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XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ] ~ ~" /~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds Other COMMENTS: Scanned by: Bevedy Mildred Daretha ~owell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is~ Kt:\..,t:1 v...:U . STATE OF ALASKA I ALASKA Oil AND GAS CONSERVATION COMM SION MAR 1 3 2007 WELL COMPLETION OR RECOMPLETION REPOttr)\~ ð~sA'f!' Commission 1 a. Well Status: Oil D Gas U Plugged 0 ' Abandoned 0 . Suspended D WAGD 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 - Exploratory D GINJ D WINJ D WDSPL D No. of Completions _ Other - Service D Stratigraphic Test D 2. Operator Name: :~mp., Susp., 17ò ~:~.Þ1 12. Permit to Drill Number: .. ConocoPhillips Alaska, Inc. o Aband. February~ 2007 198-122/306-365 3. Address: 6. rmë Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 June 6, 1998 / 50-103-20262-01 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 117' FNL, 996' FEL, Sec. 3, T09N, R07E, UM June 18, 1998 2N-337A .- At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s): Horizon: 1848' FSL, 2328' FEL, Sec. 4, T9N, R7E, UM / 28' RKB, Pad 121' / Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + lVD): Tarn Oil Pool 1827' FSL, 2675' FEL, Sec. 4, T9N, R7E, UM 3422' MD / 2501' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + lVD): 16. Property Designation: Surface: x-460597 -' y- 5911892 /' Zone- 4 .. 10245' MD / 5465' TVD I ADL 375074 .. TPI: x- 453973 y- 5908614 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 453626 y- 5908579 Zone- 4 none ALK 4293 18. Directional Survey: Yes D N00 19. Water Depth, if Offshore: 20. Thickness of approx. 1222' N/A feet MSL Permafrost: MD 21. Logs Run: GRlRes, Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH lVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE CEMENTING RECORD TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.6# H-40 28' 108' 28' 108' 24" 9 cu yds High Early 7-5/8 " 29.7# L-80 28' 2858' 28' 2311' 9.875" 274 sx AS III LW, 60 sx AS I, 240 sx Class G 5.5" 15.5# L-80 28' 9594' 28' 5015' 6.75" 210 sx GasBlok 3.5" 9.3# L-80 9594' 10232' 5015' 5456' 6.75" included above 23. Perforations open to Production (MD + lVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET none no perfs open to production 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED iGANN&D MAR 2 9 2007 cement plug @ 2558'-3422' 33 bbls Class G CIBP @ 3420' 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable ,- .... .. .".... .-.. P&A'd ./ Date otTest Hours Tested Production for OIL-BBL GAS-MCF WA TER-BBL CHOKE SIZE GAS-OIL RATIO Test Period --> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. psi 24-Hour Rate -> 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ;~~~e. ; rO~_7:,~':.¡,] H)h~ r / .- .'." ~ ; jj,""'¡: ì NONE RBDMS BFl MAR 2 9 2007 ! .k..~1 ~ Vr:::'~~( .