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Home My WebLink About185-1221. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7680' 6352'2161 None Casing Collapse Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-263-4742 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7475'6193'6860' KRU 3A-06 7144-7220' 7340-7362' 7341-7361' 7372-7420' 7444-7450' 7638' 5939-5997' 6089-6106' 6090-6105' 6114-6151' 6169-6174' 3/7/2025 3-1/2" 3-1/2" 1-15/16" Baker FHL Baker 83-40 FB-1 Baker KB Baker Model D Permanent SSSV: None Perforation Depth MD (ft): 104' 3406' 6343'7" 16" 9-5/8" 73' Burst 3375' 6967' 7066' 7140' MD 104' 3178' 7668' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025632 185-222 P.O. Box 100360, Anchorage, AK 99510 50-029-21443-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 6941'MD/5790'TVD 7042'MD/5861'TVD 7129'MD/5928'TVD 7255'MD/6024'TVD Perforation Depth TVD (ft): Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field Elliott Tuttle elliott.tuttle@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 L-80 L-80 TVD m n P 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-098 By Gavin Gluyas at 12:39 pm, Feb 21, 2025 Digitally signed by Elliott Tuttle Reason: I am approving this document Location: Anchorage Tower, CoP Date: 2025.02.21 12:24:49-09'00' Elliott Tuttle DSR-2/24/25SFD 2/26/2025 X JJL 2/25/25 X 10-404 AOGCC Witnessed BOP and Annular Test to 2500 psi. AOGCC Witnessed MITIA to 3000 psi and MITT to 3500 psi. X *&: 2/26/2025Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.26 11:02:52 -09'00' RBDMS JSB 022725 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 19, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Elliott Tuttle Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Injector 3A-06 (PTD# 185-222). 3A-06 was drilled on Parker 141 and completed by Nordic 1 in 1985 as a Kuparuk A/C producer and later converted to an injector in 1988. Stimulations were performed late 1985 and again in 1993. Well was recompleted in 1997, pulling and replacing packer and tubing. It was then worked over in 2008 to specifically install a Down Hole Intensifier Pump (DHIP), developed by Weatherford in conjunction with Conoco Phillips. 3A-06 was the first test of this technology. Many attempts were made to make the DHIP successful, but didnt come to fruitition. The well has since developed a tubing leak below the DHIP which is inaccessible to patch as well as a hole at 6827' MD. The well has been shut in since 2015. If you have any questions or require any further information, please contact me at +1-907-252-3347. The selective with the DHIP will be pulled and replaced with a straddle assembly isolating the C sands from injection. 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Should be in the ALP Baker Seal Bore Extension Locator w/ 2' space out Description FMC Gen 5 Tubing Hanger 2.875" Camco DS Nipple Camco MMG Side Pocket Mandrel SOS RBP (OAL 8.89') WFT gauge mandrel Bkr FHL Packer w/ PBR & 6.12 pup Jt GBH-22 Seal Assy and Lcoator 2' spaced out 2.812" DS Nipple Baker 83-40 FB-1 Packer Arctic Pack Cement: 10/25/1985 Pumped 29Bbls Cement, 54Bbls of Diesel TOC Est: 1998' RKB PC Cement: CBL pulled 1/3/85 Estimated TOC 6992' RKB Surface Casing Production Casing Conductor A-sand perfs 7340' - 7450' RKB C Sand Perf 7144' - 7220' RKB ,/W 3A-06 RWO Proposed Schematic Updated: 2/19/25 Description Set Depth MD Set Depth TVD OD (in)ID (in)Weight Grade Top Conn Run Date Conductor 104 104 16 15.062 62.58 H-40 10/13/1985 Surface 3406.4 3178.2 9.625 8.765 36 J-55 BTC 10/14/1985 Production 7668 6342.5 7 6.276 26 J-55 11/23/1985 New Tubing 7255 5803.989 3.5 2.992 9.3 L-80 EUE 12/13/2008 Depth (ft)ID 7255 3.25 7273.7 2.25 7280.7 2.441 Description Baker Model D Permanent Packer w/ 5' Seal Bore Camco D 2.25" Nipple Baker Shear out Surface Casing Production Casing Conductor A-sand perfs 7340' - 7450' RKB C Sand Perf 7144' - 7220' RKB Proposed Completion: 3 1/2" 9.3lb/ft Hyd563 Tubing from Surface 3 1/2" MMG GLM(s) @ XXXX' RKB 3 1/2" x 7" Hydraulic Set Packer @ ~7050' RKB 3 1/2" x 7" Hydraulic Set Packer set between: 7220' & 7253' RKB 3 1/2" XN Nipple @ XXXX' RKB 80-32 Seal Assembly, no Seals (2.441" ID) Arctic Pack Cement: 10/25/1985 Pumped 29Bbls Cement, 54Bbls of Diesel TOC Est: 1998' RKB PC Cement: CBL pulled 1/3/85 Estimated TOC 7000' RKB Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization RESCAN DIGITAL DATA OVERSIZED (Scannable) Color items: o Diskettes, No. ~ Maps: D Grayscale items: D Other. No/Type ~ Poor Quality Originals:~ ' "~~ Q~~/,~ OY"~,~' r~ Other items scannable by large scanner OVERSIZED (Non-Scannable) o Logs of various kinds n Other TOTAL PAGES: I 0"~ · NOTES: ORGANIZED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ISl Project Proofing [] By: Staff Proof Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si PAGES: 1 0~) (at the time of scanning) SCANNED BY~ ~REN VINCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ General Notes or Comments about this file: PAGES: /03 Quality Checked (done) RevlNOTScanned.wl~l STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C(~,viMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL .' GAS ~ SUSPENDED.~ ' ABANDONED SERVICE .'--] Classification of Service Well 2. Name of Operator UNOCAL (Marathon ,_0i l !3. Address P.O. Box 190247 Co., Sub-operator) Anchorage, AK 99519 4. Location of well at surface 748' FSL, 1,130,.FWL, Sec 6-8N-13W-SM At Top Producing Interval 2,550' FSL, 350' FWL, Sec 31-9N-13W-SM At Total Depth 2,350' FNL, 215' FEL, Sec 31-9H-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' KB above MSL I ADL 18730 Leg A-2 Slot 8 Dolly Varden Platform 7. Permit Number 85-122/90-885 8. APl Number so-733-20195-01 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-44 1 1. Field and Pool McArthur River Fi eld 12. Date Spudded 113. Date T.D. Reached I 14. Date Comp., Susp, or Aband. 15. Wa[er Depth, if offshore 116. No. of Completions I ! 2/1/91 302 feetMSL I 22. Type Electric or Other Logs Run CET 23. CASING, LINER AND CEMENTING RECORD i SETTING DEPTH MD GRADE TOP BOTTOM CASING SIZE WT. PER FT. HOLE SIZE CEMENTING RECORD AMOUNT PULLED t TUBING RECORD 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 27. 25. SIZE DEPTH SET (MD) PACKER SET (MD) 26. ACID, FRACTURE, CEMEN SQUEEZE, ETC. DEPTH INTERVAL (MD) t AMOUNT & KIND O_F. M__ATER____~IAL USED ~-~;TT'~ ~ 861f 50 SX Class "G" £mt 122432 - i2.465 Cmt ~lug ~12~981 - 13~070 Icmt. Plug PRODUCTION TEST Date First Production Date of Test Flow Tubing Press. JHours Tested J Casing Pressure iMethod of Operation (Flowing, gas lift, etc.) F;RODUCTION FOR IOIL-BBL TEST PERIOD * CALCULATED I OIL-BBL 24-HOUR RATE l~ GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) 28. CORE DATA Brief description of ,ithology, porosity, fractures, apparent dips and presence of oil, gas or water. Form 10-407 Submit in.,-' Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC M/~ NAME MEAS. DEPTH 31. LIST OF ATTACHMENTS RS TRUE VERT. DEPTH 30. FORMATION TESTS Include interval testea, pressure data, ail fluids recovered and gravity, GOR, and time of each phase. 32. I hereby certify that the foregoIng is true anci correct to the best of my k, nowledge Signed ~C~.,~ ~ , ~,.~v'~ Title~'~:,~.\,.~ ~o,~..,_~.aj~ 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 spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". 10-407 DAILY WELL OPERATIONS D-44 1/22/91 Prepared for rig 77 start up, filled D-44 annulus w/ brine & bullheaded 140 bbls down tbg. Set BOP's in sub deck. Skid rig to Well D-44. Set BPV. 1/23/91 Checked tree & casing for pressure - none. N/D tree. Tested surface lines & values to 250/2500 psi - OK. Tested Rams to 250/2500 psi and annulus to 250/2500 psi w/ bleed off through hanger seals - visually checked for leaks - OK. Miscellaneous rig up. 1/24/91 Built 500 bbl volume. Slipped and cut drill line. Inspected brakes and drawwork chains. R/U rig floor. R/U slicklline. RIH and attempted to lock out SCSSV. Re-ran lock out and locked out SCSSV. Verified with gauge ring. Rigged up wireline to cut tubing. 1/25/91 RIHwith wireline and cutter. Attempted to cut tubing at 11,875' Pulled hanger to rig floor. Tubing hung up. Circulated. Repaired brakes. WJrked pipe. RIH with tubing cutter. Cut pipe at 11,859'. Spotted 80 bbl HEC pill. Rigged up tubing tongs and control line spooler. 1/26/91 POOH with 3-1/2" tubing and laid down same. Unloaded tubing to boat. Rigged up and RIH with wireline to run CET log. 1/27/91 POOH with CET. Readjust centralizers. RIH with CET from 3500' to surface made up swivel and Kelly. Broke out double pin sub and inspected box on swivel. Made up Kelly. RIH with bit and scraper picking up drill pipe. 1/28/91 Finished RIH with 7" scraper. Circulated. POOH. Laid down 4-3/4" drill collars. RIH with 7" cement retainer. Set at 11,911'. Circulated. R/U and cemented with 90 SX cement. Displaced with 9.0 ppg brine. Squeezed 16.5 bbl cmt below retainer. Pulled out of retainer & dropped 2 bbl cmt on top. POOH 10 stands. Reverse circulated. R/U and displaced brine with FIW. 1/29/91 Finished displacing hole with FIW. Tested casing to 1000 psi. Mix 10 ppg mud to displace hole. 1/30/91 Finished mixing 10 ppg mud in pits. Displace FIW in well with 10 ppg mud. POOH. laid down 3-1/2" drill pipe. RIH with 9-5/8" cement retainer. H: \wp\WELLOPS\D44 -2- Daily Well Operations D-44 1/31/91 RIH w/ retainer & set @ 10,851'. Tested retainer to 2500 psi. Spotted 50 SX (5.5 bbls) balanced cmt plug on top retainer. Tested csg to 2500 psi. POOH. RIH w/ 9-5/8" retainer & attempted to set (a 3560' w/o success. POOH. Started RIH w/ new retainer. 2/1/91 RIH w/ retainer & set 3,564' POOH. Cut 9-5/8" csg ~ 75' KB. N/D BOP's and tbg spool. Speared csg - not free. Cut csg at 75' KB. Speared csg & worked free. L/D 35' csg stub. 2/2/91 Commenced drilling operations D-47. H:\wp\WELLOPS\D44 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ // Suspend __ Alter casing __ Repair well __ Change approved program .... [ 5. ~rype of Well: '" 2. Narr~(~ator(Harathon 0il L,o - bUD upera[.or) Development__ ........... ~ Exploratory__ 3'A~drl~s. sO. BOX 190247 Anch Stratigraphic orage, ~it 4. Location of well at surface · Leg .^-Z Cond. #8 Dolly Varden Platform 748' FSL, 1,130' FWL, Sec. 6- 8N- 13W- SM At to a OfL, DLr..~d~u ctive interval '2,550 FSL, 350' FWL, Sec. 31 - 9N- 13W- SM Ateff~c~t~(~Pt~NL, 291' FEE, Sec. 31 - 9N - 13W- SM Operation shutdown i Re-enter suspended well i Plugging i Time extension __ Stimulate __ Pull tubing __ Variance __ Pedorate __ Other __ Att°t~l?J~Oh' FNL, 215' FEL, Sec. 31 - 9N - 13W- SM ¢ ,.,D,.Atur~,,elev¢ion (DF, ,o,.r,K B) UD' ItU aDove Mbt feet .~ Un~tor Property rao~ ng r~ay 8. Welt number D-44 9. Permit number 85-122 10. APl b r soLf - o 95-o 12. Present well condition summary Total depth: measured true vertical Effectivedepth' measured true vertical 13,070' 13,070'-12,981' cement 9,990' feet Plugs(measured) 12,745' PX Plug feet 12,432'-12,465' BP & Cement 12,432 ' feet Junk (measured) 9,530' feet None Casing Length Size Structural Conductor Sudace 3,305' 16" Intermediate 11,218' 9-5/8" Production 2,151' 7" Liner Perforation depth: measured true vertical 13. Attachments Cemented Measured depth True vertical depth 4,550 sx 3,305' 2,942' 2,300 sx 11,218' 8,675' _ 505 sx 13,070' ,'"-~x 9,990' See Att'~rchment #1 .,~,..~i~,. L ~, I VE[~ DEC 18 19,90/ Tubing (size, grade, and measured depth) 3-1/2" 9.2#, N-80 Tbg at 11,958' Packers and SSSV (type and measured depth) Otis WBR Pkr-. ~ 11,904'; Otis WD Pkff... 0 12~725'; Otis 3-1/2" .Series 10 BV (a302' Description summary of proposal ~... Detailed operations p[ogram i BOP sketch ~ 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas I Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed < ~C~ ~----- ~ ~ Title ,¢~. '~ ,r \,% - ',,'~ ¢~ ""~ ' ~ ,...,..~ v% FOR COMMISSlbN USE ONLY-' Conditions of~pproval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical IntegrityTest / Subsequent form required 10- ~i~:~ ~) .. ~,.,,c':~ OoO~ ¢Y LONNIE C. SMITH Appr~ ~ order of the Commi~on Commi~oner I Approval No. ¢~ ~. / Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLI¢' Bench 1 Bench 2 Bench 3 Attachment #1 Well D-44 Perforations 12,108' - 12,148' MD 12,175' - 12,208' MD 12,240' - 12,290' MD 12,308' - 12,326' MD 12,350' - 12,380' MD 9,301' - 9,329' TVD 9,347' - 9,371' TVD 9,393' - 9,429' TVD 9,442' - 9,454' TVD 9,472' - 9,493' TVD doc s\dvp\d44 rd. doc Attachment #2 Wel 1 D-44 PlUg and Abandon Procedure I. Skid Rig to Well D-44. 2. Kill well. Fill and test 9-5/8" x 16" annulus to 1000 psi. Close ball valve. Set BPV. 4. ~ND tree. NU and teSt 13-5/8" BOP-stack to 250/2500 psi. 5. pull tubing and LD same. If unable to pull, make cut at 11,700' and pul 1 tubing. 6. Run cement bond log 3500' to surface to find top of cement. 7. If toP of cement is not seen or annulus fails to test in Step~, perf 3200 - 3202' with 2 SPF. Squeeze 16" annulus through perfs after Step 10, if perf. is necessary. 8, Make 7" bit and scraper trip. 9. Set ce_me~_t_a~iner_~t_ll~JS.SO'. Down squeeze production perforations. CLeave 75'~_cement above packer. 10. Set 9-5/8" CIBP at 10,850'. 11. Set cIBp at 3500'. Make cut in 9-5/8" casing above top of cement or at 3400'. 12. PU BOP Stack. Remove tbg spool. Tack slips to casing. Hang stack from substructure. _,. i~pear casing and remove s~.s~NtNand-tes-t-BOPE.--Spearrand recover'- 9-5/8" casing. 14. Mill 9-5/8" casing to 3400". \docs\dYp\d44rd.doc Attachment # 3 ~ MARATHON OIL COMPAN. DOLLY VARDEN PLATFORM BOP STACK i------" 5,8-. ~ooo .., ~ Annular Preventer ; I---"---- Clamp Conn.,or ~ Pipe Ram~ 13 5/8' 5000 p~i Double Rams Kill Line 3' 5000 pti ~ Blind Rams , , J ] ~ C · Line 3' 5000 pil Spool Ple~e~ to - Catlnghead 3' Howco Lo Torque 5000 pal Valve All Flanges are 3" 50,00 pal CHOKE MANIFOLD 3' Vent Line Pre I IP~'l Senior Remote AdJus[lable Choke ' 3/4' Manual p Cock Valve (To Be Loll Open) 1/2° M amJal ( Chok...· f 3' Bull Plug .