATION COMMISSION STEVE COWPER, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501.3192 PHONE: (907) 279-1433 June 28, 1989 T. N. Tyler BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Dear Tim: The Alaska Oil and Gas Conservation Commission (Commission) has received your letter of June 19, 1989, with your proposal to conduct a long term production test into the Endicott production facilities from the Sag Delta 9 well located in Section 20, T12N, R17E, U. M. The Commission has reviewed your proposed test plans and has determined the data to be acquired are necessary to determine an optimum reservoir management program. Pursuant to Alaska-Regulations 20 AAC 25.240(c)(3) the Con3nission hereby waives the gas - oil ratio limit required by 20 AAC 25.240(b) during production testing of. the Sag Delta 9 well. Sifre 1~ ~'~ i/Lonni e C.'--'Smi th Commissioner cc: DNR mmo;RAD. 002 RECEIVED BP EXPLORATION June 19, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: BP Exploration respectfully requests a waiver to Alaska Administrative Code 20 AAC 25.240 section (b) in order to conduct a long term production test of Sag Delta 9 for the purpose of acquiring pool performance data to determine an optimum reservoir management program per Alaska Administrative Code 20 AAC 25.240 section (c.3). In a meeting held June 13, 1989 with the Alaska Oil and Gas Conservation Commission, BP Exploration discussed their plans to conduct a long term production test of Sag Delta 9. The following facts were presented and conclusions were reached at the meeting. Two sand intervals in the lvishak formation, separated by a major shale, are to be tested both independently and in combination. BP Exploration believes that at least 18 months will be require~i te conduct an adequate test. Fluids from the well will be produced into the Endicott production facilities. All gas produced from the well will be used as fuel in the Endicott facilities. Hydrocarbon liquids produced from the well will be commingled with Endicott liquids. Fluid volumes will be allocated on the basis of choke correlations and will be well test calibrated semi-monthly. Water produced from the well will be utilized in the Endicott waterflood or, in the event of an upset in the waterflood system, disposed of in the Cretaceous zone as permitted by Area Injection Order No. 1, Duck Island Unit, Endicott Participating Area. RECEIVED JAN 1 ~ 1991 The test is scheduled to commence within the 3rd quarter 1989. Please direct any questions regarding this request t° Herman Heiiman at 564-4785. Sincerely, T. N. Tyler TNT/HLH JAN 1 ~, 1,q,ql AJaska Oil & Gas Co~. ~mmissio~ A~chor~ ... STATE OF ALASKA J~)L 28337 ALASKa,'OIL AND GAS CONSERVATION COMM,~$1ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ~,---..~..-~ , ~ --,.- ~,-A~.._-- · -- ,-, ....... feet 3. Address ...... ~'"'""~ i r y 4. Location of wel~ at surface 7-. W~-i~-~m~e-~' ..... 749' EW]'., 1000' SNL, Sec. 4, TllN, R16E, UN $~G Delta I (33-12-16) At top of productive interval 8. Permit number 75-58 At effective depth 9. APl number 50-029-20176 At total depth 10. Pool 652' E~]'., 911' NSn, Sec. 33, T12~, ~16E~ UH Wildcat 11. Present well condition summary Total depth: measured 10216 'ND feet Plugs (measured) true vertical 9906'TVDss feet 7" EZ Drill Bridge Plug 9570'~ 7" EZ Drill Bridge Plug 9674' Effective depth: measured 9570 'ND feet true vertical 9276'TVDss feet Plug in packer/tailpipe Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 20" 90 'ND Surface 13-3/8" 4164 cu. ft. 2731'ND Intermediate 9-5/8" 1525 cu. ft. 9132/2109'ND (hung as liner) Production 5 'T' 7" 415 cu, £t. 10214/8613 'ND Liner ~ 'T Perforation depth: measured 9424' -9555', 9583'-9627' 9691' -9726', 9782'-9821', 10001'-10009', '!0021'-10033', Reason £or extension= This sus~enc3.e8 10040' -10048', 10054'-10068', 10086' -10113', well is within the T.isburne ~l?o]tt~i~,~a?d'e, ar~~~0d].~e~h~D Participating Area (LPA) and is being considered £or ~uture use as a 4-1/2" 12,75# ~-80 9058' development or observation well, Packers and SSSV (/type and measured depth) 12.Attachments Description summary of proposal [] Detailed operation~]~r~¥s~ ~ '~:;'~P';:sketch [] 13. Estimated date for commencing operation : .... "~ ~ ':'-~' 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~?-~.~, ~_~ TitleD~vi.~rm ].)~]]~? RnO~.~. Commission Use Only Date Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI 7 "- 5,-- ,~-/ Approved by Form 10-403 Rev 124-85 APproved C~y ~turrm~ Commissioner by order of ~/~'~ /,~ the commission Date ~. ~ Submit ir~ triplicate -~- ADL 28337 STATE OF ALASKA ALAS~,~.:OIL AND GAS CONSERVATION COM~v.~SSION APPLICATION FOR SUNDRY APPROVALS feet~ 1. Type of Request: Abandon E] Suspend [] OPeration Shutdown F~ Re-enter suspended well i.] Alter casing ~ ! Time extension E_X Change approved program E3 Plugging [] Stimulate [] Pull tubing i i Amend order i ! Perforate i 1 Other 2. Name of Operator Standard Alaska Production Company 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of Well at surface 749' EWL, 1000' SNL, Sec. 4, TllN, R16E, UM At top of productive interval At effective depth At total depth 652' EWL, 911' NSL, Sec. 33, T12N, R16E, UM 5. Datum elevation (DF or KB) KBE - 32.16' AHSL 6. Unit or Property name Prudhoe Bay Unit 7sAV~glLnumber. uemta i (33-12-16) 8.~ ,.~._e rsr~i t number 10. Pool Wildcat 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10216'MD /' 9906'TVDss feet ~]~ugl~n~l~lrl~dbridge Plug 9570' feet 7" EZ Drill Bridge Plug 9674' 9570' FID feet 9276' TVDss feet Plug in paCker/tailpipe Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 9424'-9555' , 9583'-9627' Size Cemented Measured depth 20" 13-3/8" 9-5/8" 4164 cu. ft. 1525 cu. ft. 7" 415 cu. ft. 969l '-9726' 9782'-9821' 10001'-10009' 10021' 10033' 10040' -10048' 10054'-1006~' 10086 '-1 O11 :~' 10117'-10127', 10129'-10145' MD Tubing (size, grade and measured depth) 4-1/2" 12.75// N-80 9058' Packers and SSSV (type and measured depth) Packer 9095' True Vertical depth 90'MD 2731'MD 9132/21~9'MD (hung as liner) 10~14/8613'MD Reason for extension' This suspended well is within the Lisburne Participating Area (LPA) and is being considered for future use as a development or observation well. 12.Attachments Description summary of proposal [] Detailed operations program Request extension under 20 AAC 25.170(b) 13. Estimated date for commencing operation BOP sketch 14. If proposal was verbally approved 4,,~ ..... Oi! '~, G,~,:, COl~,~, uui'ii:~iJSSJO~ Date approved Name of approver ~" "'~" 15. I hereby certify that the foregoing is true and correct to tnebest cT my knowledge Signed ~ ~. ~. ~ TitleD~v~s~on D~11ing Engineer Date Conditions of approval Commission Use Only Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved b Form 10-403 Rev 1~1-85 ~proved C. a-Dy ~eturned ,,,, Commissioner by order of [~_~.//~ the commission Dat ~ubr~ in triplicate ,~_-~,~ _-..- .~...~ ~ -, ._ - .... . . ,. . ....... _ ~.~.~ ...... . ~, ~ ~'.~- · .~ ~ . . . , . --- _ S t~dard Alaska ProductiOn Company '._.: :..' ;-':-._:.,. P. O. Box 6612 -::-~chora~e, ~ 99502-0612 . _ : ... _ -' Re: Extension of s~pended Sta~s PBU ~ 11-33-11-12 No. 1- PBU ~ 22-31-11-13 No. 2 PBU ~ 32-30-11-13 No. 1 -' PBU ~C Trac~ 3-10-12 -- PBU ~ ~3-31-11-13 . --- .... .~?--Pu~ River BP 33-12-13 ~ -- ,~:-'...~ .... :,__ PBU ~e~on Trac~ 23-18-11-12 :.~;: .... -- Sa~ Del~a No. 3 ' - Sa~ Del~a No. 5 ..-:' ;~-: Sa~ Del~a No. 7 Telecopy No. (907) 276-7542 Sag Delta No. 8 Sag Delua 34633 No. 4 West Sak 25519 No. 17 West Sak 25523 No. 16 West Sak 25655 No. 14 PBU U-13 West Sak 25548 No. 11 West Sak 25645 No. 9 Dear Hr. Allan: A review of our records shows that the above referenced wells are suspended. Section I10(a) of the regulations states the Commission will, in its discretion, approve the suspension of a well if the well is capable of producing hYdrocarbons in paying quantities or is reasonably demonstrated to have future value as a service well. Section 105(e) states that "[e]ach well to be abandoned or suspended must be plugged...to prevent the movement of fluid either into or between freshwater and hydrocarbon sources and to .._~prevent all other fluid migrationwithin the well bore." -- ~ . In compliance with Section 170(a) of the regulations, "It]he -., location of an abandoned well onshore or upon a historically stable island must be cleared within one year following well abandonment .... " Section 170(b) provides the means for an extension of time if a valid reason exists, and the well bore is properly plugged. · · · July 31 1986 Page 2 We are, therefore, requesting you .to submit Form 10-403, Application for Sundry Approval, wtth a program which will bring the status of these wells into compliance with the new regulations and provide a schedule for this summer when our field inspectors can accompany your representatives to the well sites. for location clearance inspection· Please call Harold J. Hedlund at (907) 279-1433 if you have any questions. Lonnie C. Smith Commissioner jo/A.HJH. 06/07 SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 9950243612 MS. P. Lambert ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Mr. R. Mills Exxon Company, USA P.O. Box 5025 Thousand Oaks, CA 91359 Data Transmittal February 26, 1986 .-~t~. -'.S'ag Delta 1 Data Report, Long term production test, January 22, 1985 - January 26, 1986, Volumes 1 and 2. -~Sag Delta 1 Otis tie-in log 3/25/85 (Photocopy) -~ Sag Delta 1 Schlumberger pressure survey 1/28/8~ ~2~luelines and folded sepia. Sag Delta 1 Schlumberger production log 1/28/~uelines and Please indicate receipt of this material by signing below. Any questions may be addressed to Mr. Charlie Michel at (907) 564-4711. D. W. Fisher Received Attachments Date laska Oil & Gas Cons. Commission Anchorage CP~4:slt:2/27/86 0720R SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 , July 22, 1985 Mr. C.V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: 1985 LOCATION INSPECTION Dear Mr. Chatterton: In' compliance with State Regulation 20 AAC 25.170, attached are Fores 10-403, Sundry Notices and Reports on Wells, for the following wells. These notices request that the wells remain in suspended status. BP 41-33-12-1 3 BP 22-33-11-13 Term Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Wel 1 (23-18-11-1 2) MPC Tract Well (21-03-10-12) PBU MP 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP (22-31-11-13) No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 Sag Del ta #1 (33-12-16) Sag Delta #2A (10-11-16) Sag Delta #3 (35-12-16) Sag Delta 34633 #4 Sag Delta #5 (36-12-15) Sag Delta #7 Sag Delta #8 Sag. Delta #9 Sag Delta #10 Niakuk #lA (26-12-15) Nia.kuk #2A (23-12-15) Alaska Island #1 Niakuk #4 Ni akuk #5 RECEIVED Alaska Oii & Gas Cons. Commission Anchorage Mr. C.V. Chatterton July 22, 1985 Page 2 · Sag Delta #11 is now ready for final inspection of the abandoned well. Please advise the undersigned which day during the week of August 19-23 is acceptable for your field inspector to accompany our representative, for this annual location inspection trip. Very truly yours, RSA/CRM/sh 7228~5:0530N Attachments cc' Well File #17 R.S. Allan Acting SAPC Drilling Engineer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CuMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum ~y 75-58 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 5o-029-20176 4. Location of Well 9. Unit or Lease Name OTHER [] At surface: 749' EWL, 1000' SNL, Sec. 04~ TllN, R16E, 5. Elevation in feet (indicate KB, DF, etc.) _KBE_ = 32.16' A~L 6. Lease Designation and Serial No. ADL 34634 10. Well Number Sag Delta #1 (33-12-16) 11. Field and Pool Wildcat (Exploration) 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: Request extension under SUBSEQUENT REPORT OF' (Submit in Triplicate) 20 ~ 25,170 (b) 1,2,3 (Submit in Duplicate) Perforate [] Alter Casing [] Perforations i--] 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). Reasc~ for extension: This site is being considered for future Lisburne Reservoir development. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~ S . ~ , Title District Drillinq Enqineer The space below for Commission use R. Ho Reiley Date Conditions of Approval, if any: Approved by. OI{IG:lIA[ SIGN£D BY LOfllll'[-C. $11TIi ~kpproved Cc~p¥ j~®turned .. _x BV Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY April 29, 1985 E3.15Sag 1 Mr. William Van Dyke, Petroleum Engineer Department of Natural Resources Division of Oil & Gas 555 Cordova Street - Pouch 7-034 Anchorage, AK 99510-7034 TELEPHONE (907) 276.511~1, j ~ ~}.,'~ "" ~ ....... MAIL: POUCH 6-612 ~ ~ ANCHORAGE, ALASKA 9950~ ' - 'l 18~e~ continue d Monito~~~~u~ge Dear Mr. Van Dyke: The referenced I~ase Operations Permit was issued to Sohio for the conducting of extensive tests on the shut - in well, Sag Delta Well ~1. The approval was limited to work conducted prior to May 15 when drilling and testing is' shutdown before breakup. Those activities will be completed and the equipment removed from the island as required. ~merous precautions are planned to safeguard the well through the summer. A hydraulically actuated master valve and surface safety system will be installed to shutin the well at the surface, in an emergency. The Christmas tree is enclosed in a locked wellhouse. The operating hand wheels on all valves will be removed or locked to prevent tampering in the event unauthorized persons gain access to the wellhouse. The next sequence of monitoring is planned to continue as a long range pressure build-up test over the period of breakup to freezeup. At the time of demobilization, the HP pressure gauge will be removed and replaced with a semipermanent pressure gauge. Once a week, a helicopter will transport personnel to the island to take readings and check wellhead equipment. Each visit will take about one hour and will continue until fall when ice provides road access. At that time, this semipermanent gauge will be removed and the well suspended. This notification is intended to provide your office with an update on the status of the well. The summer monitoring program as described conforms to activities allowed under the general category of land use regulations. However, if you find additional information or review is necessary, please call me at 564-5352. Since rel y, Senior Landma ~ cc: Rik Smith, DLWM I~nnie Smith, AOGCC' RECEIVED MAY 0 2 1985 Alaska Oil & t~as L;on~, ~ummission /~chorage SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 April 26, 1985 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Wells Sag Delta No. 1 Gentlemen: Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This contains our proposal for the installation of a semi-permanent gauge to monitor the bottom hole pressure. Yours very truly, M. D. Martin Petroleum Engineer MDM/jmw Enclosures cc: Sag 1 File Drilling Well File #17 RECEIVED APR 2 6 1985 Alaska 0il & Gas Cons. commission Anchorag9 STATE OF ALASKA ALASKA t,~. AND GAS CONSERVATION CO,.,,VlISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 3. Address P. O. Bo× 6-612, Anchorage,_A_laska 4..Location of Well 99502 At Surface 749' EWL, 1000' SNL, Sec. 4, TllN, R16E, UPM 7. Permit No. 75-58 8. APl Number so- 029-20176 9, Unit or Lease Name lO. Well Number (33-12-16) Sag Delta No. 1 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KBE = 32.16 I ADL 34637 Lisburne Pool 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). The 60 day flow test was completed on March 28, 1985. The well ±s shut-±n and a H.P. pressure gauge is in the hole to monitor the bottom hole pressure. This pressure gauge will be removed prior to breakup. To continue gathering bottom hole pressure data, a semipermanent gauge will be installed prior to breakup. Access to the location to read the gauge.~ will be via helicopter approximately once per week. A hydrualically actuated master valve and surface safety system will be installed to shut- in the well at the surface in an emergency. The Christmas Tree is enclosed in a well house which will be locked. The operating hand wheels on all valves will be removed or locked .to prevent tampering in the event unauthorized persons gain access to the well house. It is expected to continue the weekly gauge readings until late November at which time road access to the location should be possible. At that time, the semipermanent gauge will be removed and the well suspended. RF.'C[IVF_D APR 2 6 1985 Alaska 0il & Gas Cons. Commisslor, Anchora0e 14. I hereby certify that the foregoi_ng is true and correct to~wledge. Sign Title Sr. Petroleum Engineer The space below for Commission use Conditions of Approval, if any: Approved ,~eturnecl Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 q30 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY PAUL J. MARTIN VICE PRESIDENT, OPERATIONS & ENGINEERING November 8, 1984 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 564-5421 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 Mr. C.V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Chatterton: Sohio is currently planning to conduct a long-term production test to assess the productivity of the Lower Dolomite zone of the Lisburne formation. The production test will be performed on the Sag Delta 81 (33-12-16) well, located on Sohio's Northeast Prudhoe Properties leases in the Sag Delta area. Sag Delta 81 is perforated in the Lower Lisburne section of the Lisburne formation and has had two previous well tests. During April 1976, four short-term drillstem tests were conducted throughout the entire Lower Lisburne. A 96 hour production test was successfully conducted on Sag Delta 81 during March 1977. An increased understanding of Lisburne productivity, as well as the need to further delineate the extent of the commercial reservoir, dictate the need for more comprehensive testing at this time. The primary objectives in performing the planned production test are as follows: 1. Obtain long-term production data to assess decline rates, GOR behavior and effects of production of well deliverability to better determine optimum production rates; 2. Attempt to define reservoir characteristics such as boundaries, faults, shales or lithology changes and determine their effects on flow behavior; 3. Collect static reservoir pressure and pressure transient data for use in making predictions of reservoir behavior; and 4. Characterize reservoir fluids to allow Sohio personnel to develop safe and effective programs for future Lower Lisburne wells. These programs include the formulation of completion fluids, drilling muds and stimulation designs. CEIVED NOV 0 S Gas Cons. Commission Anchoraoa Mr. C.V. Chatterton November 8, 1984 Page Two To facilitate this production test, which is scheduled to begin in late December, Sohio requests the AOGCC grant a flare/testing permit extending the customary 30 day test period to 60 days for the completion of the long-term production test. Liquid hydrocarbon production from the test will be metered at the wellsite and transported by truck to Prudhoe Bay Unit facilities where it will be processed for sale through the TAPS pipeline. Lisburne oil will be metered separately and separate run tickets will be generated. The average oil gravity is expected to be similar to the current oil gravity as measured at Pump Station No. 1. Because of the remoteness of the well location from Prudhoe Bay facilities, it is not economically feasible to recover gas produced during the production test. Sohio requests, therefore, the well test permit also specify the operator be allowed to flare gas on site for the duration of the test, consistent with appropriate environmental and safety regulations. Based on previous gas production rates from other Lisburne wells, the total volume of gas to be disposed of during the 60 day production test is anticipated to be on the order of 200 million standard cubic feet. In order to prevent forced interruptions of production operations, Sohio also requests the permit include contingencies to flare oil at the wellsite in the event of severe weather conditions which prevent trucking of produced hydrocarbons to Prudhoe Bay Unit facilities or in the event of Force Majeure interruptions of production operations at Prudhoe Bay. Furthermore, oil flaring will be limited to a period not to exceed 24 hours per incident and not to exceed five incidents in total. Your expeditious response to this application for permit is requested so Sohio may address any questions or concerns you may have. Additional information concerning this test should be referred to Mr. J.A. Bragg at 907-564-5564. Regards, Paul J. Martin c: G.J. Abraham J.A. Bragg A.L. Brown P.R. Clutterbuck J.H. Dickey R.A. Jones A.E. Leske RECEIVED NOV 0 $ Alast<a Oil & Gas Cons. Commission Anchorage SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 July 10, 1984 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Cc~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Re: 19 84 LOCATION INSPECTION Dear Mr. Chatterton: In compliance with State R.