~:' !" t~;t I ~~:}I : ;'::.- .",,:--::::-::..; t Form 10-407 Revised 12/2003 CONTINUED ON REVERSE t; I-¡} ~ 3·/C:;·07 ~.øØ7 G ORIGINAL 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 2N-337A T3 9723' ./ 5105' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Name Signature C:-' Title: Wells GrouP EnQineer Phone 265-6958 Date 3--/2-0"1- Prepared by Sharon Allsup-Drake 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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness, Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Conoc;F)hillips We/Mew Web Reporting Time Log Summary 06:30 08:30 2.00 DMOB P RD 13 5/8" Stack from sub, Re-instsaIl11" 5M stack. 08:30 00:00 15.50 MOB P Moving Rig 1 E pad to 2N pad 02/11/2007 00:00 05:00 5.00 9,707 9,707 MOB P Move rig onto 2N pad, spot rig over well and prepare for well work activities. 05:00 06:00 1.00 9,707 9,707 P Set tree in cellar, PJSM, move over well. Spot and level rig. Rig accepted at 0600 hrs, 11-Feb-07. 06:00 08:00 2.00 9,707 9,707 RURD P Drop tarps, berm cellar, PU lubricator and ull BPV. 08:00 12:00 4.00 9,707 9,707 RURD P RU circ lines to tree, spot highline trlr, take on fluids for well kill 0 erations. 12:00 14:00 2.00 9,707 9,707 P PJSM, RU circ hoses & lines to kill well. Pre-kill gauge readings: OA 175 psig, IA 100 psi. Tubing and IA same due to revious tubin cut rocedure. 14:00 15:30 1.50 9,707 9,707 NP Thaw frozen valves and lines on rig. 15:30 17:00 1.50 9,707 9,707 P Circ. 8.5 ppg seawater down tubing and w/lA returns at 2 bpm & 350 psi. Stage up rate to 4 bpm at 1500 psi. circ well clean wI 250 bbls brine. 17:00 20:00 3.00 9,707 9,707 P RD hoses, break down hard line, set BPV. ND tree, install blanking plug in tb han er. 20:00 00:00 4.00 9,707 9,707 P NU BOP stack. 02/12/2007 00:00 01:00 1.00 9,707 9,707 PROD1 WELCT NUND P Finish NU of BOPE and prepare for testin of same. 01:00 06:00 5.00 9,707 9,707 PROD1 WELCT BOPE P PJSM, Test BOPE 250 13500, all components, perform time I volume I press test accumulator, Witness test waived by Chuck Scheve wI AOGCC at 0100 hrs. 06:00 06:30 0.50 9,707 9,707 PROD1 WELCT BOPE P Pull TWC, flow check. 06:30 07:00 0.50 9,707 9,707 PROD1 RPCO~ PULD P PJSM, Work 3-1/2 tbg string I tbg hgr. Pull free with 125K total pull. Flow check, ull h r to floor, LD same. 07:00 08:00 1.00 9,707 9,707 PROD1 RPCO~ CIRC P Flow check, circ wellbore clean with seawater. Take unclean returns to truck and dis ose. 02/12/200708:00 21:00 13.00 9,707 9,707 PROD1 RPCOI\ PULD P PJSM, prepare floor, POH 3-1/2 tbg, stand bk 12 stds in mast for cmt stinQer, resume POH, LD in singles. 21:00 22:00 1.00 9,707 9,707 PROD1 RPCOI\ PULD P Strap remainder of pulled tubing in pipeshed and pulled jewelry, remove from rig, clear floor for next phase. Total length tbg and jewelry pulled 9542 ft for tbg total 268 jts + 12 stands for 304 jts pulled. 