~. lO 2' Blind Flange 6' to Shaker Floor STATE OF ALASKA ALASK,~ OIL AND GAS CONSERVATION COMM. ,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown E] Stimulate [] Plugging ~ Perforate ~ Pull tubing Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) UNOCAL (Marathon Oil Company - Sub Operator) 106' KB above MSL Feet 3. Address P. O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg A-2 Cond. ¢/8 Dolly Varden i-'_Lattorz 748' FSL, 1,130' FWL, Sec. 6 - 8N - 13W - SM At top of productive interval 2,550' FSL, 350' FEL, Sec. 31 - 9N - 13W- SM At effective depth 2,502' FNL, 291' FEL, Sec. 31- 9N- 13W- SM At total depth 6. Unit or Property name Trading Bay Unit 7. Well number D-44 8. Approval number 8-240 9. APl number 50-- 733-20195-01 10. Pool Hemlock 2,350' FNL, 215' FEL, Sec. 31- 9N- 13W- SM 11. Present well condition summary Total depth: measured true vertical 13,070' feet 9,990 ' feet Plugs (measured) Effective depth: measured 12,432 ' true vertical feet Junk (measured) 9,530 ' feet 13,070'-12,981' cement 12,745' PX plug 12,432'-12,465' BP & cemen None Casing Length Structural Conductor Surface 3,305 ' Intermediate 11,218 ' Production Liner 2,151' Perforation depth: measured Size Cemented Measured depth True Vertical depth 16" 4,550 sx 3,305' 2,942' 9-5/8" 2,300 sx 11,218' 8,675' 7" 505 sx 13,070' 9,990' true vertical See Attachment #1 ~bing(size, grade and measured depth) 3-1/2" 9.2# N-80 @ 11,958' Packers and SSSV(type and measured depth) Otis WBR Pkr. @ 11,904'; Otis WD Pkr. @ 12,725' ; Otis 3-1/2" Series 10 BV @ 302' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 3/24/88 20 77 474 1130 Subsequent to operation 4/27/88 202 11 664 1150 Tubing Pressure 120 115 14. Attachment~ #2 Daily Report of Well Operations Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~~Title Form 10-404 Rev. 'I-~¢86'%--'~ D..,,/Roberts Environmental Engineer Date 5/23/88 Submit in Duplicate ATTAC}tMENT #1 Well D-44 Perforations Bench 1 Bench 2 Bench 3 12,108' - 12,148' MD 12,175' - 12,208' MD 12,240' - 12,290' MD 12,308' - 12,326' MD 12,350' - 12,380' MD 9,301' - 9,329' TVD 9,347' - 9,371' TVD 9,393' - 9,429' TVD 9,442' - 9,454' TVD 9~472' - 9,493' TVD NEF/em/65A/Sundr4 Attachment #2 TBU Well D-44 Summary of Daily Well Operations 4/8/88 RU E-line. PT lubricator to 2,350 psi, OK. Made three perforating runs with 2-5/8" hollow carrier guns, 4 SPF, 0° phasing. With well flowing, correlated and perforated B-2, 12,175' - 12,208'; B-l, 12,128' - 12,148'; and B-l, 12,108' - 12,128' DIL. After first run, RIH and tagged fill at 12,410'. Turned well over to production for clean up and test. 4/9/88 RU E-line. PT lubricator, OK. Made three perforating runs with 2-5/8" hollow carrier guns, 4 SPF, 0° phasing. With well flowing, correlated and perforated B-2 from 12,308' - 12,326'; B-2 from 12,265' - 12,290'; B-2 from 12,240' - 12,265' DIL. Flowed well for clean up after each perforating run. RD and turn well over to production for test. 4/10/88 RU E-line. PT lubricator, RIH w/2-5/8" hollow carrier guns, 4 SPF, 0° phasing and with well flowing perforate B-3 from 12,350' - 12,380' DIL. POH, RD, turn well over to production and bring on slowly. NEF/em/65A/Sundr4 STATE OF ALASKA ALAS,-,~, OIL AND GAS CONSERVATION COMI,..SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend F! 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 UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg A-Z Cond. ¢~8 Oo±±y varden ciatfor~ 748' FSL, 1,130T FWL, Sec. 6 - 8N- 13W- SM At top of productive interval 2,550' FSL, 350' FEL, Sec. 31 - 9N- 13W- SM At effective depth 2,502' FNL, 291T FEL, Sec. 31 - 9N- 13W- SM At total depth 2,350' FNL, 215' FEL, Sec. 31 - 9N- 13W- SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Well number D-44 8. Permit number 85-122 9. APl number 50-- 733-20195-01 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13,070 ' feet Plugs (measured) 9,990 ' feet 12,432' feet Junk (measured) 9,530 ' feet 13,070'-12,981' cement 12,745' PX plug 12,432'-12,465' BP & cemen None Casing Structural Conductor Surface 3,305' Intermediate 11,218 ' Production Liner 2,151' Perforation depth: measured Length Size Cemented Measured depth True Vertical depth true vertical 16" 4,550 sx 3,305' 2,942' 9-5/8" 2,300 sx 11,218' 8,675' 7" 505 sx ~bing(size, grade and measured depth) 3-1/2" 9.2# N-80 @ 11,958' Packers and SSSV(type and measured depth) Otis WBR Pkr. @ 11,904'; Otis WD Pkr. @ 12,725' 13,070' ~.,~,~0 ' See Attachment ; Otis 3-1/2" Series 10 BV @ 302' 12.Attachment,~ 2 Description summary of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation April, 1988 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 D. e_rts ~,_.,.-,, Title Envi ronmcn~! m~__~neer Commission Use Only Date 3/31/88 Conditions of approval Notify commission so representative may witness I Approval No. I-!.. Plug integrity [] BOP Test [] Location clearance Approved by ORiGiNAL SIGNED BY LONNtE C. SN~l'f~ Approved Copy Returned - Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate feet Bench 1 Bench 2 ATTACHMENT #1 Well D-44 Perforations 12,108' - 12,148' MD 12,176' - 12,208' MI) 12,240' - 12,290' MI) 12,308' - 12,326' MD 9,301' - 9,329' TVD 9,348' - 9,371' TVD 9,393' - 9,429' TVD 9,442' - 9,454' TVD NEF/em/65/Sundr4 Attachment #2 Well D-44 Reperforation Procedure 1. RU E-line unit. Pressure test lubricator to 2500 psi. o RIH with 2-5/8" perforating guns, 4 SPF, 0° phasing. Perforate underbalanced or flowing and test as indicated below. Run Interval (DIL) Feet Zone 1 12,175' - 12,208' 33 2 12,128' - 12,148' 20 3 12,108' - 12,128' 20 Upper B-2 B-1 B-i Stabilize the well and test for 12 hours. 4 12,308' - 12,326' 18 5 12,265' - 12,290' 25 6 12,240' - 12,265' 25 Lower B-2 Lower B-2 Lower B-2 Stabilize the well and test for 12 hours. 5 12,350' - 12,380' 30 B-3* * May not be perforated based on results of above perforating work. Fill currently at 12,387' and may limit depth of Bench 3 perforations. 3. RD E-Line. 4. Test well for 2-3 days. 5. RU wireline, pressure test to 2,500 psi. 6. RIH with dual pressure gauges. 7. Obtain a FBHP at 12,320' (9,450' TVD). e POH, RD wireline. Wireline representative will read pressure charts, then send data and chart to W. L. Browne in Nikiski. em/65/Sundr4 ~TE ii-i9-85 MARATHON OIL. COMPANY HISTORY OF OIL OR GAS WELL FIELD McArthur River WELL NO. D-A4 STATE Alaska LEASE Trading Bay Unit PARISH COUNTY Cook Inlet, Alaska BLOCK SEC. 32 TWP 9N R. 13W,SM MEASUREMENTS TAKEN FROM ELEV. ~ ~Top OF OIL STRINg_ ELEV.__ .ToP OF ROTARY TABLE~ ELEV.~ GRD. OR MAT. ELEV, HISTORY PREPARED BY Sherry Bushue TITLE Secretary It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1985 06-21-8 06-22-85 06-23-85 06-24-85 06-25-85 06-26-85 06-27-85 06-28-85 06-29-8 06/29-0 07-04-8 07-05-85 07-06-85 07-07-85 17,010' (D-21) 7f03/85 " 5 " TBU Well D-44 (Marathon Oil AFE 8226-5) Crews arrived on platform @ 1130 hrs on 6-20-85. RU hydromatic brake on Rig #76. RD drlg equip off Rig #76 for rig mobilization of Rig #77. RU Otis on D-7RD. Cont moving misc drilling group. Continued activating Rig #77. Skid Rig #77 to D-7RD. RU Otis on D-TRD. Moved cementing unit to Rig #76. Skid Rig to D-21. Continue rig activation and began mixing mud. Continued mixing mud & activating Rig #77. NU lub on D-21. Perf circ holes in tbg @ 15,798' WLM. Circ. FIW to kill well. Unplug sep screens. Circ FIW to kill well. Cond 10 ppg mud in surf pits. Bullhead 250 bbls mud down tbg. Circ mud down tbg w/ returns to prod. :Got mud returns early indicating small leak in tbg @ ±2800'. Cont circ 10 ppg mud. After pumping 764 bbls, TP 0#, CP 65#, MW in 10 ppg, MW out 9.2 ppg. Continue circ w/ 10 ppg until had 10 ppg mud returns in ann. SD pumps. Monitor well 1 hr w/ no flow. SI D-44. RU Otis on D-42. Otis attempting to lockout ball valve on D-42. Prod attempting to lockout ball valve in Well D-42 and install a wireline retrievable ball valve. WO storm choke on install in D-42. Skidding Rig #77 to D-7RD. Storm choke in D-42 is working proper- ly. NO REPORT Crews arrived 7/04/85. Move BOPE to Rig #77. Skid rig to D-21. k~ lub. Bled 950 psi off csg & tbg. Circ mud. Set BV in nipple. Pump dn ann & had returns up tbg. Pull BV. RU to circ thru choke manifold. Change rams in 4-1/2" WL BOP to 2-1/16". Set tbg BP @ 71'. Pump into ann & tst BP to 1000'psi, OK. Had 350 psi in ann in 1-1/2 hrs. Bled press. Ann pressured to 525 psi. Increase mud wt from 9.8-11.2 ppg. Circ to kill well. Set 4-1/2" tbg bridge plug @ 85'. Tst to 1000 psi, OK. ND x-mas tree & NU BOPE. Change to 4-1/2" piperams. Tst BOPE. Finish tstg BOPE. Pull 4-1/2" tbg bridge plug. Cir¢ & cond mud. MU spear for tbg hgr. PU & work tbg. String parted @ 180,000#. Parted @ GLM (in body). TOF @ 3067'. R £EIVE. D Alaska Oil & Gas Cons. Oommissio. Anchorage _ 0-44 Well History Page 2 07-08-85 " PU 5" DP. MU fishing tools. MilI pver fish. Washover & engage fish. Worked fish, no movement ~pulled 50,000# over string wt). Run free point-indicator & CCL. ~ould not get into 3-1/2" tbg @ 11,683'. POH. Rev circ. Run freepoint & CCL. No movement below 5036'. 07-09-85 " POH w/ free point ind. Chg springs. Ran FP in 4-1/2" tbg. Tbg free to 3-1/2" XO @ 11,665'. Unable to get into 3-1/2" tbg. Ran cutter for 4-1/2" tbg-unable to get cutter down DP. Ran 2.75" cutter. Could not get below 11.696'. Presently POH w/ cutter. Will run 2.70" cutter. 07-10-85 " - Fin POH w/ 2.75" cutter. RIH w/ 2.7" cutter. Could not get past ....... :_. ..... . ...... -:::---_ .... 1!~692', ~OH.. Remove centralizer springs. RIH w/ 2.7" cutter. Locate cutter @ 11',716'~- Cut 3-1/2" tbg. Circ & cond mud. POH w/ 4-1/2" tbg. 07-11-85 " 07-12-85 " Fin POH w/ 4-1/2" tbg. RD tbg tongs. PU 3-1/2" grapple. RIH. PU 5" DP. Tag fish @ 11,730'. Work over fish. Pulled 50,000# over string wt. Fish pulled free. Presently POH. Fin POH w/ 3-1/2" tbg fish. Rec ~21 its. Left 11 its in hole. RU Otis on D-42 to replace storm choke. RIH w/ 4-1/4" grapple. Engage fish @ 15,486'. Work fish to 30,000# over string wt. Fish came free. POH. 07-13-85 · POH. LD 3-1/2" tbg. Rec 100% fish. PU 2-1/16" tbg tail. RIH to 16,751'. Circ.' Pump 80 sxs cmt. Pq!1 .~2 stds.... Attempt .to_rex_ circ. Unable to circ. POH. 07-14-85 " Fin POH. LD 30 its 3-1/2" DP and:33 jts 2-1/16" tbg w/ cmt. -PU-~ 43 jts 3-1/2" DP RIH to14,160' Circ @ 2550' 7900' 14 160' POH. SLM 3-1/2" DP. 07-15-85 " POH. PU 3-1/2" DP. RIH to 15,845'. Circ. POH. PU 25 its 2-1/16" tbg. RIH. Tag cmt @ 16,584'. Pull 30' above plug. Unable to circ. POH w/ plugged tail pipe. 07-16-85 " Fin POH w/ plugged 2-1/16" tail pipe & LD same. RIH to 15,840'. Circ @ 4300' 11,385', 15,140'. Pumped 30 sx cmt. Estimated TOC @ 15,600'. Pulled 17 stds. Rev circ DP & circ BU. LD 99 jts DP. Circ @ 11,757'. 07-17-85 " Circ @ 11,757'. RU centers. Pump 30 sxs C1 "G" cmt for plug 11,757'-11,674'. POH. LD DP. Set cmt pkg 6587'-6434' (55 sxs). POH. LD DP. RIH w/ csg scraper to 1000'. Set bridge plug @ 800'. Presently RU dialog. 07-18-85 " 07-19-85 Ran CCL, Gyro from 800' to surf. LD 5" DP. PU csg cutter. Cut csg @ 705' and 51'. NU BOPE rise~. Pulled 9-5/8" csg stub & slips free w/ 200,000#. Presently LD fish. LD 9-5/8" cut off. NU BOPE. PU 9-5/8" csg spear w/ packoff. RIH. Engage fish @ 51'. Circ w/ slow returns. Pull 375,000#. Fish came free. POH. LD 9-5/8" csg. RIH w/ bit & csg scraper to 705'. Circ clean. Set bridge plug in 13-3/8" csg @ 700'. ND BOPE. Presently NU 30" ann. 07-20-85 " Fin ND BOPE. NU 30" diverter. Function test diverter. RU loggers. Run CCL in 13-3/8" csg. 07-21-~5 " Fin CCL in 13-3/8" csg. PU csg cutter. Cut 13-3/8" csg @ 695'. PU wash pipe. Washover 13-3/8" csg from 46' to 88'. Quit making hole, Cut csg @ 92'. PU spear. Attempt to jar csg free. Spear slips off csg. WO fishing tools. 07-22-85 " PU 7' extension on csg spear. Jarred csg free. Rec 45.40' of 13-3/8" csg. Cut csg @ 110'. Jarred 17.75' csg free. Total rec 71.47'. TOF @ 110'. PU 26" drlg assy to CO to TOF. Alaska Oil & Gas Co~s. Comm. issior~ Anchorage - 0-44 Well History Page 3 07-23-85 " 07-24-85 " 07-25-85 " 07-26-85 " 07-27-85 " 07-28-85 " 07-29-85 " 07-30-85 07-31-85 " 08-01-85 " Cut 13-3/8" csg @ 127'. RIH w/ spear & jar free. POH. Recovered 17.90' of csg. TOF @ 127'. CO cmt to 127'. Cut ]3-3/8" csg @ 148', Jar on csg, no movement. Jars parted @ mandrel. MU fishing tools. Engage fish, could not jar free, back-off between oil jars & bumper sub. RIH & screw into fish. Jar, but spear would not release. Attempt to release spear from 13-3/8" csg w/ back-off shot. Back-off in DP @ 117'. POH. RIH & WO fish to 128'. Top of 13-3/8" csg @ 127'. W0 13-3/8" csg to 137'. POH. Washpipe contained 6' x 9" slice of 13-3/8" csg & 6' of cement. RIH w/ fishing tools. Recovered spear assembly. RIH w/ 12-1/4" drlg assembly & cleanout to 690'. Washover 13-3/8" csg from 126'-138'. POH. Cleanout 13-3/8" from 127'-138'. POH. RIH w/ spear assembly. Engage spear & jar on csg. Grapple broke. POH. RIH & cut csg @ 138'. RIH w/ multistring cutter. Could not get inside 13-3/8" csg. Repair Bowen spear. Engage spear & POH w/ fish. Recovered 6.63' of 13-3/8" csg. Tip 6' of fish split, smooth cut on bottom. CO w/ 26" bit to 136'. RIH w/ 12-1/4" bit. Could not get below 140'. RIH w/ spear & recovered 1.25' of 13-3/8" csg broken off main fish. RIH w/ spear. Engage spear in 13-3/8" & jar w/ no progress. POH. RIH w/ 8-1/2" bit. Could not get past 130'. LD 8-1/2" bit & PU 12-1/4" string mill. Tag junk @ 134'. Drld & pushed junk to 177'. RIH w/ I2-i/4" bit. Pushed junk to 648'. RIH w/ hyd cutter & cut csg @ 144'. RIH w/ spear, jar 3 times. Recovered 2.90' of 13-3/8" csg. RIH w/ 17-1/2" tapered mill. Drld cmt from 137'-144'. RIH w/ spear & recovered 6.90' of 13-3/8" csg after jarring. TOF @ 151'. RIH w/ 26" bit to 149'. RIH w/ 12-1/4" bit to 647'. RIH w/ hyd csg cutter. Cut 13-3/8" @ 158'. RIH w/ spear. Jarred w/ no movement. RIH w/ WP & WO 13-3/8" to 156'. Unsuccessful getting spear to hold. RIH w/ csg cutter. Cut 13-3/8" @ 161'. RIH w/ spear & jarred on csg. Recovered 11.22' 13-3/8" csg. Top 5-1/2' csg split. RIH w/ 26" bit & CO to 160'. RIH w/ 12-1/4" bit to 647'. RIH w/ csg cutter & cut csg @ 165'. RIH w/ spear. Jarred free & recovered 3.67' of 13-3/8". CO to 164' w/ 26" bit. RIH w/ mech csg cutter. Cut 13-3/8" @ 170'. RIH w/ spear & jarred w/ no movement. RIH w/ 12-1/4" bit to 230'. RIH w/ hyd csg cutter & cut csg @ 168'. RIH & engage spear. Jars parted while jarring on fish @ 165'. RIH w/ 15" overshot & guide. W0 fish. Attempt BO, ovecshot slipped. POH & change out grapple. RIH & engage fish. RIH w/ string shot. POH w/ entire fishing string. RIH w/ 26" bit & CO to 165'. RIH w/ washpipe & stinger assembly. Made no progress. POH & LD stab in stinger. RIH w/ washpipe/stinger ass. WO 13-3/8" from 165'-166.5'. RIH w/ spear. Could not get in stub. Made several unsuccessful attempts w/ 12-1/4" & 6" bits to get in stub. Attempt to work washpipe stinger into 13-3/8" stub @ 165' w/ no success. RIH w/ 14" magnet, no recover. RIH w/ 8-1/2" flat bottom mill. Mill on junk from 165'-166.5' & mill fell thru. Work mill thru top of stub. RIH w/ 