~gulation 20 AAC 25.170, attached are Forms 10-403,' Sundry Notices and Reports on Wells, for the following wells. These notices' request that the Wells remain in suspended status. BP 41-33-12-13 BP 22-33-11-13 Tenu Well B (22-20-11-13) Term Well C. (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU MP 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP 22-31-11-13) No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 Sag Delta #1 (33-12-16) Sag Delta #2A (10-11-16) Sag Delta #3 .(35-12-16) Sag Delta 34633 #4 Sag Delta #5 . (36-12-15) Sag Delta #7 Sag Delta #8 Sag Delta #9 Sag Delta #10 Niakuk #lA (26-12-15) Niakuk #2A (23-12-15) Alaska Island #1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator Sohio A!a.~ka Petroleum Cc~pany 3. Address P~ch 6-612, Anchorage, Alaska 99502 4. Location of Well COMPLETED WELL I-1 At surface: 749' EWL, 1000' SNL, Sec. 04~ TllN, R16E, UPM 5. Elevation in feet (indicate KB, DF, etc.) FRP. = 32.16' A~!__. 12. 7. Permit No. 75-58 8. APl Number s0- 029-20176 9. Unit or Lease Name 10. Well Number Sag Delta #1 (33-12-16) 11. Field and Pool Wildcat 6. Lease Designation and Serial No. (Exploration) ADL 34634 ~ Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: [:L~rt~st ~sion 1.1~r SUBSEQUENT REPORT OF: (Submit in Triplicate) 20 ,~N3 25.170 (b) 1,2,3 Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other J~[ Pulling Tubing OTHER ~ ~'~ L. _ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (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). Reason for extension: This site is being ccnsidered for future Lisburne Reser%Dir develo[m~nt. RECEIVED J U L 1 o 1984 Alaska Oil & Gas Cons. Commission Anchorage 14. I here y u Signed t% ~ v ~ \k ~'--'~~, Title Distric~ Dr'JZ1.~J.cJ' ]~-[q'.~"teer Date"~- 5 -- ~ % The space ~elow for Commission;se R. H. ~ey Approved Copy Conditions of Approval, if any: Eeturn~ S~p~ded sta~s is ~t~ded ~til ~pt~er, 1985.-./0?~&F.~.~,~ .... Form 10-403 I::lau -/.1J;ln Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate October 5, 1983 Ms. Pam Prusina H. K. van Poollen & AssOciates, Inc. 1100 W. Littleton Boulevard Littleton, Colorado 80120 Enclosed are copies of the well tests-for the Endicott Reservoir. Duck Island Unit No. 1 drill stem tests 1, 2A, 3, 3B, 5, 5B, 6, and 6A. Duck Island Unit No. 2 tests 1, 2, and 3. Sag Delta Mo. 3 well test. Sag Delta No. 4 step rate test. Sag Delta No. ? production tests 1, 2, and 3. ~,ag?!Del-ta~No.!~l well'tests 1, 2, and 2A. These tests are marked confidential and should be handled as such. Sincerely, Russell A. Douglass Petroleum Reservoir Engineer be Enclosures M E M O'RAi' D U M State of Alaska FILE NO: 108A:F2 TO: Chairma~ ~.. T~RU: Lonnie C. Smith commissioner TELEPHONE NO: FROM: Edgar W. ~*/// SipPle, Jr ' sUBJECT: Petrole~ .Inspector 1983 Inspection on Sohio's Suspended Location Listed Below. MOnday.,. AugUst 8j" 1983: I traveled this date to Prudhoe Bay, where I "met~-~ke Din~r., Sohio's representative, to look at the suspended locations listed below: Sag: Del~a %t (33-12-16} Sag Delta %2A (10-11-16) Sag Delta %3 (35-12-16) Sag Delta %34633 %4 Sag Delta %5 (36-12-15) Sag Del ta Sag Delta Sag Delta Sag Delta Attached to this report are pictures of the well head, drillin9 pads, reserve pits and a copy of the AO~CC surface suspension location report. It is my rec~endation to the Commission to approve the loca- tions listed below: Sag Delta %1 Sag Delta %4 Sag Delta %2A . Sag Delta %5 Sag Delta %3 Sag Delta %8 It is mY recc~mendation not to approve the following wells until the remaining WOrk be done to be accepted: Sag Delta #7 - Electrical Cable - removed Sag Delta #9 - Loose Boards - picked up Sag Delta #10'- Remove Timbers Attachments 02-001A(Rev. 10/79) Suspended Well and Location Report 20 AAC 25, ARTICLE 2 INFORMATION: n~ Address ~O.~.~-A SurfaCe inoca~i'On 0f We~l -- - ' ' Permit No. ~'~-'.~ - Ft. L, wel 1 Condition of Pad Condition of pits Well head - Ail outlets plugged Well sign - Attached to well head ,A~t~t~a ched to. .Attached to Ye s No Information correct Yes No · . Cellar - Opened Yes No Rat Hole Open Fil led Yes No. Fil led ( Y~ s ~ No CCO capped Open Explanation WaterWell - Plugged off Ye s No Ye s No Yes ~' N~i Photographs taken to verify above conditions Yes No Explanaton Work to be done to be acceptable This well and location is (acceptable) (unacceptable) to be classified as suspended for the period of 19 thru 19 . Inspected by: Revised 8/24/82 $e¢ q SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHQRAGE, ALASKA 99502 July 21, 1983 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Cc~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 1983 :IDCA~ON ' INSPECTION Dear Mr. Chatterton: In compliance with State Regulation 20 AAC 25.170, attached are Forms 10-403, Sundry Notices and Reports on Wells, for the following wells. These notices request that the wells remain in suspended status. BP 41-33-12-13 BP 22-33-11-13 Term Well B (22-20-11-13) Term Well C (34-03-11-12) , Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU MP 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP 22-31-11-13, No. 2 West Sak 25645 ~9 West Sak 25548 ~11 West'Sak 25655 #14 West Sak #16 West Sak 917 Kuparuk State 22-11-12 Sag Delta #2A (10-11-16) Sag Delta ~3 (35-12-16) Sag Delta 34633 ~4 Sag Delta #5 (.36-12-15) Sag De'tta #7 Sag Delta #8 Sag Delta #9 Sag Delta #10 Niakuk #lA (26-12-1.5) Niakuk #2A (23-12-15) Alaska Island #1 Mr. C. V. Chatterton July-21, 1983 Page Two Water Injection Well GC - lB (13-11-13) is also now ready for final inspecti°n of the abandoned well site. Please advise the undersigned which day during the w~ek of August 8th is acceptable for your field inspector to accompany our representative for this annual location inspection trip to the above-named well sites. very truly yours, R. H. Reiley District Drilling Engineer encs cc: Well Files 917 "' STATE OF ALASKA ALASKA GilL AND GAS CONSERVATION CuMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of Well At surface: 749' EWL, 1000' SNL, Sec. 04~.TllN, R16E, UPS 5, Elevation in feet (indicate KB, DF, etc.) KBE = 32.16~ A~L COMPLETED WELL [] 7. Permit No. 75-58 8. APl Number 50- 029-20176 9. Unit or Lease Name OTHER [] 10. Well Number Sag Delta #1 (33-12-16) 12. 6. Lease Designation and Serial No. ADL 34634 11. Field and Pool Wildcat (Exploration) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: Request extension under SUBSEQUENT REPORT OF' (Submit in Triplicate) 20 AAC 25.170 (b) 1,2,3 (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 wor'k, for Abandonment see 20 AAC 25.105-170). Reason for extension: This site is being considered for future Endicott Reservoir development. ApprOved Copy Returned- .~ ,JUL 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed [~ ~1~ ~~_J~ ~'''~ /£~'"18¥"~.--T i t'e District Drillinq Enqin"r The space below for Commission use R. IJ/~ Reilt'ey Date Conditions of Approval, if any: This location vms inspected by our representative on August 8, 1983 and clean up was found satisfactory for a suspended location. A subsequent inspection will be necessary by August 1984. ORIGINAL SIGNED By Order of ~. ~7.. <j~3 Approved by ~Y [0.~.~![ C.S..~.!T~ COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY SUSPENDED Kuparuk 22-11-12 Niakuk # 1-A Niakuk # 2 Niakuk % 2-A Niakuk # 3 Prudhoe Bay Unit 3-10-12 Sag Delta %2 Sag Delta #3 Sag Delta %33-12-16 Sag Delta 28337 %2-A Sag Delta 34633 %4 W..Sak 25519 %17 W. Sak 25548 #11 W. Sak 25645 #9 w. Sak 25655 #14 (GETTY, SOHIO, OPR.) State #1 PLUGGED & ABANDONED Challenge Is. 81 Niakuk #3 Prudhoe Bay Unit Nomination 1 RD Prudhoe Bay Unit TR 15-11-12 Reindeer Is. Strat Test 91 W. Sak 25667 #4 (BP/SOHIO) Kemik Unit Niakuk % 1 MEMOF \NDUM S of Alaska ALASKA OIL AND' GAS CONSERVATION COMMISSION ~.~,~~~~tert°n DATE: November 9, 1982 TO: C. FILE NO: 10 8/A Thru: Lonnie C. Smith ~/-~ Commissioner TELEPHONE NO: FROM: DOug Amo S ~.~- Petroleum Inspector SUBJECT: Inspection of Sohio's Suspended Locations Listed Below Friday, August 27,... 1982 - I traveled this date to Prudhoe B~Y' where I met Jerry segar, Sohio representative, and conducted the Second clean-up inspection on the locations listed below. Attached to this report are pictures of well heads, reserve pits,, drilling pads and a copy of the Form 10-403. I recommend to the Commission that the following locations be accepted in regard to location clean-up, well sign placement, and .pit condition. PBU MP 22-31-11-13 No. 2 Term Well ~ (22-20-11-13) Term Well C (34-03-11-12) MPC Tract Well 21-03-10-12 MPC 11-33-11-12 Getty State No. 1 (2-10-13) PBU MP 43-31-11-13 'West Sak 25645 $9 (3-11-9) West Sak 25548 $11 (36-12-8) West Sak 25655 $14 West Sak $16 (31-36-13-08) West Sak ~17 (44-26-13-09) Kuparuk State 2 2-11-12 Sag Delta $5 (36-12-15) Sag Delta $1 (33-12-16) . No pictures, ran out of film Sag Delta $2A (10-11-16) " " " " " " Sag Delta $3 (35-12-16) " " Sag Delta .$4 (34633) " " Sag Delta $7 " " Sag Delta $8 " " Sag Delta $9 ,' " " Sag Delta $10 " " MP Tract Well 32-30-11-13 " " Niakuk $1A (26-12-15) Niakuk $2A (23-12-15) Chevron Tract Well (23-18-11-12) II II II II II II II II II II II II II II Il II II II II II II II II II II II II In summary, I inspected the above listed suspended locations 'for clean-up, well signs, and pit conditions. 02-001 A( Rev.l 0/79) Suspena~d Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: · Opera~0r _ ~gP~ID_ A~~ ~.~/~U~_ ~, Date Suspended Addre s s . Surface Location of Well Permit No. ~ Ft. ~~L, /~' Ft.~~ L aPI No. 50 ~2~- Sec~, T// ~,-R~~'; ~FM-- Unit or Lease Name - ~/~ Field ~ Pool /~ Condition of. Pad ~z7!~_~%~ Condition of Pi ts Well head - Ail outlets plugged Well sign - Attached 'to well head Attached to well guard · Attached to Information correct Ye s No No ce 1 .la r - Opened Filled Covered Wat'erWell - Plugged off Yes ~ Rat Hole Ye's ~o Open Explanation Open Yes ~ Fil led ~ No Covered ~ No Photographs t,aken.~to v~e~ify above conditions Yes Work to be done to be acceptable X,///~ Explanaton This well and location-is (~acceptable_) (unacceptable) to suspended for the period of ~ F~7--~19.. thru ~-Z7 Inspected by: b~t-t'~ . ' '~~~.~ be classified as 19_~. Revi ned 8/24 / 82 SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265~0000 MAIL: POUCH 6-612 ANCHORAG E, ALASKA 99502 July 30, 1982 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcup'!ne Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: In compliance with State Regulation 20 AAC 25.170, attached are Fonns 10-403, Sundry Notices and Reports on Wells, for ~he following wells. These notices request that the wells remain in suspended status o BP 41-.33-12-13 BP 22-.33-11-13 Term Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU ~ 43-31-11-13 MPC 11-33-11-12 Getty State ~1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP 22-31-11-13, No. '2 West Sak 25645 #9 West Sak 25548 #11 West 'Sak 25655 #14 West Sak %16 West Sak #17 Kuparuk State 22-11-12 ~-~ (33-12-16) Sag Delta %2A (10-11-16) Sag Delta #3. (35-12-16) Sag Delta 34633 #4 Sag Delta %5 (36-12-15) Sag Delta #7 Sag Delta #8 Sag Delta #9 Sag Delta %,10 Niakuk #lA (26-12-15) Niakuk #2A (23-12-15) Alaska Island #1 ~.--~ ~,~ f STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL F'I OTHER~ 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of Well At surface: 74.9' EWL, 1000' SNL, Sec. 4, TllN, R16E, UPM 5. Elevation in feet (indicate KB, DF, etc.) ~RW. = 32.16' AMSL 12. I 6 . Lease Designation and Serial No. ADL 34634 7. Permit No. 75-58 8. APl Number s0- 029-20176 9. Unit or Lease Name 10. Well Number Sag Delta #1 (33-12-16) 11. Field and Pool Wildcat (Exploration) Check Appropriate Box To Indicate Nature of Notice. Report. or Other Data . NOTICE OF INTENTION TO: Re. st exl:e13s±on ul~d~ SUBSEQUENT REPORT OF: {Submit in Triplicate) 20 ~ 25.170 (b) 1,2,3 Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (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). Reason for extension: This site is being considered for future sag Delta development Clean-up to date: a) Major structures have been removed. b) Loose debris has been removed. AUG- 31 382 Alaska Oil & Gas Cons. Anchora~,e Approved Copy Eeturned 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title District Drilling Engineer Date The space be iley Conditions of Approval, if any:This location was inspected by our representative on August 27, 1982 and clean up was found to be satisfactory for a suspended loctioan. A subsequent inspec- tion will be necessary by August 1983. Form 10-403 Subm,! "lntent,ons" ,n Tr,plmate .,,~ , ~ .... r.,..., · /' ; 20 AAC 25, ARTICLE 2 FILE INFORHATION: Surface ~ocationrof Well /- Wel 1 No. 20 AAC 25.120: WEI. L ?~T HARKER: - Din. Steel Post (4'Min.) ~,O~ , Length (10 Min.) Height Above Final Grade L6vel/(4' Hin.) Top of Marker Pipe Closed with: Cement Plug Screw Cap Welds Set: On Well Head ~, On Cutoff Casing ____, In Concrete Plug Distance Below Final Grade Level Ft. in. Side Outlets: All Valves and Nipples Removed All Openings Closed ~. , With Blinds ~- , With Cement INFORHATION BI~AI)WELI)ISI) DItlI';Ci'ELY TO M.\RKI~,R POST: (List ,,~ere Di~~t from File Information) Operator ' ~/~ Unit or Lease Name Well Number , Surface Location of Well: Ft. F L, Ft., F L, Sec , T , R Other 20 AAC 25.170: LOCATION CLEAN-UP PITS: ~Pd Filled I Liners Removed or Buried , Debris Removed SURFACE OF PAD M{D/OR LOC.,\YION: Rough , Smooth l..~.~, Contoured , Flat , Compacted __ Other CLEAN UP OF t?AD AND/OR.. LOCATION: ~ 'Clean ,~/"/, Pipe Scrap , Iron Scral{ Paper , Other , Wood , Mud , Cement SURROUNDING AREA: Wooded , Brush Sand , Other , Tundra , Grass , Dirt , Gravel~..-~/ CONDITION SURROUNDING AREA: Clean ~..-~'; Trash from Site Other ACCESS ROAD: , Tree~ and/or Brush fro,n Clearing Site Dirt ., Gravel __, Ice , O, tt~er CONI)£TIONi~A~.CESS ROAD AND SURROUNI)INC: CleanN_~, Rough , Smooth , Trash'from Operations , Trees' find/or Brush from Clearing Road , Spoil from Clearing Road Other REMAINING TO BE DONE: 05/26/81 , ' -.- ~ ' -. ] No Final Inspection i OOIB ~Rev 10~;6~ STATE of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION TO: ~H°yle H. Hamilton~ Chairman ThrU: Lonnie C. Smith~ Commissioner Bobby Foster~~/~' Petroleum Inspector DATE: FILE NO: September 11, 1981 TELEPHONE NO: SUBJECT: Inspection of SOHIO ' s Suspended Locations Listed Below _Monday AugUst 31 Thru Wednesday September 2:. I traveled to prudhoe Bay Monday AuguSt 31,-1981 where I met with Jack Barr, Judy Golding and Jerry Stegar, Sohio representatives and discussed the upcoming location inspection. Attached to this report are pictures of well heads, reserve pit, drilling pad, and a copy of' surface suspension report. It is my recommendation to the commission that the following locations be accepted in regard to location clean-up, well sign placement, and pit condition. Mobil Phil lips Mobil Phil lips MObil Phil lips Chevron Tract West Sak West Sak West Sak West -Sak Mobil Phil lips Mobil Phil lips Mobil Phil lips Term wel 1 Term well Getty State Niakuk Niakuk Niakuk Niakuk Sag Delta Sag Delta Sag Delta Sag. Delta Sag Delta Sag Delta Sag Delta 21-03-11-12 11-33-11-12 22-11-12 23-18-11-12 #9 #11 #16 #17 22-31-11-13 43-31-11-13 32-30-11-13 B C #1 #1 #la #2 #2A #2 #2A #3 #4 #5 #8 In summary, I inspected the above listed suspended locations for · clean-up, well signs, and pit conditions. SOHIO ALASKA PETROLEUM COMPANY A N(;~.i()!.~A(} E. ALASKA ELF PHONE (907) 27t;5111 MAIL POUCH 0.612 ANGH()P, AGF ALASKA .99502 August 17, 1981 Mr. Lonnie Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: In compliance with State Regulation 20 AAC 25.170, attached are Forms 10-403, Sundry Notices & Reports on Wells, for the follc~ing wells. These notices request that the wells remain in suspended status. Term Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBUMP 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-13) MPTract Well (32-30-11-13) PBUMP 22-31-11-13, No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Sag Delta #2 (10-11-16) Sag Delta #2A (10-11-16) Sag Delta #3 (35-12-16) Sag Delta 34633 #4 Sag Delta #5 (36,12-15) Sag Delta #7 Sag Delta #8 Niakuk #1 (26-12-15)-abandoned Niakuk #iA (26-12-15) Niakuk #2 - abandoned Niakuk #2A (23-12-15) Niakuk ~3 (13-12-15) RECEIVED AUG ,? 198i Alaska Oil & (:';as C:,ns. Col]llllj$$iO~ Mr. Lonnie Smith August 17, 1981 Page Two We would like to have your field inspector present sometime during~ the week of August 31 - September 4 to accompany our representative for final location inspection of the follc~ing wells: Challenge Island #1. Reindeer Island Stratigraphic Test #1 West Sak #4 Kemik Unit#2 WestKuparuk State 3-11-11 Hurl State 5-10-13 Socal-Mobil 33-29E (29-12-11) Kuparuk State 33-11-12 Kuparuk 9-11-12 MPC 7-11-12 Kuparuk State '21-11-12 MPTract Well 13-15-11-12 PRJ:JLG:ja Attachments cc: Well Files CC~ 37,291 Yours very truly, P. R. Judd Manager Drilling ' ~ STATE OF ALASKA ~ ALASKA ( AND GAS CONSERVATION C¢ VIISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchoraqe, Alaska 4. Location of Well At surface: 99502 749' ~L, 1000' SNL, Sec. 4, TllN, R16E, UPM 6. Lease Designation and Serial No. ADL 34634 5. Elevation in feet (indicate KB, DF, etc.) KBE = 32.16' AMSL 7. Permit No. 75-58 8. APl Number 50-029-20176 9. Unit or Lease Name 10. Well Number Sag Delta ~1 (33-12-16) 11. Field and Pool Wildcat (Exploration) 12. Check Appropriate BoX To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: Request extension under (Submit in Triplicate) 20 AAC 25.170 (b) 1,2,3 Perforate [] Alter Casing [] ~ Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing {Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 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). Reason for extension: This site is being considered for future Sag Delta development. Clean-up to date: a) Major structures have been removed. b) Loose debris has been removed. RECEIVED AUG 2 6 1981 Naska 0il & Gas Cons. Commission Anchorage ,, Approved 0:.