22:00 00:00 2.00 9,707 9,707 PROD1 PLUG MPSP P PJSM, install wear bushing, RU eline, RIH wI CCL and junk basket and 4.725" gauge ring to 3650ft, no obstructions. POOH. 02/13/2007 00:00 00:30 0.50 9,707 9,707 PROD1 PLUG MPSP P Continue POOH wI eline wI gauge ring and CCL. 00:30 03:00 2.50 9,707 3,420 PROD1 PLUG MPSP P PJSM. RD pack-off, LD gauge ring and junk basket. Install CIBP, re-install pack-off and RIH wI eline. Successfully set CIBP at 3420'. PU and RIH wI set tool and tag wI eline to verify location, OK. POOH wI eline. 03:00 04:00 1.00 3,420 3,420 PROD1 PLUG MPSP P RD eline and remove pack-off wI lubricator from rig floor. LD. 04:00 06:00 2.00 3,420 3,420 PROD1 RPCOI\ SFEQ P PJSM, set test plug, cIa top set of rams in BOP to 5 1/2". Function test. Install 5 1/2" IdQ jt. 06:00 07:00 1.00 3,420 3,420 PROD1 WELCT BOPE P Test 5-1/2 rams I door seals 250 I 3500 psi. 07:00 08:00 1.00 3,420 3,420 PROD1 WELCT BOPE P Clear floor, LD BOPE test equip, remove test plug, flow check. 08:00 11:00 3.00 3,420 3,420 PROD1 WELCT OTHR P PJSM, bleed 5-1/2 X 7-5/8 ann. Initial 170 psi, final "0" psi in 1 hr. Observe annulus, no press build I flow. 11:00 13:00 2.00 3,420 3,420 PROD1 RPCOI\ PULD T Attempt pull 5-112 pkf. Pkf stuck in wellhead. Doublecheck LD screws. Cont work I rotate loose. Pull to floor, LD pkf I running tool. Pkf scarred I damaged from LDSs. Screws out completely. Repair tentative for later date. (After cmt plug) 13:00 13:30 0.50 3,420 3,420 PROD1 RPCOI\ PULD P Pull tension in 5-1/2 60K total), set in slips under tension. 13:30 15:30 2.00 3,420 3,420 PROD1 FISH ELNE P PJSM, Rig up Schlum E-line, place jet cutter equip riq floor, RU same. 15:30 17:30 2.00 3,420 3,420 PROD1 FISH ELNE P RIH jet cutter on E-line, correlate depth with CCL, fire cutter at 3058 ft. POH E-line, note cutter fired, RD Schlum equip, clear floor. 17:30 18:30 1.00 3,420 3,420 PROD1 RPCOI\ RCST P PJSM, flow check, wellbore stable, attempt break 5-1/2 free. Work string with and without torque. Can not free, I partial or no cut. 18:30 19:00 0.50 3,420 3,420 PROD1 RPCOI\ RURD P PJSM, Load Geopilot skid onto rig floor. 19:00 22:00 3.00 3,420 3,420 PROD1 WELCT BOPE P PJSM, Change upper pipe rams fl 5 1/2 to 2 7/8. 23:30 00:00 0.50 3,420 3,420 PROD1 WELCT BOPE P 02/14/200700:00 01:00 1.00 3,420 3,420 PROD1 FISH RURD P Install stabbing guide on top drive drive. 01:00 04:30 3.50 3,420 3,420 PROD1 FISH TRIP P RIH w/5 1/2 Baker mechanical cutter on 2 7/8 PAC. 04:30 06:00 1.50 3,420 3,420 PROD1 FISH RURD P Adust torque limit on top drive, break circ 1.6 bpm 1100 psi. Up 60, dn 55. Commence cut 5-112 csg as per BOT re . 06:00 09:30 3.50 3,420 3,420 PROD1 WELCT KLWL T Gas cut returns (bubbling with no flow), PJSM, circ 2-7/8 X 5-1/2 annulus, displace with 9.6 ppg mud. Line up I bullhead 53 bbls 9.6 mud to 5-1/2 X 7-5/8 annulus. 1 bpm 1890 psi, final = 1 bpm 1460 psi. Open well, flow check, well static. 