12-1/4" string mill & 8-1/2" flat btm mill. Ream thru top 2' of csg. RIH w/ spear. Could not get spear to hold after engaging fish. POH. MU spear. RIH unable to get into TOF. RIH w/ 8-1/2" flat btm mill and 12-1/4" tapered mill. Work into fish. Dress TOF. RIH w/ spear. Work into fish. Engage spear. Jarred on fish 1 hr. Tools came free. POH. Rec 4" of 13-3/8" csg. Clean break on btm. RIH w/ 8-1/2" flat btm mill and 12-1/4" string mill. CO t3-3/8" csg to 210'. POH. MU pilot mill w/ 12-1/4" tapered mill below pilot mill. RIH. Milling on TOF. _ 0-44 Well History Page 4 08-02-85 " 08-03-85 " 08-04-85 " 08-05-85 08-06-85 " 08-07-85 " 08-08-85 " 08-09-85 " 08-10-85 " 08-11-85 08-12-85 08-13-85 08-14-85 08-15-85 538' TD 1,348' TD 2,451' TD 3,232' TD 'Mill on csg w/ 14-3/4" pilot mill @ 165.5'. POH. Stab pads below mill worn. Modified mill. RIH. Mill on csg w/ pilot mill. Milling very rough. POH. RIH w/ 12-1/4" bit to 628'. POH. RIH w/ pilot mill. Mill on csg 165.5' to 168'. Mill on csg clr and junk 168'-170.5'. RIH w/ spear. Rec 4.25' csg. RIH w/ csg cutter. Presently cutting csg @ 191'. Fin cutting csg @ 191'. Run spear. Rec 16' csg. Run csg cutter. Cut csg @ 206'. Run spear. Rec 14.75' csg. Cut csg @ 212;. Run spear. Engage and jar on fish. Unable to jar free. Run pilot mill. Milling on 13-3/8" csg 206'-207'. Mill 13-3/8" csg w/ pilot mill 207'-207.5'. RIH w/ spear. Engage fish. Jarred free. POH. Rec 4.'32' csg. RIH w/ hyd cutter. Cut csg @ 220'. Rec 8.77' csg. Cut csg @ 228'. Rec 8.0' csg. Presently cutting csg @ 247'. TOF @ 228'. Cut and pull 13-3/8" csg. Rec total of 96' csg. TOF @ 324'. Presently CO cmt @ 324'. PU 17-1/2" mill & mill cmt from 324'-326'. RIH w/ 12-1/4" bit & CO junk 650'-671'. RIH w/ multi string cutter & cut 13-3/8" csg @ 660'. Cut 13-3/8" csg 385'. RIH w/ spear & jar on fish. Fish moved ±2'. RIH w/ csg cutter. Unable to get cutter into stub. Get into csg stub & make cut @ 385' & 362'. RIH w/ spear & jar fish free. Recovered 3811' 13-3/8" csg. RIH w/ 26' bit, CO from 324'-360'. RIH w/ 17-1/2" mill, CO cmt from 360'-362'. Circ @ 362'. POH. RIH w/ 12-1/4" & CO to 390'. RIH w/ spear & jar fish free. Recovered 20.20' of 13-3/8" csg. RIH w/ 26" bit & CO to 380'. RIH w/ 17-1/2" tapered mill & CO to 382'. RIH w/ 12-1/4" bit & circ. RIH w/ spear. Jar on fish, no movement. RIH w/ csg cutter & cut 13-3/8" @ 505'. RIH w/ spear & jar fish free. LD 119.86' of 13-3/8" csg. CO to 400' w/ 26" bit. RIH w/ 17-1/2" tapered mill & CO:from 400'-410'.~ POH. Open hole to 17-1/2" from 410'-503'. Set spear @-505'. Jar on fish w/ no movement. Ret spear. POH. Cut csg @ 558'. Jar on fish, no movement. Cut csg @ 518'. Jar on fish. Rec 12.73' of 13-3/8" csg. Jar on csg. Rec 39.20' of 13-3/8" csg. Jar on csg. Rec 39.20' of 13-3/8" csg. CO to TOF @ 558'. RIH w/ cutter to cut csg @ 596'. Cut 13-3/8" csg @ 597'. RIH w/ spear & jar fish free. Recover 38.90' of 13-3/8" csg. Function tst diverter system. RIH w/ 17-1/2" hole opener & cleanout from 558'-597'. RIH w/ 12-]./4" bit to 661'. RIH & cut csg @ 636'. RIH w/ spear & jar fish free. Recovered 38.80' of 13-3/8" csg. TOF @ 636'. RIH w/ 17-1/2" hole opener & CO f/ 597'-636'. RIH w/ spear & recovered 23.83' of 13-3/8" csg. TOF @ 660' LD fshg tools. RIH w/ OEDP to 660'. Pump 250 sks cmt. POH LD DP. Unable to work boats @ dock due to weather. WOC. Diverter system inspected by AOGCC. RIH & tag cmt @ 498'. Drld hard cmt to 538'. WO drlg tools because of weather. Continue bleeding annulus pressure from wells. RIH w/ mud motor & orient to ±N70W. Drld & surveyed from 538'-891~. Drld w/ mud motor & steering tool 891'-1348'. POH. MU angle bldg assbly & RIH. Drld & surf. 1348'-2238'. POH. ~Chg bits. RIH drld & surv 2238'-2451'. POH RU steering tool. RIH w/ mud motor. Orient steering tool. Drld & surv 2451'-2609'. POH. LD tools. RIH. Drld & surv 2609'-3232'. Bit torqued. Lost 400# pump press. POH. Looking for washout. Found no washout. Clean BHA. RIH. _~ D-44 Well History Page 5 08-16-85 3,310' TD 08-17-85 08-18-85 08-19-85 08-20-85 3,335' TD 08-21-85 08-22-85 08-23-85 08-24-85 08-25-85 08-26-85 08-27-85 08-28-85 5,835' TD 08-29-85 6,099' TD 08-30-85 6,636' TD 08-31-85 7,228' TD 09-01-85 7,521' TD 09-02-85 7,880' TD 09-03-85 8,073' TD 09-04-85 09-05-85 8,239' TD Drld & surv 3232'-3310'. POH. LD DP. PU 17-1/2" HO. Opened hole to 17-1/2" 503'-1450'. OH to 17-1/2" 1450'-2440'. Chgd hole openers. OH 2440'-2665'. OH to 17-1/2" 2665'-3308'. Chgd to 22" HO. OH to 22" 403'-1325'. OH to 22" 1325'-3301'. C & C mud. .. Circ. POH. RIH w/ 17-1/2" bit. Drld 3310'-3335'. Circ. POH. PU 22" HO. OH to 22" to 3328'. Circ. ST. Circ for csg. POH for 16" csg. Fin POH. LD 17-1/2" drilling tools. RU and ran 16" csg to 3305'. Ran 5" DP and stab in stinger on 5" DP. Stabbed into FLT clr @ 3219'. Circ and cond mud. RU cmters. Presently cmting 16" csg. Have pumped 2500 sxs lite cmt @ 13.3 ppg. Mixed & pumped lead slurry of 3700 sks Class "G" w/ 8% gel, 75% D-31, .25% R-5, .1% D-6 @ 13.3 ppg and tail slurry of 500 sks .75% D-31, .1% R-5 & .1% D-6L @ 15.9 ppg. Class "G" w/ 1% CaC10, CIP @ 0753 hrs on 8/21. Lost returns w/ 13 ppg cmt to surface. POH w/ DP. Cut off 16" csg & ND 29-1/2" diverter system. Found top of cmt @ 210' in 30" conductor. Weld 16" casing head & test to 1500 psi. NU BOPE. RIH w/ 2-1/16" tbg between 30" conductor & 16" csg to 188'. Mix & pump 350 sks Class "G" w/ 2% CaC1 @ 15.9 ppg. Fin NU BOPE. Close blind rams. Test csg to 2500#. RIH w/ 13-1/2" bit tag cmt @ 2735'. Drld cmt 2735'-2806'. RIH to FC @ 3220'. Circ and cond mud to 9.5 ppg. Chg out drilling line. Close pipe rams and test to 2500#, ann to 1500#. Repair vlvs on std pipe. Drld FC @ 3220', FS @ 3305'. Drld 5' new hole 3335'-3340'. Run leak off test to 14.0 ppg EMW. POH. Ran gyro from surf to 3300'. RIH. Drld & surv 3340'-3621'. Drld 3621'-3653'. POH to chg BHA. RIH. Drld and surv 3653'-4043'. Dr!d & surveyed from 4048'-5160'. Drld & surv 5160'-5308'. POH. Chg bits and BHA. RIH. Drld 5308'-5835'. Surv @ 5835'. Drld to 5910'. Circ. POH. Chg BHA. RIH. Drld 5910'-6099'. Surv. POH. Chg BHA. RIH. RIH to sboe. Cut DL. Fin RIH. Drld & surv. 6099'-6510'. CBU. POH for bit chg. RIH. Drld 6510'-6636'. Drld from 6636'-7228'. POOH. Finished tripping for new bit. Drld from 7228'-7521'. Drld from 7521'-7650'. Tripped for new bit. Drld from 7650'-7880'. Circ. POH. Chg bits. RIH. Drld 7880'-8073'. Lost 500# pump press. POH. Looking for washout. POH looking for washout. Pulled into tight spot @ 3980'. Lost 20,000# of string wt. Fin POH. Left 118' of BNA in hole. Test BOPE. RIH w/ overshot. Tag fish @ 7955'. Engage fish. POH. LD tools. RIH w/ bit #17. FJ.n RIH. Drld 8073'-8223'. Circ. Droo surv. POH. Chg bits. RIH. Drld 8223'-8239'. _~ D-44 Well History Page 6 09-06-85 8,621' TD 09-07-85 8,747' TD 09-08-85 9,070' TD 09-09-85 9,235' TD 09-10-85 9,331' TD 09-11-85 9,560' TD 09-12-85 9,798' TD 09-13-85 10,002' TD 09-14-85 10,135' TD 09-15-85 10,333' TD 09-16-85 10,487' TD 09-17-85 10,626' TD 09-18-85 10,721' TD 09-19-85 10,985' TD 09-20-85 11,100' TD 09-21-85 11,253' TD 09-22-85 " 09-23-85 " 09-24-85 " 09-25-85 " 09-26-85 11,258' TD 09-27-85 11,503' TD 09-28-85 11,836' TD 09-29-85 12,094' TD Drld 8239'-8405'. Circ. Drop surv. POH. RIH w/ new bit. Drld 8405'-8621'. Drld 8621'-8624'. Circ. Drop surv. POH. Chg bits. RIH. Drld 8624'-8747'. Circ. POH. Chg bits. RIH. Fin RIH. Drld 8747'-9070'. Circ. Drop surv. POH. Fin POH. Chg bits. RIH. Drld 9070'-9235'. Drld 9235'-9245'. Circ. Drop surv. POH. Chg bits. RIH. Drld 9245'-9331'. Circ. POH. Chg bits. RIH. RIH w/ bit #24. Drld 9331'-9560'. Circ. POH. Chg bits. RIH. Fin RIH. Drld 9560'-9798'. Circ. Drop surv. POH. Test BOPE. Fin testing BOPE. Chg BHA. RIH. Drld 9798'-10,002'. Circ. Surv. Tripped for new bit. Drilled from 10,002'-10,135'. Lost 300 psi pump pressure. POH looking for washout. Finished POOH looking for washout. Changed bit. RIH. Drilled from 10,135'010,333'. Circ. Tripped for new bit. Drilled from 10,333'-10,487'. Drilled from 10,487'-10,506'. Tripped for bit #30. Drilled from 10,506'-10,626'. Drilled to 10,692'. Tripped for washout and bit #31. Drilled to 10,721'. Drld & surveyed from 10,721'-10,985'. Dropped survey & POH. PU bit #32 & RIH. Drld from 10,985'-11,100'. Drld from 11,100'-11,156'. Pumped pill & pulled 45 std trip. RIH to 11,156'. Drld 11,156'-11,253', lost 200 psi pump press. POH. Found washout in 28th std. Trip to 16" csg shoe @ 3305'. RIH to TD. Circ & cond hole for logs. POH & SLM, no correction. Logging run #1 GR-SP-CAL-DIL-Sonic. From TD to 16" csg shoe. RIH & ].og w/ LSS. Finish run #2 w/ LSS. POH. RIH for run #3, GR-CAL-FDC-DNL from TD to 16" csg shoe. POH & RD loggers. LD monel DC's & stabilizers. RIH to TD. Circ & cond hole to run csg. POH, hole in good shape. Fin RU to run csg. Ran 9-5/8" csg to 11,218'. Circ and cond mud for cmting. Presently cmting csg. Fin cmting 9-5/8" csg w/ 1800 sxs lite @ 13.3 ppg followed by 500 sxs C1 "G" @ 15.9 ppg. Bump plug to 1950#. CIP @ 1000 hrs. ND BOPE. Set csg slips. NU tbg spool. NU BOPE. Test BOPE. PU BHA. RIH test csg to 3000 psi. Drld cmt from 1]_,111'-11,186'. Tst csg to 3000 psi. Dr!d shoe & 5' of new hole. Pressure shoe to 11.7 ppg EMW w/ no leakoff. POH. Run gyro survey 11,180'-11,500'. RIH. Drld from 11,258'11-503' w/ no problems. Drld & surveyed from 11,503'-11,836' w/ no problems. POH. LD lead clr & PU bit #35.. RIH. Wash & ream 190' to bottom. Drld from 11,836'-12,094'. _~ 0-44 Well History Page 7 0930-85 12,318' TD 10-01-85 12,622 TD 10-02-85 12,874 TD 10-03-85 12,941' TD __ 10-04-85 13,068' TD ~10-05-85 13,070' TD 10-06-85 10-07-85 10-08-85 10-09-85 10-10-85 10-11-85 10-12-85 10-13-85 10-14-85 Drld from 12,094'-12,136' and surveyed. POH to 16" csg shoe. Work tight hole from 11,986'-11,630'. RIH. Wash 60' to bottom. Drld 12,136'-12,318'. POH. POH. MU bit #36. Change out NB stab, top stab & 2 jts. HWDP. RIH. Ream 12,258'-12,318'. Drld from 12,318'-12,622' w/ no problems. Drop survey & POH. MU bit #37 & change out 2 stab. RIH. Ream from 12,562'-12,622'. Drld to 12,874'. Drld from 12,874'-12,941' & surveyed. Short trip to 9-5/8" csg shoe. Circ & cond hole for logs. POH. RU loggers. Log from TD 12,930'-11,196' DIL. Run #1DIL-Sonic-GR-SP. Run #2 LSS. Fin logging w/ LSS. Ran FCD-CNL-GR-CAL. Log 12,927'-11,198'. POH. RD loggers. RIH w/ bit to 12,884' to 12,884'. Ream 12,884'-12,941'. Drld 12,941'-13,068'. Drld to 13,070'. Circ & cond hole for csg. POH. Run 51 jts 7" csg. Circ & cond mud while reciprocating liner. RU cementer & test lines to 5000 psi. Mix preflush for cement job. Pumped 505 sks Class "G" w/ additives. Displacement was 5 bbls over CALC value. Bump plug to 3200 psi. Floats held. CIP @ 0746 hrs. Released liner running tool. POH 10 stds & rev circ. No cmt recovered. POH. Tst BOPE. MU 8-1/2" bit & 9-5/8" 47# csg scraper. RIH to TOL @ 10,919'. CBU & rec ±30 bbls slightly contaminated mud. POH. PU 4-3/4" DC & 6" bit. PU 3-1/2" DP. RIH w/ 6" bit & tag cmt @ 12,838'. Drld soft cmt 12,838'-12,981'. CBU. POH. RIH w/ gyro. Set down @ 5188' DIL. POH. RIH w/ 8-1/2" bit to TOL. Pump vis sweep, rec some cmt cuttings. POH. RIH w/ gyro, could not get into liner top. RIH to PBTD @ 12,981' w/ 6" bit & 7", 29# csg scraper. Circ & POH. Run gyro from 10,800'-12,970'. Run CBL/VDL/GR/CCL from PBTD @ 12,974' CBL to TOL. Tst 9", 7" csg & liner lap to 3000 psi. Press bled to 2550 psi in 15 min. MU & RIH w/ tools for dry test. Dry tst had steady blow for 2 hrs. POH to fluid. Recovered 12 bbls. Rev circ & POH. RIH to 10,951' w/ 3-1/2" DP stinger. Tst cmt lines to 6000 psi. Set pkr @ 10,475'. Pump 8 bbls water into liner lap # 3/8BPM & 3750 psi. Pump 100 sks Class "G" w/ addi- tives followed by 5 bbls water. Spot cmt @ 7" liner lap. Pump 12 bbls into liner lap w/ 3250-4250 psi final squeeze press. Press bled to 3000 psi in 1 hr. POH w/ squeeze pkr. PU 8-1/2" bit and 9-5/8" csg scraper. RIH to 10,331'. WOC. RIH. Tag cmt @ 10,821'. Drld and circ soft cmt to 10,885'. WOC w/ 1000# on csg. Drld hard cmt to TOL @ 10,919'. Circ hole clean, cut DL. Fin cut DL. POH w/ 8-1/2" bit. MU DST tools. RIH. Fill 57 std w/ H~O. Set pkr @ 10,847'. Open tool 2 hrs. Had very light stea~y flow. Close tool 2 hrs. POH to H~0 cushion. Rec 10 bbls fluid. Rev circ. Fin POH. Test csg tc ~000# for 30 min w/ no leak off. RIH w/ 6" bit and 7" csg scraper. RIH w/ 6" bit and 7" csg scraper. Drld cmt 10,919'-10,993'. RIH to 12,981'. CBU. POH. RIH w/ squeeze pkr. Spot 20 bbls H20. Press to 5000#. Bled to 4100# in 15 min. Unable to PI to lap WO acid. Spot 500 gals 15% HCL. Pump 6 bbls acid. Press inc to 5000#. Bled to 4000#. Press to 4200#. Broke dwn. PI @ 3 BPM w/ 3900#. SI. Press bled to 2500# in 10 min. Prep to squeeze lap. Mix and pump 125 sxs C1 "G" cmt. Squeeze 100 sxs ~nto liner lap. WOC. Rel pkr. POH. RIH w/ 8-1/2" bit & 9-5/8" csg scraper. RIH w/ 8-1/2" bit and 9-5/8" csg scraper. Tag cmt @ 10,548'. Drld cmt stringers and hard cmt to TOL @ 10,919'. CBU. POH. PU _~ D-44 Well History Page 8 10-15-85 10-16-85 10-17-85 " 10-18-85 10-19-85 10-20-85 10-21-85 10-22-85 10-23-85 10-24-85 10-25-85 10-26-85 10-27-85 10-28-85 10-29-85 10-30-85 10-31-85 11/01-03/85 " DST tools. RIH. Fill 57 std w/ fresh H 0. Set pkr @ 10,847'. Open tool 1 hr. Had very light blow 5 m~n then dead. Close tool 2 hrs. POH. Reverse out water cushion and finish POH. RIH w/ 6" bit and 7" csg scraper. Drilled cmt 10,919'-10,951'. RIH to PBTD @ 12,981'. CBU, clean hole and change over to FIW. Spot 100 bbls of FIW w/ 3% KCL on bottom. POH. Run gauge ring and junk basket. Fin running gauge ring and junk basket to 12,850'. Set insulation packer and plug profile at 12,725'. Set permanent production packer at 11,888'. RIH w/ drill pipe and test production packer to 3000 psi--OK. POH. LD DP. Fin LD DP. RU and run 3-1/2" completion tubing with side string chemical injection tubing. Fin RIH w/ 3-1/2" tbg. Land tbg. ND BOPE. Prep to NU prod tree. NU tree. Seal flange would not test. ND tree. PU tbg. Chg seal on tbg hgr. NU tree. Test to 5000#. NU flow lines and gas lift lines. Unload FIW prior to perf. Fin unloading FIW. RU WL. Perf Hemlock B-6, 12,810'-12,830' DIL. Presently unloading well @ 30 bbls/hr. Cum fluid prod 584 bbls. Total fluid to btm GLV = 749 bbls. Cont flow test Hemlock B-6. Well began cycling gas after 682 bbls. No prod from B-6. RU WL perf Hemlock B-4 12,522'-12,554' DIL. Flow test well w/ EST rate 96 BFPD, 100% WC, TP 115, CP 1050, lift gas 2021, slight oil sheen. Flow tested well for 24 hrs. Avg rate last 6 hrs - 100 BFPD, 94% WC, 6 BOPD, 2347 MCFD lift gas, 115 psi TP, 890 psi CP. Total fluid produced - 830 bbls. Flow test well f/ Hemlock Benches 4 & 6. Perforated additional Bench 4 at 4 HPF. Under drawdo~ f/ 12,482'-12,512' DIL, 12,512'-12,532' DIL, 12,554'-12,562' DIL. Flow tested well, est rate - 67 BFPD, 85% WC, 10 BOPD, 2222 MCFD lift gas. Flow tested well for 24 hrs. Avg rate last 6 hrs - 92 BFPD, 86% WC, 13 BOPD, 2424 MCFD lift gas. No tests available - platform shutdown for scheduled maintenance. No tests available. Stabilizing production after scheduled platform shutdown. Produced well for 24 hrs. Avg rate last 6 hrs - 90 BFPD, 78% WC, 20 BOPD, 1948 MCFD lift gas, 150 psi TP, 750 psi CP. Produced well for 24 hrs. Avg rate last 6 hrs - 66 BFPD, 79% WC, 14 BOPD, 1919 MCFD lift gas, 175 psi TP, 750 psi CP. Produced well for 24 hrs. No tests available due to compressor downtime. Well shut-in to prepare for acid job. Fill 3-1/2" tubing with FIW. Set plug in isolation packer assem- bly between Benches 4 & 6. Fill tubing/casing annulus with FIW. RU coil tubing unit and acid equipment. RIH with coiled tubing. Establish injection into Bench 4 with 3% KCL, .25 BPM, 4350 psi matrix-acidized Bench 4 with 4000 gallons 7-1/2% HCL, 10,000 gallons 6% HCL 1-1/2% HF mud acid, 500 gallons diesel, 4000 gallons clay acid. Overdisplaced with 2 bbls diesel. Final rate and pressure 1.0 BPM, 1300 psi. Let acid soak. _ ~-44 Well History Page 9 11-04-85 " 11-05-85 " Flowed well at restricted rate for clean-up after acid job. Well shut-in twice because of platform-to-shore emulsion problems. 