~¥ Returned 14.1hereby~if~t~i~nd~:rect to the best of my knowledge. ~_ /~/?~./~/- ~ Signed t! v v ~ '~ '-'--'--~\ TitleDistrict Drillinq Engineer . The space below for Commission use R. 'H. P~!~ley Date Cond,t,ons of Approval ,f any ~z~l.l-S SUS nded lo :L " ,' : ' pe ca'c'on was inspected' by ou~¢~representative on 9/1/81 and the clean-~o was fou~cl 'co be acceptable. Ap~oval is given ~Vt~e pi'cs oE~n, the well head on, a gravel stockpile in c~eration, and ~he cellar open. This approval is given until 9/1/82. A subsequent inspectiQ~ will be necessary by mid-summer 1982. ORIG,NA~ $IGN£I~'~ By Order of Approved by ' .,, ,n,,,:~r ~ ~,~T[; COMMISSIONER the Commission Date / Form 10~,03 t~! LU[~C I~. ,,)ia)~m~ Submit "intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate June 4, 1981 Sohio Alaska Petroleum Company Pouch 6-612 Anchorage,. Alaska 99502 Re: Alaska Oil and Gas Conservation Commission ~Regulations Article 2, ABA~DO~ENT AND PLUGGING, 20 AAC 25.120 ~LL ABANDONMENT ~ARKER and 20 'AAC 25.170 LOCATION C~EAN UP. Gentlemen: In regard to the above referenced 'regulations, your attention is called to an attached list of wells which, according to our records, have not received~ a final location inspection and approval of clean up. In complianCe with 20 AAC 25.170 Section (a), "Within one year of suspension or abandonment of an on- shore well", all clean up work is to be finished. Section (b) provides the means for an extension of time if a valid reason exists. Section (c) provides for on site inspection. Consequently, we are presenting the following list of your abandoned and/or suspended wells. ~any of these are now more than one year old and are not in compliance with regulations. Others should have the final inspection completed this su~.]mer while weather permitS. This list covers the years 1975 to date. There may be some earlier %.~ells that also need inspec- tion. if you have any earlier wells to be inspected this summer please inform us. Therefore, we are requesting a schedule from you for this sumner when our field inspectors can accompany your representa- tives to these sites for the final clean up inspection. Yours truly 'Lonnie CL Smith Commi s sione r LCS/JKT:t~ AUgUSt 27, 1979 B.P. Sa~ Delta No. 1, Sec. 33, T12N, RZ6E, Noxth Slope, Alaska Mobil Oil ~tion P.O. B~x 5444 Denvar, Colorado 80217 Dear Bill~ Pursuant to. our August 22, 1979 discussion, pezmission is hereby granted to Mobil Oil Cor~orat/on to ma~ ~lxur/mately I cc. ~s from ~ foot of the State's set of core ~ps at the depths of 9459', 9470~, a~d 9553' ~n the subject well for the ~ of ~ing thin sece-to~. As we have noted, there is sufftc/ent quanti~ of mater~al in the State l~azy set of these Very truly yours, William V~-~ Alert Petrole~ G~olo~i~t July 18, 1979 ~r. Ma~k ~~ citi~ S~vice Ca~my ~xpl. & Prod. ~mear~ Box 50408 Tulsa, Oklahca~ 74150 ..... ' ..... 9324"-(a)! 9459'i '-9470 ~ 9755 B.P. Niakuk %1 ..... 1~,64,,0~ - Sinoer~/y, William Van Alen Petroleum Geologist OIL ~ ~ C~~"~ ~SSl'C~ A~O~(~ ~~ 99501 80202 336 334 BP~ %1 9284 ~-9875 ~ 9000'-9400' 10,100'-10,600' 10,700'-14,400' 9000'-9600' 10,400-11,635' 9300'-10,900' Very tz~aly yours, Wi~ van Alert P~ SOHIO PETROLEUM COMPANY Division of Sohio Natural ReSOurces Company SOHIO-BP ALASKA PRODUCTION DIVISION 3111 'C" STREET ANCHORAGE, ALASKA TE LEPHON E (907)265-0000 MAI L: P. O. BOX 4-1379 ANCHORAGE, ALASKA 99509 TO: Mr. Hoyle Hamilton State Division of Oil & Gas 3001 Porcupine Drive Anchoragev Alaska May 25, 1978 REFERENCE: BP SAG DELTA (33-12~16) The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- (1) copy of Table 2 & 3-Summary of Tests on Inte~als 1-4 for the above referenced well. · Betty Hedstrand RECEIVED DATE TABLE 2 BP WELL SAG DELTA (_33-_1~2-t6) SUMM~\RY OF ~TESTS ON INTERVALS 1 - 3 Reservoir' Test ~ Flew Length of Pressure I Interval[ Test FI:ow [?_e~riod IBHCelP t Gradient FBHFP FWHFP FBHSiP ' ' Number No. Date Hours Mins. ~ ~ .]2 si_.g/_f t___ _ p_si,~__ ps~i_g ...... psig~. Maximum BHT '~F.' Produced Fluids 1 ~ 1-A I 4-10-76 2 00 NA ! NA NA 0!tNA 188 @ 10,140' BKB i No recovery i i-B 4-10-76 to 4-11-76 7 30 NA NA NA 0 NA NA Diesel contaminated with ~ , . small to measure. i 2-A 4-12-76 to 4-13-76 25 15 .4895' 0.513 4018' i 0 NA ~ - Mostly oil with some water I ~ '~ i I at rate too small to I 2-B 4-13-76 to 4-14-76 23 35 - - 4015' 0 4238* 181 @ 9850' BKB 50_+% oil (25.4 - 27.5° AP1) i I + 50.+.% formation water/ ~ I I i spent acid at rate too ~ I i ............... t ............. . ........ small to measure. _ _ i 3 i 3-A i 4-17-76 15 02 4815+ 0.515 I 4470+ I 0 4584+ 175 @ 9655' BKB 5+% oil + 95+% formation ! ~! I , I water/spent acid at' rate ~ ..... I ...... I J i ~ . ,! .... too small to measure- .. * ?4easured at 9845 ft. BKB (9544 ft. TVD SS). + }~easured at 9644 ft. BKB (9349 ft. TVD SS). Anohora~e TABLE 3 ~_Pi~WELL SAG DELTA .(33-12-16) SUMbI~RY OF TESTS ON INTERVAL NO i~ 4- Flow [ Test ~ ~o. (i) i Date 4-A ~ 4-21-76 to 14-22-76 Time 1013-1410) 1410-0137) I 4-B-i i4-22-76 to 1929-0002) i 4-23-76 0002-0205) 4-B-2 14-23-76 to 1535-0401 I~,/'-24- 76 I 4-B-3 14-24-76 to i 4-25-76 ~-26-76 J-B-4 4-B-5 [4-27-76 to !4-29-76 Length of 'F!ow Period 15 I_ 24 6 t 36 ' i 12 26 1913-2121) 2121-0113) 12 0113-0713) 0930-2131) 16 ;2131-0200) 00 30 iBHCiP I Choke psig . _I 64ths 4576 (2) Vario~ NA 4469 4470 4442 40 530 Va~ous - 40 1317 30 1431 44 1313 40 1376 36 1390 44 1378 30 1390 , Average ~HFP t Rat e - t NA 2626 t i 1462 I - I NA NA I 71.00 4304 D 4229 D 4145 D 4109 D 2746 NA 6877(5) 4779 7877(6) 2302 4372 2O Average ' · S~P'-..SCFfSeP-' BBL. NA '288-471 NA NA 134 NA 286 . . 175 177 after Flow Period PPig_ 4548 after SI 12 ,iho:~.rs_, 06 rains. 4469 after' SI 13 'hours~ 25 mins. 4470 after SI 15 hours, il mins. 4442 after S! 26 hours, 17 mins. 3996 D 454 4124 I 756 175 4372 after SI 17 ho~r~ ~00 mins. Conditioned well at very low rate before and.during bottom-hole sampling. · (1) A = Pre Acid; B = Post Acid Test (2) Initial reservoir pressure gradient (TVD subsea) = 0.494 psig/ft. This IBHcIP was recorded at 9549 ft. BKB (9257 ft. TVD SS). (3) I' Increasing; D = Decreasing Bottom-hole pressure measured at 9549' BKB (9257 ft. TVD SS), (4) Temperature at 9560: E, KB (5) Rate ~ start of period = 7450 sep. bbls./D. Rate @ end of period = 5590 sep. bb!s./D. (6) Rate :'? start of period = 9380 sep. bbls./D. Rate @ end of period'= 6700 sep. bbis./D. ~=5 GOR ~'~n~ct due to li~qid carryover into orifice differential recorder lines. ~,1 · ,. ,-- ~ ,~veraqe' ~r-ield-measured oil gravzty' = 28.1© AP1 ,,q. 60° F. w/trace water. Ficid-measurod bubble points of bottom-hole samples = 3840 - 3920 psig @ approximately 65° F. RECEIVED . Anchorag~ BP ALASKA INC. CONFIDENTIAL P.O. BOX 4-1379 3111 - C - STREET ANCHORAGE, ALASKA 99503 TELEPHONE {907) 279-0~44 June 10, 1977 State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Hoyle Hamilton, Director Gentlemen: Well Number: BP Sag Delta #1 (33-12-16) Enclosed please find in triplicate, Form 10-403, Sundry Notices and Reports on Wells, for the above named well. This report contains our proposal to perforate the well. / Very truly yours, BP ALASKA INC. Manager Operations Enclosures cc: Drilling Well Files: Sag Delta #1 #17 P.E. Well Files: Sag Delta #1 RECEIVED Form 10-403 REV. 1-10-73 Subml t "I ntentlons" in Triplicate & "Subsequent Reports" tn Duplicate ~"~NFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OIL r~ GAS D WELL l.J~l WELL OTHER NAME OF OPERATOR BP Alaska Inc. 5. APl NUMERICAL CODE 50-029-20].79 6. LEASEDESIGNATIONANO$ERIALNO. ADL-28337 surface ADL-24634 subsurface 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME 3. ADDRESS OF OPERATOR ~ 9. WELL NO. P.O. Box 4-1379, Anchorage, Alaska 99509 Sag Delta #1 (33-12-16) 4. LOCATION OF WELL At su trace 4, TllN, R16E, UPM 749' ENL, 1000' SNL, Sec. 13. ELEVATIONS (Show whether DF, RT, GR, et~) KB 32.16 AMSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Wi] dcat ....... 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 33 T12N R16E, UPM 12. PERMIT NO. 75-58 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING g-.._J FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF= WATER SHUT-OFF ~ . REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) FLOW w~11 (NOTE; Report results of multiple completion on Well Coml31etlon or Recompletion Repo~ and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state ali pertinent (retails, ancl give pertinent dates, including estimated date of starting any pro.posed work, Feb 28-Mar 5, 77 Moved t° location and rigged up. Recovered PXN plug from 9126 ft. BKB. Mar 6 Mar 10 Mar 15 Mar 17 Mar 18 Mar 20 Mar 21 RIH with Hewlett Packard and Tandem Amerada gauges. Opened well to flow, 40/64ths choke, turned into ARCo separator Flowed well for 96 hours. Closed well in for PBU Ran spinner flowmeter and temp. tools Turned well into separator to check G0R Closed well in, ran temp. log across perf. intervals. Attempted to set PXN plug - did not set - weather deteriorating. Ran PXN plug and prong into XN nipple @ 9126 ft. BKB. Installed Cameron BPV in wellhead. Rigged down all surface equipment. Cleaned up location. Re-test of well completed. 16. I hereby certify that the foregoing is true and correct SIGNED (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE ....... DATE See Instructions On Reverse Side STATE of ALASKA To: F- FROM: 3.14 .500.41 }byle ]~milton, Director Division of Oil ar~C~s D^TE , March 31, 1977 Pedro Denton Chief, Minerals Section Sag Delta-No. 4 (36-12-16) F~LE: Enclosed are copies of letters from BP AlaSka Inc., requesting production certification of Niakuk Well #2A and Sag Delta #1 well. Please confirm whether these wells are capable of producing in paying quantities. Also enclosed is a copy of a BP letter dated March 30, 1977, inf~ us of drilling operations 'being ool~ucted on lands covered by a lease whose primary 'term ends March 31, 1977. May we have your confirmation of this so we may proceed accordingly? RECEIVED A["it "4 le77 Divisie~ r,[ 0;1 a;~,d (:::~ ¢on:~,qrvatlon bP ALASKA INC. 3! ! 1 - C - STREET · TELEPHONE {907} 279-0644 MAILING ADDRESS: P.O. BOX 4-1379 ANCHORAGE. ALASKA 99509 March 30, 1977 Assistant Commissioner and Director Division of Lands Department of Natural Resources 323 E. 4th Avenue Anchorage, Alaska 99501 Attn: Mr. O.Ko Gilbreth, Director, Division of Minerals and Energy,Management RE: State Lease ADL 34634, BP Alaska Sag Delta ~1 Well (33-12-16) Dear Sir: On March 6 and 7, 1977 the referenced well, bottomed and completed on the referenced lease, was tested successfully and produced hydrocarbons in excess of that required to establish it as a well capable of producing oil or gas in paying quantities. The test was witnessed by.Mr. Ben Lenorman_j Inspector for the Division of Oil and Gas Conservation, and Mr. Russ Douglas, Petroleum Engineer for the Division of Oil & Gas Conservation. We hereby request that the records of the Division be amended to reflect that the referenced lease is now held by shut in production as provided in the terms of the lease and in the regulations of the Department, 11 AAC 83.135. RCH:lpb Very truly yours, Roger C. Herrera Exploration Representative ./ RECEIVED DATE:,. RECEIVED APR - 4 1977 02~)01B STATE of ALASKA DEPARTMENT OF NATURAL RESOURCES Division of 0ti and Cas Conservation TO: Director Chief Petroleum Engineer FROM: Russell A. Douglass Petroleum Engineer DATE : March 15, 1977 SUBJECT: Paying quantities flow test, BP Sag Delta #1, 33-12-16 Monday, March 7, _19..77 - Tra~!.ed.. to Prud.ho~, Bay.to take over field inspection clUtl'e~'-f6i~ Ben LeNorman. Pu~se of my tr~p' was to witness flow testing of BP Sag Delta #l well 33-t2-16. Ben had already collected a day's data and BP's well testing program. I confirmed Ben's data and made mY .own. observations. Since the results are confidential, they are ftled in a s.eparate report in one of our bank safe deposit boxes. ~i~n....s~ry_: i witnessed flow testing of BP's Sag Delta #1, 33-12-16. BP ALASKA INC. STRICTLY CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Hayle Hamilton, Director P.O. BOX 4-1379 311 I - C - STREET ANCHORAGE. ALASKA 99503 TELEPHONE [907) 279-0644 Gentlemen: Well Number: BP Sag Delta #1 (33-12-16) Enclosed please find, in triplicate, Form 10-403, Sundry Notices and Reports on Wells, for the above named well. This confirms the discussions between yourself and Mr. Plisga in January regarding the testing program for this well. Very truly yours, BP ALASKA INC. ,~r. G. D. Taylor Manager Operations Enclosures cc: Drilling Well File #17 P. E. Well File RECEIVFD FEB ~ 5 1977 D:,visicn of Oil and G~:.',:.s Cop. se, rv~tion Anchora2e Form~l 0-403 REV. 1-!0-73 Submit "Intentions" in Triplicate & "Subsequent Reports" In Duplicate STRICTLY CONFIDENTIAL STATE'OF ALASKA' OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form' for proposals to drill or to deepen - Use "APPLICATION FOR PERMIT--" for such proposals.) 1, OIL ~ GAS ~ WELL~ WELL I._.J OTHER Wildcat · 2. NAME OF OPERATOR BP Alaska Inc. 3. ADDRESS OF OPERATOR P.O. Box 4-1379, ,Anchorage, Alaska 99509 4. LOCATION OF WELL At surface 749' ENL, 1000' SNL, Sec. 4, ~llN, R16E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc.). KB 32.16 AMSL Check Appropriate I~ox To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20176 6. LEASE DESIGNATION AND SERIAL NO. Al)I. 28337 Surface Al)l. 34634 Subsurface 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8, UNIT, FARM OR LEASE NAME 9. WELL NO. Sag Delta (33-12-16) 10. FIELD AND POOL, OR WILDCAT Wlldcat 11. SEC., T.. R.. M., (BOTTOM HOLE OBJECTIVE) Sec. 33, T12N, R16E, UPM 12. PERMIT NO. , 75-58 ~ort, or Other Data. NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L-----J FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) ]Flow Test PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results, of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any pro. posed work. Remove back-pressure valve from'well-head. Recover down-hole blanking plug. Run pressure-guages. Flow well through separator for 4 days at approximately 5000 STB/D -SI well and monitor pressure build-up for 6 days. Recover guages. Run spinner flowmeter'with well flowing at 5000 STB/D. Run PX plug in "X" nipple at 9126' BKB,' Bleed off wellhead pressure to zero psi. Install back pressure valve in .tubing hanger. Estimate total oil to be flared: = approx. 22,000 STB Estimate test program to start March 1, 1977 16. I hereby certlty that tho foregoing Is true a.d correct CONDITIONS O~APPROVAL, IF ~NY~- - ~/' ~ Appr~ed Copy Returned ~e Instructions On Revere Side ~_.~ ~ . ~, ¢/ /J-~ o ~/0o Form No. P-4 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS (:ONFIDENTIAL 5. AP! NUMERICAL CODE 50-029-20176 6. LEASE DESIGNATION AND SERIAL NO. ADL. 28337 Surface ADL 34634 Subsurface WELL WELL OTHER Wildcat 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME BP -Alaska Inc;. 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 4-1379, Anchorage, Alaska 99509 Sag Delta (33-12-16) 4. LOCATION OF WELL 749' EWL, 1000' SNL' Sec. 4, TllN, R16E, UPM 10. FIELD AND POOL, OR WIL~AT Wildcat 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 33, T12N, R16E, UPM 12. PERMIT NO. 75-58 13. REPORT TOTAL DE~H AT END OF MOTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DE~H SET AND VOLUMES USED, PERFORATIONS, TESTS AND R~ULTS FISHING JOBS JUNK IN HOLE AND SIDE~RACKED HOLE AND ANY OTHER SIGNIFICA~ CHANGES IN HOLE CONDITIONS. February, 1976 Set 20" 94# H-40 conductor at 90' BKB and'installed 20" 2000 psi diverter system. Spudded well 0600 hrs., February 3, 1976. Drilled 18-1/2" hole to 2745' and ran open hole logs Ran and cemented 13-3/8" ~ · '72#AN-80 Buttress casing at 2731' with 4164 cu. ft. Arcticset cement. Removed 20"diverter systemand installed 13-5/8" starting head and 5000 psi BOPE. Directionally drilled 12-1/4" hole to 9071'. Ran multishot survey andopen hole logs. Drilled 12-1/4" hole to 9161'. Ran 9-5/8" 47# Buttress casing to 9132" and hung as liner with top of PBR a '. (Soo-95 9132' - 8242' and~N-80 8242' - 2063') Cemented with 1275 cu. ft.~/of 12.4 ppg Litepoz 300 cememt, and 250 cu. ft. 16 ppg Class "G" cement. Squeezed 9-5/8" by 13-3/8" liner lap with 525 cu. ft. Arcticset cement. Pressure tested casing and lap to 3000 psi. SIGNED -- TITLE Manager Operations DATE NOTE--Report on this form is req~uired for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. BP ALASKA iNC. 31 ! I : C - STREET · TELEPHONE (907) 279-0644 CONFIDENTIAL MAILING ADu~ES$= P.O. BOX 4-1379 ANCHORAGE, ALASKA 99509 May 28, 1976 State of AlaS~m Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 · Attention: Mr. 0. K. Gilbreth, Director 1976 Gentlemen: BP Well Sag Delta (33-12-16.) Enclosed please find in duplicate Form P-7, Well Completion or RecOmpletion Report and Log, for the above described well. Also enclosed are: CNL/FDC BHCS CBL DIL 1. Well History 2. S;,mmary of Testing Operations 3. Mud Log (Baroid) 104 - 10,216 ft. 4. Directional Survey 5. Core Data 6. Core Chips 7. Dry Samples, one set from 104 ft. to 10,216 ft. 8. Electric logs, one each, print and sepia Scale Interval 5" & 2"* 10,093 - 9156 5" 10,085 - 9155 Scale Interval 5" 10,089 - 9156 5"'& 2"* 10,216 - 9159 5" 10,168- 8400 5" & 2"* 10,216- 9159 5" & 2" 2392 - 98 5" 9059 - 6800 5" 9058 - 6500 5" & 2"* 5" & 2" 5" & 2"* 5" & 2" 10,098 - 9156 9058 - 2722 10,096 - 9160 9058 - 2722 * On same film. Please sign in the space provided below to confirm receipt. RH:vJy Enclosures cc: File Sag Delta ~17 Very truly yours, BP ALASKA INC. Manager Operations Received by: Date : BP ALASKA INC. 3111 - C - STREET · TELEPHONE (907} 279-0644 MAILING ADDRESS: P.O. BOX 4-1379 ANCHORAGE, ALASKA 99509 May 13, 1976 CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. O. K. Gilbreth, Director Gentlemen: S_ag Delta (33-12-16) Enclosed please find in duplicate, Form P-4, Monthly Report of Drilling and Workover Operations for the above mentioned well for the month of April, 1976, Very truly yours, BP ALASKA INC, JFV:vjy Enclosures cc: Well File Sag Delta #17 Mr. Roger Herrera G. D. Taylor Manager Operations 1976 DIVISION OII Oti. ANO GAS ~n'n No, ]0NF IDENT IAL STATE Ch' ALASKA SUSMrr IN DUPLICAT~ OIL AND GAS CONSERVATION CO/V~IT-rEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WKLL __ WELL 2. NA/~E OF OP]~RATOR BP Alaska Inc. ~. ADD~ESS oF opntAToa Wildcat P. O. Box 4-1379, Anchorage, Alaska 99509 4. LOCATION OF W Surface: 749' EWL, 1000' SNL, Sec. 4, TllN, R16E, UPM. AP1 NI.~{ERICAL CODE '" 50-029-20176 LEASE DESIGI~ATION AND SERIAL NO. ADL 28337 Surface ADL 34634 Subsurface ,$ ,NmA~, ^~OTrEE O~ TmSE 8. L,~IT F~'iAI OR LEASE NA~E 9 WELL NO Sag Delta (33-12-16) lO FI~T .D A_ND POOL, OR WILDCAT Wildcat I1 SEC, T., R., M.. (BO/TOM HOLE oaz~mv~ Sec. 33, T12N, R16E, UPM 12. PERMIT NO 75-58 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA_NGES IN HOLE SIZE. CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLLrMES USED. PEP,.FOHATIONS. TESTS AND RESULTS FISHING JO]~ JUNK LN HOLE AND SIDE-TI~ACKED HOLE A2CD A2~Y OTHER SIGNIFICANT CHANGES IN HOL~ CONDITIONS. April, 1976 Cored 10,111' to 10,216'. Logged 8½" open hole. Ran 7" 29# N-80 Buttress liner. Shoe at 10,214'. Top of hanger 8613'. Cemented with 415 cu. ft. Class G. Tested lap to 3000 psi. Ran DST's as per table below. Zones were isolated with bridge plugs after testing at 9674' and 9570'. The well was completed with 4½" 12.75# N-80 tubing. Packer set at 9095', and wellhead installed. Perforated 9555' to 9424' and flow tested well. Well suspended with 100' of diesel in tubing annulus. Set plug in packer tailpipe. Tubing topped with diesel. Released rig at 1200 hours, May 1, 1976. Interval Tested Packer at Acid 10,145'/10,001' 9930' 96 bbls. 9,821'/9,691' 9620 144 bbls. 9,627'/9,583' 9485' - 9,555'/9,424' 9095' 250 bbls. MAY ! R 1976 OMSION OF OIL AND GAR CONFID.SNTIAL STATE OF ALASKA COPY ,, Manager Operations ~ 1~ '7 ~ SIGNED TITLE DATE L~t ~. 