09:30 10:30 1.00 3,420 3,420 PROD1 FISH CPBO P PJSM, resume cut 5-1/2 csg. Confirm cut with ress I wt test. Flow check. 10:30 12:00 1.50 3,420 3,420 PROD1 RPCOI\ CIRC P Monitor well, circulate clean wI 9.6 mud w/1 ,300 si 4b m. 12:00 12:30 0.50 3,420 3,420 PROD1 RPCOI\ OWFF P PJSM, BD Top Drive, Monitor Well static . 12:30 14:30 2.00 3,420 3,420 PROD1 RPCOI\ TRIP P POH w/5 1/2 mechanical cutter on 2 7/8" DP f/3,069'. 14:30 15:30 1.00 3,420 3,420 PROD1 WELCT EQRP P Change upper pipe rams fl 2 7/8" to 5 1/2". 15:30 16:00 0.50 3,420 3,420 PROD1 WELCT BOPE P Pull wear bushing, run test plug. 16:00 17:00 1.00 3,420 3,420 PROD1 WELCT BOPE P Test upper pipe rams to 250 psi/3,500 si, blow down to drive. 17:00 18:30 1.50 3,420 3,420 PROD1 RPCOI\ PULD P PJSM, MU Idg jt with run I retrieve tool to 5-112 hgr. Drain stack, observe well, flow check. Begin take pull on 5-1/2 to free csg cut. Stage pulls in 1 OK overpull intervals, resulting in final pull at 275K. (Buoyed wt at cut 41 K, max to yield 404K) 275K - 35K top drive = 240K total pull. Total stretch 6.5 ft. No success with pull. Press 5-1/2 with 1500 psi, attempt "hydraulic" string free. Press. holding, packed off. Cont re-cip pipe two 5 ft strokes. String free, moving slowly, press bleeding with upward movement. Pump 3 jts out, press bleeds to "0" psi. Pull two more jts to 7-518 shoe. Fluid dropping in csg to BOP level. Flow check. 18:30 19:00 0.50 3,420 3,420 PROD1 RPCOI\ CIRC P CBU X 2 @ 5 bpm wI 220 psi. Shaker clean. No abnormal quantity I quality cuttin s returns. No ain I loss. 02/14/2007 19:00 19:30 0.50 3,420 3,420 PROD1 RPCO~ OWFF P Blow down Top Drive, monitor well (static). 19:30 23:30 4.00 3,420 3,420 PROD1 RPCO~ PULD P POH, LD 51/2" casing, strap in pipe shed. 23:30 00:00 0.50 3,420 3,420 PROD1 RPCO~ PULD P PJSM. LD 2 7/8" PAC drill pipe fl derrick in mousehole. 02/15/2007 00:00 04:00 4.00 3,420 3,420 PROD1 RPCO~ PULD P LD 27/8" DP fl derrick in mouse hole. 04:00 06:30 2.50 3,420 3,420 PROD1 RPCO~ PULD P Remove 2 7/8" DP ff pipe shed, load & tally 4" DP 06:30 09:30 3.00 3,420 3,420 PROD1 RPCO~ PULD P PJSM, change lower rams to 3-1/2, lower rams to 4". 09:30 10:30 1.00 3,420 3,420 PROD1 WELCT BOPE P PJSM, test rams I door seals 250 I 3500 psi. Test successful, no re-tests 10:30 13:00 2.50 3,420 3,420 PROD1 RPCO~ OTHR P cIa saver sub top drive to 4" DP. 13:00 17:30 4.50 3,420 3,420 PROD1 RPCO~ PULD P PJSM, flow check, PU 4" DP in singles for clean out run to tag top 5-1/2 stub at 3055 ft. 17:30 20:00 2.50 3,420 3,420 PROD1 RPCO~ CIRC P Pump 2 Hi-Vis sweeps surface to surface. Hole cleaned up. 20:00 20:30 0.50 3,420 3,420 PROD1 RPCO~ OWFF P Blow down top drive, monitor well ! (static). 