694 bbls of a total load volume of 1250 bbls produced at a restricted rate of 350 BFPD, 99% WC. Continue to flow test well at an average rate of 575 BFPD, 99% WC~ At report time water cut dropping and PH of produced fluid rising indicating the last of the load fluid being produced 1224 of 1250 bbls load fluid produced so far. 11-06-85 " 11-06-85 " Continue to fl~ test well at an average rate of 993 BFPD, 30 BOPD, 97% WC. Well still clemning up after acid job. D-4RD Injecting FIWdown tubing thru hydraulic jet pump at 3000 BFPD, surface tubing pressure of 3300 psi. Taking returns up the annulus at a total rate of 4472 BFPD. Formation is producing 1472 BFPD, 177 BOPD, 88% WC. Rig released to D-30RD. 11-07-85 " 11-08-85 " 11/09-11/85 " 11/12-22/85 " 11/23-25/85 " 11-26-85 " 11-27-85 " 11-28-85 " 12-03-85 " 12-04-85 " 12/06-09/85 " 12-10-85 " D-44 continued Flow tested well at an average rate of 816 BFPD, 57 BOPD, 93% ~. Well still cleaning up after acid job. Continue flow testing well to group separator. No rates available Average ~ = 93%. Continue flow testing well. Shut well in. Final WC = 93%. Prepare to abandon Bench 4. Well SI in preparation for abandonment of Bench 4. RUWL. Set thru tbging bridge plug in 7" csg @ 12,470' DIL to abandon B-4 perfs 12,482'-12,562' DIL. RU dump bailer. RIH w/ 2-1/4" x 40' dump bailer w/ 7.4 gals of 15.5#/gal cmt. Bailer fired but cmt did not dump. RIH w/ 1.8 gals sand slurry. Dumped sand on top of BP. POH. WL strand broke loose and balled up into lubricator. Pump FI~ into well. RD lub. POH w/ WL. RIH w/ 1.8 gals sand. Fired bailer. Tag sand @ 12,467' DIL. POH. Bailer did not fire. Clean bailer. Made 3 unsuccessful bailer runs w/ cmt. Two runs did not dump, one run did not fire. Bringing out new cement for slurry. Will perf B-1 12,108'-12,148' DIL once B-4 is abandoned. Mix neat cement for bailer. Made 5 runs and dump 22.5' of cement on top of bridge plug. Est TOC @ 12,437'. RD WL. Will flow test well to assure effective seal prior to perf B-1. Wait on cmt 24 hrs. Presently flow testing well to check plug integrity. Flow tested well to check plug integrity. Plug leaked badly. Tag bridge plug 12,470' DIL w/ no cement on top of plug. Set another thru-tubing bridge plug @ 12,460' DIL. Presently dump bailing cement on top of bridge plug. Fin dump bailing cmt on top of BP. ~XDC prior to flow testing well to check plug integrity. Will flow test well @ 1400 brs 12/05/85. WOC for 48 hrs. Flow tested well to check plug inte~c~rity - well cycled gas. Tag TOC @ 12,427' CBL (2' high). Perforate Hemlcok Bench 1 f/ 12,108'-12,148' DIL w/ 2-5/8" g~ns, 4 HPF, 0° phasing. Unload well to test separator. Flow tested well for 24 hrs. Avg rate after unloading - 224 BFPD, 0.7% WC, 222 BOPD, 1600 MCFD lift gas, 200 psi TP, 700 psi CP. _~ D-44 Well History Page 10 12-11-85 " 12-12-85 " 12-13-85 " 12-14-85 " 12-15-85 12-16-85 " 12-17-85 " 12-18-85 " 12-19-85 " 12-20-85 " 12-21-85 " 12-22-85 " 12-23-85 " 12-24-85 " 12-25-85 " 12-26-85 " 12-27-85 " 12-28-85 " 12-29-85 " 12-30-85 " 12-31-85 " l, Flow testing well. 24 hr flow test - 232 BFPD, .6% WC, 231BOPD, 1460 MCFD lift, 120 psi TP, 720 psi CP. Flow tested well for 16 hrs. Avg rate - 270 BFPD, 0.5% WC, 269 BOPD, 1321 MCFD lift gas. RIHw/ BHP tools to 12,320' WLM for 24 hr PBU. Well SI total of 31 hrs for PBU. Fin POH w/ BHP bcmb. Analyzed PBU data. Resumed flow tests for 4 hrs - 312 BFPD, 0.6% WC, 310 BOPD. Well tested 24 hrs - 314 BFPD, 1.0% WC, 311BOPD, 1541 MCFD lift gas, 140 psi TP, 800 psi CP. Well tested 24 hrs - 125 BFPD, 0.4% WC, 124 BOPD, 1490 MCFD lift gas, 135 psi TP, 700 psi CP. Tested for 24 hrs - 97 BFPD, 0.1% WC, 97 BOPD, 1478 MCFD lift gas, 120 psi TP, 860 psi CP. Flow meter checked, OK. Tested for 24 hrs - 108 BFPD, 0.3% WC, 108 BOPD, 1486 MCFD lift gas, 120 psi TP, 840 psi CP. Currently re-evaluating PBU data. Tested well 24 hrs - 300 BFPD, 0.1% WC, 300 BOPD, 1616 lift gas, 120 psi TP, 990 psi CP. Rate increase by manual dumping of test separator. (Well's flow rate too low for accurate metering with automatic dumping. Tested well 24 hrs - 344 BFPD, 0.1% WC, 344 BOPD, 1755 lift gas, 120 psi TP, 760 psi CP. Tested well 24 hrs - avg rate last 6 hrs - 294 BFPD, 294 BOPD, 2218 MCFD lift gas, 120 psi TP, 910 psi CP. Tested well last 6 hrs - 276 BFPD, 276 BOPD, 2213 MCFD lift gas, 130 psi TP, 920 psi CP. Tested well last 6 hrs - 243 BFPD, 243 BOPD, 1977 MCFD lift gas, 120 psi TP, 840 psi CP. Currently awaiting completion of CB #2 ccmpressor overhaul before perforating lower Bench 2. Flowed well to group sep, no tests available. Flowed well to group sep, no tests available. Flow tested well last 6 hrs - 254 BFPD, 254 BOPD, 1714 MCFD lift gas, 130 psi TP, 935 psi CP. Currently proparing to perforate Hemlock Middle Bench 2. Flowed well to test separator, avg rate - 236 BFPD, 235 BOPD, 1686 lift gas. RU WL unit & lubr. Wait for crane to finish offloading boat. SI well. Fin armingperf-guns & press test lubr. RIH w/ 2-5/8" 9mns, 4 KPF, 0° phasing & perforate Hemlock ~ddle Bench 2, 12,270'-12,280' DIL, under drawdown. Tag btm @ 12,427' DIL. POH & RD~. Tested well 24 hrs - 304 BFPD, ].6% WC, 255 BOPD, 2418 MCFD lift gas, 105 psi TP, 1010 psi CP. Tested well 24 hrs - 240 BFPD, 14% WC, 206 BOPD, 2494 MCFD lift gas, 120 psi TP, 1040 psi CP. Currently planning to perforate Hemlock Upper Bench 2. RUWL, lubr, & test same. SI well. RIH w/ 2-5/8" perf guns, 4 HPF, 0° phasing. Perforate Hemlock Upper Bench 2, 12,176'-12,208' DIL, under drawdown. POH & RD ~'~. Flow tested well 8 hrs - 416 BFPD, 31% WC, 287 BOPD, 2275 lift gas, 120 psi TP, 1030 psi CP. _~D-44 Well History Page 11 01-01-86 " 01-02-86 " 01-03-86 " Tested well 24 D~s - 400 BFPD, 27% WC, 292 BOPD, 2249 k~FD lift gas, 120 psi TP, 860 psi CP. Tested well 12 hrs - 364 BFPD, 18% WC, 297 BOPD, 2181MCFD lift gas, 120 psi TP, 880 psi CP. Tested 24 hfs - 351 BFPD, 19% WC, 284 F~DPD, 2213 MCFD, 120 psi TP, 940 psi CP. Final report until further wellwork cc~pleted. -- STATE OF ALASKA ALASF, OIL AND GAS CONSERVATION COMk SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Fl, Stimulate [] Plugging © Perforate I~ Pull tubing Lq Alter Casing .~ Other Fi 2. Name of Operator UNOCAl, * 3. Address P. O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg A-2 Cond. 748' FSL, 1,130' ;FWL, Sec. At top of productive interval 2,550' FSL, 350' FEL, Sec. At effective depth 2,502' ~l~L, 291' FEL, Sec. At total depth 2,350' FNL~ 215' FELt Sec. #8 Dolly Varden Platform 6 - 8N - 13W- SM 31 - 9N- 13W- SM 31 - 9N - 13W - SM 31 - 9N - 13W - SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Well number .4. D-44 SEP 1 :.; 1986 8. A p p rova~. ~,e ~OCi(~V OO]2) 277 9. APl number 50-- 773-20195-01 10. Pool McArthur River Field 11. Present well condition summary Total depth: measured true vertical 13,070' feet 9,990' feet Effective depth: measured 12,432 ' feet true vertical 9,530 ' feet Casing Length Size Structural Conductor Surface 3,305 ' 16" Intermediate 11,218' 9 5/8" Production Liner 2,151 ' 7" Perforation depth: measured Plugs (measured) Junk (measured)None 13,070' - 12,981' cement 12,745' PX plug 12,432' - 12,465' BP & cement Cemented Measured depth 4,550 sx Class G 2,300 sx Class G True Vertical depth 3,305' 2,942' 11,218' 8,675' 505 sx Class G 13,070' 9,990' See Attachment #1 true vertical Tubing (size, grade and measured depth) 3 1/2" 9.2# N-80 @ 11,958' Packers and SSSV (type and measured depth) Otis 3 1/2" Series 10 BV @ 302' Otis WBR Packer @ 11 904' Otis WD Packe~ ¢ 12;725' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 7/16/86 134 6 186 680 psig Subsequent to operation 8/22/86 275 99 234 1,140 psig ~bing Pressure 120 psig 130 psig 14. Attachment~ #2 Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge * Marathon Oil Company, Sub-Operator Title Environmental Engineer Form 10-40~1¢ev. 12-1-8~i Date ¢; -" , Submit in Duplicate Bench 1 Bench 2 ATTACHMENT #1 Well D-44 Perforations 12,108' - 12,148' MD 12,176' - 12,208' MD 12,240' - 12,290' MD 12,308' - 12,326' MD 9,301' - 9,329' TVD 9,348' - 9,371' TVD 9,393' - 9,429' TVD 9,442' - 9,454' TVD MDC/em/094/OEll ATTACHMENT # 2 DAILY REPORT OF WELL OPERATIONS Well D-44 August 9, 1986 · e Be e RIH with 2 5/8", 0°phased perforating guns. 1st run perforated Bench 2 12,280' - 12,290' and 12,308' - 12,326' with 4 SPF. 2nd run perforated Bench 2 12,240' - 12,270' with 4 SPF. Put well on production. MDC/em/094/OEll STATE OF ALASKA ALA,~ .A OIL AND GAS CONSERVATION COk. .,ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend .rq Operation Shutdown [] Re-enter suspended well '~ Alter casing ~ Time extension .~ Change approved program .rq. Plugging [] Stimulate [] Pull tubing © Amend order~4 Perforate~. Other '_% ~ 2. Name of Operator 5. Datum elevation (DF or KB) .~ UNOCAL* 106' KB above MSL fe 3. Address 6. Unit or Property name P. O. Box 190247 Anchorage, AK 99519 Trading Bay Unit 4. Location of well at surface Leg A-2 Cond #8, Dolly Varden Platform 748' FSL, 1,130' FWL, Sec. 6 - 8N- 13W- SM At top of productive interval 2,550' FSL, 350' FEL, Sec. 31- 9N- 13W- SM At effective depth 2,502' FNL, 291' FEL, Sec. 31- 9N- 13W- SM At total depth 2,350' FNL, 215' FEL, Sec. 31 - 9N - 13W- SM 7. Well number D-44 8. Permit number 85-122 9. APInumber 50-- 773-20195-01 10. Pool Mc Arthur River Field 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 3,305 ' Intermediate 11,218' Production Liner 2,151' Perforation depth: measured !3,070' feet Plugs (measured) 12,432' - 9,9 90 ' feet 12,981' - 12,432 feet Junk (measured) NONE 9,559 feet Size Cemented Measured depth 17" 4,550 sx Class G 3,305' 9 5/8" 2,300 sx Class G 1].,218' 7!1 Present effective Perfs = 12,108' - true vertical 9,195' - 9,223', 9,243' - Tubing (size, grade and measured depth) 3 1/2" 9.2 #N-80 @ 11,958' Packers and SSSV (type and measured depth) Otis 3 1/2" Series 10 Ball Valve @ 302' 505 sx Class G 13,070' 12,148' 12 176' - 12,208' , , , 9,265' 9 309' - 9 316' , , , , Otis WBR Packer @ 11,904' 12.Attachments 12,465', PX Plug @12,745' 13,070' True Vertical depth 2,842' 8,675' ., 12,270' 9,990' - 12,280' Description summary of proposal ~ Otis WD Packer @12,7 Detailed operations program ~ BOP sketch ~ 13. Estimated date for commencing operation July 25, 1986 14. If proposal was verbally approved Name of approver approved .. 15. I hereb_.¥ certify th.c~t the foregoing is true a,~d correct to the best of my knowledge Signed ROyC-D. RobCr;f.E ~?~,.~{.': ,,//¢~-5 'l'itle Environmental ,Engineer Commission Use Only Conditions of approval *Marathon Oil Company, Sub-Operator Approved by ~ ~.i?i-~':'~ ~. ~l~') Form 10-403 Rev 12:1-85 _-~ ; Notify commission so representative may witness Approval [] Plug integrity [] BOP Test [] Location clearance : -. ..... ~ ..'"~., ~ ,' .,!~ .:~,' .¢4-,~,. ',, "V ~' ,.[.; ¢-:i';:,.,: :; .Date 7/22/86 NO. Commissioner by order of the commission Date Submit in triplicate 25' i · 2~ Be e · · AFE 8267-6 WELL D-44 Perforation Procedure Run 12 hour production test on D-44. Rig up MOC pump-in-sub and electric line over D-44. Perforate the following zones underbalanced with 2 5/8" guns, 4 SPF, 180° phasing: Bench 2 12,240' - 12,270' DIL 30' Bench 2 12,280' - 12,290' DIL 10' Bench 2 12,308' - 12,326' DIL 18' Test well for 24 hours. If an incremental 200 BOPD has been achieved, rig do~ wireline and continue to test well. If an incremental 200 BOPD is not achieved, continue with Step 5. Perforate the following zone with the same guns as in Step 3: Bench 3 12,356' - 12,388' 32' Rig down wireline and test well. WCB/em/036/OE8 JUL I 8 L986 Unocal Oil & Gas Divisi Unocal Corporation RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Environmental Group Alaska District February 14, 1986 Mr. C.V. Chatterton AK. Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Hr. Chatterton: WELL COMPLETION REPORT D-44 Attached please find two (2) copies of the Well Completion or Recompletion Report for D-44, Trading Bay Unit for your information and files. Very truly yours, Roberts Environmental Engineer tj/O124n Attachments (2) · , STATE OF ALASKA ALASKA _AND GAS CONSERVATION C(, vllSSION 'WELL COMPLETIUN OR RECOMPLETION I EPORT AND LOG 1. Status of Well OIL [] G~AS [] SUSPENDED [] ABANDONED [] SERVICE [] Classification of Service Well 2. Name of Operator LTnion 0±1 Company of Cai±lorn±a* 3. Address P.O. Box 6247, Anchorage, AK 99502 4. Location of well at surface Leg A-2, Cond. ¢/$, Doily Varden Platform 748' FSL, 1130' ~,~L, Sec 6-gN-13W-SM At Top Producing Interval ' 2550' FSL, 350' FEL, Sec. 31-9N-13W-SM At Total Depth 2350' FNL, 215' FEL, Sec. 31-9N-13W-S~T 7. Permit Number 85-122 8. APl Number 50- 773-20195-01 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-44 11. Field and Pool .5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' KB above MSL I ADL - 18730 McArthur River Field 1-~. Date Spud'~de~-~ l~.-~a~e--~.