'rav ~or - ~ . NOTE'--Rel)ort on this form ~$ required fo~ .each calendar monthS regardless of the status of operations, and must bo filed in duplioale with the oil and gas conservation committee by the 15th of the succeeding month, unless otherwise directed, '.-' ..... '" STATE OF ALASKA OIL AI~D GAS CONSERVATION WELL ON RECOMPLETION la. TYPE OF WELL: OlLw ELL ~] GAS,¥ ELL [] DRY [] b. TYPE OF COMPLE~ON: WELL OVER EX BACK EE~VR. Other Suspe_nded 2. NAME OF OPERATOR BP Alaska Inc. 3. ADDRESS OF OPERATOR P. O. Box 4-1379, Anchorage, Alaska 99509 4. LOC^r[ON OF WELL (Report location clearlE and in accordance with amy 8tate requirements)' ~t~R~e 749' EWL, 1000' SNL, Sec. 4, TllN, R16E, UPM ~ top prod. interval reported below At total depth 652~ EWL, 911~ NSL, Sec. 33, T12N, R16E, UPM C 0 N'F'I'D'E'N'T'I'A L APl NU1VLF. PAC~ CODE 50-029-20176 6. It,~i, SE~D~IC~I~i~A"~ON t~ND SER~L NO. , ~ zo~/ ~urrace ~L 34634 Subsurface 7. IF INDI~, ~O~E OR TRIBE N~ 8. UNIT,F~{ OR L~KME NAME 9. W~L NO. ~6~.) Sag Delta (33-12- 10. F~ ~D POOL. OH Wildcat 11. SEC.. T.. R., M., (BOSOM HO~ O~E~IVE~ Sec. 33,"Ti2N, R16E, UPM 12. PEP,~ilT NO. 75-58 2-3-76 4-3-76 4-28-76 KB 32.16 AMSL ~pprox. 8.5' AMSL · I~O~V i~L'~iWY* ROTARY TOOLS CABI,E TOOLS (9906' TVD SS) J (9276' TVD SS) - All - 22.PRODUCING !NT-~E~VAL(S),OF THIS COMPLETIO~N--TOP, BOTTOM. NAME (MD AND TV'D)' ,23, ~VAS DIRECTIONAL ! SURVEY MADE None. ! Yes. 24. T~PE ELECTRIC AND OTHI~P~ LOGS RUN 8½" Hole - P/ML, HDT, CNL/FDC,' BHc's, CBL, DIL. 20" 94 13~" 9~_,, 7" 26. 72 47 ' 6~SING'RECORD (Report all strings set in w;ll) , ,[ [ G ,iR~DE: DEPTH SET (1VLD} HOLE SIZE IH-40 ! 90' 24" I 27n' N-80 I 9132/ ~09' 12~" 8~" 9555 - 9424 ft. BKB @ 2 shots per foot. (9261 - 9134 ft. TVD SS) Il IIII I 30. PR. ODUcT!ON Intermediate logs: DIL/SP, BHCS/GR, HDT. l~ i ! i , ........... CEMLNTING RECOI~D i 4164 CF _ 1525 CF 385 QF 27. SCi'tEEN (~¢D) / SIZE i A?.¢OUNT PULLED i i i i i i i ii TUBING RES O~LD DEPTH SE/' (51D; ; PACKER SET (P/iD) i ' DATE FIRST PIIODUCTION [ FrP, ODUCT1ON MEI[-[OD (Flov.'ii~g. U.a$ Ii*rt. pumping--size and type of pump, DATZ OF T~ST, OI~BEL. G~X~A'ICF. FLOXV. TUBING CA~L~qG PRESSURE [cAI.C~T~ OI~B~L. 31. O~SPOS~TmN or oas (Sold, u, ed for ]u~l, vented, etc.) ' ' 32. LIST OF ATTACHMENTS (1) Details of Well Logs, (2) Well Logs, (3) Well History, i V, ELI. JYl'A'I'US ( Producing or ]\VATER--2BL. ] OAS-O~L R.xTIO WA~--BBL. lO1L GRAVITY-~I (CORR.) 1 ITE~T WITNESSED BY (6) Sum~ry of Testing Operations · 23.1SiGNEDhereby certifyg~,_that ~and attached informationo, '"fa}rio r I~/_ TITLEI" complete and eorreetManager 0perationsaS determined f rom 'all-~ ~:all able D.a'r ~.:~"~a~ ............. $~~~ ~ i i ii i L · (See Instructions .n~ S~ce. ~o, A~ifio.~' D:,~ on Rev,fsi FIDENTIAL " ...... 0F A!_AS COPY INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and: log. on, all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise showrfl for depth measure- meats given in ather spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc, praduction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prc. Jucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the intervol reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the.~diditional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this...well should show the:details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~l. (See'instruction for items 20 and 22 above). a4. SUMMA. R¥ OF ~ORMATION "TESTS iNCLuDIN(;' IN'I'E~VAI~ *'F,~TED. PI'IF-,SSUIrtlg DATA. AI'qI)'R,F, CO'VE'RIES" OF OIL. ~AS. ' ..... WATEr( AND MUD · N.~ BKB SUBSEA .... :. :, Tertiar_z Sagavanirktok Fm Surface Surface See attached Summary of Testing Operations. . ~ Upper Cretaceous .... ( Colville Group 5347 5226 Ii Top Shale Sequence 7528 I'Lower Cretaceous · ................. 'HRZ' 9020 38. COn. E DATA. Aq~'ACI! BR1~. D~q~;~4~ONS OF.~ hlTHOI~OGY. PORO,~HTY: FRAcTuRES.~ A~~' ~-P~ : DETAILS 0F CORES T~N ~'m~m~n m,ows o~ om. ~: o~ wA~: - Mis sis s ippian ~ .... ~8 ~it Recov~rYl9 % R~co~er.v100% - ~ 9252-9811Interval Ft RecoverY59 ~ %: R~coverY100%. .Lisburne Gp. - 9276 ' 8990 ~_9218-9253 35 100% ~ '~12 9811-984~ '~ " 100% 3 92~3~9286 ...... 33- f00% - #13 ..... 9845-98'75 _ 30 "' 100% '-- T.D. 10,216 9891 % 92s6-934 .... g5 ooz 9s -99 2 ..... - ooz- 5 ·_37 :i '#i5 ..... 993 _9990 - 5s ........ ooz , 6 9493-9553 60 100% #16 9990-9997 6 86% 7 9553-9-~97' 44 .... 100% #17 9997-999~ ....... 1 .... 100% .... 8__9597-9657 -- 60' ~'00% ~lfi- 10,0~4-10,~6 -- '51 ~' 98% ~ 9_ 9657'97'1~ ..... 60 100~ #19 10. 096L']~, 156 6U ...... ]00% O 971 5-q759 ~7 1 ~ t~9~ lb' I g~_l h' '01 ~ ga 1 mat ....... #~ See attachment for further details. C Om F I DENT IAL Febru_ary,~ 1~7~. WELL SAG DELTA (33-12-16) Set 20" 94# H-40 conductor at 90' BKB and installed 20" 2000 psi diverter system. Spudded well 0600 hours, February 3, 1976. Drilled 18-1/2" hole to 2745' and ran open hole logs, Ran and cemented 13-3/8" 72# N-80 Buttress casing at 2731' with 4164 cu. ft. Arcticset cement. Removed 20" diverter system and installed 13-5/8" starting head and 5000 psi BOPE. Directionally drilled 12-1/4" hole to 9071'. Ran multishot survey and open hole logs. Drilled 12-1/4" hole to 9161'. Ran 9-5/8" 47# Buttress casing to 9132' and hUng as liner with top of PBR at 2063'. (Soo-95 9132' - 8242' and N-80 8242' - 2063'). Cemented with 1275 cu. ft. of 12.4 ppg Litepoz 300 cement and 250 cu. ft. 16 ppg Class "G" cement. Squeezed 9-5/8" by 13-3/8" liner lap with 525 cu. ft. Arcticset cement. Pressure tested casing and lap to 3000 psi. March.:, 1.976 Drilled out 9-5/8" shoe and pressure tested to 0.7 psi/ft, gradient. Drilled 8-1/2" hole to 9199'. Cored from 9199' to 9346'. Reamed and drilled 8-1/2" hole to 9456'. Cored from 9456' to 9597'. Performed drill stem test of interval 9132' - 9597' with packer set at 9117' in 9-5/8" casing with 2000-ft. water cushion. Cored from 9597'- 9998'. Drilled 8-1/2" hole to 10,044'. Cored from 10,044' - 10,096". Ran Schlumberger logs. Cored from 10,096' to 10,111'. Apri!~:,_~9.76 Cored 10,111' to 10,216'. Logged 8-1/2" thole. Ran 7" 29# N-80 Buttress liner. 8hoe at 10,214'. Top of hanger/8613/. Cemented with 415 cu. ft. Class "G" s t · Te ted lap to 3000 psi. Ran DST ~ as/per table below· Zones were isolated with bridge plugs after testin~-~ft 9674' and 9570'· The well was completed with 4-1/2" 12.75# N-80 tubing. Packer set at 9095', and.wellhead installed· Perforated 9555' to 9424' and flow tested well·. Well suspended with 100' of diesel in tubing.annulus· Set plug in packer tailpipe. Tubing topped with diesel. Released rig at 1200 hours, May 1, 1976. Interval Tested Packer at Acid 10,145'/10,001' 9,821'/ 9,691' 9,627'/ 9,583' 9,555'/ 9'424' 9930' 96 bbls. 9620 144 bbls. 9485' - 9095' 250 bbls. CON, IDEN tAL OF AIASKJ COPY { !AY 3 ? 1976 CONFIDENTIAL S~IRARY OF TEST'I'~~OSS~'A~ SAG DELTA ~1 ~33-12-16) March 12, 1976 March 13, 1976 March 14, 1976 : RIH with DST tools to test the open-hole interval from 9132 - 9575 ft. BKB. : Opened well for initial flow period of 7 mins. followed by an initial shut-in period (IFP = 3789 psig, ISIP = 4498 psig at 9147 ft. BKB). Opened well for 2nd flow period. Flowed oil and gas to surface at an average measured rate of 4350 sep. bbls./day with a GOR of 1950 scf/sep, bbl. (FFP = 3~78 psig at 9147 ft. BKB). CI to record PBU. (FSIP = 4503 psig). : POH with DST tools. End of initial testing operations. April -9 - 11, 1976 : RIH with test string. Perforated the intervals 10,145 - ............ ., 10,129, 10,127 - 10,117, 10,113 - 10,086, 10,068 - /~./ 10,054, 10,048 - 10,040, 10,033 - 10,021 and 10,009 - % ......... 10,001 ft. BKB (open-hole sonic log reference) @ 2 SPF. Zero WHCIP on drill pipe after perforating. RIH with pressure gauge assembly to record BHCIP (BHP = 3513 ~ psig at 10,135 ft. BKB). Established an injection rate and pressure with diesel and opened the well to flow, WHFP zero psig with'a very small back flow of diesel. stimulated the perforated interval With 96 bbls. HC1 acid (28%). Opened the well to flow, WHFP zero psig with a very small backflow of diesel. Within 7½ hours the well was dead. Reversed out drill pipe volume (20% spent acid, 80% crude oil/diesel mixture). April 12 - 14, 1976 : :Reset packers and perforated the intervals 9821 - /~:~77.~ 9782, 9726 - 9691 ft. BKB (open-hole sonic reference) ~Y } ~ @ 2 SPF RIH with pressure gauge assembly (BHCIP = 4894 psig). Opened well to flow, WHFP zero psig with a very small backflow of diesel. POHwith gauge assembly. Collected a bottom-hole sample from 9686 ft. BKB and closed-in well. Reversed out drill pipe volume (35% diesel, 18% crude oil/diesel mixture, 32% crude oil, 15% CaC12 contaminated with oil/gas). Stimulated the perforated interval with 144 bbls. HC1 acid (28%). Opened the well to. flow. Flowed back diesel followed by crude oil/acid/water mixture (approximately 50-50), WHFP 110 psig declining to zero psig after 20 hours. CI for PBU. (FBHCIP = 4015 psig, BHCIP = 4240 psig at 9854 ft. BKB.) Reversed out drill pipe volume. (12% crude oil, ~88% formation:::wate~.:co~tamin~t~d'.with Spent ~cid.~}i~'~:PO~i:~wi~-h'tesi~ string. CONFIDENTIAL SUMMARY OF TESTING OPERATIONS AT SAG DELTA #1 ~3~!.2_.-16) - (Continued) April 15, 1976 : Set Howco 'EZ' drill bridge plug @ 9674 ft. BKB. April 16 - 18, 1976 : RIH with test string. Perforated the interval 9627 - 9583 ft. BKB (open-hole sonic log reference) @ 2 SPF. RIH with pressure gauge assembly (BHCIP = 4815 psig ~ at 9644 ft. BKB). Opened well to flow, WHFP zero psig with a very small backflow of diesel. Closed-in well and reversed out drill pipe volume (28% crude oil and diesel, 72% crude oil cut water). POH with test string. Set Howco 'EZ' drill bridge plug @ 9570 ft. BKB. April 19, 1976 : Set production Pac'ker and tailpipe assembly @ 9095 ft. BKB. April 20 - 21, 1976 : RIH with test string. Perforated the interval 9555 - 9424 ft. BKB (open-hole sonic log reference) @ 2 SPF. RIH with gauge assembly (BHCIP = 4576 psig at 9549 ft. BKB). Opened well to flow. F_~l.gwed crude oil and ~as ,~a.~ ave_ ~;~?~as~_qur~ oi~l. r~a~__of' 1462 se----------~~s.~7~a~..~-'---~.'--_t.'h ~~R~o~_~,JZ!~7~z~.ppl. (FBHFP = 2618 psig at 9549 ft. BKB). April 22, 1976 : CI for PBU. Recovered gauge assembly (BHCIP = 4547 psig @ 9549 ft. BKB). Stimulated the perforated interval with 250 bbls. HCl acid (28%). Opened well to clean-up. April 23, 1976 : Ran pressure gauge assembly., C1 for PBU.. (BHCIP = 4471 Psig.'@ 9549'~'ftl'BKB.~.), Opened well to flow; flowed to clean-up then choked back to flow through separator. ~1 rat~_e~_27~50,,se~., b~b_~ls,_.Jd__ay, GOR 134 scf/sep, bbl. (FBHFP = 4304 psig at 9549 ft. BKB). April 24, 1976 : CI for PBU. (BHCIP = 4462 psig @ 9549 ft. BKB.) Opened well to flow; average mga~Dred oil rate 6880 sep. bbls./day, GOR 231 scf/sep, bbl. (BHFP = 4145 psig @ 9549 ft. BKB). April 25, 1976 April 26, 1976 : Choked back to a lower flow rate; average measured oil rate 4780 sep. bbls./day, GOR 286 scf/sep, bbl. (BHFP = 4105 psig @ 9549 ft. BKB). CI for PBU. (BHCIP = 4430 psig @ 9549 ft. BKB). : Op, e~ed well to flow; average measured oil rate 7875 sep. bbl~./day, GOR 4514 sCf/sep, bbl. (BHFP = 3996 psig at 9549 ft. BKB) Choked back to a lower flow rate; average measured oil rate 2500 sep. bbls./day, GOR 756 scf/sep. bbl (BHFP = 4123 psig at 9549 ft. BKB.) CONFIDENTIAL SUMMARY OF TESTING OPERATIONS AT SAG DELTA #1 ~3~_-1_2~7.16) - (Continued) April 27, 1976 April 28, 1976 : CI for PBU. (BHCIP = 4370 psig at 9549 ft. BKB.) Opened well to condition for bottom-hole sampling. : Collected four valid bottom-hole samples. Two were collected at 9490 ft. BKB and two at 9420 ft. BKB. CI well. End of testing operations. CONFIDENTIAL 36. No. CORE DATA Interval, dd. ft. 1 9199 - 9218 2 9218 - 9253 3 9253 - 9286 4 9286 - 9346 5 9456 - 9493 6 9493 - 9553 7 9553 - 9597 8 9597 - 9657 9 9657 - 9715 10 9715 - 9752 11 9752 - 9811 12 9811 - 9845 13 9845 - 9875 14 9875 - 9932 15 9932 ' 9990 16 9990 - 9997 17 9997 ' 9998 18 10,044 - 10,096 19 10,096- 10,156 20 10,156 - 10,216 Description Shale Shale Shale - Chert Limestone Limestone - Dolomite Dolomite Dolomite - Breccia Dolomite - Breccia Limestone - Dolomite Limestone - Dolomite Limestone Limestone - Dolomite Limestone Limestone - Shale Shale Limestone Chert Limestone - Shale Limestone Limestone - Shale Poroperm Shows Very poor Fair to poor oil Very poor Very poor Very poor Poor " Poor " Poor " Poor " Poor " Poor " Poor " Poor " Poor " Poor " Poor " Poor " Very poor Very poor Very poor Very poor OF ,bi ASKA COPY '7' ........' i"::"i"i.$P£RRY-.SUN NELL. SURVEYZNG COMPANY ~ -A'NC HO F~ AG-E'-;~-A IA SK A ~ ' ALASKA STATE OF ALASKA COPY PAGE .......... _. DATE OF SURVEY APRIL 6, 1976 SURWEL GYROSCOPIC MUL'TIsH.OT_.SU~..V_.~_Y 'jO B -'NUM g-E'~"-' SU 3-~ i'&'~'G2 ............. KELLY BUSHING ELEV, : $2o_16 FT, TRUE SUB.S~~)RAo:,. cOURSE COURSE MEASURED VERTICAL VERTICAL INCLINATION DIRECTION DEPTH DEPTH' DEPTH ? S O. 0 W S 1~9~ E S I0o5~ W O' 0.00 -~2o16 0 0 IO'O 99'~-9-9 6T;'85 0~"11 200 199.99 167,8~ 0 500 299.99 ~67.~ 0 10 ~0'0 399-~-99 --~'~7" '--':"'.:'.'" 500 ~9~.99 ~67,83 600 599.99 TO"O g99';-99" '~'07~-8'3 0---~0S-"2~";'59'"~ 800 799.99 767.83 0 10 S 61.55 900 899.99 867.8~ 0 8 S 8.~7 ~-1'000 .............. 999.99 ............ ~G7"~85'- 0 ...... 5 .... S'"~2;70 .... !I00 1099,99 I067.8~ O 15 S 2,16 1200 1199.99 1167.85 0 !0 S 18.57 lqO0 1~99.99 1567,8~ 0 10 S ~o6~ 1500 1499.99 lq67.8~ 0 17 S qO.80 i700 1699.99 i667.85 . 0 1800 1799.99 1767,83 ' · 0 !~ N ~8.75 2000 1999o98 1967.82 0 iO N 66~5 DOG-LEG TOTAL SEVERITY RECTANGULAR COORDINATES VERTICAL T'DE'~-'?"fO'O-' '--~N 0 RTH'] S'O U~T'~-K"A-ST /W E' S T ............ SE C T I 0 OoO0 0.00 0o00 0,00 ........................ ~0.15 --- 0-~"~ U'~'IE-S-- 0'.02 W 0,0~ 0~47 S 0.05 ~ -O,q7 0,0~ 0.77 S 0,07 W -0.77 S ~-~'17 "'~ .............................. 0 . 9'2 0,08 0.91 S 0.25 W -0.89 · .. 0,05 0.88 S 0,2~ W -0.86 O~-i7 -- ~'O'O-'S 'O"; 29 ~ .................. 0 , 99 0.10 1,20 S 0.48 W -1.!8 0.63 W -1.35 0'.-59 W ...................... -1.52"-- 0,55 w -1.80 0.61W .2.!5 O-~-'6~-W ............... -2.~3 0.63 W -2,72 5.09 S 0.81 W -3.0~ ~.~1 ~ 1-;03 '-W '" ~ 55 S' ~.!7 W -3,29 3,20 S 1o37 ~ .3o22 276~% 1';50 .... W ................ ~2',58-- 2.22 S I~63 W -2olq 2.18 S 1.77 ~- .... l~-53'-W ........ -2 08--- 2~09 S 1,00 ~ -2,0q, 1078 S 0.58 Y~ -1o75 io~7 g 0j37 W ~1,25-- 0,82 $ O 31 W -0 60 0.55 S 0.31 W -0.53 .... r. --' ' ........... ~ ~--- 0~4~ S 'OT25-'W- 0.28 N 0.66 W 0.52 = 22 N 2,10 W 3.32 0.15 1.39 S 0,'10 ................... i';50 S 0.19 1o8~ S O,lO 2,18 S 0','07 2~'7-S 0o0~ 2°75 S 0.~7 0"~20 0.03 0o19 0~'2~ 0,39 2100 2099.98 2067.82 0 i S !3, 7 W 0,17 '2200 .... 2!99,98 2167;82~ U--'-!? .... ~-82.'50-'-E ......... 0-.'28 2~00 2299.98 2267~82 O 20 N 83.46 E 0,05 2qO0 2399.98 2367.82 0 21 N 2q,68 E __0°$3 250'0 2q99'~gg----'--2~&7-~8~ O--I~------N-'ig;T3-E O-;OT 2600 2599,98 2567,82 0 15 N 5.~8 W 0,i! 2700 2699.98 2667,82 0 ~ N 20,58 E 0.i9 ...... ~o9---.9~-----27~7;--g2 ~ 5----'-7--~--'5&";~2 '~ O-';"05. ~o -- 28~7'081 'I 0 N o~, 7 W l. OO =-O0 ~899.97 ~ 7~ 2 ~5 N 25~6 W 1.76 ~000 2999.90 2967, .... ' .... '" ST T£ OF :: PAGE 2 SpERRY'SUN WELL SURVEYING COMPANY -" ~NCHORAG£, ALASKA DATE OF SURVEY APRIL 6, [976 SURWEL GYROSCOPIC MULTISHOT SURVEY ...... COMPUTATION DA KELLY BUSHING ELEV. = 32.[G F~. 3P ALASKA INCo SAG DELIA 55-12-16 PRUDROE--BAY ALASKA - A COURSE COURSE DOG-LEG T~UE SUB SE ..... n~ECTION SEVERITY RECTANGULAR cOORDINATES " L INCL[NA~zUm MEASUREO VERTICAL v~EZ!?L __--~---~TN'-~:-DEGR[ES'-T' OCG/iO0 DEPTR- .... DEPTH ..... 25100 2~099,75 25067,59 ------5200-------5 ['99-,-~7------5 .'52500 25298,76 ]5266,60 3400 ,3397.61 VERTICAL SECTION 3':: 35 N 16.68 W 0,91 8.~2 N 5,95 W 8.61 __________~_~_:5~__________~5T55-~-- 5-; 86'~ .............. ~5"2 8"5------ 8 ~ N 15,~0 W 3,67 26,88 N 8,89 W 27,~0 0 ~3 ~1 5~ N 12,62 W ~2,13 8 50 N ~ 5,16 W I-3'--'~5S-;'3 ~N~ 15'~ 79 W 79.10 ' . 102.65 ~50--~54'96'-~'~~~ :N 7,30 W... 1 60 78,26 N 18,57 W 5600 559~,07 556X 91 ': :.N [~,~5 W'.::: :"~:~":2'7- [0~,6~.N_ 22,51 W 5700 369 ~, 20~ . . -~~ 12~~~~O 2-8-.;-72--~~28"j15" 3900 3882,~7 3850,~1 19 5 N !2,51 W 0,50 190,15 N ~!,68 W 192.02 268 .... ~059',52'--~8 ......... 5~' ......N'-'~2,'52'"U 0.22 255.58 N 55.70 W 256.08 ~l'O0 .... ~07I ~i3~.12 . 18 56 N ~2,69 W 62 79 W 287.92 ~200 ~166,~8 ,.~- ~R :" ..:'~-18 ~6'.~>. N X2,67 W_ 0,16 2~5,~0 N ' ~o0 ~26o,9~ 7~o,L.~.~'~. 7- . ~~.7~_~~..~,u~~z~s~9;5~-.~ .................. ~[9.~5- ~.0U~355~~52~5~ ~o ~ 0.25 3~7.19 N 75.98 W 350.59 ~500 ~50.57 . _ -~ 0 N 1!,82 W O 25 577 65 N 82,57 W 581,32 . ~418.~1 X8 15 N 11.88 W · · .......... ~ll.7~- ~70O~'6~O-~W~wou°."~ -~ 0.21 q37.70 N 95.55 W ' 467,~5 N 102.35 W 472,0~ ~ 6 17 50 - N 15, 0 W ~gnO :: ~851,i5" w~o~j T~~2%1-3~ u,~ ll* 97 W 550,9' *, o.2v 525. 8 N · 559. 5 _ . 17 5 N 11,77 W - ~ 554,2~ N 120,65 W 2 0 ~989.88 81 W u,~u _. ~ .......... 5100 o02_,_~ ~n.~ ~7 16 ~0 N 10, .~~.-n~ 582~-4~--~~2~_ .. 616 62 ....... ~ Z~ w~ · 1 o~u, .... 6q5 ~'~Sn~- ~215',52~181'3- -~ "6 N 10,~6 W 0,1 -~ ~., 156,65 W · 5500 5~05.08 ~3~2~ ~_ _~5.~N--.iO. ZTO-'~-- -u.~ ;;%00 N 1~7.23 W 701.58 ~~-~-'9~5~68.//~° 0.05 o~u. 729 8-0 ~60~ Dour. o - · ~7nn 5596.77 5564.6: .. =n N 10,~6 ~ 0.~5 '.=-.--~~1-~7';~6 ~ ........ 756;0~ ~--~-- _ -- --__ ~ ~L7 ~ O~ ~ ~1-7 I~e~ '" ' ~ - ..... ~ ~2 65 u~v.= ~ ~,~-~'6 N v. ..... 5~ W 786.55 oouu ~' ' 5756~5~~ ~'~'~ '~--' ' " 0.I1 779.10 N ' ~' .... __ 6000 588~,~ :~,,~ n7 16 50 N 8, ~ w G~O0 5980,23 BP ALASKA INC, SAG DELTA 53-12-16 .PRUDMOE-B-AY ALASKA SPERRY-SUN NELL SURVEYING COMPANY 'ANCHORAGE'"' ....AEASK'A COMPUTATION DATE DATE OF SURVEY APRIL 6, 1976 SURWEL GYROSCOPIC MULTISHOT SURVEY OO~--NUMBER'-SU~'i'G062 KELLY BUSHING ELEV, : 32,16 FT, TRUE SUB-SEA MEASURED VERTICAL VERTICAL__ dEPTH DEPTH DEPTH 6200 6076,15 60~3,97 ...~:..:i'., 16 25 N 7,6~ W 0,1~ 835.22 N 6~00 6267 GO 6235,~ !6 58 N 6.89 W 0.16 892.5~ N · 0o~9 921,79 N 6~00 6363.17 6331.01 17 15 N 5o_52_~__~__...^ ...... 95i'2'3~ N 6700 655q,09 6521,93 17 2b N 5,99 W 981.03 N 6800 66~9.56 6617.~0 ~':17 15 'N 5.79 W 0.16 1010.65 N __ COURSE COURSE DOG-LEG TOTAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEG.~.:..Mi~.~TDEGREE~-.-~EGTIO-~ .... NORTH'~'SOUTFF-- .... EA-ST'?'WEST .... SECTION- 170.59 N 8~2.80 i7~';3~-'-W ............... 87i.38 - !77,97 ~ 900o~2 181.15 W 929.79 I8~,19--W ................. 959o~7 187,36 ~ 989,28 I90,~2 ~ 1019,01 7O0O 7100 .... 7200 7500 7~00 ----'7500 7600 68~0.80 6808 6q 16 q9 N 5,36 W 0,19 1068.91 N 196.11 W 1077.~8 6936 5~ 690g.38 16 ~5 N 5 13 W 0 09 1097 66 N 198.75 W 1106.~5 ' , · , .... 99 7032.3~ .......... :""7000.18 ...... 16 ...... 35 ......... N ~,65"W 0o21 1126.2~ ............. 201',20-'W 1134 7~28.17 7096o01 16 3~ N ~o58 ~ 0.09 115~.73 N 205oq5 ~ ~163.57 722~,06 7191.90 1G 20 N ~,~6 W 0o30 1183.02 N 205,63 W 1191~93 .7520-~-05------7287~8~ I~ I~ ---N----q.-~7?-~ O-~5-------121'O-~'9~-N--'207,89---W ......... 1219.9~ 7~16,19 738~,03 15 ~ N 5,20 ~ 0,~ 1238,$7 N 210,28 ~ 12~7.w5 7700 7512,~5 ?~80,29 15 38 N' ~,70 ~ 0,18 ~265,33 N 2~2,61 ~ 127~.