20:30 22:30 2.00 3,420 3,420 PROD1 RPCO~ TRIP P POH wI DP 22:30 23:30 1.00 3,420 3,420 PROD1 RPCO~ RURD P RU to run 3 1/2 tubing stinger fl balanced plug 23:30 00:00 0.50 3,420 3,420 PROD1 RPCm TRIP P PJSM, RIH wI mule shoe & 1,141' of 3 1/2 tubing 02/16/2007 00:00 01:00 1.00 3,420 3,420 PROD1 RPCO~ RURD P PJSM, RU 4" DP handling equipment. 01:00 02:00 1.00 3,420 3,420 PROD1 RPCO~ TRIP P RIH wI 4" DP, Tagged up 3,145. No indication pass through 5-1/2 stub at 3058. 02:00 04:30 2.50 3,420 3,420 PROD1 RPCm FCO P MU Top Drive, rack back stand & wash to cement retainer @ 3,422'. 4bpm 1250 psi. Trace sands I clay returns to shaker. Cont circ clean. No gain I loss. 04:30 05:00 0.50 3,420 3,420 PROD1 RPCO~ CIRC P Cont circ shaker clean for cmt plug. 05:00 06:30 1.50 3,420 3,420 PROD1 CEMEI\ RURD P PJSM, RU to cement, PJSM, prime up cement van, RU floor for cmt plug. 06:30 07:00 0.50 3,420 3,420 PROD1 CEMEI\ PLUG P PJSM, Commence set cmt plug. ./' Pump 5 bbls H2o, test lines 3000 psi, Mix I pump 33 bbls, 17 ppg, "G", follow with 2.3 bbls H2o for balanced interface, displace with 24 bbls drlg mud. ICP = 169 psi, FCP = 119 psi, 100% returns, no gain floss. 07:00 08:00 1.00 3,420 3,420 PROD1 CEMEI\ TRIP P Break cmt lines (slight vacuum), POH to 2376 ft. (TOC 2558 ft). Fluid dropping, no flow back. 08:00 09:00 1.00 3,420 3,420 PROD1 CEMEI\ CIRC P Circ DP clean @ 6 bpm 1180 psi. Approx .5 cu ft contanimate to surface. Blow down top drive. . 02/16/2007 09:00 10:00 1.00 3,420 3,420 PROD1 CEMEI\ TRIP P POH remainder 4" DP fl 2376' to 1141', Change out handling equipment to 3 1/2". 10:00 11:30 1.50 3,420 3,420 PROD1 RPCm PULD P LD 3 1/2 Tubing f/1141' to surface. 11 :30 12:00 0.50 3,420 3,420 PROD1 RPCOI\ RURD P Clear floor & remove tubing f/ pipe shed. 12:00 19:30 7.50 3,420 3,420 PROD1 RPCOII. RURD P PJSM, prep & tally 4" DP, change out grabber dies, RU Geospan unit. 19:30 21:00 1.50 3,420 3,420 PROD1 RPCOII. PULD P PU & torque 4" DP & stand back in derrick. 21:00 23:00 2,00 3,420 3,420 PROD1 RPCOII. PULD T RIH wI 2019' 4" DP, set storm packer below wellhead, test to 500 psi. 23:00 00:00 1.00 3,420 3,420 PROD1 RPCOII. PULD T Pull wear ring, change out Lock Down Screws, contiue racking back 4' DP. Note: repair due to damage sustained in pulling 5-1/2 PKF prior. 02117/2007 00:00 01:30 1.50 3,420 3,420 PROD1 WELCì EQRP T Replacing lockdown screws in wellhead, continue racking back 4" DP in derrick. 01:30 02:30 1.00 3,420 3,420 PROD1 WELCì EQRP P Change lower pipe rams f/3 1/2" to 4". 02:30 04:30 2.00 3,420 3,420 PROD1 WELCì EQRP T Lay down Baker storm packer. 04:30 05:30 1.00 3,420 3,420 PROD1 RPCOII. PULD T POH wI 4" DP f/2019' 05:30 06:00 0.50 3,420 3,420 PROD1 WELCT BOPE P Pull wear bushing, install test plug. 06:00 07:00 1.00 3,420 3,420 PROD1 WELCì BOPE P Fill stack wI H20, thaw out annulus valve, RU test hoses, troubleshoot test I plug (chanç¡e out o-ring). 07:00 12:00 5.00 3,420 3,420 PROD1 WELCì BOPE P PJSM, test BOPE, all components 250/3500 psi. Perform time I volume I press test accumulator. Test floor valves, top drY to pumps. Witnessed by Mr Lou Grimaldi AOGCC. 