-D. Reached ~-4~i Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 6/25/85 110/5/85 10/19/85 106' KB feet MSL (1) one 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 19. Directional Survey 1 20. Depth where SSSV set 21. Thickness of Permafrost 13,070' - 9,990 I 12,432'-9,559' YEST~ NO[] I or~, feetMD 22. Type Electric or Other Logs Run DIL, OR, SP, FDC, C~., CAL, Sonic, LSS, CBL, VDL, CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD GRADE X'56 P-il0 N-80 7" 29 N-80 I CASING SIZEIWT, PER FT. 16" 120 9-5/8" 47 SETTING DEPTH MD TOP I BOTTOM Surface I ~305 / SurfaceIi11'218' 13,070' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Attachment HOLE SIZE 22" 12~1/4" 8--1/2" 25. SIZE 3-1/2" CEMENTING RECORD 4550 SxC1G 2300 SXC1G 505 SxC1G 26. DEPTH INTERVAL (MD) Attachment AMOUNT PULLED 250~000 250,000 TUBING RECORD DEPTHSET(MD) PACKERSET(MD) 11,958~ 11,904z ACID, FRACTURE, CEMENT SQUEEZE, ETC. AMOUNT& KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production io/2if$5 Date of Test Flow Tubing Press. 120 Hours Tested 24 Casing Pressure 80O 28. Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FORIOIL-BBL TEST PERIOD I~ I 27.2 CALCULATED , I OIL-BBL 2A-HouR RATE ]~ I 272 GAS-MCF 53 WATER-BBL 6_8. CHOKE SIZE GAS-OIL RATIO 1.95 GAS-MCF WATER-BBL OILGRAVITY-API(corr) 53 68 35 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ; · * Marathon Oil Company Sub-Operator Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE .. Submit in duplic?~ ,- 29. -- .~ ~1~' 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH _ TRUE VERT. DEPTH .GOR, and time of each phase. , 31. LIST OF ATTACHMENTS · . :32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed R~)~ ~.' Roberts TitleErlvir. Erlgineer Date 02/14/86 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 wa~er 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 gi~ven in other spac~es on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. . Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. ! Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". I 0-40'7 D-44 WELL COMPLETION REPORT Attachment Perforations: 2 5/8" guns, 4SPF, 0° Phasing TVD . Bench 6 12,810' - 12,830 DIL 9,797' - 9,812' DIL Bench 4 12,482' - 12,532' DIL 12,522' - 12,562' DIL 9,565' - 9,601' DIL 9,594' - 9,616' DIL Plug & Abandoned Benches 4 and 6. Bench 1 12,108' - 12,148' DIL Bench 2 12,270' - 12,280' DIL 12,176' - 12,208' DIL 9,323' - 9,352' DIL 9,441' - 9,448' DIL 9,373' - 9,396' DIL Acid, Frac, Squeeze, etc. 7" Liner, Top at 10,919', 100 sx CL "G" cmt, 500 gal. of 15% HC1, 125 sx of C1 "G" cmt and squeeze to 4250 psi. Set "X" lock mandrel in isolation packer at 12,750' WLM to abandon Bench 6. Pump acid into Bench 4 as follows: 89 bbls of 7 1/2% HC1, 238 bbls of 6/1-1/2% HF Mud Acid, 12 bbls of diesel, 95 bbls of Clay Acid, 20 bbls of diesel displacement. Abandon Bench 4 as follows: Set a through tubing budge plug at 12,455' CBL, dump cement on plug, tag TOC at 12,427' CBL. WJL/mcm/061 NL SPERRY--,SUN, INC. P.O. BOX 190''~''~ /~,NCHORAGE, AK 99~, 9- 0207 sun Mr. Mazzolini Marathon Oil Company P. 0. Box 2580 Anchorage, Alaska ~9510 October 8, 1985 Re: Our BOSS Gyroscopic Survey Job No. AK-BO-50108 Well: D44 Trading Bay Unit Alaska Survey Date: October 7, 1985 Operator: J. Same: Mr. Mazzolini: Please find enclosed the "Original" and two (2) copies of our Boss Gyroscopic Survey on the above well. PI ease note this survey is a tie in wi th Gyro-Data· Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC· K'en Broussard District Manager Enclosures ANCHORAGE ALASKA COMF'UTATION DATE MARATHON OIL COMPANY D- 44 ]'RAD I NLq BAY LIN I T ..' Fu':TFIBER_ _ _ . ,_q,, 1 "-":"-"=; ,:,.-, . ALASKA . . · VERTICAL '.:-;ECTION CALCI..ILATED ALL-JNG CLOSURE .. ...... , TRUE MEA.'=-:URED VER':f~CAL DEF'I'H I'}EF'TH 10700 F;I IB-::;EA COLIRL:;E L. Jl_ RoE VE:RT I CALI NCL I NAT I ON D I RECT I ON SEVERITY DATE OF SURVEY OCTOBER 7, BOF.;S RYRF~SCOPIC .:,L RVEY :./C, .J ,_lOB NLIMBER AK-BO-50. . .. 10':',_, ' . ~....';.:::: I<ELLY BLISHING ELEV. = 106.00 FT. "." :" F/F'ERATOR-,J..., '-'~:AMEF_: ]'O'FAL RECTANGULAF? COORI] INA] E.:, VERT I CAL 82 !? 4.00 DEGREES DEG/100".:': NF~RTFI/F;CH ITH , , E A :...5; ]" / W El' :E; T 41 26 N 11. 19 E 0.00 /:,08:.3. 50 N 78:::../.-,C) W S E C T I I.-~ Iq ,i 6116. 17 1 C)::::00 :::3:3/:,F:. 74 :.:!:2/_-,2.74 109 00 84- 42.77. 8:3 :':: 6.77 1 10 00.. ,_,._':' .=; 16 , () 7 41 49 42 ':":" N 11.50 E 0.42 6148.64 hi 775.52 W N 11.50 E 0.84 6 '214.51 N 76:2.12 W :'--:410. 07 , ~,_,1.14' N '. 748,4.4 W 4:7:: 3 N 11.69 E 0 42 6'-'° 1 11 O0 85:.-]:9. 06' 8483.06. , I 1. 200 8661.80 8555.80 ' -- 11 :--: 00 :-=: 7':~i 4"~ ]36:--: 6:28. :3/::, I 1400 :."-i: 806,. 78 ' :--: 7 () 0.78 I 1.500 :--::']:7'?. 20 :--:773.20 43 29 Iq 12. 0 E 6:7:: 7'7.6, 7 6444.20 6 5'~-(i';,"i3o ...... 43 4.2 iq 12.5(.") E 4:_:: :29 N 12..89 E 0.41 6550. '25 N 69:3.08 W 6,577.34 6 :.,4.:,. 74 0,.:,'-'.._,':-" 6617 , ._~.~.'.--' N 677, o...'2_ IAI / '-' 116C)('D 8950. 'P:3 117(:)(.') 9020.90 11800 5;'0:--:9, 43 8:.--.:44.9:3 44 50 N .. 8914.90 ::"'.. 46'. 20 . N :::';/':":' 43 :" 47 8' N -- , m_m ...! · 13. 10 E . 1 ...._, ,.:,:,,.,._ 40 N , 1-, 7.:,.., 05 N 50 E :,.:":::.. 1 :]-:O')'E'' ": 0 '79 '""-'/' · 6,,::, ..' :,. C) 4 N 1 19 00 ';"'7i'-57.24--'F,' 051. :24. 47 '28 N 13. :39 _; 1. '2 ('D ()(')'-'} 22 ?] .=; 2 9119 ':'-' .......... ..' 4./=, 27: N 1':' /-,9 121 oep 'F,'2'F/5. C).5 91:39. (35 4.5 30 N 14.30 12200 9:.365.6,2 9259.62 4-4 41 N 13.89 127:00 94:36.38 9330. '._:::3 45 13 N 14.19 124. 00 9507.2 CD ':';' 401.20 44 :35 N 15.19 12500 957:3. I I 9472.11 45 4 N 15./:,9 :1. 2/_-, C)C) 9/_-,4-:-q. 81 'P542.81 44 56 N 17. :E:9 12700 9719.73 9/.:, 13.7:--: 44. 4:2: N 19. 10 · . ' ' ~'-' 24 6:,... W. ::: 646.4:2 W /:,:3C), 1.6, bi - (-) .-, .:,.._, 6:397. = '= N /-, 1:3 1. 9 W ~ .. · ,..I ,_l .. m . ] .... 7 Iq .5'P./:, C)::: W 1.1. 1 6'F.//:.8 ~- , .... 7_ . . '~ "" 6':.-, 0.98 70:38:31 N ._ 7,:,. ' W · 0.86 7107.01 hi .561.4.3 W 0 ._7 7175 F,A N .._44 2:3 W . , 724:--:, ""'? 0 'P 5 c,._, N ..5'26. :7::7 W 7:--: 1 i. 80 N 507.5:--: Lq 72:79.50 N 4:37. 15 W 7446,. :--:6 N 464.7:3 W 6710.72 6779.46 6849.51 ./:,990. O'P 705 :iF.:. 8:3 7194. 7261. :38 732:::. 2:!:".': 7 :_::'? 4. :--: 2 7460.43 J ......... 2 ::: c)(] 9790. :3/-, '.:/6:34 . :--: 6 44 ._,'--'...=; N ,-'s' 1 . :7:_ o_ E 1 . .=;_ 5 7512 .31 N 44 CD . .=;_ 1 W 12 'i) ('D (') 9:::/-,2 76 ':)7~/-, 76, 4:7-.:2/-, N 2:_:: 10 E' "'' 1 69 7576 64 N 4-14 27 W ..... · .... # _ . ....,, ....., · m · 12'770 'P':.-' 17:. 71 9807.71 4:--: :3 N 24.10 ' E : ,: ' i. 07 7/_-.20.6:3 N :3'F/5.05 W __ HORIZONTAL DI:_:;F'LAIZ:EMENT = 76:30.:37 FEET AT NORTH 2 DEG. 58 MIN. WEST A'T MD -- 12970 THE CA LCULATION F'ROCEDLIRES ARE BASED ON THE USE L-JF THREE DIMENSIONAL RADILI:--; OF CLIRVATL1RE NETFIOD. , . · :,FERF, Y-.=,_N WELL S~ IRVEYING CF~MPANY , F AL E:. 2 MARA'I"HON OIL COMPANY I]-44 ANF:HORAGE ALASKA COMF'UTATION DATE BATE OF. SURVEY OCTOBER 7, 1'- '-' ~':'':::.:, ._, ...... 'gR~I]ING BAY UNIT ALAtE;I.:::A ORTOBER '-' _ . ,=,, 1':.-~85 . , dOB NLIMBER AE'BO-501c.~'°,:., KELLY BUSHING ELEV. = 106.00 FT. C ' -" I-I -' r. -I-' ~F ERAT_ I-x-d. .:,AME... INTERPOLATED VALLE.z, ---' _ FUI--, EVEN 1000 FEET ~]F MEASLIRED DEF'TH MEASURED I]EP]'H TRUE '-1 '-' ' ... o JB-.z, EA TOTAL :..... " .... '1 " k"ERT I''~ gERT IC:AL' :: :: VERTICAL .": ..:'":. REL.] ANI..',L LAF'? COORDINATE.:, ME-TVD : _.AL.:.. DEF'TH I.. EF I H N~]RTH/F;F~[.ITH EA::;T/WEST D I FFERENCE CORRECT I ON 10700 :.:.:2'~4.00 :--.:I :.--::_::. 00 /_-,08:.~:. 50 N 7:--:8./_-,0 W 2406. C~0 i 1700 'P0'..].:0, 'F.;O :F.:'.~',' 14. ':7,'0 6755.05 1'4 646.4.2 W 26,7'.;;, 10 273, 10 127~5b 9"~-i-~i~]'-=~3 ':.-~c'-,i']~:. 73 744/-_,.':_:.:6 N 464.7:.:_: W '.:";~::::('~. 27 301.18 12':.-,"70 ,-Tz,z.; 13, 71 ?807.71 7620,63 N '-'"' '= · . ..:, ..:..'.~,. 05 W :2:056.29 .7 ./:,. () 2 ..... TI-.iE C:ALE:ULATION IZ'ROC:EDURE'.~-_'.; ARE 4 '-' - F. A .:, E D 0 N T H E I_1L:; E 01z T H R E E D I I"1E N S I 01'4 A I_ R A D I I_1'.~; 0 F C I_1R V A T I_1R I.-- M I'-- T I--I 0 D. i oFERRY-.-,LN WELL SLIRVEYING f-:nMPANV F'AGE MARA'I'HEflq OIl_ COMPANY D-44 ]'RAD ]: NF'-~ BAY LIN I T ANCHORAGE ALASKA COMF'UTATION DATE OCTOBER 8, 1 '-;¢,-=,'-'=._, I]ATE OF SURVEY OCTOBER 7, ,_lOB NUMBER AK-BO-5010:E: AL. ASI.:::A KELLY BUE:HING ELEV. LFERATUR-,J. SAMEC .. = 106.00 FT. INTERPOLATED VALLIE'.E: FOR. EVEN 100 FEET OF SI...IB-SEA F. EFTHI ' MEAF.;LIRED DEF'TH TRLIE .:. _IE -.:,.,,-, TOTAL VERT I ,/:AL .. VERT I CAL. RE,..-..'TANGULAR ,"':O(]RD I NATES MI.]'T, VD VERT I F:AL DEF'TH DF_'F'TFI NC, R'I'H/SOUTH ' EAST FFERENCE '::] }::: :" :' CORF~I:-..CTI- ON :-:-: :2 9 4.0 C) ,::,"" 1:3 8 . ¢')_ C).. 6 c') '-'c, ,.:,"". 5 0 N 7 '-',:, '-',=,. 6 .... C.) W ',? 4 C) 6.0 0 ............. -'.~ 7.:,._ 02 ]. 06.00 0 ()0 1010.06 F; 21 '-} 2 0..5 W -299 0 '.7' '-" '-' :'~. _ . :3 0 6.0 0 2 0 0. (')0 :'-': 7 9. :-31. 40 6.00 :300.00 .8.'3 :'::. ]. 1 21 '?6, 14 W '292, 55 .":::: ' 0.4C) 25 C) 506,. 00 4 C)0.00 :384 606.00 500.00 516 7 C) 6,. (') 0 6 (:)0.00 ._~ ,_,,b ._ ~ :::: C) 6, .00 7 o_ c).. (') 0 650 906.00 800.00 786 1 C) 0 6.00 '? (') 0.00 743./-,2 .'_.--; 655.97 S 572.0::: S 2177,93 W - 255.5';-.' :36,. 'F,' 7 216(-).09 W -221.41 :34. 17 2:14 2. ,6 2 W - 18 9.9 4 :31.4 7 6,1 /_-,1 · Z., (_) 4'.-".,' W 87 W ,, :3'7 :'W 1058 12(:) 6.0(:) 11 C) C). (')c) I 16,:3 ]. :30 6,. C)0 ]. 200.0 410.99 F; 211 C). 00 W - 18:3.2.'..--.: :35.9'F~ :32 C). 69.:,'-' 2 c)_ 9. 1 . 75 W - 147 .24 2_ f"]_. 9. '::.,.. 272.06: :E; 2 (')'P :3. ':.-/:3 W - 142.41 4. :..:.: :3 12 6, 9 14. 0 6,. 0 (') 1200. C) C) 1405 150 6, ~ (:)0 ]. 4-0 (]) · C) 1 Fi42 1/_-,C)/_-,. (")C)150C). 0C) 224.55 :-; 20':.-;5. 7:2 W - 1 E: 6' ' ,~ .7 15.44. 41 5 5 '-' 2 (').=, 7 :::'.-' W - 6,:'::. =._ 3 6, :-':/-, 16 ~ !-."; --170,"_-,. 00 ]. 6 c)0.00 18 c) 6 I :--: (:) 6.0 c) 1700. (-)0 4 '?. '? 5 N 20 :F.: 8. ?.:' 9 W - 2_' 6.3'? :3/_-,. 86 1:2 (:). 4:3 N 1 '?':.-; 5.8:2 W 0.6, 0 2 6,. ':.-~ !;) · SPERRY-SLIN WELL SLIRVEYINL-~ COMPANY MARATHON OIL COMF'ANY D-44 ANCHORAGE ALAF;KA COMPUTATION DATE BATE OF SURVEY OCTOBER 7, F'AGE_.__ 19:35 .... =Fi~AD ING BAY LIN IT ALASKA n C T 0 B E R :--:. 1 '='... ,_,'='._ ,_lOB NL MBER AK-BO-5010:=: . KELLY BI_ISHING ELEV. = 106.00 FT. OF'ERATFIR-._I. ,=,AME .... INTERF'OLATEB VALLIES FI]IR EVEN 100 FEET I]F '=;IIB-'.:;EA DEF'TH ,'" [ MEA.=.L RED DEF'I"H ]' RI_IE :3UB- SE A ]'O TA L VER]' I CAL VERT I CAL RECTANGLILAR L':OORD I NATES', MD-TVL] i,: ", ' VERT I CAL I]EF'TIt DEPTH IqCIRTH/SOI, ITH EASI'/WEST ' [IIFFERENCE C:ORRECTI ON 1 'P 06.00 1800. 00 195.00 N 1 '::¢.=1 ::-::. :2:7 W '.'2 ............. 00/-,. 0 ("~ 19 (') F) . (') .... 0 ";',....,_,._':' "~. 31 Iq 1 '?. :-'::':_ .'-']_. 14 W '2'7.84 :27. :24 6,,5.00 :37. I' 6, 2208 :;;.":2:45 24-61 ...;; ~.- ,-.~;-=--- .,::..j ,-., 2718 .,::. ,-', .j ~, 597.36 N .,.:,92.02 N 784.99 N 187:3. :.-::6 W :1. 74 · 60 1:354.95 W 2: :L 2.38 18:36.54 W 250.16 15) . :=:7. .'..5:7. 06 78 78 312 9 2:806,. 00 · :. ~ 6 ....'=' 906,. 00 26()0.00 27 (] 0.00 2800.0 c~, 876. N .,, ':~ .=;. ::q 1 N 1075.06, N :37. 35. · "'~ IL,- ..::, ._1 . 7:3 6'7 354 :_=: :=: 106.0 ..-, · ,-./ ..:,a,/,:, :3206.0C) :,.=.: 100. 1 .1. 67.74 Iq 12/=,C). 52 1. :355:. 42 N J. 8:37.39 W :399.19 1L::17.67 W 437.01 1798.24 W 472.77 :.37. :35. :2:928 :=: 40/=.. 00 :2::300.00 4-06, 6 :3506. C)0 .'7.: 400.00 14:30.65 N 1509. 'P 1 N 16c):3.23 N 1804.6:=: W 1810.52 W 17:=:9. L=.::.-:: W .."' .: · 498.45 ~22 F; 1 . .~,/., (-.) 0.% 24. 38. 05 :2:4 1/= 96.56 N 1 7:E:9. 85) N 1769. 14 W 4.., W 174L:. ' '= 599. 1 'P 6:37. '::3 .] SPERRY-SLIN WELL ::-';URVEyIhlG COMF'ANY F'AGE MARATHON OIL COMF'ANY D-44 ANCHORAGE ALASKA COMF'UTATION DA]'E DATE OF SLIRVEY OCTOBER 7, TRADING' BAY UNIT A L A ::]; I.::: A f'IC:TF~BER E', " .... , .L ,..lOB NUMBER AK-BO-50108 KELLY BLISI4IIqG ELEV. = OF'ERATOR-,J. F:;AMEC 106.00 FT. INTERF'OLATED VALUES FOR EVEN 100 FEET OF SUB.-SIKA DEF'TI4 TRUE SUB-L--:EA. MEA.'_--;LIRED VERT I CAL VERT I CAL ;,____I.:.! E P TH DEP ]'Fi DL--: P TH TOTAl. · RECTANGLILAR L- OORD I NATES NORTH/SOLITH EAc, T/WE.:,T , MD-TVD "[) I FFERENRE . VERTICAL ' :" ::"C r) R R E C:T I 0 hi 4.4.'.;',,'5 4644 478:3 4-'.'--~ 21 5057 · '_--:806. O0 3700. O0 :3906. ()0 ::,:.:800. (-)C) 4. i':R>'~::-::b ..... 4.106.00 4000.00 4206.0 C) 4100, 0 C) 1740.04 W 17::]:1.24 W 6, 89.00 7:38. 12 51.47 LI.',-?. 11 777.7'7 . 815.59 . '. · .-i r"' ,:,-_, 1.6 8 · 2290.2:--: N 1677.2 J. W 2:28:3.21 N 16 86.7 :':: 1,4 2 :..:: F: C) , 03 N 16./:.:::. 99 1,4 ...], .,." . .::, ...I . 42. 1 77 5471 46, 06.00 4500. C)C) 56,14 4.7C)6.0C) 4.6C)C). 0(:) 5676 48 C) 6. C) C) 47 C) 0.0 0 :3':?. 42, '7:7. ':: ~ '-"-' 4'? (-) b,. (_") 0 4. ::]I 0 0 (') ._.l / '"'I'"" ~" # - - 5884 5 0 C) 6.0 C) 490 0. C) C) 6 C) 29 55 1 C) 6,. C) 0 5C) C) C). C) C) 254.4.68 hi 2648. 16, N :2750.4.5 Iq 1579.96 1556.9!5 15:2:4.27 W ':"--'":' 4C) ,_'j ._1 e.. W 87:3. '? :,--_._' W 'F'2:3.76 ._.! i_m mm C) 9 52 :34 617:3 5 ~i 6:-.-' 00 5100. C) 0 6, 27'P 5 ::]: C) 6. C) 0 '520 C). 0 C) 6:3 8 5 5 4 C) 6. C) C) 5:3 C)C). C) C) ." C,._, C) · '=': ~ . ._1 ,~.! N '29C) 7.4.8 N 296.3.87 N 151 i. 9C) 1 ~]'-"-' C)6 ._ ..' ,~,. 1543.2:2 1,4 '.'?/-,'7. C):L:: W 9 7:3 '-":' W '? 79. :36, :27 C) '? F.,___._F, :z:-? .,.,5 5 C) 6. C)C) 5 4. 0 0 . C)..... C) :--: C)/-, 7 .7 (')_ N 6, 6, 79 56, 0 ,/-,. 00 550 C). C)C) :':', 17:3.5',::', N 1518.50 W 149:3.6!5 W 1026. :36 1 C) 7:3. :36, 47.0 0 47.0C) MARATHnlq OIL CF'~I"IPANY D.-44 SF'ERRY-S!JN WELL L=;LIRVEYING C.L]MF'ANY AIqCHORAGE ALA'.--;KA COMPUTATION I]ATE DATE OF 'SURVEY OCTOBER 7, PA_¢.!E 1985 TRADING BAY UNIT ALA:E;KA JOB I',ILIMBER AI<-BO-501L,=,')'"" KELLY BU:-;HING ELEV. = F~F'ERATOR-,J. SAMEC IN]'ERF'OLATED VAL. UES FOR EVEN 100 FEET OF SI_lB-SEA DEF'TH ]':RUE :E;LIB-SEA TOTAL 106. O0 FT. MEA._-,L R ED VER'T I C:AL VERT I CAL RECTANGLILAR ~ I]EF"I'H I']EF'TH I]EPI'H NOF;tTFI/SOI, ITH ........... m .... .-i --~ ~. 68 24. 57 C)/-,. 00 Pi 1-, 00 0 (] ..:,.~- 7 :,. 44 hi 6'F,'57 5:306. O0 ?'~700. ()0 :.--.::2:6:3.72 Iq ' COORDINATES MD-TVD E A ~E; T / W E S T D I F F E R E hi E: E{ 146 ?. 1 ¢) W 1 :L 18. '?:3 1452. O:E: W 1151. ';?:5 VERT I E:AL 6:0 I::,: R E C T I 0 N 45. !57 70 86: 5'P 0 6.00 58 C} 0.00 7238 6006. O0 .5'F/00. O0 7384 /_-,106. O0 6000, O0 7.':5 :E.. 4 6. 206.00 6]-Ci"0-:'"¢i 0 77:24 6306.00 62()0.00 7'P 11 6406. O0 /.:,:--:0('~,. 00 :Z-:66, 0 24' N :]-:767 '-.' F; . ..._ Iq 3'~3:.'._:'. 70 N 40'P2. :'::7 Iq 1409.4. 8': W "' :'>i.: .. 1 ...._,.~":":":'. :2:4 13:34 43 W 1278,8'7 1:358. :-39 W 1 :_--:2:3.12 1 :.T.::2'7 · 78 W 141 :i-':. 68 1. 2'?~7.16 W 1505./.:-,6 4.'?/. 25 'iPO. 56. :E:6. '? :.:.: ' '' 4195.73 N 4. 2'::'/-., ':":' Iq , ' , · .. _ ,_l 4:377.84 N 77 46 I' 1 ] 6./:, .: :' ' :.--_:'~ , · 70 46.04 i""l ~---i '' .::.._, ..