~9 7800' ~608288-~576i72. ~5----5'~N'--~77~'B '0-255'~-~29~-~-7~ .... ~,'79-'B ........ 7900 7705,28 7673,12 15 ~ N X,50 W 1o09 ~3~8,27 N 216,22 ~ 1327,55 8000 7801.38 7769.22 1G 21 N 0.79 E 0.86 13~5.93 N 216.38 W 1355.17 -8100-- 7897";20------7865;"0% i"~--53' '-N' 3; ..... I-E '0;82-----'1~7%;-5W N 215.~3--~ .......... 1383,66-- 0.86 1%03,83 N 213.23 W 1%12.8% 8200 7992.77 7960,61 17 20 N 5.51E 8300 8088.0% 8055,88 18 ~ N 8.~5 E 1.1~ 1% 3.98 N 209.53 ~ 1~%2.77 -~00 .... 8182;-88--' 8150;72 ~655~--~0'-;96--E' - 1'$i~I~5~'2'~~- 20~,17'"W ....... 1qT3'fGg- &500 8277.39 82~5.25 19 15 N 15.!0 E 0.76 1~97.16 N 197.56 W 1505.25. 8600 8372 03 8339.87 18 28 N 13.93 E 0.79 1528.5G N 189.81W 1536.23 B700----8~67';10 ..... 8~'.~ ~ ~7~0'" ~13';8~'~E-0';'80~-}558';-67'-~-- ~18~.56'-W .......... · 159~.27 ~' 0.85 1587.~ N 175,20 W 8800 8562 60 8530 ~ 16 ~9 N 1~. 7 E . · 0,~6 1615,20 N 1~8.25 ~ 1621.65 8900 8658.~2 8626,26 16 27 N 1~, ~ E --0;9{ ~lGq1';~I~lol~55"-W ..... 16%7.~- 9100 8850.99 8818,8~ 15 7 ' N i~.63 E 0,.~5 16&7,5! N 15~.95 W - ......................... 9200 89~7.8S 8915.67 1~ %q N 15,2~ E 1.~9 1691..58 N !%8.5~ W . 1696 BP ALASKA INC. SAG DELTA 33-12-16 PRUD-HOE--B'A Y ALASKA W~'LL SURVEYING COMPANY CMO RAG E-f-- AI~'A S K A COMPUTATION DATE R'IE--8-J-I97g CONFID[NTIAt 5TATE. OF - --COPY .......................... PAGE DATE OF SURVEY APRIL 6,. 1976 SURWEL GYROSCOPIC MULTISHOT SURVEY -J 0 ~-N O MB'E~-'-S U 5'~"~ ~ 662 ............................................. KELLY BUSHING ELEV. = 32,16 FT. TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEFTH DEPTH DEPTH COURSE COURSE DOG-LEG TOTAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES ..OEG'-:-TM~-~ ~EG'REE-~-~7:'DE~?IO-~'~-'NORTH~SOOTR ..... EAST/~EST VERTICAL SECTION' 9300 '9~0'0 9500 9600 9337.80 9505. 970-0--9~352-3 ~[-------9 ~ 0 90~5,1g 9012,98 92~0.22 9'208,06 9500,60. 9598.03i~ 96'95.-~9 9795.07 9841.89 .... 99'0~'35 :'12 5~ N 15.1, E 0.85 1715.81 N 142.50 ['2---'g'-~ ..... N--IS';--?-E 0-;'-1'6' I755';-'22 N-- !2 35 N 1..22 E 0.26 1756.~0 N 151.19 12 ~ N 1~.10 E 0.18 1777.62 N 125.85 13,~, N 12.25 E 0.31 1821.03 N 115.63 15 0 N 12,15E 0,07 18~5.07 'N 110.88 ~ 52 ~1-2' ~2 ~E O'~'I~~B 6 ~ ~ ' lOg-~-"l 5 12 25 N 11.65 E 0.~7 1886.~6 N 101.62 12 50 N 10.52 E 0.50 18~.9~ N 99.55 I2 ....... I5 -N ..... 9~-51-'" E 0'~5~ .......... I910~ 87-N 97,'09 9800 9552.76 9900 96~0.19 10000 II 972Tj65 10100 9825.2~ 10150 987~.05 '~'~-I02~'6 ..... 99~8,5~ 1718.85 1759,95-- 1760.79 !781.71 1802.9~ ...... 182~.55 18~6.52 1867'~ 1889.08 1899.55 191~.~ HORIZONTAL DISPLACEMENT = 191~.3~ FEET AT NORTH, 2 DEG. 5~ MIN. WEST AT MD = 10216 . THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. BP ALASKA INC, SAG DELTA 53-12'16 PRUDROE--BA¥ ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCRORA'GE~%UAS'K'A ' ' ! ................................................................... CONF, DENTIAL STATE OF AL^$1 COPY ...................... PAGE 5 COMPUTATION DATE -AP'RI' E--B-,--Y 5r76' DATE OF SURVEY APRIL G, 197G SURWEL GYROSCOPIC MULTISHOT SURVEY ~ NUMBER SUo-i6OG2 KELLY BUSHING ELEV, = 52.16 FT, ALASKA KEEqS¥-B~USTiIN'G--~E V . 5' ........ 5 2; IG'-F'T. INTER PO'EAT ED--VALIJES--F~-EV E'N-X UOU.--F EET--OF-M Eh S UR ED-DEPTH TRUE SUB-SEA i:.! TOTAL MEAS~RTYCAL-' VERTICAL '''RECTA'NGUL-A-R--~'OO'RDIN~TES MD~TVD DEPTH DEPTH DEPTH' NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 1000 iili .' 2000 " '500"0 ~000 5000 ~000--- 7000 :: 8000 ' ~Ooo 10000 --yl02i6 999.99 967.83 1999.98 i:i! 1967. 299~r~,'9'0 ..... 29'~'-?~?'~ 5977.12 59~,96 ~926.51 ~89.o55 588';'3~ ......... 5~52'-;18 68~0.80 6508.6~ 7801.58 7769.22 " '875~F;-5'~ ~722~39 9727.65 9695,~9 9958.51 9906,55 2.22 .65 W 0.01 5'~. '22--N 2 .-.-.-.-~-0--~ 0709 190.15 N q1.68 L~ 22°87 qgG,Sq N 108,8q- W 7~.q8 10G8,91 N 196,11 W 159 19 ~6~1~9I N I'615-5 3-~ 2 q'5';-'q q ~8G~,95 N ~OG,15 W 272.5~ 1910.87 N 97,09 W 277,~8 22.78 50.60 -~+ 2" 1'~ .................. · · : ::':: 59, q-2 26o89 5.~ THE CALCULATION PROCEDURES A RE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD, CONFIDENTIAL BP ALASKA INC, SAG DELTA 33-12-16 Pt~DRO E--B-A Y ALASKA i,i ::;::!' ~ SPERRY-SUN WELL;':',SURVEYING COMPANY COMPUTATION DATE STATE',:.OF ALA--SKA-COPY PAGE DATE OP.. SURVEY APRIL 6, 1976 SURWEL G~,YROSCOPIC MULTISHOT SURVEY JOB--NI]Mi~"E R-"SU:5;i'G 0 G'2 KELLY BUSHING ELEV. = 32.16 FT. INTERPOLATED VALUES FOR EVEN 100 .FEET OF SUB-SEA DEPTH MEASURED DEPTH .TRUE VERTICAL DEPTH --'SUB;SEA TO'T~U- VERTICAL RECTANGULAR COORDINATES MO-TVD DEPTH'. NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 0.00 .32 32.16 ' 132 232 232.16 532 532.16 ~32 532 532,16 632 632.16 -32.16 0,00 0.00 0,00 0.00 0.00 0,00 ~0.00 I 00;"00 0';2 5--$ ~;'0 ~-"]W 0;'00 200.00 ?,..,~ii,i:?~:::,,0.57 S :?'/:i 0.0 ~ W 0.00 300,00 0.86 S 0,08 W 0,00 ~00-.--0'0 0~'9~-'~ 0'~2l-~' O~'O'O' 500.00 0.89 S 0.25 W 0,00 600.00 0,87 S 0.23 W 0.00 732 ............... 732,16 ............ 700.00 832 932 ~Z 0'32 ..... 1132 1232 --I53-2 - 1~32 1532 1732 832.16 8.00.00 932.16 900,00 ..... 1032'~'I-G~1000~'00 1132,16 1100,00 1232.16 1200,00 1~52,16. 1~00.o00 1532.1G~ 1500.00 I~32~!G: ~600-.--00 1732.16 1700,00 1,09 1.25 S 1.~6 S I;-59 'S 1,97 S 2.27 S 2.85 S 3,21 ;5,3:5--S ~.35 S S ....................... 0;33 W ................................... 0.00 0.56 W 0.00 0,64 W 0.00 O~,'5&-W 0.56 W 0,00 0,6~ W 0,00 ~j63'--W O'~OO' 0.6~ W 0,00 0,91 W 0,00 i.07-W --~,-,00 1.21 W 0,00 0.00 0,00 0.00 O, 0.00 0.00 0.00 ................. 0.00 0.00 0;-00 0.00 0.00 0',-00 0.00 0,00 0;~0-- 0,00 Si' Al' E 0 F ALASKACOPY ........................ .:"': SP£RRY-SUN WELL BP ALASKA INC, SAG DELTA 33-12-'16 P-RgDFi O-[-IB--A-y ALASKA SURVEYING COMPANY A N'C'H 0 RA-GE-'---A EA S'K'A COMPUTATION DATE PAGE '7 DATE OF SURVEY APRIL 6, 1976 SURWEL GYROSCOPIC MULTISHOT SURVEY KELLY BUSHING ELEV, : 32,16 FT. INTERPOLATED VALUES FOR EVEN lO0 FEET OF SUB-SEA DEPTH TRUF. MEASURED VERTICAL DEPTH DEPTH SUB;SEA VERTICAL ,RECTANGULAR COORDINATES.~.~ MD-TVD DEPTH ' NORTH/SOUTH EAST/WEST i DIFFERENC£ VERTICAL CORRECTION 1832 1832,16 1952 1932.16 2'032'" 2132 2132.16 2232 2232.16 2332' 2332~'~6 2432 2452.16 2532 2532,16 1800.00 1900.00 2'000;00 2100,00 2200,00 23'0'0~-00 2~00.00 2500.00 ~2632---2632;I6- 26'0 2752 2752.16 270 2832 2832,16 280 "' 293'~ 2932;16 290 3032 3032,16 300 3132 3132,16 310 ~3232 3333 3332,16 330 3536 ' 3639 0.00 0,00 oToo 0.00 0,00 07OO 0.00 3%32.16 5400,00 5532~--"&-'6 ' 350'0~0 3632,16 3600.00 ! 3.09 S 2,q2 S 2.19 S 2,1~ S 2 TO 7--S 1,61 S 1.1~ S 0V6"8'--S 0.51 S 0,4~6 S 0-.-76--N 4,64 N 10,~6 N 18 31.73 N 46,77 N 65'-;%2-'T.,t' 86.91 N 1,~5 W 1.50 W 1,77 1,37 W 0781--~ 0.50 0.52 W 0~0 0,2S W 0;98~ 2.72 W ,*.5~ ' ~0~25 . 13.8~ W 16~'8~ 19.85 W 0.00 0.00 0.01 0.01 0~0'i 0,01 0.01 o';oI 0.01 0.01 0,12 0.30 0~68 1.60 2,79 6,91 0.00 0.00 0,00 0.00 0.00 0.00 0o00 0.00 O.OO 0.00 o¥oz 0.09 0,!8 O-J7 0,92 1,!8 1.--72 2.39 BP ALASKA INC. SAG DELTA 33-12'16 FRUDROE~A¥-- ALASKA SPERRY'SUN WELL SURVEYING COMPANY ANC H 0 R'AG'E-,---AL-A-SK A COMPUTATION DATE A P R'IE--8'¥'Y97G CONFIDENTIAL STATE: OF ALASKACOP¥' PAGE. DATE OF SURVEY APRIL G, 1976 SURWEL GYROSCOPIC MULTISHOT SURVEY UO~-NUMBER-'SU~;-i~'06'2 ........................... KELLY BUSHING ELEV. : 32.16 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH I'OTAI~ RECTANGULAR COORDINATES MD'TVD ;NORTH/SOUTH EAST/WEST.'.i DIFFERENCE VERTI CORREC CAL TION 3742 5732.16 3700.00 58~6 .3832.15 3800.0Q 595'2 393'2,-~J5 5900~-~00 ~058 q032.16 ~000.00 q163 ,~152.16 ~100.00 ~375 ~332.16 ~500.00 ~80 ~32.16 ~00.00 '~585 ~532'1~ ...... ~'500;00 112.%G N 2~.70 W 1~2.29 N 31.06 W 208.70 N ~5.79 2~2.16 N 53,13 W 275'757--~ 60;65-W 308.62 N 67.9~ W 3~1o2~ N 7~.7~ W 375.35-'N 8I',~8""-'W ~690 ~632.15 ~600. ,,...~_ ,00 :i:'::.. i'~05 06 N" 88.23 W ~796 ~732.16 95.28 N q'90i q.-852;-I6' " ~'80'O-;Ii"O 5005 ~932.16 ~900.00 5110 5032.15 5000.00 52I~ 5132-~16 5100%~"0 5319 : 5232.16 5200.00 5~2~ 5332.1G ' ' 552'8 5 ~'32~I6 5~-00~0'0 5652 5532.16 5500.00 q, 98.56 N 528.82 N 5'5-8~ -q.'9'--N 587.9q. N 617.52 N 6 ~'6-~8 ~ N 676.09 N !-0'2';'% 2--W 109.21 W 115,60 W 127,08 W 1~2,60 158 .~'6-W 1~3.71 W 10.25 1~.80 20~'27 2&,06 ~1,76 57;-~'6 53'69 58,81 i'i'".'.65o88 73.75 78.~2 82'.-8 9 87,29 91.72 9G;08 100.~2 3.33 ~.55 5';-'4-6--- 5,79 5.70 5,70-- 5.57 ' 5.~0 5,2~ .................................................. 5.12 5.06 · ~.85 ~.67 ~.39 *.~2 BP ALASKA INC, SAG DELTA 33-12-16 PRUDHOE-B~Y ALASKA SPERRY-SUN WELL SURVEYING COMPANY ~NC'HORA-G[F~ASKA COMPUTATION DATE APR'!~--~-'IgTG CONFIDENTIAL 'STATE. OF-A-[ASKA-COPY PAGE DATE OF SURVEY APRIL &, 1976 SURWEL GYROSCOPIC MULTISHOT SURVEY ~O~.-NUMBER--SU.3~-GO~2 .......... KELLY BUSHING ELEV, = 52.16 FT, MEASURED DEPTH INTERPOLATED TRUE SUB;SEA VERTICAL VERTICAL DEPTH DEPTH VALUES FOR EVEN lO0 FEET OF -TOTAL----= RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST SUB-SEA DEPTH MD-TVD DIFFERENCE VERTICAL CORRECTION 5736 5632,16 5600,00 58~[ 5732,16 5700,00 --59~5 ...... 5632','IG ........ 5800;00 60q9 5932.16 5900.00 615~ 6032,16 6000.00 6258 -~I-~2~'I~ -6100~5'0 6362 6232,16 6200,00 6~67 6332,16 6300,00 --6572 ...... 6~52;i~ ........ 6~00~00 6677 6532.16 6500.00 678~ 6632.15 6600,00 6'8~6 ''673'2;[G ' 6700;00 6990 6852,15 7095 6932,15 6900,00 ?I9~~~052.--].6 7000~"00 730~ 7152,15 7100,00 7~08 7252,~6 7200,00 15~-2------7532',--'1-~-------7'500~-00 7616 7~32.i6 7~00.00 705,37 N 1~9,16 W 73~,51 N 15~,5~.W 795,06 N ~6~.69 W 822o~8 N 168,86 W 85[-~7 N 881,81 N 176,67 9i2,20 N i80o22 9~3"[5~'N ................ 185,29"W · . 97~,i9 N 186o65 1005,28 N "' i89,88 I0'36P01--~-- 1066,50 N i95o87 1096.55 N 198~63 W 1155.92 N 203o5~ W · ~185,39 N 205,82 W 12~2,86 N 210.69 W 10~.76 109,06 117.70 121.99 150,78 l~O,'OB 15~";2~ 165.26 [72o00 176o25 ~,29 ~.51 q,57 ~,7I ........................ · 8,76 '~;66 ~,52 ~o~5 ~o27 3,99 CONFIDENTIAL STATE OF ALASKA" COP BP ALASKA INC, SAG DELTA 35'12-16 PRUD'RUE--B~ ALASKA SPERRY'SUN WELL SURVEYING COMPANY A NCHOR'AGE-~--AE-A-gKA COMPUTATION DATE >;."- . ...:: ......'. , .' PAGE 1( DATE OF SURVEY APRIL G, 1976 SURWEL GYROSCOPIC MULTISHOT SURVE KELLY BUSHING ELEV. = 32.16 FT, TRUE MEASURED VERTICAL DEPTH DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH .SU~;'SEA. VERTICAL. ::"RECTANGULAR COORDINATES DEPTH i::.NORTH/SOUTH"::..: EAST/WEST MD-TVD DIFFERENCE VERTI CORREC CAL TION 7720 7532.16 7500,00 7824 7632,15 7600,00 " 7927---~7732;'!'~ : 770-0;'0'0 8052 7832,16 7800,00 8136 79~2.16 7900,00 82-~1 803'2-2"I~ 80'00~0 83~6 8132.16 8100,00 8~52 8232.1~ 8200.00 .... 8557 ......... 835'2';'I~ ...... 8300',0'0 8663 8768 ~672-- 8976! ~080 --9'I83-- 9286 9589 9~9I 9594 8q~2,16 8~00,00 8552,16 .i 8500,00 8732.16 8700.00 88~2.16 8800.00 8-9~2-~I~ .... ~'9U0'¥00 9052.16 9000.00 91~2.16 9100.00! ' 9232.-:~- ~'2ooToo 9S~2.16 9SO0.O0 1270.82 N 213.06 W 1297.97 N 215.51 W I~25.8~T-N ~i6.~2 ~ 1554,96 N 216.26 W 199 1~85.10 N 21~.87 W 20~ I$'~';"O7-h--212;O-~--T~ 209 1~48.25 N 207.36 W 214 1481.82 N 200.88 ~ 219 I'515'~62-N .......... 19~;02'"'W ............... 225 1547.86 N 185.0~ W 2~1 188.29 191.94 I95";-'7~ .91 ;09 .25 ,95 ,79 ,16 1578o50 N :. 177o~ W 16~5.88 N 165,06 W 1662.59 N 156.2~ W 1687'~--88 N 1710.9~ N 1~5.28 W 17~2o95 N 1~7,5~ 17'5q":6'~ 1776.58 N 126o1~ 2~.59 2~8.52 251';'70 25~,5i 257o0~ 259;5? 262.05 3.86 4..14 4.~5 5.15 5.68 5; 85 ..................................... 5e37 :Fj. ~2 .......... 5.75 2.81 2,5& 2.~7 CONFID NTI^L STATE ALASi - BP ALASKA INC, SAG DELTA 33-12-16 PRUDHOE'B-A ¥ ALASKA : . SPERRY-SUN WELL SURVEYING COMPANY ANCH URA-GE~-AI~A'SK-A COMPUTATION DATE · :..,. ~ A'PR IL-'87-~97'6 PAGE 11 DATE OF SURVEY APRIL '6, 1976 SURWEL GYROSCOPIC MULTISHOT SURVE3 JOB--NUMBER-'S'U~;~6'O'~2 KELLY BUSHING ELEV. : 32.16 FT. INTERPOLATED VALUES FOR EVEN lO0 FEET OF SUB.SEA DEPTH TRUE MEASURED VERTICAL DEPTH DEPTH SUB;SEA TO~L~ VERTICAL % RECTANGULAR COORDINATES MD-TVD DEPTH~; NORTtt/SOUTH' EAST/WEST DIFFERENCE VERTICAL CORRECTION 9696 9~52,16 9~00.00 9799 95~2.16 9500,00 ~000~ 9732,16 970'0,00 10107 9832.15 9800.00 ~iU209~'~93'2;~1-6 9900~00 ~10216 99~8~5! 990'6.35 1798,~ N 120o75 W 1820,89 N li5,66 W 1865.95 N :105.93 W 1887.85 N 101,~1W I9'09-;'5I-N 97~'32-W 1910.87 N 97°09 ...... THE--CAI~CUL'ATIO N-P R 0 CEDU R E S"'-USE-A-L-INEAR--I NTE R PO LAT I ON "-B ET~EE N THE NEAREST 20 FOOT MD. (FROM RADIUS OF CURVATURE) POINTS · 26~.59 267.21 2'69;B'5 272,~6 27~.93 277,~8 2,5q 2,61 2,6~ 2,60 2,,7 2',-39' CONFIDENTIAL STATE OF ALA$ -CO -- BP ALASKA INC. SAG DELTA 33-12-16 PRUDROg'--BA-Y ALASKA' '~::':':i"'.:;;":?'."SPERRY-SUN:;'~':: 'i ~,'JELL SURVEYING COMPANY ANCHOR ~-~ ~-,-"'~:~s'~<~TM COMPUTATION DATE PAGE 12 DATE OF SURVEY APRIL G, 1976 SURWEL GYROSCOPIC MULTISHOT SURVEY KELLY.BUSHING ELEVo = 32.16 FT. INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE-- S UB;;-SE-A MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER 82%2 8032.87 8000.71 1~16,29 N 212,03 W 9 5/8" N-80/SOO-'95XO 8617 8388.16 835G,00 1553.79 N 188.52 W TOP 7" LINER ~Z-~2 .... 888I;-88--'88~'9-;72- ~6-7'5;58-N ...... ~-.-~'52'; 8~--~"~ 9 578" ...... SHOE 9~98 9238.27 920G,li ~:.~:~'- 1755,98 N 131.29 W RADIOACTIVE MARKER ~10~72 9895.53 98G~.37 190~,62 N 98.68 N CLEAN OUT DEPTH ~lOR16 9938.51 9906.35 1910.87 N 97.09 W TD 8 1/2,, HOLE SAG DELTA STRATIGRAPHIC SUMMARY ME~SU'R'ED--D-EP~TR BKB ....- -- TVD ....... BKB SUB-SEA VERTICAL COORDINATES :~TH-'REF;"'TOWELE~AO IORIGIN-IOOOSNL 7~gEWL) SEC S~ TllN R1GE 9 5/8" N-80/SOO-95XO 82~2 TOP 7" LINER 8617 .::: --~-'5'78'~--SROE 9-I'32 RADIOACTIVE MARKER 9498 ~.CLEAN OUT DEPTH 10172 ~TD 8 1/2" HOLE 10216 : 8032,87- 8000.71 8588.16 '~ 855g,00 9238.27 9206,11 9895~5~ 986.3.37 9938,51 '9906 o~5 1~16.29N 212.0~W 1535,79N 188,52W i'675Z'~58N ....... 152,'-84W'--- 1755o98N 131.29W 1901.62N 98'.68W 1910.87N 97.09W ~0 M-L-I Nt-~ R--EXT RA'PO L-~ON--B E'L-OW-DE ER E~ST-STA-TTO N , 2)COMPUTER PROGRAM-SPERRY SUN THREE DIMENSIONAL RADIUS OF CURVATURE, DATA CALCULATION AND INTERPOLATION BY RADIUS OF CURVATURE C-O MP UTA-TI-O i~F~AT APRIL 8, 1976 DATE OF SURVEY APRIL 6, 1976 sURWEE--~YROSCOP-~-C--MUCTISHOT"--S'URVET-- dOB NUMBER SU5-16062 KELLY BUSHING ELEV. = $2.16 FT. bpaLaska inc. 311 1 C STREET · TELEPHONE (907) 279-0644 JdAILING ADDRESS: P.O. BOX 4-1379 ANCHORAGE, ALASKA 99509 April 21, 1976 CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Gentlemen: Mr. O. K. Gilbreth Director BP Well Sas Delta 433-12-16) Enclosed is Form 10-4.03, Sundry Notices and Reports on Wells, indicating our proposal to complete the well for further testing and to suspend operations on or before May 1, 1976. Very tru~ yours, :endent PRJ:Jle Enclosure cc: Well File ~$~0~ O~ O~t ~ GAS Form 10-403 R~M. 1-10-73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate 749' EWE, 1000' SNL, See. 4, T11N, E16E, OPM Sec. 33, T12N, R16E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, et~) 12. PERMIT NO. ~ 32.16' AHSL 75-58 ~4. CheCk AppropHaM Box To Indicate Natum of Notice, Repo~, or Other Data STATE OF ALASKA 15. APl NUMERICAL CODE OIL AND GAS CONSERVATION COMMITTEE Ii 30-029-20176 J6. LEASE DESIGNATION AND SERIAL NO. SUNDRY NOTICES AND REPORTS ON WELLS I ADL 28337 Sur£aee (Do not use this form for proposals to drill or to deepen [ADL 34634 Subsurface Use "APPLICATION FOR PERMIT--" for such proposals.) I w..._ ,,,.,.,,,,,,. 2. NAME OF OPERATOR - - "' UNIT, FARM OR LEASE NAME BP Alaska Inc. ~ : 3. ADDRESS OF OPERATOR -- . WELL NO. ' P. O. Bex 6-1379, Aachorage, Alaeka 99509 Sag DelCa (33-12-16) 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT At surface Wildcat ' 11. SEC., T., R., M., (BOTTOM'HOLE OBJ~i~CTIVE) . NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF L---J PULL OR ALTER CASING L---.J FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Suspend SUBSEQUENT REPORT OF: WATER SHUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) REPAIRING WELL ALTERING CASING ABANDONMENT* (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLIED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated daM~of ~a~,ng any proposed work. 1/2" hole hu been drilled Co 10~216'; ~d 7" 29~~,~led~ie~ ~80 BuCCreso 8 ~aain$ has been ~n Co 10,21~' ~d h~$ as a lhe~at /~61~'.,la~[ cemented wich 350 sacks Class C ceaent. Drill sc~ caeca ~ave been~r£ormad ove~ Che ~ce~s 10,145' - 10e001' 9821' - 9691' and:;9627' - 9583' as per our S~~ce dac~ ~ril 6, 1976. A 7" EZ Drill brid~ Plugha' b'~ ~C ae 9674' ~d ~9~ ~e n~ ~Cend co proceed as foll~as oz befo~e~y 1, 1976. 16. I hereby~~t//e,~oingSiGNED ~,~J~~is true and correct T,TLEDrill~tS Super~ntendenC (This space for State office use) / - See Instructions On Reverse Side Approved Copy Returned. 3. Suspend well. I~ the well has been per£orated in (2) above, a rubies plus wilt be set in the tailpipa below the packer. If the well has not been perforated, tM tubin~ will contain Calc!un Chloride kill f,luid. In either case, non-freez~ fluids w~ll be le~t in all annuli through the perualrost zone and a back-pressure valve set in the tubin$ h anser. EiI¥1SION OF 01l AND ALASKA INC - - STREET · TELEPHONE (907) 279-0644 MAILING ADDRESS: P.O. BOX 4-1379 ANCHORAGE, ALASKA 99509 April 8, 1976 CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Dear Hoyle: Mr. HoyleHamilton Chief Petroleum Engineer BP Well Sag Delta No. 1 Open Pit Burning Permit For your information I enclose copies of the letters we have sent to Mr. Thomas R. Hanna of t~he Department of Environmental Conservation, requesting an Open Pit Burning Penuit. encls /i'PR i 1976 Very truly yours, BP ALASKA INC. G. D. Taylor Manager Operations BP WELL SAG DELTA [/1 (33-12-16) POTENTIAL WELL TEST PROGRAM ~Objective : Perform flow test: to seek Discovery status for lease. Current Status : Well S.I., -PX plug in X nipple at 9126' BKB, Cameron ~ BPV in tubing hanger. KB elevation 32.16" BF elevation 7.72' Program: 1. Move all test equipment to well site and rig up manifold house, Otis 2 b~tBTU heater, ~4~ separator (if available) and flare line. 2. Chec.,~ wellhead for pressure. Remove Otis quick union from wellhead and install Cameron BPV lubricator. Recover BPV. Reinstall ·Otis quick union tree cap. 3. Rig up ~ lubricator. Pressure test lubricator and line to manifold house to 3500 psig. Pressure test to end of flare' line to 1000 psig. 4. Recover 2-7/8" PX plug from X nipple at 9126' BKB. 5.~RIH with Hewlett-Packard pressure gau~e and tande~ Amerada sure gauges (with 144 hour clocks) to 9500' BKB. Allow gauges to thermally stabilize for one hour aod then drop down to 9549' BKB (H.P. gauge depth) and sit for one to two hours. 6. Open well to flow on 40/64ths inch c~oke setting. When downstream ~___ heater temperature ~ea~]~e~ 80~ ~. ~u~ ~n~o ~epa~ato~. Monito~ 8e~a~a~o~ readings, WHFP, WHFT, downstream choke pressure, and annuli pressure~ every hour. Monitor oil gravity, BS & W, D & S, gas CO2 and H2S con~ent every three hours. Do not allow annuli pressure~to exceed 500 psig. 7. If separator gas readings appear anomalous or if ~arator operation questionable, obtain ~separator oil and ~ separator gas samples approximately two hours before end of flow period. ~F~er 96 hours total flow time, S.I. well a~ wing valve on tree. (If rates ~.g and bottom-hol~ pressures stabilize prior to 96 hours flow time, ~/~~ consideration should be given to shutting well in early.) Monitor · ~-~ pressure buildup for 6~ days. If the Hewlett--Packard pressure gauge is .- wo.rking properly, do not pull. gauges after clocks have run out on Ameradas. 9. After 6± days PBU, pull gauges. sp:.nner survey at al:proximately :.a,,:<. tea ,.:r . st f:n Use cl:olce p~.