12:00 13:00 1.00 3,420 3,420 PROD1 WELCì BOPE P PJSM, Remove test plug & install wear bushing. 13:00 20:00 7.00 3,420 3,420 PROD1 RPCOII. PULD P PU & torque 5421' of 4" DP & stand back in derrick. 20:00 21:30 1.50 3,420 3,420 PROD1 RIGMN SVRG P PJSM, cut & slip drill line, calibrate block height. 21:30 22:30 1.00 3,420 3,420 PROD1 RPCOII. SFEQ P Calibrate block height for Epoch & Sperry Sun. 22:30 00:00 1.50 3,420 3,420 PROD1 STK PULD P PJSM, PU Sperry Geo-pilot w/6 3/4 bit, attempt to RIH, tagged ice @ 32' RKB. 02/18/2007 00:00 01:30 1.50 3,420 3,420 PROD1 STK PULD T Break off PDC bit & LD Geopilot tools, PU 6 1/8 mill tooth bit on stand of 4" DP and wash ice out of casing @ 32', RIH to 180' to confirm ability to trip 6 3/4 bit, POH & break off 6 1/8 bit, stand back stand. 01:30 03:30 2.00 3,420 3,420 PROD1 STK PULD P PJSM, MU PDC bit onto Geopilot tools, PU MWD & LWD tools. 03:30 04:30 1.00 3,420 3,420 PROD1 STK PULD P Plug in & upload to MWD & LWD tools-Check communication (OK). 02/18/2007 04:30 05:30 1.00 3,420 3,420 PROD1 STK PULD P MU Top Drive, shallow test MWD tools (OK), blow down Top Drive. 05:30 06:30 1.00 3,420 3,420 PROD1 STK PULD P Install nuclear source in LWD tools. 06:30 07:30 1.00 3,420 3,420 PROD1 STK PULD P MU drctnl BHA I HWDP RIH same. 07:30 08:30 1.00 2,469 2,469 PROD1 STK TRIP P Flow check, follow BHA with 4" DP to 2469 ft. 08:30 09:00 0.50 2,469 2,469 PROD1 STK CIRC P Run Geo Pilot seals with rotation I circ. 09:00 09:30 0.50 2,469 2,586 PROD1 STK OTHR P Wash 2469 - 2586 ft to tag cmt plug, 250 gpm. 20K on plug. Will not wash away. 09:30 10:00 0.50 2,586 2,646 PROD1 CEMEf\ DRLG P Drill cmt 2586 - 2646 ft. Medium hard initially' becomil}9 harder at 2646 ft. 10:00 10:30 0.50 2,646 2,646 PROD1 STK CIRC P Circ shaker clean for csg test. 10:30 12:30 2.00 2,646 2,646 PROD1 STK OTHR P PJSM, test 7-5/8 csg 2500 psi 130 min. Test successful. RD test eauip. 12:30 18:00 5.50 2,646 2,891 PROD1 CEMEf\ DRLG P Resume drill cmt plug 2646' to '~-Sl 2891'-Drilling parameters: up w1==80K, J~ down wt=70K, rot wt=75k, pump pressure 900 psi @ 6 bpm, / torque==2400 ftllbs. 18:00 18:30 0.50 2,891 2,941 PROD1 DRILL KOST P Drill ahead 6-3/4 hole fl 2891' to 2941 '-Sidetrack fl old wellbore. ')Ñ- ) ~~ t:\ 18:30 19:00 0.50 2,941 2,941 PROD1 DRILL CIRC P CBU, MWin == MWout, 9.7 ppg, shakers cleaned up, no excessive or unusual cuttings observed. 19:00 19:30 0.50 2,941 2,941 PROD1 DRILL LOT P Blow down top drive, RU to perform LOT 19:30 20:30 1.00 2,941 2,941 PROD1 DRILL LOT P Perform LOT as per well program (MD 2949, TVD 2340) Leaked off @ 400 psi wI 9.7 ppg MW == 13 ppg EMW. Pumped 3.6 bbl, bled back 2 bbl. 20:30 21:00 0.50 2,941 2,941 PROD1 RIGMN SVRG P RD test equipment, adjust Top Drive torque to 10K. 21:00 00:00 3.00 2,941 2,983 PROD1 DRILL DDRL P Drill ahead 6-3/4 hole drctnl, fl 2941' to 2983' MD, 2357' ND wI the following parameters: up w1=82K, down wt=65K, pump pressure 1090 psi @ 6.5 bpm, torque==3180 ftllbs on bottom, 2720 ftllbs off bottom. Max gas observed 2350 units. 