- U 6:_::06.00 6700.00 :::: 6, 'i:') 0 6 ? ,F~ 6. O, 0 6. ',E: O,F~,. ¢:, 0 ::-': 8 :--: :3 7006,. 00 6, 'F/o 0.00 8'?7/_-, 7106.00 -- 70ex). OO '::'/. 1 1 ,:,'-' 7:2--.' A_/-,_ · q_ A 710 A. 00 ':7282 7:306.00 7200.00 4542.04 N 4681.89 N 4. 780.52 N 4877.16 N 4.'F-/77.20, N 5103.0:2 iq 1201.04 W 1714 117';?. 37 W 1784 1154. '.'.,'/_-. W 1:327 1129.08 W 187(] 1103.9:--: W 1':7,12 10..:.4.8:2 W 1 '..776 .56 72.86 .88 70. :3:2 .55: 42.70 .. . .-,c, 42.70 · '77 4:2.70 · 3:.'-:: 6:3.41 '!:? 4 4 2 721- 0 6.0 0 7:2:0 0.0 0 5 2:24.3'? N 95 :--: 3 7506.00 74. A O. 00 5 :S: 2,n,. 4. 6. N 1 (]_ 27 .34 W 2: ..... 0 ::: ,/-, . ::-.-: ._,"- 1 C:, ():E:. 5"1- W '.S-:,n '77.55 /_-. 0.47 40.70 SF'ERRY-SUN WELL :--:l_ _IRVEYING COMPANY MARATHON OIL COMF'ANY D-44 ANE:HORAGE ALASKA COMF'I_ITATION DATE DATE OF SURVEY OCTOBER 7, TRADINL] BAY UNIT ALA'.:;KA OCTOBER A, 1'-'-'= ,_ .':! ,-, ._1 .. . . . ,_lOB NUMBER AK-BO-5010:=: KELLY BLISHING ELEV. = 106.0(.] FT. OPERATOR-J. ,:,AME_, INTERPOLATED VAL. LIES FOR EVEN l c)0 FEET OF SI. IB-E;EA DEF'TH MEASURED E. IEF'TH TRLIE VERT I CAL DEP]'H o_ B-.=,EA TOTAL VERTICAL REL. TAN JLILAR COORDINATES I.. EF TH NOF~TH/SOL.ITH EAE;T/WEST · MD_TVD . ..,: DIFFERENCE "' VERT I CAL.' C 0 R R E C T I 0 N 9724 98/z, 5 1 0.1. 2 7 10269 104. 1. 1 7606.00 7706. ()0 7806.00 7'.-.-; 06.00 F: 006,. 00 :iii: 106.0 (~.~-- 8206.00 :iii: :306,. 00 ....... c, 406.00 ~--~ ~ .. .: .... U6.00 10557: 1. 0704 (..) ,:, .j ..:, 10994 11134 7500.00 7,{-, C) c). 7700. ()0 78Cx). 00 79 (')("~,. 0 ~_ 8 O, 00. (') 0 8100.0 C) 820(). ()0 E:'~'F00.00 84 ~] 0.0 O, c,._, C)(.). 0 0 5416 54 N '--;79 76 W ':'118 24 40 '70 551:3.05 N 955.91 W ...7:1 E '-T;. 59 41..34 · _,._,:: ._,. :37 N 5679.'79 Iq · t-]77ci I1 N .... :,/.-,. 4-4 Iq 597:3.16 N 6,086.0 ::": N . ..-._, W :'.:.':_::05. C)5 41. ,:;.z; 84 :::. !50 Lq 234'7.04 41.98 Fi::.--.:O. :----:2 W 2 :_--: 'F; :--: . 10 .'.51. ()6 6196.11 N /. '-."3 - _,~... 1.5:_-: N 6:]-:E',6.40 N ':'1 C) 99 W I_. . . . · 7E:5.16 W 759.31 W 4'F'. 51 40.47: 40 ~ 43 J. J. 274. 1141'1 J. 154:_-: 1 168':-/ :::706.00 8806.0(} 89C)6. (}0 9Cff)6.00 8600. O0 8700.00 8800.00 89(:)(3. O0 6481.77 N 733.45 W 2568.89 6571.6,1 N 712.28 W 2605.09 6/_-,/_-,2.'F'4 N 6,'_--:'F;. 97 W 2/_-,42.C)8 6,759.6:.3 N /_-,62.80 N 2683.93 40.4.:3 :2: 6. :20 :36,. 99 41 1 J. L:::_:: 1 11 '? 7:2: '?106. C)0 9206.00 900C). 00 91C)C). 00 6,'=:.-, :, C) 2 N 6-,952.6A ..... N 60:-': F,:q' 'W " 2767. 1.~":' 41.41 41.79 1211.= 12257 '? 7:06.00 94. (') 6,. 0 9'..-:: 0 C) 9300. 7051.41 N 586.76 W 280':T;. 07 714L::. 94 N .~/-, 1_ _ .61 W ..',:,._,""'-'= 1 . C)4. 4.1.95 41.9 .:,F ERR¥-.:,_IN NELL_ :"';~ ~RVEY I NG "COHPANY F'AGE MARATHON FIIL COMF'ANY D-44 ]"RADINL] BAY UNIT' ANC:HORAGE ALASKA COMF'LITATION DATE F'IL-:I'FIBER,=,'":, 19E:F,.. _ DATE OF SLIRVE¥ OCTOBER ,..lOB, NLfMBER AI<-BO-5010'=',_, A L A ::; K A KELLY ~U.:,HINb ELEV OF'ERATOR-,J..'::.;A ME F: = 106.0°. FT. I NTERF'OLATEB VALLIE°.F.: FOR EVEN 100 FEET OF F;UB-SEA DEF'TFI MEA.=,L RED DEF' TH 'T'RLIE VER'F I CA L DEF'TH SLIB-::;EA VERT I CAL DEF'TH TOTAL RECTANGLII_AR COORDINATES .:'. MD-TVB NORTH/SOUTFI EAST/WEST' ' D I FFERENCE VERT I CAL CORREE:T I ON 12:39:5: ':..-,'5C.)/_-,. 0(] 1. '25:2:'? 96C)/..:,, 00 94(:)(:). C)0 7243. :.-]:'i?¢ N 5:::(:). 9:5 W .'.28'72. 2:3 9 ..... ?i (') (') .00 73:2:8 .8:2: N 5 .... c) c) .28 W ,...'.';":~.....':: :::... ._, ~' .-"" 41. 19 4.1.2::]: 12680 9706.00 12821 '~.~:::06. O0 12959 99C)6.00 '.::,'/_-,00. C)(:) ' 745:3.50 N · 469.2:2: W :.: 2974.6:9 .9700 00 7F,'.-.'/- o.-, : ..:'i:::4.:,.~ ..... ...z. Iq ... ........ . . L "./ 14 .;., .) 1 27 '? ::: (-) ¢) 0 0 ' !": 7 614 C) Zl. N ..:, -, o ..... ...... ....:,( .... .:, 41.16 40. ?;'-"',' :]-',8.17 1 '297C) 99 ]. :'-':, 71 'F..;'807.71 7620.63 N F:95, 05 W :-..:056.29 THE RALCI..ILATION F'ROCEDURE'.3 USE A LINEAR INTERPOLA]-ION BETWEEN ]"'ILiE-IqE~RE~ii'-7~-'i"]~i~i~.iT-ifiEi'-(FF;~i~.'~'' I.'-?AI] I LIS OF RLIRVATLIRE ) F:'O I NTS .... :'.. A Gyrodata Directional for Survey MARATHON OIL COMPANY TRADING BAY, McARTHER RIVER DOLLY VARDON, WELL #D'44 Date Run: 25-SEP-85 23: O: 0 Job Number: CAO985G090 Surveyor: D'AMICO Calculation Method: RADIUS OF CURVATURE Proposed Well Direction: N 2deg Omin Osec W Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Referenced to Well Head OONF DENllAL i~ARATHON OIL COMPANY TRADING BaY, McARTHER RIVER DOLLY VARDON, WELL #D-44 Page MEAS INCL BORE HOLE DEPTH BEARING ft deg min deg min 0.0 0 0 600.0 3 38 700.0 5 9 800.0 G 50 900.0 7 39 1000.0 7 36 1100.0 7 59 1200.0 8 47 1300.0 9 11 1400.0 10 3 1500.0 11 41 1600.0 13 48 1700.0 1G 29 1800.0 19 18 1900.0 23 0 2000.0 26 47 2100.0 30 44 2200.0 34 55 2300.0 39 5 2400.0 42 53 2500.0 42 45 2600.0 41 52 2700.0 42 36 2800.0 43 17 2900.0 43 58 N 0 0 E N 85 14 W N 84 37 W N 81 44 W N75 5W N 59 17 W N 46 8 W N 35 43 W N 25 55 W N 19 8W N 15 51 W N 12 55 W Nil 15W N 10 42 W N 9 14 W N 9 3 W N 8 34 W N 7 52 W N 7 41 W N 8 14 W N 10 3O W N 13 10 W N 13 40 W N 13 37 W N 13 36 W VERT DEPTH ft 0.0 599.6 699.3 798.8 898.0 997.1 1096.2 1195.1 1293.9 1392.5 1490.7 1588.2 1684.7 1779.9 1873.1 1963.8 2051.5 2135.5 2215.3 2290.8 2364.1 2438.1 2512.1 2585.3 2657.7 VERT SECTION ft 0.0 2.2 3.2 4.8 7.7 13.3 21.8 33.2 46.8 62.5 80.6 102.2 127.9 158.2 193.9 235.7 283.5 337.3 397.2 462.4 529.8 596.1 662.0 728.7 796.4 CLOSURE DISTANCE BEARING ft deg min 0.0 N 0 0 E 19.0 N 85 14 W 26.7 N, 85 9 W 37.1 N 84 36 W 49.6 N 83 2 W 62.5 N 79 43 W 74.8 N 75 0 W 87.2 N 69 38 W 99.8 N 64 1 W 112.9 N 58 24 W 127.7 N 52 51W 145.6 N 47 27 W 167.6 N 42 16 W 194.5 N 37 34 W 227.1 N 33 21W 266.0 N 29 38 W 311.5 N 26 29 W 363.3 N 23 48 W 421.5 N 21 33 W 485.5 N 19 43 W 552.4 N 18 27 W 619.3 N 17 44 W 686.4 N 17 19 W 754.4 N 1G 59 W 823.3 N 16 42 W HORIZONTAL COORD feet DOG-LEG SEVERITY deg/lO0' .ON .OE 0.00 1.6N 18.9W .6~ 2.3 N 26.6 W 1.5 ~ 3.5 N 36.9 W 1.70 6.0 N 49.3 W 1.18 ll.2N 61.5W 19.3N 72.2W 30.3N 81.7W 43.7N 89.7W 59.1N 96.1W 77.1 N 101.8 W 98.5 N 107.3 W 124.0 N 112.7 W 154.2 N 118.6 W 189.7 N 124.8 W 231.2 N 131.5 W 278.8 N 138.9 W 332.4 N 146.6 W 392.0 N 154.8 W 457.0 N 163.8 W 524.0 N 174.9 W 589.9 N 188.7 W 655.3 N 204.3 W 721.5 N 220.4 W 788.6 N 236.6 W 2.09 1.82 1.71 1.58 1.43 1.74 2.22 2.71 2.83 ' 3.73 3.79 3.96 , 4.20 4.15 3.82 2.01 .81 .68 .69 ~{ARATHON OIL COMPANY TRADING BAY, McARTHER RIVER DOLLY VARDON, WELL #D-44 CONFIDENTIAL Page 2 MEAS INCL BORE HOLE DEPTH BEARING ft deg min deg min 3000,0 44 42 3100.0 45 19 3200.0 45 55 3300.0 46 37 3400.0 48 7 3500.0 48 50 3600.0 48 50 3700.0 48 30 3800.0 48 37 3900.0' 47 50 4000.0 48 12 4100.0 47 8 4200.0 46 41 4300.0 46 56 4400.0 46 16 4500.0 46 55 4600.0 46 8 4700.0 45 52 4800.0 46 39 4900.0 45 17 5000.0 46 11 5100.0 43 48 5200.0 43 17 5300.0 43 5 5400,0 42 48 N 13 28 W N 13 23 W N 13 25W N 13 41 W N 1330W N 13 29 W N 13 56 W N 13 57 W N 14 18 W N 14 37 W N 14 38W N 14 54 W N 15 N 14 44 W N 14 21 W N 14 17 W N 14 3 W N 14 16 W N 1340W N 14 0 W N 14 4W N 13 N 12 35 W N 12 17 W N 1232W VERT DEPTH it 2729.2 2799,9 2869.9 2939.0 3006.8 3073.1 3138.9 3204.9 3271.1 3337.7 3404.6 3472.0 3540.3 3608.7 3677.4 3746.2 3814.9 3884.4 3953.6 4023.1 4092.9 4163.6 4236.1 4309.0 4382.2 VERT SECTION £t 864.8 934.2 1004.2 1075.0 1147.1 1220.5 1294.2 1367.7 1440.9 1513.8 1586.3 1658.4 1729.6 1800.6 1871.6 1942.S 2013.5 2083.8 2154.5 2224.8 2294.9 2364.2 2431.8 2499.1 2566.2 CLOSURE DISTANCE BEARING ft deg min 893.1 N 16 27 W 963.7 N 16 14 W 1035.1 N 16 2 W 1107.3 N 15 52 W 1180.8 N 15 44 W 1255,6 N 15 36 W 1330.9 N 15 29 W ' 1406.0 N 15 24 W 1480.9 N 15 20 W 1555.5 N 15 18 W 1629.8 N 15 16 W 1703.7 N 15 15 W 1776.8 N 15 14 W 1849.7 N 15 13 W 1922.3 N 15 12 W 1994.9 N 15 10 W 2067.5 N 15 8 W 2139.4 N 15 6 W 2211.7 N 15 3 W 2283.5 N 15 1W 2355.1 N 14 59 W 2425,8 N 14 57 W 2494.7 N 14 53 W 2563.1 N 14 49 W 2631.1 N 14 46 W HORIZONTAL CO'ORD feet 856.5 N 252.9 925.3 N 269.4 994.9 N 285.9 1065.1N 302.8 1136.6 N 320.1 1209.4 N 337.6 1282.6 N 355.4 1355.4 N 373.5 1428.1 N 391,8 1500.4 N 410.4 1572.3 N 429.2 1643.8 N 448.0 1714.3 N 466,8 1784.8 N 485.6 1855.1N 50318 1925.5 N 521.8 1995.9 N 539.5 2065.6 N 557,1 2135.7 N 574.6 2205.5 N 591.7 2275.0 N 609.1 2343.8 N 625.7 2410.9 N 640.9 2477.8 N 655.7 2544.3 N 670.3 DOG-LEG SEVERITY' deg/lO0' ,74 II, .?~ .50 .72 .33 .34 .29 .82 .37 1.08 .47 .3i .72 ,66 .80 ,32 .90 1.39 ., .t 2.5O .60 .29 .33 MARATHON OIL COMPANY TRADING BAY, McARTHER RIVER DOLLY VARDON, WELL #D-44 Page 3 MEAS INCL BORE HOLE DEPTH BEARING £t deg min de9 min 5500.0 42 58 5600.0 42 44 5700.0 41 42 5800.0 40 3 5900.0 39 41 6000.0 40 59 6100.0 40 1 6200.0 41 32 6300.0 41 17 6400.0 42 2 6500.0 42 11 6600.0 42 30 6700.0 42 27 6800.0 42 25 6900.0 42 55 7000.0 42 52 7100.0 43 !0 7200.0 43 28 7300.0 42 51 7400.0 41 54 7500.0 42 34 7600.0 42 2 7700.0 43 19 7800.0 42 43 7900.0 42 35 N 12 19 W N 1232W N 11 21 W N 10 17W N 10 41 W N 10 11 W N 10 47 W N 10 29 W N 10 38 W N 10 28W N 10 10 W N 10 6W N 10 11W N 944W N 9 15 W N 9 17 W 9 11 W N 8 52 W N 7 59 W N 722W N 7 6 W N 6 11 W N 5 38W N 4 39 W N 259W VERT DEPTH ft 4455.4 4528.8 4602.8 4678.4 4755.2 4831.4 4907.5 4983.2 5058.2 5132.9 5207.1 5281.0 5354.7 5428.6 5502.1 5575.4 5648.5 5721.2 5794.2 5868.0 5942.1 6016.0 6089.6 6162.7 6236.2 VERT SECTION £t 2633.1 2700.0 2766.2 2830.8 2894.2 2958.2 3022.5 3087.0 3152.4 3218.2 3284.5 3351.2 3418.0 3484.9 3552.1 3619.6 3687.3 3755.3 3823.3 3890.4 3957.3 4024.4 4092.0 4160.1 4227.9 CLOSURE DISTANCE BEARING ft deg min 2699.1 N 14 42 W 2767.1 N 14 39 W 2834.2 N 14 35 W 2899.5 N 14 30 W 2963.4 N 14 25 W 3028.0 N 14 19 W 3092.8 N 14 15 W 3158.0 N 14 10 W 3224.0 N 14 6 W 3290.3 N 14 1W 3357.2 N 13 57 W 3424.5 N 13 52 W 3491.9 N 13 48 W 3559.2 N 13 44 W 3626.8 N 13 39 W 3694.6 N 13 34 W 3762.7 N 13 29 W 3831.1 N 13 25 W 3899.2 N 13 19 W 3966.3 N 13 14 W 4033.2 N 13 8 W 4100.0 N 13 1W 4167.3 N 12 54 W 4234.9 N 12 47 W 4301.8 N 12 39 W HORIZONTAL CO0 RD feet 2610.8 N 684.9 W 2677.2 N 699.6 W 2742.9 N 713.5 W 2807.2 N 725.8 W 2870.2 N 737.4 W 2933.9 N 749.2 2997.7 N 761.0 3061.9 N 773.0 3126.9 N 785.1 3192.3 N 797,3 3258.2 N 809.3 W 3324.6 N 821.2 3391.0 N 833.1 3457.5 N 844.7 3524.3 N 855.9 3591.5 N 866.9 3658.8 N 877.8 3726.6 N 888.6 3794.3 N 89B.6 3861.1 N 907.6 3927.7 N 916.1 3994.6 N 923.9 4062.0 N 930.9 4130.0 N 937.0 4197.6 N 941.5 DOG-LEG SEVERITY de9/1OO' .22 1.80 .45 1.34 1.05 1,54 .27 .75 .25 .32 .07 .30 .59 .05 .30 .38 .86 1.05 .6 .81 1.34 .90 1.13 ?IARATHON OIL COMPANY TRADING BAY, NcARTHER RIVER DOLLY VARDON, WELL #D-44 CONFIDENTIAL Page 4 MEAS INCL BORE HOLE DEPTH BEARING it deg min de9 min 8000.0 43 2 8100,0 43 15 8200.0 42 15 8300.0 42 40 8400,0 42 43 8500.0 43 46 8600.0 43 54 8700.0 42 35 8800.0 42 39 8900.0 43 17 9000.0 42 44 9100,0 41 42 9200.0 41 53 9300.0 41 40 9400.0 41 15 95O0.0 4O 52 9600.0 40 2 9700.0 40 21 9800.0 39 46 9900.0 42 24 10000.0 44 10 10100.0 45 6 10200.0 45 17 10300.0 44 51 10400.0 45 10 N 2 40W N 1 50W N 1 21 W N 1 lOW N 0 52 W N 0 18 E N 047E N 1 45E N 2 6 E N 242E N 3 19E N 4 19 E N 4 37E N 4 45 E N 456E N 5 29 E N 5 50 E N 7 7 E N 731 E N 835E N 8 48E N 9 28 E N 9 37E N 940E N 10 22 E VERT DEPTH it 6309.6 6382,5 6456,0 6529.7 6603.2 6676.1 6748.2 6821.1 6894.6 6967.8 7040.9 7115.0 7189,6 7264.1 7339,1 7414.5 7490.6 7567.0 7643.5 7718.9 7791.7 7862.8 7933.3 8003.9 8074.6 VERT SECTION 4295.8 4364,2 4432.1 4499.6 4567.4 4635.9 4705.0 4773.4 4841.0 4909.0 4976,9 5043.7 5110.0 5176.1 5.241.9 5307.0 5371.3 5435.2 5498.7 5563.4 5630.7 5699.7 5769.2 5838.5 5907.7 CLOSURE DISTANCE BEARING £t de9 min 4368.8 N 12 29 W 4436,1 N 12 20 W 4502.8 N 12 10 W 4569.2 N 12 1W 4635.7 N 11 51W 4702.9 N 11 41W 4770.6 N 11 30 W 4837.4 N 11 20 W 4903.3 N 11 9 W 4969.6 N 10 58 W 5035.9 N 10 47 W 5100.9 N 10 35 W 5165.3 N 10 24 W 5229.6 N 10 12 W 5293.6 N 10 1W 5357.0 N 9 50 W 5419.6 N 9 39 W 5481.6 N 9 28 W 5543.2 N 9 16 W 5606.0 N 9 4 W 5671.3 N 8 52 W 5738.2 N 8 39 W 5805.6 N 8 25 W 5873.0 N 8 13 W 5940.2 N 8 0 W HORIZONTAL COORD feet 4265.4 N 944.8 4333.8 N 947.5 4401.6 N 949.4 4469.1 N 950,9 4536.9 N 952,1 4605.4 N 952.4 W 4674.7 N 951.7 W 4743.2 N 950.2 W 4810.8 N 948.0 W 4878.9 N 945.1 W 4947.1N 941.5 5014.1 N 937.0 5080.5 N 931.9 5146.9 N 926,4 5212.9 N 920,8 5278.3 N 914,9 5342.9 N 908.5 5407.0 N 901.2 5470.8 N 893.0 5535.9 N 883.8 5603.7 N 873.4 5673.0 N 862.3 5743.0 N 850.5 5812.8 N 838.7 5882.4 N 826.4 DOG-LEG SEVERITY deg/lO0' ; , .50 .43 .21 1.31 .37 1.48 .25 .75 .70 1.23 .26 .23 .43 .53 .87 .89 .64 2.72 '~, 1.; 1.04 .21 .43 .59 MARATHON OIL COMPANY TRADING BAY, McARTHER RIVER DOLLY VARDON, WELL #D-44 CONFIDEN'I'II L Page 5 MEAS INCL BORE HOLE VERT VERT DEPTH BEARING DEPTH SECTION ft deg min deg min ft ft 10500.0 43 42 N 10 28 E 8146.0 , 5976.1 10600.0 42 17 N 10 42 E 8219.2 6042.6 10700.0 40 53 N 11 9 E 8294.0 6107.3 10800.0 42 11 N 11 40 E 8368.8 6171.8 10900.0 42 45 N 11 45 E 8442.6 6237.4 11000.0 42 59 N 11 58 E 8515.9 6303.4 11100.0 43 5 N 11 49 E 8589.0 6369.6 11180.0 43 15 N 11 49 E 8647.4 6422.7 CLOSURE DISTANCE BEARING ft de9 min 6006.7 N 7 47 W 6071.4 N 7 35 W 6134.4 N 7 23 W 6197.2 N 7 11W 6261.1 N 6 59 W 6325.5 N 6 47 W 6390.1 N. 6 36 W ' 6442.1 N 6 26 W Final Station Closure: 6442.1 feet North 6 de9 26 min 24 sec West HORIZONTAL COORD feet 5951.3 N 813.7 6018.3 N 801.2 6083.5 N 788.6 6148.5 N 775.5 6214.5 N 761.8 6281.1 N 747.8 6347.9 N 733.8 6401.4 N 722.5 DOG-LEG SEVERITY deg/lO0' 1146 1.3q .53 .31 .15 .22 Suggested form t° be inserted in each "Active" well folder to cheek for timely compliance with our regulations. · · . · . ......... keqUJ.~:ed " Date Reee:f-~,ed ~marks .... Completion Report .._ - ~ud Log ..... . , ~'--Pt ? .,. - ~!~ t , . ~ ~ ~ ~ -. Reg~a~e~ed guava7 Inclination Survey Drill Stem Test Reports / L.FJ.06 Unocal Oil & Gas Division Unocal Corporation PO. Box 190247 Anchorage, Alaska 99519-0z47 Telephone (907) 276-7600 UNOCAL ) Environmental Group Alaska District December 26, 1985 Mr. Chat Chatterton AK. Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: MONTHLY REPORTS Attached for your files are two copies each of the monthly report of drilling and workover operations for D-3ORD, D-4RD and D-44. Very truly yours, Ro~O. Roberts ENVIRONMENTAL SPECIALIST tj Attachments RECEIVED 'oEc 2 7 '191~ Alaska 0il & Gas Cons. C0mrnissWn Anchorage · ' _ STATE OF ALASKA _ ALASKAt .AND GAS CONSERVATION CC ~IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ,1. Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. Union Oil Company of' California* 85-122 3. Address 8. APl Number P.O. Box 6247, Anchorage, AK 99502 50- 733-20195-01 4. Location of Well at surface ~ A-2, Conductor #8, Dolly garden Platform 748' FSL, 1130' FWqL, Sec. 6, T8N, R13W, SM Marathon Oil Cc~pany - Suboperator 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 106' KB Above MSL ADL-17579 9. Unit or Lease Name Trading Bay Unit 10. Well No. D-44 11. Field and Pool McArthur River For the Month of November ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Hemlock Bench 4 was acidized with 18,000 gallons HCl, mud and clay acid. 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run 1 6. DST data, perforating data, shows of H2S, miscellaneous data .,, Heralock Bench ~4 p~rfs from 12,482'-12,562' DIL abandoned wi~h a br±dge plug at 12,460' DIT. and 33' of Class "G" cermnt on top of the plug. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED. Ro~D~ Rbberts TITLE Environmental Specialist DATE 12/26/85 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 Unocal Oil & Gas Divis~ :' Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska District DOCUMENT TRANSMITTAL December 16, 1985 HAND DELIVERED TO: Bill Van Alen FROM: R.C. Warthen R. B. Stickney LOCATION: Anchorage LOCATION: Alaska District Alaska Oil & Gas Conservation Commission Transmitting: Logs and data are included herewith for the following well: Marathon, TBU D-44, McArthur River Field, Cook Inlet, AK, Section 31, TgN, R13W, APl# 507332019501 DIFL-SP-GR DIFL-SP-GR (TVD) Aooustilog-SP-GR Dens/Neut-GR-Cal-Tens Densilog-Corr Gyroscopic Surveys: Sperry-Sun 0 to 775' Sperry-Sun 10700 to 12970' Gyrodata 0 to 11180' Digital Tape w/curve specs. 6546 to 12930' 3292 to 11247' 2" & 5" 3292 to 11247' 2" 3292 to 11247' 5" 3292 to 11249' 5" 3292 to 11249' 5" PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY' DATED: Unocal Oil & Gas Divisi( Unocal Corporation RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Environmental Group Alaska District November 18, 1985 Mr. Chat Chatterton AK. Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: MONTHLY REPORTS Attached for your files are two copies each of the monthly report of drilling and workover operations for WD #1, D-4RD and D-44. Very truly yours, Lawrence O. Cutting Environmental Specialist Attachments '-- .... STATE OF ALASKA " ALASKAC _ AND GAS CONSERVATION CCI ]ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well E~ Workover operation [] 2. Name of operator 7. Permit No. Union Oil Company of California 85-122 3. Address 8. APl Number P.O. Box 6247, Anchorage, AK 99502 50- 733-20195-01 4. Location of Well at surface Leg A-2, Conductor #8, Dolly Varden Platform 748' FSL, 1130' FWL, Sec. 6, T8N, R13W, SM * Marathon Oil Company - Suboperator 5. Elevationli~)ge~t (indicateKB Abov&KB DF.MSLetc.) I 6. Lease DesignationlRDL_17579and Serial No. October For the Month of ,19__ 9. Unit or Lease Name Trading Bay Unit 10. Well No. D-44 11. Field and Pool McArthur River 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks The well was drilled to a total depth of 13,070' A total of 11,900' of 3-1/2" 9.2#, N-80 butt tubing was run with a continuous sidestring chemical injection line. 13. Casing or liner run and quantities of cement, results of pressure tests A total of 51 joints of 7" 29# N-80 butt casing was run and set from 10,919'-13,070' The liner was cemented in place with 505 sacks Class "G". Liner lap was squeezed twice with 100 sks and 125 sks Class "G". A good dry test was obtained after the second squeeze. 14. Coring resume and brief description 15. Logs run and depth where run These open hole logs were run from 12,930'-11,196'; DIL-Sonic-GR-SP and FDC-CNL-GR-CAL. The LSS was run from 12,930'-11,800'. The Gyro survey was run from 12,970-10,800' and CBL-VDL-GR-CCL from 12,974' to 10,919' All depths are WLM. 1 6. DST data, perforating data, shows of H2S, miscellaneous data Hemlock Bench #6 was perforated with 2-5/8" slimkone guns @ 4 SPF, 0° phasing from 12,810'-12,830' DIL. Hemlock Bench #4 was perforated with 2-5/8" slimkone guns @ 4 SPF, 0° phasing from 12,522'-12,554' DIL. 17.1 hereb¥ce~~_e~correct, to the best of my knowledge. ¢~/~_- SIGNED. ,Lawrence O. Cutting TITLE ENVIRONMENTAL SPECIALIST DATE 11/10/85 NOTE--Repor~ on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 Submit in duplicate Rev. 7-1-80 Unocal Oil & Gas Divisi¢ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Environmental Group Alaska District October 8, 1985 Mr. Chat Chatterton AK. Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Monthly Report - D-44 Attached for your files are two copies of the monthly report of drilling and workover operations for Well D-44, Trading Bay Unit. Very truly yours, Environmental Department tj Attachments ..... STATE OF ALASKA ALASKA L. ~ AND GAS CONSERVATION CO MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I1. Drilling well I-X Workover operation [] 2. Name of operator 7. Permit No. Union Oil Company of California 85-122 3. Address 8. APl Number P.O. Box 6247, Anchorage, AK 99502 50- 733-20195-01 4. Location of Well at surface Leg A-2, Conductor #8, Dolly Varden Platform 748' FSL, 1130' FWL, Sec. 6, T8N, R13W, SM * Marathon Oil Company - Suboperator 5. Elevationli6gect (indicate KB DF. etc.) I 6. Lease Oesiqnation and Serial No. KB AbovA MSL ADL-17579 I 9. Unit or Lease Name TradSng Bay Unit 10. Well No. D-44 11. Field and Pool McArthur River For the Month of. September 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at the end of month was 12,622' MD, 4742' of hole was drilled during September. At 8073' a washout occurred which caused an 8" drill collar to part at the pin. The portion of the bottom hole assembly left in the hole was recovered with an overshot assembly. 13. Casing or liner run and quantities of cement, results of pressure tests 11,218' of 9-5/8", 47# N-80 & P-110 casing was run and cemented with 2300 sacks of Class "G" cement with additives. 5' of new hole was drilled and the 9-5/8" casing shoe was tested to 11.7 ppg EMW with no leakoff. 14. Coring resume and brief description 15. Logs run and depth where run All logs were run from TD of 11,253' MD to 16" casing shoe at 3305' MD. Run #1 SP-GR-CAL-DIL-Sonic #2 LSS · #3 GR-CAL-FDC-CNL il 6. DST data, perforating data, shows of H2S, miscellaneous data Lawrence 0. Cutting ENVIRONMENTAL SPECIALIST SIGNED· TITLE DATE 10/08/85 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 Union Oil and Gas Division' Western Region Union Oil Company o, ,.;alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union September 19, 1985 Mr. Chat Chatterton Ak Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: .Trading Bay Unit - D-44 Attached for your file are two copies of the monthly report of drilling and workover operations for Well D-44. Very truly yours, Candace Lockwoo¢ Environmental Department cwl Attachments -- STATE OF ALASKA ALASKA _ AND GAS CONSERVATION CC MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well E~ Workover operation [] 2. Name of operator 7. Permit No. Union Oil Company of California 85-122 3. Address 8. APl Number P.O. Box 6247, Anchorage, AK 99502 50-' 733-20195-01 4. Location of Well at surface Leg A-2, Conductor #8, Dolly Varden Platform 748' FSL, 1130' FWL, Sec. 6, T8N, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 106' KB avove HSL ADL-17594 9. Unit or Lease Name Trading Bay Unit 10. Well No. D-44 11. Field and Pool McArthur River For the Month of, August , 19 85 -- 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks -' Recovered conductor #8. Cut and Pulled 9-5/8" csg from surf to 705'. Cut and pulled 13-3/8" csg from surf to 660'. Set a cmt plug w/250 sxs C1 G cmt 660'-498'. Direc- tionally drld 12-1/4" hole 498'-3335'. OH to 17-1/2" and then 22". Ran 16" csg to 3305'. Cmt csg to surface w/4200 sxs cmt. NU test BOPE. Test csg to 2500#. Drld shoe and 5' form to 3340'. Test shoe to 14.0 ppg EMW. Directionally drld 12-1/4" hole to 7521'. Presently drlg. 13. Casing or liner run and quantities of cement, results of pressure tests Surface csg: 16" 102#, X-56, butt csg from surf to 3305' Cmt w/3700 sx C1 G + 8% gel + .75% D-31 + .25% R-5 + .1% D-6 @ 13.3 ppg followed by 500 sxs C1 G + 1% CaCi^ +.75% D-31 + .1% R-5 @ 15.9 ppg. Circ cmt to surf. Bump plug. CIP @20753 hrs, 8-21-85. Did top job w/350 sxs C1 G + 2% CaC12 to 188'. 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE 16. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. .. SIGNED Lawrence O. Cutting TITLE Environmental .qp~cialigt. DATE f}q/17/g5 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· Form 10-404 Submit in duplicate Rev. 7-1-80 MEMORANDUM TO: THRU: State of Alaska ALASKA OIL DJ~D GAS CONSERVATION COt~R"IISSION C. V, ~t~rton Chai~a~ Lonnie C. Smith ,¢..~;: Commissioner ...... ~ FROM: Bobby D. Foster SUBJECT: Petroleum inspector DATE: FILE NO: August 26, 1985 D. BDF. 71 TELEPHONE NO: BOPE Test Marathon Oil Well No. D-44 McArthur River Field Permit No. 85-122 Thursd~ay, August 22, 1985: I traveled to the Dolly Varden Plati'orm ~-i-hiS da~'~'-~ W{~n~ ~-he upcoming BOPE test. Friday_., August .23,_ 1985: The BOPE test began at !:00 P1,'r, and v~as concluded at 4:00 PM. As the attached BOPE test report shows, there was one failure which was corrected before I departed the platform. Chat Chatterton approved the test pressure of 2500 psi instead of the 3000 psi called for in the permit. in summary, I witnessed the BOPE test on Marathon's D-44. Attachment 02-001A(Rev. 10/79) O&G #4 5184 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Ins p ec t~~_ ~f~. ~~.~/ Operator ~~~~~ LoCation: Sec ~ T~__~_~R .~M ~ g~ Drilling Contractor~~~ Rig # Location, General ~p/~ Well Sign General Housekeeping ~ Rig f2)~'. Mud Systems Visual Audio Trip Tank' Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures Date Representative Permit # ~.~- 1.~ Representative~;~ AcC~ATOR SYST~ Full Charge Pressure ~~ psig Pressure After Closure /~ ~ psig Pump incr. clos. preS. 200 psig - mind, sec. Full Charge Pressure Attained: / min~Osec. N~ e~ ~ =~ psig Controls: Master Remote~~ Blinds switch cover~~, Kelly and Floor Safety Valves Upper Kelly Lower Kelly Ball Type Inside BOP / Test Pressure / Test Pressure / Test Pressure I Test Pressure Choke Manifold ~~ Test Pressure No. Valves / ~ No. flanges .~ ~ Adjustable Chokes / ~ Hydrauically operated choke Test Time ~ hrs. Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor ...... STATE Or: ALASKA ALASKA£ _ AND GAS CONSERVATION CO .41SSION ~ MONTHLY REPORT OF DRILLING AND WORKOVER Oi ;[RATIONS-- · Drilling well E~ Workover operation [] 2. Name of operator 7, Permit No. Union Oil Company of California 85-122 3. Address 8. APl Number P 0 Box 6247, Anchorage, AK 99502 50- 733-20195-01 9. Unit or Lease Name 4. Location of Well at surface Leg A-2, Conductor #8, Dolly Varden Platform 748' FSL, 1130' FWL, Sec. 6, T8N, R13W, SM 106' KB above MSL 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. I ADL 17594 For the Month of. July , 19 85 Trading Bay Unit 10. Well No. D-44 11. Field and Pool McArthur River 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks : When pulling tubing to abandon D-21 wellbore the string parted at 3067'. A freepoint log showed no movement in tubing string below 11,683'. Cut tubing at 11,716', engaged fish and recovered 3763' of tubing. The top of the fish was located at 15,493' and the final 11 joints of tubing were recovered using an overshot. 13. Casing or liner run and quantities of cement, results of pressure tests Abandonment of D-21 wellbore: Plug #1 was set across Hemlock perforations from 16,751'-16,584' and consisted of 80 sks of Class "G" mixed to 16.2 ppg. Plug #2 was set from 15,840'-15,600' and consisted of 30 sacks of Class "G". Plug #3 was set across stage collar in 9-5/8" casing from 6587'-6437' and consisted of 55 sacks Class "G' mixed to 15.9 ppg. 14. Coring resume and brief description 15. Logs run and depth where run 1 6. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereb~ tha_tthe true certify foregoing is and correct to the best of my knowledge. SIGNED Lawrence 0. Cutting TITLE Envirnnm~nt. al .qp~nialiStDATE 08-13-85 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 M EMORAN OUM State of Alaska ALASKA~-.OIL AND GAS COI:~SERVATION CO1,R{ISSION --~ -,/~ ~ TO: C. ~.~ ~~¢=~o~ DATE: Au~usE ~5 Z985 Chai~'~ ' THRU- Lonnie C. Smith '-/:::(:' D.H~I. 55 FILE NO: Co~issioner TELEPHONE NO: FROM: Harold R. Hawkins /.:..-,'. :/' Petroleum Inspector :/:~// SUBJECT: Diverter Test Marathon, TBU D-44 Dolly Varden Platform McArthur River Field Saturday, August !0, 1985: I left Anchorage at 6:30 A2~ by AAI to Kenai, arriving at 7:00-~. I drove to North Kenai, Nikiski Heliport and arrived on the Doily Platform at 9:15 AM. I inspected the diverter, the lines, and all the valves and also function tested same. I also picked-up a schematic of the diverter system. In summary, the function test of the diverter system was satisfac- torily performed. Attachment 02-001A!Rev. !0/79~ . . . . . . . . . " ' ................ T.'.-7 - - :- ...... ~Z ............................. ) ...... ' ........................... _ .. .. ...~'~ .. . . :. .. · . .~ -: . . .. :. . ~ . . . -_: ~-.~ , ~. "~' ... - , ... . . . . ... -. . ~. ~'~ - }... . .: i.'-_ . - ,. - .......... ~'~-'--; -- --~ ................................. -r. ...................................... ~ -- 4: ' ......... '"-~ -'"' · I~ 5~O~_ ~E~~ ~ : . , . ....' ' '"'-'"'" '.__~ ....... L. . ...... ¥_.~.~.:..~_ ~ _ ._ . - .......................... ~.,..-~)-. - ................. , . . . . ',.-'. '"'.-' , .... :~ .......... ~ . . . - .......................................... ~ ............ . . . · ·.. '- ,, ' ~ . . --.' · ~. '.'. . . . ~{ Anchora '}istrict Productk,,, Cnited States Marathon Oil Company P.O. Box 102380 Anchorage, Alaska 99510 Telephone 907/561-5311 June 24, 1985 Alaska Oil & Gas Conservation Commission Mr. Mike Minder 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Minder: Per our conversation of June 14, 1985, I am submitting the following statements for your records. "The 8" full opening gate valve to the diverter system is hydraulically connected to the annular preventor and opens automatically when the annular preventor is closed." "All tees and elbows on the diverter system will be targeted before rig startup." "The 8" gate valves on the east/west diverter lines will be tied open before rig startup. A mechanical connection between the two valves will be installed at a later date to insure one line is open at all times. The Drilling Engineer on the rig will notify your office of the completion of these projects in time to allow your inspection before rig startup. Sincerely, W. J. LAVERDURE Operations Technician WJL: cas xc: G. A. Newberry RECEIVED Anchorage June 18, 1985 Lawrence O. Cutting Environmental Technician Union Oil Company of California P. O. Box 6247 ~mchorage, Alaska 99502-0247 Re: Trading Bay Unit D-44 Union Oil Company of California Permit No. 85-122 Sur. Loc. 748'FSL, 1130"~, Sec. 6, T8N, R13W, SM. Btmho!e Loc. 3156'FSL, 19'FEL, Sec. 31, T9N, R13W, SM. Dear Mr. Cutting: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25. 