-e~;sur'es to estimat<:~ race ~:ath~:r tha~ iJ.o',~;jng wc].l tt~rougl~ 11. Rig down ~:lun:bc:-oc:: and rig up ~. Rerun PX p].ug in X nipple at 91.26' BKB. Bleed off all pressure on wellhead. 12. Run back pressure valve. Close all wellhead valves. Rig down aud move all equipment from location. A. E. Leske . .. · CONCUR: · o April 7, 1976 Further to our letter of FeBrua~f 17, 1976 and to your letter of FeBruary 26 with th~ e~)cZo~e.~ open pit bu~ing permit for the atpove ~ntioned well (P~it Nui~er AQC-405)~ we are writing to advise you that ~ open hole drill ste~ test was ca~ied out in BP ~!ell Sag Delta t~o. ! on 1,~arch 12/14. A t~taI of 1500 barrel~ of crnde oil were flared over a period of el[Iht ho~rs. Th~ q~mntity is greater th,,n, our original estimate of 1000 B~rrels of c~da ~il to Be flared during the drill stem test Because of $o~t~at higher productivity than anticipated. We u~w intend to carry out a fairly extenmive production testing program in this well. This program is emt~:~ated to start on April 8 .: and continu~ n~til near the en~ of April, and thus, would ba cov::~rerJ by the opa~ pit ~ing p~rmit ~reldy issued to us. We %~sh to ~.dvt~ you that wa ~ow est~m~te th~ total ~m.o~t of oil to Bo burned during ~thls t~t!n5 program to be approni~t~l~ 7500 ~arrels~ with a total f~rlng t~e ~f appro~t~y i20 hours durl~g the peried April 8 to April 30, !976. We wili, of course~ be mubm~tting a report to yo~ giving the data as stipulated In the op~ pit burnir~g pe~it. We ~-ould like to request an ~:~tension of ti~ for the submission of this report to .... M~y 15, 1976~ Because it ~s likely that testing operatio'n~ ~ilI not cease until near ~h~ e~ of April. if we can provl,la amy further info~tiom, please do not hesitate to call ~ro B. E. Davies, ~ur District Petrolem~ Engineer.. 1 2 1976 bcc: District Petroleum Engineer Attorney Drilling Superintendent P.E. Well File Sag Delta No. File GEN-AK-527/2B :~. Vet~ tr~ly yours, O, D. Taylor ~-~ger O'per~tion~ February 17~ 1.976 Air Quality Control Supervisor State of ~a~a Dapartr~cnt of Environn~ntai Co~.se~atio~ Pouch O Eva!~mtion Te~t~ BP Well Sag Delta No. I for c31~en-Pit Bu~nin~ PeT~it As yo~ are probably awa~e, BP Alaska i~ currently dril!in~ an e:~loration well to Secti~n 33~ To~ship 12 l, lortb~ R~ge 16 ~ast, frow~'~a surfac~ site located 749 calls fo~7 an open~ho%,~ drill gte~ test to be carried out soon after setti~.g casing~ The purpose of thig~ test would be to detep=ine the fluid content of any ~,~'~s~ .... ~ ~.+~'r~ rock ~r~c~r~ ~ ~. ~ .~atel'~. y below the 9-5/8~ casing ~.~.~oe. Wo anticipate that this tes~ ,gill be performed some time during the first two weeks of }~arch, 1976. *C~a test ~pi!l consist of temporarily cc~pleting the well u~ing a drill stcw~ test string and f%o%~ing to s~face for appro~i~mtely six to eight hours to establish the natu~Te c?f th~ prod~ced ft~d. This fl~.~d will be disposed of to the flare pit at the ~urfa~e toc~.tion~ where~ if it i~ combr~.s~ible~ it will ba bnrn~d. We e~t~ate that the ms~i~r~ ~oun~t of oil disposed of in this m~mner will be !OOO bbls. Flaring will tsJ. ce place for approx~ately six to eight heurs during the actual fi~,~ix~.g period and ~pp~:oxf~ately on~ hour during the reverse circulation period. Depending upon the results of this te.st~ tek, ting opprobrious mmy be required fo~.!ow~ng the c~mpleti~ of the w~II. If perfo~md, these testing operation~ would include st~iation of the fo~mtiom by injecting acid. The testing program wcuid consJ~st of a flow period of s~ to eight hours to cI~nup ~e well, injection of acid to ~tirou!ate ~be fo~mtion, fo!l~ea by a s~ hour clea~-~fl~w-~ period during whici~ the spent ac_a ~u.~u. be r~produced at the surface, e~d fir~ily, a !2 hour flow period to evaluate the product~vity of the w~ll and the effects of the st~n!ation. W~ estimate ~hat a mazi~nn amou~at of 3000 bbls~ of oil would be burned ~ith a maximum t~al figuring tim~ of 36 bouts over a fiw~ day period. '~e produced fluids would be di~pose~i ~f to the fiare~ pi~ at th~ surface loca~ion ~ere ~my combumtibie elements P!eaae consider thi~ letter a formal application to dispose of, by open-pSt burning in the flare pit at th~ Sag Delta N~er 1 location (Section 04, Tom~hlp 11 North~ Range 16 E~st) any co~i~stibla fluid produced during the drill stem te~t to be es. tried out in the first two w~eks of March and during the fl~ testing operations which m~y be carried ou~ s~e time in April, 1976 in the sg~ie well. If ?~.~p~x~d~ ~~~r info~ation, pleas~ do not hesitate to call -- APR 1 2 bcc:"~strict Drilling Engin er BP :2):"~. Arl!pq~A~l%%i~ Superintendent ~. D',' Tayl~= j ' /~ ~le P E Well F}le Sag DEI~ :vi p ...... ~ager Operations Delta No. 1 ~ ......... ~, GE~-AK-52 7/2B BP WELL SAG DELTA DIAGRAMMATIC SKE'FCH OF TEST STRING AS RUN ON APRIL 20, 1976 -~EPTH BK8 ........ ---- ..... ROTARY 'TABLE .. . .A.O0 .TUBING HANGER o 1 ~095.0' ...... - 0570.0' ...... ~ ---' 4 I/2." 12.755~/FT. N-BO TU31NG · . XO 4 I/2" BUTTRESS X 4 !/2" ltYDRIL OTIS "XA" SLIDING SLEEVE XO ,'~ i/2" HYDRIL X 4 I/2", BUTTRESS JT. 4 I/2" HYDRIL XO 5 !/2" BUTTRESS X 4 I/2" HYDRIL 7" P~AKER F-I PACKER : SEAL BORE ASSEMBLY .: XO 4 i/2" BuTTREsS X 2. 7/8" ASL -~- PUP JT. 2. 7/8 ....X" NIPPLE .' ~_ ~8" PERFORATED dT. 2. ?/8" ,IT. · XO 2 7/8" EUE X 2. 7/8" ASI_ 2 7/8" XN ~IPPLE XO 2-/'/8" ASL X 2 7/8" EUE ~ELL NIPPLE PERFORATIONS: 9424'-9555' BKB EZ-DRILL BRIDGE PLUG FIG. 1 C STREET TELEPHONE {907) 279-0644 MAILING ADDRESS: P.O. BOX 4- ! 379 ANCHORAGE, ALASKA 99509 ApriI 7, 1976 CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. O. K. Gilbreth, Director Gentlemen: Well Sag Delta (33-12-16) Enclosed is Form P-4, Monthly Report of Drilling Operations, for Sag Delta (33-12-16) covering the month of March, 1976. Very truly yours, BP ALASKA INC. DRAFT sec CONFER: FILE: ~.~ PRJ :vjp Attachments cc: Well File G. D. Taylor Manager Operations APR 8 1976 I~IVIStON OF OIL Al,ID GAS Form No. P-4 REV. 3-1-70 : ~ SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS CONFIDENTIAL 5. APl NUME~CAL CODE 50-029-20176 6. LEASE DESIGNATION AND SERIAL NO. ADL 28337 Surface ADL 34634 Subsurface 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME · OIL [~ OAS [--] Wildcat WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME BP Al-aska Inc. 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 4-1379, Anchorage, Alaska 99509 Sag Delta (33-12-16) 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT Wildcat Surface: 749' EWL, 1000' SNL, Sec. 4, TllN, R16E, UPM 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 33, T12N, R16E, UPM 12. PERMIT NO. 75-58 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. March, 1976 Drilled out 9-5/8" shoe and pressure tested to 0.7 psi/ft, gradient. Drilled 8-1/2" hole to 9199'. Cored from 9199' to 9346'. Reamed and drilled 8-1/2" hole to 9456'. Cored from 9456' to 9597'. Performed drill stem test of interval 9132' - 9597' with packer set at 9117' in 9-5/8" casing.with 2000-ft. water cushion. Cored from 9597' - 9998'. Drilled 8-1/2"'hole to 10,044'. Cored from 10,044' - 10,096'. Ran Schlumberger logs. Cored from 10,096' to 10,111'. APR 8 1976 DIVISION OF OIL AND GAS, ANCHORAC~ .CONFIDENTIAL STATE OF ALASKA COPY 14. I he. eby certify that~e~ortect SIGNED G. ]3.,- T~y%~r TITLE Manager Operations DATE NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. bpal.aska inc. 3111 C STREET TELEPHONE {907} 279 0644 I~AILIN{; ADDRESS: P.O. BOX 4-1379 ANCHORAGE, ALASKA 99509 April 7, 1976 ~ C ONF I DENT IAL State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. O. K. Gilbreth, Director Gentlemen: Well Sag Delta ~(33-12-16) Enclosed is Form 10-403, Sundry Notices and Reports on Wells, indicating our proposal to conduct drill stem tests in Sag Delta (33-12-16). Very truly yours, BP ALASKA INC. PRJ :vjp Attachments cc: Well File G. D. Taylor Manager Operations APR '? 1976 DIVISION OF OIL AND GAS ForJlo~03 REV. 1-10-~3 Submit "intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use ,,APPLICATION FOR PERMIT--" for such proposals.) OIL r""'"l GAS O OTHER Wildcat WELL~ ~ WELL 2. NAME OF OPERATOR BP Al~_~k~ ThC. 3. ADDRESS OF OPERATOR P. O. Box 4-1379, Anchorage, M-re_ks 99509 4. LOCATION OF WELL At surface 749' ~, 1000' S1TL, Sec. 4, TllN, R/6E, ~ 13~ ELEVATIONS (Show whether DF, RT, OR, etc.) KB 32.16' AMSL 14. 5. APl NUMERICAL CODE 50-029-20176 6. LEASE DESIGNATION AND SERIAL NO. ADL 28337 Surface ADL 34634 Subsurface 7. IF INDIAN, ALLOI TEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME 9. WELL NO. Sag Delta (33-12-16) 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 33, T12N, ~16E, UPH 12. PERMIT NO. 75-58 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L--~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE 'SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE *TREATMENT ALTER lNG CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other)· (NOTE: RepOrt results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBEPROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. We plan to conduct three drill stem tests begt~mtng April 7, 1976 over the follo~rlng ', ~ross intervals within the Ltsburne formation: 1. 10,154' - 10,001' 2. 9,821' - 9,691' 3. 9,627' - 9,583' Each test will consist of perforating'2 shots/foot within 7" casing, a flow test, actdtzatton if required and a second flow test. The tests will be performed consecutively through drill pipewith an RTTS packer set above the zone. A retrievable bridge plug will be set. above each zone prior to testing the next higher interval. 7 197§ DIVISION OF OIL AND GAS CONFIDENTIAL STATE OF ALASKA COPY · 16. I hereby certify that/kJle~oregping is true and correct SIGNED ~~/ (This space for State office use) . APPROVEDBY ~'~/~~~~ CONDITIONS OF APPI~VAL, I~= ANY: TITLE Manager Operations DATE TITLE, ~~-~~-W~'~~.-. DATE See Instructions On Reverse Side nfO nd gas conservation '?~'f~/?~?'?,~: · ' SUSJECT, Paytng quantities ~'' ..~:~:;:~,::::,.-floyle fl.. fla~~n - Sag ~lta ~o.. 33-1Z-1 ~.~,¢?~,~.: , 0t rect · · ROL 34634 -:.:~/:?, On ~rch..'6 and 7, 1977, ~trOle~ tnspec__r eNoCh ec~d da j:- ,.:~~~=~ e glair' Rus~l,1 ~uglass,. )i~ess~. and ~~:.?_~.. .~, ,,~tes'tJ°~;subJ~t well'. ~:"7. :.L '~. ~- ...... ,-,~-.-,-;~.,:,:,.~ ,~-',;'"-~;,, '.~.:;~.~, '~:'~"'~'~ ~ "':,. ~' '''~'" ' :'"~'~' '~"':test':~ has b~n" ~viewed and we p~uctng ~'~ accept~ as verification that this ell ts,~ble :t: mca~ons i~ paying q~nt!.ttes.' '::.';.'.~~bJ~ bPaLasKa iNC. 311 I C STREET · TELEPHONE (907} 279-0644 MAILING ADDRESS: P.O. BOX 4-1379 ANCHORAGE. ALASKA 99509 March 10, 1976 CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. O. K. Gilbreth, Director Gentlemen: Well Sag Delta (33-12-16) E~closed herewith please find in duplicate, Form P-4, Monthly Report of Drilling and Workover Operations for the above described well, for the month of February, 1976. Very truly yours, BP ALASKA INC. vip Enclosures G. D. Taylor Manager Operations cc: Well File Sag Delta #17 - / - ." i j ,,'r~ L! ~" d I~..F'G, t~,~z_~ ~d,~',, c,..,,~ U ',.3, l,...~qJ / DEPART)lENT OF NATURAL RESOURCES/$25 DIVISION Of L ANDS E. 4TH AVENDE-ANCHORAGE 99501 i,,"~c:::h. 1, 1976 MAR $ - I976 BP Alaska Exploration, Inc. P. O. Box 4-1379 Anchorage, Alaska 99509 Attention: H.A. Schmidt Re: LO/NS 75-29 Gentle~x~: TD~ modification of the plan of ope~atio~ dated February 5, 1976, is k~-~_reby approved subject to the sam~ stipulations outlined in our approval letter of April 7, 1975. Sincerely, Pedro. Denton Chief, ~2nerals Section 02,,0018 STATE O. K. Gilbreth, Director Divisio~ of O&G f, Minerals Sectioj)~""'""' DATE SUBJECT: February 11, 19 ID/NS 75-29 Sag Delta 33-12-1~ ADL-28337 Attache~ is a ¢o~ of IH~'S modification for th~ subject well.. We see no problems but if you wi~h to oo~ment, please do so. Attac/~ 69~ - ~ BP ALASKA EXPLORATIOI~'*:¥'~:C '":' P.O. BOX 4-1379 3111 - C - STREET ANCHORAGE, ALASKA 99503 TELEPHONE (907) 278-2611 February 5, 1976 State of Alaska Department of Natural Resources Division of Lands 323 East 4th Avenue Anchorage, Alaska 99501 Attention: Pedro Denton, Chief Minerals Section Gentlemen: Modification to I/kNS 75-29 Sag Delta - 33-12-16 ADL 28337 Further to our letters of July 3, 1975 and December 31, 1975 concerning Sag Delta Well 33-12-16, ADL-28337, we now enclose two copies of Drawing CC-001-03. Our Drilling Department has found it necessary to make certain modifications to the drill pad, using gravel supplies stockpiled on the existing pad. These modifications consist of: 1]' Enlarged reserve mud pit. 2] Enlargement of the drilling pad adjacent to the standby sewage holding lagoon. 3] Relocation of flare pit for safety reasons, taking advantage of prevailing winds. The above amendments are further depicted in red on 'the enclosed drawings. Please include these modifications with our previously suhnitted Plan of Development, thereafter giving your approval, non-objection, or ~ts as appropriate, to this office. FER 1 Very truly yours, H. A. Schmidt District Lan~ of ALASKA ~ DEPARTMENT OF NATURAL RESOURCES Division of Oil and Gas TO: FO. K. Gilbreth, Jr. Di rector Thru: Hoyl e H.. Hami 1 ton Chief Petroleum Engineer Russell A. Douglass ~.0 Petroleum Engineer Consultant DATE '..February 11., 1976 SUBJECT: -~IOw O.tverter Systmn, BP .Sag Delta 33-12-~.16, Prudhoe .Bay Tuesday, February 3, 1976- Flew to Deadhorse on the BP charter.flight~ from. Anchorage. Purpose- of my trip' ~as"'t° inspect .the fl.ow dtverter system .on BP's Sag Delta well. This is the first well to be drilled since the pool rules were.revised, requiring this system on the surface hole .... I proceeded to BP's base camp and talked with Swede.Swenson. He arranged trans-... portatton to the drtll site of Nabors Rig g. Met JtmBrown,-BP drilltng supervisor, on location and together we took a .l.ook at the dive~, system. It consisted of a 20" X 20" dtverter with a 20" hydrtl on top.~ A 10 3/4" line comes off. the dtverter . · & and through a butterfly valve, which is kept.closed..The 1.0 3/4 1.)ne ([tgure.. 1... 2) about 180 feet long, ran straight to an open .pit. _Another valve .was tns~lled-at the end (.F. tgure_3)aand is always open... An auxiliary 7".~l_tne Is_conn. ected near the end (~), but before the valve cm. the 10 3/4" ltne....Thts .llne runs alongside .the pit aha is open at the end approximately 230, from where the l0 3/4" line opens. All pipe is welded and each joint.was visually inspected ~fOr :obstructions before welding. The only fault with the system was.,the fact that it was, welded. This means the system would have to be dtsmantled,_then refabrtcated at anew location. This does not affect its capability to perform the required functions of a diverter, system, . In summary I inspected the diverter .system installed an. BP's Sag Delta 33-12-16 well. This system is a new addition to the Prudhoe Bay Pool Ru]es as of !/g/76, The system was above specifications and met all requirements of .C0.#137. Attachments 0 o zIP SEMI-LOGARITHMIC 3 CYCLES X '[40 DIVISIONS KEUFFEL & ESSER CO. 46 5813 MADE IN U.S.A. · ../ Nove, ber 4, 1975 Re: Sag Delta BP Alaska Znc. 75-58 Mr. G. D. Taylor Manager Operations BP Alaska I~. P. O. Box 4-1379 Anchorage, Alaska Dear Sir: 99509 Enclosed ts the approv~ appltcat, ton f~ perm{tto dr111 the..above .referenced well at a locatlon tn Sectton 33. Townshlp 12N,-Range t{ell samples, core chips, and. a mud 1o9 .are required. · A d{recttonal survey ts required. .. Many rtvers tn Alaska and thetr dratnage systems have been classtf,ied as. Important for the spawntng or migration of ana~ fl~h. ~rattofls in these areas are sub{ect -to AS 16,S0.870 ~ t~._~latteas ~]gated.lthere- under (Tltle 5, Alaska Admlntstratlve Code)~. Prfor 'to-:c~{t~ operat, ons you may be contacted by the Habttat Coordt~tor's ofl'tce.-..:~tment o¢ Fish and Game. Pollution of any waters of ~ State ls prohibited bY..A$ 46, ~p~ .03, Arttcle 7 and the regulatt(ms ~Iga~ ~~ (Tttle _18, Atask. a 1 Admlntstrattve Code,. Chapter.70) and by t~ Federal. Mater. Pollution contro- Act, as amended. Prtor to ~tng operettonS .you may be con~c~d by a representative of the Oepartmnent ef Env~~l ~atlon. Pursuant to AS 38.40, Local Htre :Under State ~Leases, ~ Alaska Department of Labor ts betng not1¢ted of the lssuance of thls permtt to dr111. To a td us tn schedullag fteld ~ork, we would apprec{ate _your notifying this of¢tce wtthtn 48 hours after the well ts s~. ~ would also 11ke to be nottfled so that a representative of the O4vlston may ,be .p~es~t to wttness testtng of blowout preventer equipment .before surface caslng shoe ~s drilled. gr. G. D. Ta~lor I~. Tha~s R. t~rsl~11, ~. November 4, 1975 In the event of suspenst~ or abandoment please gtve thts oCftce adequate advaace notification so that we may have a wltness present. Very truly yours, Thomas R. Marshall, gr. Executive Secretar~ Alaska 0tl ~d Gas Conservation ¢o~nlttee TRl4:be Enclosure cc: Oepartment ot' Ftsh and. Game.,. Habitat Section w/o eric1. Departawnt of Envtromne~tal' Conservation w/o enc]. ~rtsmat-of-Labor, Supervisor, Labor Law Compliance Otvlston w/o eric1. October 27, 1975 Alaska Exploration Inc. P.O.Bo~ 4-1379 Anchorage, ALasP~ 99503 ~Re: LO~S 75-29 ~ ADL-28337 Attention: H.A. ~t DL~rict ~ By letter of October 21~ 1975, you dis~msed items 2, 3 and 4 of our 1975, ~$ ~ ~le r~~ of ~ Dlv~l~ of O~ ~ [~. ~ You have typed confident/al on ~he top of ~ letterd4ated October 21, 1975. We do not oons~ this of a confidential nature~ Sincerely, PEDRO DragON (~!ef, mLnerals Section Div. O&G Scott Grundy, ADF&G OCT 3 i 1975 JAY $. HAMMOND, Governor i DEPART~IENT OF NATURAL RESOURC 'S .... j'-~. ~:~r 6~' !~ ~WfSIO~ OF ~4~D~ ~TI~ AVENUE ..... ~' c ',,~.,-~ I '..' ~to'.~r 27, 1975 1 ~ BP AlasP. a Exploration Inc. P.O.Box 4-1379 ~Anchorage, Alas.W~ 99503 .LO,~JS 75-29 Sag Delta W~ll ADL-28337 ... . .. ..... i ..... ,.-- ' :... - ~,). Attention: H.A. Schm~dL District By letter of October 21, 1975, you discussed items 2, 3 ~u~ 4 of our approval of October 14, 1975. The proposals in items 2 and 3 are hereby approved. Item ~4~.as indicated in our letter of Octobe~ 1~--~7 1975, comes under the review of the Division of Oil and Gas. ~ You 1maya typed confidential on ~he top of your letter dated October 21, 1975. B~ do. not consider this of a confidential nature., PEDRO DmkvIC~ Chief, R..~nerals Section 00'1'~ .:l~f5 BP ALASKA EXPLORATION INC. CONFIDE~(~-~i~ ANCHORAGE ALASKA 99503 TELEPHONE (907)279-0644 October 21, 1975 State of Alaska Department of Na'tural ReSources Division of Lands 323 East Fourth .Avenue ~ Anchorage, AK 99501 ATTENTION: Mr. Pedro Denton - Chief Minerals Section Re: Your File #LO/NS 75 29 Sag Delta Well #4-11.-16 (Surface Lo- cation) and 33-12-16 (Bottom Hole Location) Oil and Gas Lease #ADL-28337 Dear Mr. Denton: Items 2, 3, and 4 in your letter of October 14, 1975, were the sub- jects of discussion with the state Division of Oil and Gas on Oc- tober -17, 1975. Following these discussions and clarifications our response is as follows: ITEM #2 It is our standard practice to use steel tanks for holding the mud supply during drilling operations. The open mud pit incorporated in the drill pad is intended as a safety reservoir for holding sur- plus quantities of mUd and cuttings. Prior to use, this pit is sealed with a bentonite coating, which from experience, has proven to be an effective method for containing sump fluids. ITEM #3 SurroUnding the fuel tanks with a gravel berm and impervious liner is not a relyable spill containment procedure. Placement of heavy fuel tanks within the diked area ruptures the liner, destroying its effectiveness For winter operations we have found that dikes con- structed of multi-layered snow and ice to b'e more effective than a gravel supported liner. With your concurrence, we would surround all tanks (including those with double hulls) with snow - ice berms 'for spill containment purposes. -2- IT~EM #4 It is our intention to advise the Division of Oil and Gas suffic- iently in adVance of a blow Out Preventer test ~to allow for a State representative to. be present during the test. While drilling opera- tions are in progress, our operating manuel requires the following blow.out prevention tests: 1. Daily operational~ tests. 2. Weekly pressure tests. Please advise if further monitoring of these tests by a State rep- resentat'ive is required. Kindly reply as soon as possible, whether the procedures set forth above are accePtable.' 'Herman A. Schmidt District Landman HAS/ks cc: Hoyle H. Hamilton,. Chief Division of Oil and Gas 3'001 Porcupine Drive Anchorage, AK 99504 CONFIDENTIAL z-~ ~ Not~--~-,~y Bra~h C~ ief · Dow~--.g .......... ~]el~0n ........... - ~ecretary ....... Assigned ....... ,. BP ALASKA EXPLO~ATIO~ i~"~3e in Branch ............ P.O. BOX 4-1379 3111 - C ° STREET ANCHORAGE. ALASKA 99503 TELEPHONE (907) 279-0644 EXP-PB-200/3 October 21, 1975 State of Alaska Department of Natural Resources Division of Lands 323 East Fourth Avenue Anchorage, AK 99501 ATTENTION: Mr. Pedro Denton- Chief Minerals Section Re: Your File #LO/N~~5-2~a Well~#4-11~-16 (Surface Lo- cation) an~33_12_16~6~ottom ~-i~e Location). Oil and. .Gas Lease #ADL-28337 Dear Mr. Denton: Items 2, 3, and 4 in your letter of October 14, 1975, were the sub- jects of discussion with~;the State Division of Oil and Gas on Oc- tober 17, 1975. Following these discussions and clarifications our response is as follows: ITEM #2 It is our standard practice to use steel tanks for holding the mud supply during drilling operations° The open mud pit incorporated in the drill pad is intended as a safety reservoir for holding sur- ~ ~*-'+ies of mud and cuttings. Prior to use~ this pit is p~us qua:,.-~ sealed with a bentonite coating, which from experience, has proven to be an effective method for containing sump fluids, ITEM #3 Surrounding the fuel tanks with a gravel berm and impervious liner is not a relyable spill containment procedure~ Placement of heavy fuel tanks within the diked area ruptures the liner, destroying its effectiveness. For winter operations we have found that dikes Con- structed of multi-layered snow and ice to be more effective than a gravel supported liner. With your concurrence, we would surround all tanks (including those with double hulls) with snow - ice berms for spill containment purposes. -2- ITEM #4 It is our intention to advise the Division of Oil and Gas suffic- iently in advance of a blow out preventer test to allow for a State, representative to be present during the test. While drilling opera- tions are in progress, our operating manuel requires the following blow out prevention tests: 1. Daily operational tests. 2. Weekly pressure tests. Please advise if further monitoring of these tests by a State rep- resentative is required. Kindly reply as soon as possibles whether the procedu, res set forth above are acceptable° Herman A. Schmidt District Landman, HAS/ks cc: Hoyle Ho Hamilton, Chief Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99504 P.O.Box 4-1379 Ar~, A/aska 99503 Re: LO/Y{S 75-29 AUD-~337 Attention: }L A. ~dt Die, rick landman The plan of.c~ cu~!.~ned in your letter of July 3, t975, is ap~ letter. ~ated April 7, 1975, plus the following: 1. After Apri~ 15, 197~, the use of ground contact vehicles '2. B~muse of th~ location on th~ river-d~lta and th~ pr~ty to sea le~1, ~ tanks must b~ used for the mud pi~ unless 3. A plan for a ~ surro~.~u~ the 4ou~.~e %~/~ f~.m~ tankz with an tmpez~ou~ 1Lner must be_ f!ls~ before ~prove~ by' the Divis~_~n of Oil ~ Gas.. Scott ~, ADFaG Div. of Oil & Gas imt~r Dept. Well Number Sag ProPosed Drilling Program Dry bucket 26" hole to about 80 ft. below ground level and cement conductor to surface using Permafrost cement. Install 20" diverter. Drill 17-1/2" hole to about 2700 ft. and cement 13-3/8" casing to surface using Permafrost cement. Install 13-5/8" 5000# BOPE. Drill 12-1/4" hole under directional conditions to approximately 9000 ft. TVD. Cement 9-5/8" casing in stages with Halliburton Light, class "G" and Permafrost cement. Drill 8-1/2" hole under directional conditions to TD at approximately 10,750' TVD. Cement 7" liner to approximately 500 ft. inside of 9-5/8" casing-shoe with Class "G" cement. Blowout preventer program will consist of at least two 5000 psi W.P. ram-type and one annular-type blowout preventer from the 13-3/8" casing point to TD. A 20" diverter, will be installed on the 20" con-~ ductor pipe from 105' to 2700'. bP ALASKA INC. 31 1 1 - C - STREET · TELEPHONE (907) 279-0644 COI iI)mTIAL MAILING ADDRESS: P.O. BOX 4-1379 ANCHORAGE, ALASKA 99509 October 9, 1975 CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. O. K. Gilbreth Director Gentlemen: Well Number Sag Delta (33-12-16) Enclosed please find the following documents: 1. Application for Permit to Drill Well Sag Delta (33-12-16) 2. Proposed Drillimg Program Outline 3. Our check in the amount of $100.00 to cover the permit filing fee 4. Three copies of surveyor's plat showing well location. Very truly yours, BP ALASKA INC. Manager Operations Enclosures 61 la OCT ! 0 i975 cc: Well File #17 i:~.~i!~::i~.?~ ,,., ,.~ ......... Form 10'-- 401 R~V. I--I--71 l&.TYPE OF WORK b. TYPI OF WmLL OIL ~ WELL STATE OF ALASKA OIL AND GAS CONSERVATIO'N PERMIT TO DRILL OR DEEPE DRILL ~ DEEPEN 0'" ~ Wildcat 2, NAME OF OPERATOR BP Alaska Inc. 3,ADDRESS O~F UP--TaR P. 0. BOx ~-1379, Anchora§e, Alaska 99509 LOCATION OF WELL Atsurface 749' EWL, 1000' SNL, Sec. 4, TllN, R16E, UPM At proposed prod. zone 750' EWL, 1180' NSL, Sec. 33, T12N, R16E, UPM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 15 miles east of Deadhorse CONFIDENTIAL API#50-029-20176 ADL-34634 - BHL 1. IF IN"DIAN, ALLOTTEE OR TRIBE NA2~E None 8. UNIT, FARM OR LEASE NAME None 9. WELL NO. Sag Delta (33-12~16) 10. FIELD AND POOL, OR WILDCAT Wildcat !l. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 33, T12N, R16E, UPM I4. BOND INFORMATION: .state of Alaska TYPE Blanket S,rety ~.d/or ~o. Federal Insurance Company 80391192 ~o,,-, $100,000'.00 15 DISTANCE FROM PROPOSED' 7"^' g. f 'mNO. OF ACRES IN LEASE -!17. NO. ACRES ASSIGNED LOCATION TO NEAREST ' ~)U O [ TO ~iS WELL PROPERTY OR LEASE LINE, ~. 640 (A~o ~o ~rest d~. ~i~, i~ a~ ~ ~ ~ .... acre srac~n~ ~, DISTANCE FROM PROPOSED LOCA~ON* ]19. PROPOS~ D~ '~ 20. ROTARY OR CABLE TOOLS TO NEAREST WELL D~LL~NG, COMPLETe, OH APPLIED FOR, ~. Approximately 11 miles-SE of Niakuk#~ 10,750' T~ 11,050'~· Rotary 21. ELEVATIONS {Show whe~thcr D~, HT, CH, etc.} ]~. APPHOX. DATE WORK WILL STAHT* ~E 25' ~SL (est.) ~ 12/15/75 23. PROPOSED CASING AND CEMEN~NG PHOGR~ , , SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRAI~E ~ ~DsIcrrlNG DEPTH MD quantity of cement 26" 20" 133# K-55 105' 105' 150 cu. ft. 17-1/2" 13-3/8" 72# N'80 Z700' 2700' 3~00 cu. ft. ~ 12-i/4" 9-5/8" 47# , N-80 &;000' 9235" 2500 cu. ft. , , '~ S°p -95 8-1/2" 7" 29# ' N_80 L0,750' 11050'! 350 cu. ft. " See attached Drilling Program Outline. IN ABOVE SlmAC"E DESCRIBE PROPOSED PROGRAM: Ii proposal is to dee~n 'give ~ on present p~u~lve zo~ ~d pro~ ~w prffdu~iVe ~e. Jf_~C~I iS W drill 0r a~n d~ec~[o~lly, give pertinent ~' on s~bSu~a~ ~tW~ ~d .meas~d ~d ~ue Ve~ical dept. Give blo~ut P~e~e0ter- p~gFam.. -" - 24.1 hereby certify~~n~ is~-ue anc~ Correct (This space for S~te office u~) CONDI~ONS OF ~P~V~, IF A~: SAMPL~ AND CORE CHIPS H.~U~ I MUD LOG ~ ~U~~: I ]¥ES ~ NO P~RM1T N~ APPROVED .~o- o z g .- 7_0/' 7g, November 4, 1975 A~I~ROVAL DAT~ Manager Operations · mm,Executi ve Secretary · ~' In,lmctionl On Reve~ Side DAT~ November 4, 1975 Well Number San Delta (3~-12-16) Pr__oposed D~-ill~in~. Program Dry bucket 26" hole to about 80 ft. below ground level and cement conductor to surface using Permafrost cement. Install 20" diverter. Drill 17-1/2" hole to about 2700 ft. and ce.ment 13-3/8" casing to surface using Permafrost 'cement. Install 13-5/8" 5000~ BOPE. Drill 12-1/4" hole under directional conditions to approximately 9000 ft. TVD. Cement 9-5/8" casing in stages with Halliburton Light, Class "G" and Permafrost cement Drill 8-1/2" hole under directional conditions fo TD at approximately 10,750' TVD. Cement 7" liner to approximately 500 ft. inside of 9-5/8" casing shoe with Class "G" cement. BloWout preventer program will consist of at least two 5000 psi W.P. ram-type and one annular-type bloWout preventer from the 13-3/8" casing point to TD. A 20" diverter, will be installed on the 20" con-. ductor pipe from 105' to 2700'. 'r I I I ~'xlut:-oIP~ I I I I I ~'~'~II I 2~ I 2T I 26I 25 I I I I I ~ I I ~___ 1 ~S S~8 DKLT~ (55-~-~6) LONG. 148°06'16. I I I = I X: 735,543 I Y: 5,977,898 I I I GROUND ELEV PROPOSED SAG DELTA (:53-12-16) 5 34 - STAKED 36 ~ ~ CERTIFICATE OF SURVEYOR · I hereby certify that I om properly registered and licensed to practice land surveying in the State of Alaska and that this plot represents o location survey mode by me or under my supervision, and that oll dimensions and other details ore correct. Dote 5"4~_000 . SURVEYOR DETAIL No Scale BOTTOM HOLE LOCAT!Q~ OL,: 0 1975 ~I2N. SA6 DELTA (33-12-16) T. 12 N. '[liN. REVISED WELL NUMBER OCT. 3,1975 C.J.R REVISED PROPOSED BOTTOM HOLE LOC. SEPT. 30,1975C.J.R. ADDED BOTTOM HOLE LOCATION JUNE 25,1975 C.J.R. _ I AS- STAKED SAG DELTA (33-12-16) Located in NW I/4 PROTRACTED SEC. 4~ T. II N.~R.16E.~ UMIAT MERIDIAN,AK. Surveyed for B.P ALASKA INC. Surveyed by F.M. LINDSEY I~ ASSOC. LAND & HYDROGRAPHIC SURVEYORS 2502: West Northern Lights Boulevard Box 4-081 Anchorage Alaska I I MEMO RAN DU TO: Pedro Denton Chief Mineral Section FROM: O. K. Gilbreth, Director State o, Alaska DATE: September 26, 1975 FILE NO: l~umber 3.14 & LO/NS 75-29 Sag Del ta TELEPHONE NO: SUBJECT: BP Sag Deltap~i-,q-t~-~-~'''f'ttc---'' Reserve Mud We have reviewed the plan of operations submitted by BP Alaska for subject well and cann_ot.__~_~c~~b~):~_)~ of the plan as presented without addi ti onal-ekPl-a ina ~i on. Several recent events open new considerations concerning drilling. location reserve pit areas. On page 2, Item ll, the reserve pit as outlined has been an approved method of construction for reserve pits on the North Slope and in the defined field area; however, this well will be in an unexplored area of the field. Also, since the location, is well out on the river delta area and very near sea level, we have reservations about the ability of the operator to confine contaminates to the mud pit or exclude seawater from the pit. Perhaps steel tanks such as utilized on the Niakuk and Gull Island locations would be.best. Under Item 13, for Fuel Storage BP states the operational use of the double walled fuel tanks at Prudhoe Bay and the Kemik Unit #2 Wellsite, has "a history of zero spills". On a recent inspection visit with USGS at the Kemik #2 location we observed what appeared to be diesel oll leaking out of the gravel pad and proceeding down the road several hundred feet. Use of a double walled tank obviously does not preclude all leaks or spills onto the pad and we are still of the opinion that additional secondary containment provisions ~h~:-,~e~essary.. Item 14, indicates that no BOP equipment will be installed until surface casing has been installed. Since this is considered an exploratory well, we will require BOPE equipment prior to setting the surface casing before we will approve the drilling permit which. has not yet been requested. Attachment MEMORANDUM State of Alaska TO: Pedro Denton Chief ~ltneral Section FROM: O. K. GIlbreth, Director DATE: September 26, 1975 FILE NO: Number 3.14 & LO/RS 75-29 Sag Delta TELEPHONE NO: Reserve I~ud Pt . Ne have reviewed the pltn of operations submitted by BP Alaska for sub,oct well and cannot recommend approval of the pian as presented without additional explalnatton. Sever&l recent events open new considerations concerning drt111n9 location reserve pit a~eas. On page 2. Item 11, the reserve ptt as outlined has been an approved'method of construction for reserve pits on the North Slope and tn the defined field a~ea; however, this well w111 be In ~n unexplo~ed area of the fteld. Also, s?nce the location Is ye11 out on the r~ve~ delta area and very near sea lev. el, we have reservations about the abt.11ty of the operator to co,fine co. tab, nates te the ~ud p~t or exclude se~ter f~om the p~t. Perhaps steel ta~s such as utilized on the g~a~u~ ~nd Gull Zs1~nd locations ~euld be best. Under item 13, for Fuel Storage BP states the operational use of the double walled fuel tanks at Prudhoe Bay and the Kemik Untt g2 Mol!site, has "a hlstery of zero sptl!s". On a recent Inspection vtslt wtth USGS at the KemJk t.2 1,carton we observed what appeared to be dtesel o11 leaktn out of the §ravel pad and proceeding down the road several hundre~ feet..Use of a double walled tank obviously does net preclude all leaks er sptlls onto the pad and we are st111 ~f the opJnton that additional secondary containment pr, visions ~~{enessary. Item 14, fndtcates that no BOP equipment wt11 be Instal]ed unt11 surface castng has been Installed. Stnce thts ts considered an exploratory well, we wt11 requlre BOPE equipment prtor to setttng the surface castn9 before we wt11 approve the drtllln9 permit whtch has not yet been requested. Attachment MEMORANDU? TO: FROM: O. K. Gilbreth, Director Division of Oil & Gas State .-xlaska FILE NO: ' . 3.,1..].4 & EO,~I'S 75-29 TELEPHONE NO: ,~t, cJ' De~'J::~ ...... !,." "; - ("~ · SUBJECT: ' i ' : .... Sag Delta 4-11-16 ID/NS 75-29 ---Fi. ' =",:';:. :.'.,,~ , ..... .... J. . F,';V " Er~--tosed is a plan of operations from BP AI~~ka. Also enclosed are Fi~% ~ G~ o~---~.nts. As 2c~ c~ see ~',~..y- red, est that you review this application to make sure tbs reserve mud pit is adequate. EI~oslire "lJ SEP 1 9 1975, DIVISION ot,' OiL AND ~' '{" ~ ' ¢~ "* 1-~ MEMORANDUM TO: FROM: O. K. Gilbreth, Director Division of Oil & Gas State of Alaska DEPARTMENT OF NA~ RESOURCES DMSIONfOF LANDS DATE: FILE NO.' August 29, 1975 3~14 & ID/NS 75-29 Sag Delta TELEPHONE NO: I SUBJECT: Pedro Denton Sag Delta 4-11-16 Chief, ML~nerals Section ID/NS 75-29 Enclosed is a plan of operations frum BP Alaska. Also enclosed are Fish ar~ Games ~ts. As you can see tb~y request that you review this application to make sure: the reserve~.~ud pit is adequate. Enclosure P.S. Enclosed is a copy of the map showing the reserve mud pit and layout. May w~ have our mp returned %~m~h your review. SEE .1975 I I 3, I I PROPOSED I BE',4Ub-Otp I I I I I I I I I I I I I j f-- T , ~2 I I I I I ~ I ~ SAG DELTA (33-12-16) I BOTT M HOLE LOCATION'~I,~ SEE DETAIL II ~ ~ AS- STAKED I I LONG. = 148°06' 16. 5 I X= 733,543 I 4 Y= 5,977~898 I 35 I 2 I 25 36 I T. 12N. I I ,,,__~. GROUND ELEV = 2' I _ / ~ ~ SCALE~ I"= IMILE CERTIFICATE OF SURVEYOR I hereby certify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision, and that all dimensions and other details are correct. Date SURVEYOR DETAIL No Scale PROPOSED BOTTOM HOLE LOCATION TI2N. SAG DELTA (33-12-16) I 5 4 ,., ,- OF 4/. -~ ~,,~ ..... ......,~,? · -- ~, ir ,./~...,: V 9e, I / '~1 er. RE VI~ED WF[ I NUMBER ~)CT ~,19~5 C J.N ADDED BOTTOM HoLF LOCATION JUNE 23,19t~ C,JR SAG DELTA Locoted In Surveyed for B. R ALASKA INC. Surveyed by F. M. LINDSEY I~ ASSOC. LAND /& HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-081 Anchorage Alaska 'MEMORANDUM State of Alaska TO: Pedro Denton, Chief Minerals Section Alaska Division of Lands Anchorage DATE: FILE NO: 'TELEPHONE NO: FROM: James W. Brooks, Commissioner SUBJECT: Department of Fish'and Game J. Scott Grundy, Reg. Habitat Supv Habitat Protection Section Fairbanks August 20, 1975 LO/NS 75-29 Sag. Delta Well #4-11-.I6 The Alaska Department of Fish and Game has reviewed the subject proposal and development plan by BP Alaska and found it to be an excellent plan of operation. Because an oil. spill or discharge in this vicinity could be disasterous to Fish and Game resources, we request the Division of Oil and Gas review this application in detail to be certain the management and size of the reserve mud pit is adequate to contain all discharges in the event.of an emergency. Because of the location we suggest that steel containers be considered for use in lieu of gravel reserve mud and flare pits. We have no objection to the proposed use of water from the Sagavanirktok River in this vicinity, However, if a representative of this Department considers the use of water to be detrimental to fishes overwintering in the vicinity, this approval is subject to immediate cancellation. As we understand, a water use permit may be required by the Water Resource~Section of your Department. Has the possibility of desalination been considered? We wish to stress the importance of completion of all activities in the a~ea ~ prior to spring breakup 1976 to avoid conflicts with migratory avifauna. (~,~ 'This authorization is valid only until midnight May 20, 1976 or spring breakup,- whichever occurs first. cc- D. Lowery W. Copeland D. Nation H. Schmidt D. Braden H. Hami!~on,~'~ AUG 5 1915 BP ALASKA EXPLORATION I1~:~::.~: -': ............. " P.O. BOX 4-1379 3111 - C - STREET ANCHORAGE, ALASKA 99503 TELEPHONE (907) 279-0644 EXP/PB-200/3 (Confidential) July 3, 1975 State of Alaska De~t of Natural Resources Division of Lands 323 East Fourth Avenue Anchorage, Alaska 99501 Attention: Pedro Denton Chief, Minerals Section Enclosed in triplicate is a Development Plan with exhibits for proposed drilling operations of Sag DeltaWe!l ~4-11-16, within Oil and Gas Lease ADL-28337. As you are aware, the drilling pad at this location was constructed prior to spring breakup during April 1975, and that the site is unoccupied at the present time. Although there is no intention of returning to the location until the 1975/ 1976 winter drilling season, the enclosed material and information is being submitted at this time to allow an~le time for its consideration. Hopefully, this advance planning will result in multiple tim~ saving divi- de~s and increase the probability of a permit being granted in advance of desperate need. ~ne application to drill the well will be filed with the State Division of Oil and Gas at a date closer to the projected well commencement time. ID. the meantime, we shall begrateful if the information contained herein is given confidential handling procedures. H. A. Schmidt District Landman Enclosures PROPOSED SAG D~TA · DEV~_LDPMEh~f PLAN BP AIA~KA EXPLOP~ATION INC., OPERATOR l. ¸2. 3~ . . SITE IOO%TION (See Exhibit "A") The proposedasite of Sag Delta 0~ is the NW 1/4, Section 4 TllN, R16E, Umiat N-eridian. SITE DESCRIt>~ION The drilling pad has been constructe~d on ~n tmvegeta'~ed silt flat in the delta of the Sagav~irktok .P,~ver. The grog. md elevalion at the site is approximately ~o feet (2 ft. ) above mean sea level. SITE D.PA_TNAGE The drill site slopes gently towards the Beaufort Sea and the nearby river channels. Adequate drainage to these areas from the site will result. AREA WILDLIFE Field inspections have revealed little wildlife in the area during the anticipated operational period. Construction and drilling operations for the proposed well will comum_nce after freeze-up and be completed prior to the spring thaw. Some birds which may be found in the general area during winter are willow ptarmigan, sncx~y owl, and the comron raven. Other birds are probably in the general area during the summer as well as caribou, %~lves, fox and legndmg. It is anticipated that operations will not hinder the daily habi-hs of any local winter wildlife. AREA FISH The drilling site is located approximate.ly 3/4 mile from the n~ain channel Sagavanirktok River and drilling operations should have no effect on fish that may use the river. 