050(b) (5). If avai!able, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their ~drainage systems have been classified as important for the spa~Jx.aing or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation] ~Jr. Lawrence O. o~tting Trading Bay Unit D-44 June 18, ]985 To aid us in-scheduling field work, please notify this office 24 hours prior to co~encing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. I~ere a diverter system is required, please also notify this office 24 hours prior to commenci.~g equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please g.iva this office adequate advance notification so that we may have a witness present. Very t_~al¥ yours, I A/.-?A/ C. V. Chattert6n Chairman of Alaska Oil and Gas Conservation Commission be Enclosure cc: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o enc!. Mr n~ H Lamoreaux ALASKA OIL AND GAS CONSERVATION COMMISSION ~ 3001 PORCUPINE DRIVE / ANCHORAGE, ALASKA 99501-3192 _. ~' TELEPHONE (907) 279-1433 June 12, 1985 A D M I N'I S T R A T I V E A P P R O V A L NO. 80.50 Re.. The application of Union Oil Company of California, operator of the Trading Bay Unit, to drill, complete, and produce the Trading Bay Unit No. D-44 well as part of the pressure maintenance project approved by Conservation Order No. 80. Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502-0247 Dear Mr. Anderson: -- The application was received on June 11, 1985 and stated that the drilling, completion, and production of the Trading Bay Unit No. D-44 well will provide for additional oil recovery. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion, and production of the referenced well pursuant to Rule 5 of Conservation Order No. 80. Yours very truly, Harry W. Commissioner BY ORDER OF THE COMMISSION be:3.AA80 Union Oil and Gas r 'sion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager 'June 10, 1985 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 9?504 TRADING BAY UNTT ,S.t.a,t,e_ .o,f, McArthur River Field Application to Drill and Complete TBUS D-44 Gentlemen: Union Oil Company of California, as operator of the Trading Bay Unit, hereby requests approval to drill, complete and produce Trading Bay Unit State D-44 in the Hemlock 0il Pool pursuant to Rule 5, Conservation Order No. 80. The proposed completion of thls well will result in additional recovery of Hemlock Production. Your approval of this request will be appreciated. sk cc: C. Case R. Warthen Very truly yours, Robert T. ~nde~son ,JUN ¢,,,,,,,~ ~ ...... ¢, cons. Commission STATE OF ALASKA ALASKA .L AND GAS CONSERVATION C( MISSION S JNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL~] OTHER [] 2. Name of Operator Union Oil Coz-~any of Ca] ifornia * 3. Address P. O. Box 6247, Anchoraqe, AK 99502 4. Location of Well Surface: Leg A-2, Conductor #8, Dolly Varden Platform 748' FSL, 1130' FWL, Sec. 6, T8N, R13W, SM 7. Permit No. 69-74 8. APl Number 50- 133-20195 9. Unit or Lease Name Trading Ray I'In-i't-_ 10. Well Number D-21 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ~B_ = 106 ' _AMST. APT. 17579 McArthur River Field 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). D-21 ABANDONMENT PROCEDLSRE 1. Kill D-21. 2. Install BPV. ND X-mas tree. NU and test BOPE. Pull BPV. 3. POH w/& ID 4 1/2" and 3 1/2" tbg & compl'n equipment. 4. Abandon the Hemlock perforations w/a balanced c~t plug from 15,800' to top of fill @ +16,764' (+175 sx cmt). 5. Set a br-idge plug--in the 9 5/8" csg @ +_800'. 6. Cut and'pull the 9 5/8'.' csg to +700'. 7. Cut and Dull (cz~ washover) the 13' 3/8" csg to +700'. 8. Spot a c~n~_nt ~!ug across the casing stubs, fr~m 600' to top of bridge plug @800' (+180 sx). *MARATHON OIL COMPANY - Sub Operator RECEIVED Alaska 0il & Gas Corm. Commission Anchorage 14. i hereb~t ~ore~correct t° the best °f mY k n owl ed g e. _,(~/-"~ Signed Lawrence 0. Cut+ii~g Title Envi ronmen+a I The space below for Commission use Specialist Date 06-06-85 Conditions of Approval, if any: Form 10-403 ~-' Rev. 7-1-80 COMMISSIONER By Order of the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate WELL D-21 C 4,706, 5,949, 7,002, 7,891, 8,585, 9,208, 9,598, 9,951, 0,261, 4-1/2". SL, ;:-$0. 12.u~ tu:ing 9-5/9", 47~. :i-~0, P-I;O, AR-'?5 c_-sing 05. 4-1/2" C2F mandrel w/ Guiberson ;4-77 GL¥ GLV as above GLV as above GLV as above GLV as above GLV as above GLV as above GLV as above GLV as above GLV as above 4-1/2" x 3-1/2" XO ~ !1,689 5-3/8" OD x 3-1/2 Slip joint ~ 11,690 ~-1/2", SL, N-80, 9.31 tubing Top of liner @ 11,801 .9-5/8 shoe.~ 11,982 7", 29~, RG-5, X-line liner 5-1/2" USI Circula,ing sleeve @ 15,815, 2.75" ID g landing nipple @ 15,84%2.625" ID 2-7/8" Type P Landing Coupling ~ith 8' seals Guiberson AGT Packer @ 15,845 End of tubing ~ 15,855 · i Bench I perfs: I Bench 2 perfs; "~ Bench 3 perfs: Bench 4 perfs: Bench 5 perfs: PBTD ~ 16,945 TD j 17,OI0 15,945 - 16,OI5 DIL 16,060 - 16,170 DIL 16,215 - 16,260, 16,400 - 16,430 16,480 - 16,510, 16,590 - 16,6)0 16,6g0 - 16,730, 16,755 - 16,345 RECEIVED JUN'I Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASK,-, ,.)IL AND GAS CONSERVATION L,©MMISSION PER IT TO DRILL 20 AAC 25.O05 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT Gl L 'j~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Union Oil Company of California * 3. Address P. O. Box 6247, Anchorage, AK 99502 4. Lo~tion of w~ll at surface Leg A-2, Conductor #8, Dolly Varden Platform 748' FSL, 1130' FWL, Sec. 6, T8N, R13W, SM At top of propose~ producing interval 2600' FSL, 0' FWL, Sec. 32, T9N,.R13W, SM At total depth 3156' FSL, 19' ~EL, Sec. 31, T9N, R13W, SM 5. Elevation in feet (indicate KB, DF etc.) KB = 106' AMSL 6. Lease designation and serial no. ADL 17594 9. Unit or lease name Tradin~ Bay Unit 10. Well non'her " ]}-44 11. Field and pool McArthur River Field 12. Bond information (see 20 AAC 25.025) Type Blanket Drilling Surety and/or number B-2-165-724-1 Amount $200,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 21 mil&s NW of Kena, n~s : 2600feet well D-40RD @ 1050 feet -. 16. Proposed depth (MD & TVD) 12,877 MI)/9999' TVD feet 17. Number of acres in lease 5116 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 600 feet. MAXIMUM HOLE ANGLE 21 20. Anticipated pressures 42 o I (see 20 AAC 25.035 (c) (2) 18. Approximate spud date June, 1985 2633 psig@ (-} Surface 3200 psig@ 9850 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole Casing Weight 26 116 109 t 17 ~ : 13 3/8 68 .12,,¼ I ; 55~88 "47 I s% !7 29 22. Describe proposed program: CASING AND LINER Grade K-55 K-55 N-80 Coupling butt butt butt Length 3300 1050 10,500 SETTING DEPTH MD TOP TVD surface 3000I ~ 2660 surface 10 500~ , ~ 8232 MD BOTTOM TVD QUANTITY OFCEMENT 3300 2890 4050 3439 10,500 8232 11,400 8901 12,877 9999 (include stage data) 9700 sx 700 sx P-110 butt 900 N-80 butt 1727 t1,150~ 8715 500 sx 1400'sx stage 1 ** 1400 sx stage 2 See attached for Drilling Procedure ** stage collar @ 7200' ,'RECE!Vk D * MARATHON OIL COMPANY - Sub Operator S~GNED Lawrence O. Cu±±ing. The space below fo~ Commission use Alaska Oil & Gas Cons. A,chorage TITLE ENV I RONMFNTA L SPEC I ....... AI I qT DATE(hF,-06-85 CONDITIONS OF APPROVAL Samples required IIYES Permit number AP':'ROVED ~Y Form 10~01 Mud log required I Directional Survey required [-]YES ~:~O I J~YES I-lNG Approval date 7/ /.// .// // JAPI number so_733-20195-01 SEE COVER LETTER FOR OTHER REQUIREMENTS · ,COMMISSIONER DATE June 18, 1985 by order of the Commission Submit in triplicate D-44 PROCEDURE i) Skid Rig 77 to conductor 8, leg A-2, Dolly Varden Platform. 2) Kill TBU Well D-21 3) Install BPVo ND X-mas tree. NU BOPE and test. Pull BPV~ 4) POH and LD tbg~ 5) Abandon Hemlock w/a cement plug. 6) NU BOPE on 13-3/8" csg spool. 7) Cut and pull 9-5/8" csg to ±700'. 8) NU riser on conductor. 9) Cut and pull or wash over 13-3/8" csg to ±700'. 10) NU and function test diverter. 11) Drill 17-1/2" hole to 3300' per directional program. 12) Open 17-1/2" hole to 26". 13) Run and cement 16" casing. 14) Nipple up and test BOPE. 15) Drill 12-1/4" hole to 4050v per directional program. 16) Underream 12-1/4" hole to ]7-!/2". 17) Run and cement 13-3/8" liner thru abpormally pressured interval. 18) Drill 12-1/4" hole to 11,400' per directional program. 19) Run open hole logs. Run and cement 9-5/8" casing. 20) Drill 8-1/2" hole to 12,877' per directional program. 21) Run open hole logs. Run and cement 7" liner. 22) Clean out liner and displace dri!]~ng mud w/FIW. 23) Complete as a Hemlock producer. RE'~'[EIV~D J,~Yd~03 ']10 NOHI~'I~V~ J. ISIHX~ '%. J · · · · Illllllllll~ / / / / / ..... ~'~ ~t~oO ,suog se9 ~ iiO · - i i · · · · · · · · / · · · ! . =~SEC. 31.,TgN,RI3W . -'o MARATHON OIL COMPANY · . TBU WELL ................ DIRECTIONAL D-44 PROGRAM TARGET ....... SEC. 32,TgN, RI3 W ..... t ............. { ................ ~ ............. : - I150' WELLHEAD ....... ..... ~ -, ~,~ ~.,.: ~. , ~ , ._:_~ ................ ~ ........... - ., , ...................... + ._ ~ .. :.4000-- · 52_; :.>___:. :: .... 2: ;.. :-::-::- .: . . . :L_:::_: :: ' · . - .... :~ ; 8000-- n,-. - :'' : i : '~ :' : ' ' ' ~-" :-: : : :.: -' ' ~ ' ._ i ' : TVD = 9380 ' ............ ~. ....... TMD= 12,045' : . ~ ................. ~ ...... DEP = 7134' - .... ---'--:':' ! ' · ,o,ooo- . .:.-..: '.' ..... TD: TVD= 9999' ..... i ..... ';-: · '-~' - · :.--:-+-~-:-. .... ' TMD= 12,877' ..... "' t ............. ; ................... ............. -- · - ;---~-~ ~-~ ,t ............... I ........ :. ' ....... ' - - DEP= 7690 .............. t ................ .... ; ....... . - , . .: . L _. ,: ........... r . . . ..... _ . . , . ' ' ' ' RECEIVED":-._';-i-i: ;._. 0 2000 4000 6000 8000 : ! . · .JO N ~. '~ ~,~]§ ::. HORIZONTAL DEPARTURE (fi;) AlasKa Oil & Gas Cons. Commissio~ ~.nchorage ..... ..... ~ .......... :: L_':: j:: :"_:::'::: ..... ~ ' ...... ~ ~ ......... - ................. t -MARATHON O.IL GO.. t . -- DOLLY VARDI~N PLATFORM - 0 , C N" x ~ 2,ooo''' x, Preventer (20", 2,oo0 I-l.ydr il ) Room Floor- % R 'CEIVED UN ~ ~ ~ Alask~ "& Gas Cons, commission C. lc~h-,p- oh l-tub ,% ~3't C, or~dt, tc't-o~ (- MARATHON OTL GO.- k Mud Pan DOLLY VARDEN . . PL/NT FORM -- (~ydrit) , -~-,~ ........ _ ~ _ % 2_ Ft. Spool o o~ 12".5,000~ Oasing Head w/Flon~e.d Outlets ~ ~olves C_.,ol lo.r Surface. /6" ~r O- 3:~' C~onduotor · _~- .. - Di~~~ 2- I~/o ~ 5,000 [~ o Riser s BOP Sf~ck For-~ o¢ D~illin9~ From Uhdew 15~/6'~ ~ Surface C~sin9 To TD.~ . Cio, rap C..o nne c--'fo'e 'Tt)RQ L · . LE" '50()o.~ VA · . LBCK' VAry ~0~ i , : I ~ i , I . : , , , I D.V.P CHECK LIST FOR NEW WELL P!7'P~MITS Company ~ Lease & Well No.. ~ ~ L~ ~-~V ! ITEM APPROVE DATE :(2 thru 8) (4) Cas~f+~.~ ~ (13 tfiru 21) (5) BOPE ~<~, ~--?~-~ (22 thru 26) 13, ]5. I :5. :7. · '2. :.'4, , , ':.5. :1'5. ~: Eng%n.~ering: JAL rev: 03/13/85 6.011 is the permit fee attached ......................................... Is well to be located in a defined pool ........................... .~ Is well located proper distance from property line ................. Is well located proper distance from other wells ................... Is sufficient undedicated acreage available in this pool .......... Is well to be deviated and is wellbore plat included Is operator the only affected party ................................ Can permit be approved before ten-day wait .......................... Does operatOr have a bond in force ................................. Is a conservation order need'ed ...... [! j~_~~~ Is administrative' approval needed . . . Is the lease number appr°priate .. 'Is 'conductor string 'provided .......... , ............................. Is enough' cement used to circulate on conductor and surface ......... Will cement' tie' in surface and intermediate or production strings... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will ali Casing.give'adequate safety in collapse, tension and burst.. Is this' well to:b'e' kicked off 'from an existing wellbore ............. 'Is'01d,wellbor~ abandonment 'procedure included on 10-403'. ........... Is adequate Wellbore separation proposed ............................ Is a diverter system required ..' ...... , .... - Are necessary~'diagrams' of 'diverter and· BOP equipment attached D6es BOPE have sUfficient .presSure rating - Test to Does' the chok~' manifold:' comply w/API RP-53 (Feb. 78) ......... ......... I~ the presence of H2S gas probable ...................... , .......... .. Additional requirements ...... REMARKS "~ ' 'INITIAL GEO. UNI'T ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. LIBRARY TAPE CURVE SPECIFICATIONS Company MARATHON OIL COMPANY Well D-44 Field McArthur River County, State Kenai, Alaska Date 9-26-85 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale RFOC RESISTIVITY FOCUSED DIFL BHC-AC DIFL/CN-CDL .2 2000 RZLM RESISTIViTy MEDIUM DIFL .2 2000 RILD RESISTIVITY DEEP DIFL .2 2000 150 0 BHC-AC DIFL/CN-CDL 0 150 BHC-AC 150 50 CN/CDL 6 -16 CN/CDL 2 3 CN/CDL 60 0 CN/CDL -.5 .5 CN/CDL 60 0 CN/CDL 0 150 GR GAMMA RAY SP SPONTANEOUS POTENTIAL AC ACOUSTIC CAL CALIPER DEN BULK DENSITY DENP DENSITY POROSITY CORR CORRECTION CN COMPENSATED NEUTRON GR1 GAMMA RAY 1 , - rvw o_D :, :.- ,~ . .... ~ ........ ..;...~ .....~,..,.~...~......_~..~_,.~_,,..,~ ............. ?._.~.._.~..--.--, .................... ~..,._/;..:~..,~¥., ........................ ~-~,.~,:-,~...~;.: _, :. ~' ;-._* :: ..:~ ~ ~..-~? ~ ~ ,_ . ¢ .;: . - , : : -- . -. ,.?;~..::.. :.~¢ p - _ ,~ -.. ;_ ~, ~ ~ "- ' .:..'_. ~. ~. q' X .... ~, ' Z .~ :' ~ ~ -:'.:"/~ · ;'.-: ~-- ~- ~:."~&.'. ;~ -~ -' :~ ~'.--~:' ~' '.'; --). -"? ." .; - - - .................................... . ~ f. ~- ' ~' ~:-~f~ ~ ':~;;.%;:~} ~:~;~':;~.:f .::7...z. ~:x' z~ ./~ ..... .q~.;-: Z;- ~ -""" ~ ~ .................. "~ "'z:'~'~'% ............... : ................ ~ ........... -~'"~f-~'-: -':"~--'"'"'~r~"~'~""-~j"q:'.---'~'~:;:'':~ ......... 'z:~'~;:~-%-~-~-: z ...~q ~.::'~ ~. ~ . .: :-.: .-- ~' ........ ._ ........................................... . ~ .. ~ ~.~:i ¥....:.~_ ~..~ . ., _ . ~. .... :~...~_-_~_ _ ~.~..~L~-~ ..................... '. . ~' . .......... ............................... _ '. . .............................. ·