6. AREA SETT!.F~4~NT No settlers or villages are i_n the vicinity of the proposed location. About 13 miles southwest of the vmllsite is Deadhorse, the closest settlement which has a public airport, hotel, and support facilities. No road exists between Deadhorse and the site. Surface transportation is possible only in the winter after construction of ice and/or snow roads. 7. ACCESS PLAN (See Drawing CC-001-04) A winter road will be constn~cted from the existing spine road to the proposed wellsite via the Sagavanirktok River after freeze-up 1975 (Exhibit). The ice and/or sn~¢ roads will be maSmtained above tundra _c~rade and no blading of ttmdra will be done. Where feasible, the winter road will be off-shore or follcx~ the river bed to minimize road construction on the t~ndra. Clusters of ~ick scrub gro:~Th will be avoided. Roads will be maintained and clearly marked during operations. -1- . . 10. 11. 12. 13. Stmeam and river crossings will be acco~plisha~ by constructing ice and/or snow bridges at the ba_nks. No doz]~.g or ievelh~g will Da done which might disturb stre~am banks. Construction equi~ent, the drilling rig, fuel, a~.~d ~'ost supplies will be transporte+3 overland from Prudhhe Bay by trucks, sleds, ~d rolligons. The rolligons a~d sled trains c-~n-travel over snOW with no clearing or leveling except for the deep sno..~ drifts whid~ t/ney cannot negotiate. SITE PLAN (See Drawing CC-001-03) The drillsite has been constructed of ice-free gravel and consists of a single pad of minimml size with sufficient areas for the drilling rig, can~, storage and pits. GRAVEL SOU~,CES Gravel has been extracted from exposed bars and channels in the Sagavanirktok River with T10N, R15E and TllN, R15E, bTaM. The gravel has been ha~tled to the pad lOCation using an ice road fol].c~g one of the channels of the Sagavanirktok River. This phase of the operation was completed April 28, 1975. PEtqV~FRO ST The drilling pad has been constructed on silt delta. Total depth of Permafrost beneath the wellsite is estin%ated to be 1800 feet. Normally, only the top few feet thaws in summer. Facilities with a source of heat (i.e. camp) will have insulation and/or air circulation beneath to insure that thawing belc~ the gravel pad does not OCcur. RESERVE PIT The reserve mud pit adjacent to the drilling pad is five feet deep and constructed entirely above the tundra. The gravel berm surround- ing the pit has been core, acted and the coat the gravel in the berm to provide an mnpervzous barrier~_ FLARE PIT A flare pit has not yet been constructed, but 16,000 cubic yards of gravel have been stockpiled on location for this purpose. FU?_/3 S~DRA~ (See Exhibit "B") ~in fuel storage (2 x 20,000 gallon double hulled steel ta~s) will be lOCated at the rig site. These tar~s were originally fabricated in 1973 at the request of BP Alaska Inc. ~ihey are designed to provide protection against spillage and a means of secondary containment. Their double hull has been found to ~ superior to bladder tanks and gravel dykes with liners. These -2- portable tar~<s have keen .in opera t_i.ona], use at PrucLhoe P~y and th~. K-~d~ .Unit ~2 wellsite for over one year, with a histo~~ of zero -i~i'ils' a~-elir~Lnates the need for addiaio~ ~'~e'I-'~xcavation and db~rUction of dykes. Their use follo~.d discussions wimh the EnviromP~ntal Protection Agency, and State Departrent of L~virop. menta~ Conservation, and agre~Jnent by those departments, containm~nt dykeo// could be elh~nated. The tanks are designed and construCted to provide storage for the centents of the inner t~s in the event of a leak and also to provide containment in the event of an overfill. Provisions have been incorporated to all~ drainage and inspection of the annuli between the two hulls. '~' Filling of the tmmks is accomplished by bottom loading. In the .,.i event of an overfill, the fl~¢ will run dc~vn the sides of the inner tank and be contain~t in the annulus. Tanks are gauged visually on filling and stick-dipped for record keeping. As referenced earlier, all persomnel engaged in handling these tanks will be briefed on the posted Fuel Transfer Procedures with recurrent discussions at shift changes. Company contracts provide for the discharge of contractor's employees found guilty of gross negligence. The lines leading from the double hulled tanks will be protected by burial to allow traffic .passage. Employees will be briefed on the location of these lines and the necessity for caution in operating around them. For those tanks provided by the contractor that are not double hulled, a sn~ berm will be constructed for seCOndary con'tain~ent. Once the sn~¢ berm is constructed, it will be sprayed with water, which when frozen will form an ice barrier. Any fuel from a spill coming in contact with this ice would be at ~mbient temperatures. Insofar as the drilling program calls for completion prior to break-up, these dykes will be competent based on past experience. They also eleiminate the need for additional gravel and site restoration. . .. Fuel transfer procedures will be developed for all fuel storage and transfer facilities. These will consist of posting at the appropriate facility, flow diagrams and printed instructions, in conj%~nction with tagged valves, showing the proper valving seq~ence to safely transfer fuel. The Rig Representative will discuss this with the work shifts daily as a reminder and to answer any questions. The same type of procedures have been drafted, with the concurrence of the EPA, for use in the Prudhoe Bay Operating Area. 14. BLOK~DgT PREVEN~flON EQUIR ~MARrf (See Exhibit "C") Afar. er s_~urface casing has been ~t~ll~,. BOPE will be in use continuously durmng drzlIing operations. The BOPE wzll conszst of an annular . · ..' -3- 15. 16. 17. 18. preventer, pipe a~d blind rams. 11~e BOPE will be pressure tested ~=~.~ed. iately after installation and at least weekly thereafter. In additien, daily ope. rational checks will k~; made. SPILL PREV~WTION, CONTFROL AND COU~P'kLR NEASUPJES Areas of potential hydrocarbon spills include 'the reserve .pi~, the fuel storage t~xf<s ox'~d 'k_2le wel~re. ~Operator will provide a we].ded steel building of 3/16" steel plate, skid mounted, measuring 9'W x 7'H x 16'L. This buildimg will have access doors at each end with inte~al lighting ~nd contain a sufficient quantity of sorbent materials and necessary clean-up small tools. This counter-measure building will be located on the site and employees familiarized in the use of its contents. Ln addition to the counter measure building, the contractor will have located on the site, items of heavy equipment such as dozers, front-end loaders, vacuum trucks and graders. If a spill shot~ld occur in spite of the preventative measures previously described, equipment will always be available to immediately construct contain- ment berms. Since the surrounding plain is nearly flat, contair~rent should be easy and clean-up relatively simple. Snow cover and the frozen condition of the tundra would minimize environmental damage. .LAYOUT (See Ey/~.Lbit ,'E") ~ne cexp area on the drilling pad is sufficient for a typical 50- Pan om~. ~Yne configuration position of facilities and elece_rical det~ils of the c~mp structures are sh~n on drawing no. 2652 designated Exhibit "E". These structures are designed to provide for the ultimate safety and convenience of the occupe~nts consistent with the modules available for use by the contractor. The food service contractor for the camp' will be required 'to insure that all food is frcm approved sources. Food storage and refrigeration areas will be required to have adequate shelving to keep package food off the floor. Cleanliness will be maintained. Kitchen and dining facilities 'will meet National Sanitation Foundation standards. WATER SUPPLY 7~ND TREA%P~ (See Exhibit "D") Water for camp use and drilling will be hauled from the closest source, the Sagavanirktok River, about three-quarters nd_lc west of the location. Water for camp use will be made potable using water treahrent facilities designed and constructed by Parker Drilling Company o 7%e facility is entirely enclosed in a 37.5' x 9.5' x 10.0' insulated steel building mounted on skids. The building is constructed to -4- facilitate transportation to and from 'the drill_~g site. Ail connections 'to ~he building are i]-ounted flush with the walls so that they will not be d~mage~t durLng trans~portation 'to the site. Enclosed inside of the metal building is a 4,600 gallon steel reservoir to store the raw water supply. The reservoir will contain one day's supply of water for the 50-m~m~. c~p based upon a usage of 90 gallons per day per man. The reser¥oir is entire-ely inside of the steel building and the raw water will be heated slightly which assists the treatment process. 'Ene reservoir is vented to the treatment plant disposal drain so tha~ any overfills will not result in a flooded building. Pressure is supplied to the treahTent plant by a centrifugal p~mto located render a portion of the reservoir. A second identical pump is also located in the treatment plant as a spare. The p~gps are interchangeable in the event of a pump failure. The ptmto is controlled by a pressure switch acutated by a small water pressure tank on the discharge side of the pump. 1~ne pressure switch shuts -the purp off at high pressures and turns the pu~p on at low pressures. A pressure range of 30 to 70 p.s.i, would be desirable for this .system. The pressure ~itch is set less than 75 p.s.i, since the maxin~m all~,vable pressure to the filters is 75 p.s.i. The water pressure tar~% absorbs small draws on the system so that the pump is not constantly cycling. A hypochlorinator is installed in the treatment facility. The hypochlorinator consists of a thirty gallon solution tank and a small positive displacement diaphragm pump with speed and stroke adjustments. The diaphragm p~p is paced by the centrifugal pressure switch. That is, when the centrifugal pump is running, the chlorinator is operating. A chlorine solution of knc~ concentration can be injected into the raw water to control algae and bacteria and to precipitate manganese, iron and hydrogen sulfide. Either calcium hypochlorite or sodium hypochlorite can be used in the chlorinator. Sodium hytx~hlorite, more c~nly known as laundry bleach, is a liquid at a strength of 12 to 15 percent 'available chlorine. Calcium hypochlorite, known under trade na~es such as ~I%I, Perchlorin and Pittchlor, is a p~der with an available chlorine content of 70 percent. The amount of chlorine solution to be applied to the raw %~'ter is a function of the water quality. C~_ne?ally the following amount of chlorine should be added to the raw water for the best quality effluent: Iron Mg/1 X .9 Manganese Mg/1 X 1.3 Hydrogen Sulfide Mg/1 X 8.5 Algae p.p.m. Chlorine p.p.m. Chlorine p. p.m. Chlorine p.p.m. Chlorine Total Chlorine Demand p.p.m. Calorine -5- The treatm~nt pl~n'h effluent should have a chlorine residlml of 0.1 to 0.5 p.p.m, chlorine. The next step in the trea~r~nt' process in the ren~val of tl~e sediment frcm the water. This is acco~rplished by ~o (2) 30 gallon per minute pressure filters comnected in series. Each contains 210 pounds of 1/2" to 1/16" gradual gravel ~nd 8 cubic feet of a non- hydrous al~m~Cnmm silicate filter media. Non-hydrous al~ninum silicate provides a 1~,~ loss of head filter media and requires t~,~ice the fl~.~ rate for bac~.~sh. After the water has passed through the sedim~ent filters, it enters the iron and manganese r~moval filter. The filter contains 210 po~mds of 1/2" to 1/16" graded gravel and 8 cubic feet of ~nng~mnese greensand. The manganese greensand has been treated with manganous chloride to convert it to manganeris zeolite. The greensand is treated with potassium permanganate which results in the precipitation of the manganese and iron oxides on the zeolite grains. The filter is bac]cwashed periodically and occassionally the filter must be regenerated with potassium permanganate. Frequency of the back~ash and regeneration is again a function of the water quality. The water then enters the carbon filter which removes any taste, odor, or color. The filter contains 210 pounds of 1/2" to 1/16" graded gravel and 8 cubic feet of graded carbon material. Occassionally the carbon '~aterial will have to be replced in this filter as the absorption ability of the carbon becomes e~daausted. The need to replace the carbon material is again a function of the water quality. The two (2) sediment filters, the manganese greensand filter and the carbon filter are all bac~ashed with an automatic stager controller. The controller controls tt~e intervals at which the filters are backwashed. The controller is operator actuated. The water then passes through a 90,000 grain sodium zeolite water softener. Calcium and magnesium ions are replaced by sodium ions in the zeolite. When 'the bed is saturated by the hardness ions (calcium and magnesium) the zeolite bed is backwashed with sodium chloride which reverses the process. The backwash water is wasted to ,the plant drain system. The sodium chloride used to backwash the zeolite softener is stored in a 100 gallon brine tank. The backwash of the softener is controlled by an automatic -time control. Frequency of the backwash operation is dependent upon the hardness of the water. Treated water is stored in two (2) 75 gallon glasslined hot water heaters located in the treatment plant building and three (3) 400 gallon storage tanks located throughout the camp. The storage tanks provide an ample amo~t of treated water to supply the camp during periods when the treatment plant is bac]cwashing and to -6- 19. 20. 21. prevent the treatment plant from %~cling on ~d off with every snmll draw on the system. The backwash water from-the trea'[mmnt plant be disposed direct].y to the pit utilized for the sewage treahn-en't plant effluent. There is nothing harmful of toxic disch~.arg~=~t from the water treaOrent plant. By-passing the seumge trea-hnYant pl~mnt wi~da the bac]~sh water decreases the load on the sewage treat?c.~n't plant. A residual of 0.1 to 0.5 ppm Jm t~he tin'eared water will tys maintained. If there is no cholrine residual Lq the treated water due to the m~nganese greensand, carbon, and waher softe~ing processes, a second diaphragm pumto will be installed to inject a chlorine solution into the treated water after the trea-hment process has taken plac&. The efficiency of the water treatment plan and the ability of the water treatment plant to produce a good effluent is a function of the raw water quality and operator skill. If operated correctly, this treatment plant has the capability of ~producing an excellent effluent from a poor water source. SOLID %~%STE DISPOSAL All trash, used drill bits, fuel drums, etc , from both the camp and the drilling rig will be disposed of by back-hauling to Prudhoe Bay and disposed of at the approved sanitary landfill site. Drill solids will be dtmt0ed into the reserve pit which will be backfilled after the well completion. Sludge collected on filter paper in the sewage treatment unit will be in incinerated on location using a comtro incinerator. S E~IAGE DISPOSAL The sewage disposal facility will be either a physical/chemical treatment plant or other type that meets the state requir~t for secondary treatment. Treated water discharged from the plant will drain into a effluent holding pit constructed for that purpose. The sewage pit will be constructed the same as -the reserve pit and have a capacity of approximately 75,000 gallons. In conjunction with the sewage treatment plant, the incinerator previously discussed will be used to destroy waste sludge and solids filtered out in the sewage treatment process. In the event of a plant failure or breakdown, raw sewage will be trucked to the BP Alaska Operations Center and processed. AIR POLLUTION Air pollution will be held to a minimum through use of the incinerator described above. Emissions from the engines, generators and boilers required by the operations will not effect tine ~obient air. State Air Quality Requir~nents will be complied with. -7- 22. SI%~ I%ESTO~%TION Special efforts to maintain a cleam operation and prose_fly dispose of dJoris will be made. Upon co~©!etion of operations, a final cle~n-up will be pe_rfommed. A s~amr inspe, c<ion of t_he gravel extraction aund wellsites will be nmde am_d, if necessamqf, a hand clean-up operation carried out. The gravel extraction site restoration included elimination of "pot holes", berms, stockpiles and winter roads. 'l'~ne n%ined areas have been graded and contoured to blend into the surrounding area. If economical q~aantities of oil or gas are not found, the %~mll will be abandoned in con~liance with all applicab%e State and Federal regulations and all pits, including those containing %~ste flmids and drilled solids will be back-filled using gravel from the pad. Should the well be capable of oil ~nd/or gas prcduction which will justify develop.Tent wells and production facilities (i.e. pipeline), the well will be shut-in until the field is developed. 99503 DiTo of April 7, 1975 - _. ~ lease _~ c~ in ~ur letter of Fe~ 27, 1975, ar~ 1. ~~~~of~~~~~~~~~' 2. X~~~"~~f~~~~~~" : . 7. S~ ~ ?, ~75 10o 1300 co~ ~=aa, Fainb~3~, alaska 99701 (pnon~ 452-1531], sha]_% be n~fcified at least 14 days ~ to · _-- _t of An accounti=3 of tbs martial used for ead~ constru~~ feature {~,~, ~.) ~ ~ ~~ ~t ~ ~t o~ ~ A cop~ of the app~t~_~_ aha ~ letter s~_~!! be postea i~ a ~mimmt location in the operators camp.. o of oper~tio~. Dept. of Labor Div. of O&G . o CHECK LIST FOR NEW WELL PERMITS Company 4.2.'~'~. ,,,z./~.~.'o~ Yes No Remarks 1. Is the permit fee attached ...................... ~/~c 2. Is well to be located in a defined pool .............. ~q 3. Is a registered survey plat attached ................ /W~a.~ 4. Is well located proper distance from property line .......... ~k/ 5. Is well located proper distance from other wells ............ ~.~K 6. Is sufficient undedicated acreage available in this pool ....... ~ 7. Is well to be deviated ....................... 8. Is operator the only affected party ................ K/~a~( 9, Can permit be approved before ten-day wait ............. ~ l0 Does operator have a bond in force ................. l l. Is a conservation order needed ................... 12. Is administrative approval needed ................. 13. Is conductor string provided .................... 14. Is enough cement used to circulate on conductor and surface .... 15. Will cement tie in surface and intermediate or production strings 16. Will cement cover all known productive horizons .......... 17. Will surface casing protect fresh water zones 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating ............. · , · , '~-~ · : ~ ~? i~) '~ Additional Requirements. ]~ a~< ~/ /~ ~ ~.~ ? Approval Recommended' Geo 1 ogy Engi nee ri ng' TRM HWK H-~ .~ OKG HHH JAL LCS ~z~'~ JCM ? Revised 1/15/75