02/19/2007 00:00 12:00 12.00 2,983 3,312 PROD1 DRILL DDRL P Drill ahead 6-3/4 hole drctnl, wI Sperry Geopilot f/2983' to 3312 ft. SPP 1580, SPM 130, GPM 322 gpm, WOB 5/10, RPM 130/140 Up 80, Dn 65, Rot 75, ART = 13.42 hrs, ECD 10.8, Max gas 32 No gain I loss. Cuttings return normal quantity I quality. Rap low 15 - 30 ftlhr at worst, vary parameters, pump nut plug, "dril zone" Prepare trip for BHA. 12:00 13:00 1.00 3,312 3,312 PROD1 DRILL CIRC P Pump hi-vis sweep, circ shaker clean. No gain I loss. 02/19/2007 13:00 13:30 0.50 3,312 3,312 PROD1 DRILL TRIP P PJSM, flow check, POH 4" DP to 7-5/8 shoe at 2858 ft. Normal drag, no swab, correct hole fill. 13:30 14:00 0.50 3,312 3,312 PROD1 DRILL OWFF P Flow check while adjust hole fill s stem. 14:00 17:00 3.00 3,312 3,312 PROD1 DRILL TRIP P Resume POH 4" DP to BHA 17:00 19:30 2.50 3,312 3,312 PROD1 DRILL PULD P PJSM, Remove nuclear sources, download MWD/LWD, break off bit & LD Geo ilot. 19:30 20:00 0.50 3,312 3,312 PROD1 DRILL PULD P Inspect bit, not balled up, one plugged nozzle I Clean ri floor. 20:00 23:30 3.50 3,312 3,312 PROD1 DRILL PULD P Build BHA #2, PU mud motor, upload MWD/LWD, PJSM, install nuclear sources. 23:30 00:00 0.50 3,312 3,312 PROD1 DRILL CIRC P Shallow test MWD, blow down top drive. 02/20/2007 00:00 03:00 3.00 3,312 3,312 PROD1 DRILL TRIP P RIH fl 486' to 3,046' MD. Precautionary flow check. Continue RIH, survey every 30' to bottom at 3312' MD. 03:00 04:00 1.00 3,312 3,312 PROD1 DRILL SRVY P Pump up surveys. 04:00 12:00 8.00 3,312 3,906 PROD1 DRILL DRLG P Directional Drill from 3312' MD to 3906' MD, 2702' TVD. 85 K# PU, 70 K# SO, 78 K# Rot. wt. 85 RPM, 5 to 8 K# was, TQ 3800 ft-Ib on btm, TQ 2800 ft-Ib off btm. 120 SPM, 6.5 BPM, 1700 psi on btm, 1600 psi off btm. 1200 Units Max. Gas. 6.16 hrs ADT, 5.00 hrs ART, 1.16 hrs AST. 12:00 00:00 12.00 3,906 4,669 PROD1 DRILL DRLG P Directional Drill from 3906' MD to 4669' MD, 3017' TVD. 98 K# PU, 70 K# SO, 80 K# Rot. wt. 85 RPM, 5 to 6 K# WOB, TQ 4220 ft-Ib on btm, TQ 3320 ft-Ib off btm. 110 SPM, 6.4 BPM, 1560 psi on btm, 1430 psi off btm, 313 Units Max. Gas. 7.81 hrs ADT, 6.64 hrs ART, 1.20 hrs AST. 02/21/2007 00:00 12:00 12.00 4,669 5,660 PROD1 DRILL DDRL P Directional Drill from 4,669' MD to 5,660' MD, 3,419' TVD. 115 K# PU, 75 K# SO, 90 K# Rot. wt. 85 RPM, 5 to 8 K# WOB, TQ 5,100 ft-Ib on btm, TQ 4,000 ft-Ib off btm., 10.9 ECD, 110 SPM, 6.4 BPM, 1,840 psi on btm, 1,780 psi off btm. 220 Units Max. Gas. 8.39 hrs ADT, 7.70 hrs ART, 0.69 hrs AST. 12:00 00:00 12.00 5,660 6,191 PROD1 DRILL DDRL P Directional Drill from 5660' MD to 6191' MD, 3640' TVD. 123 K# PU, 73 K# SO, 87 K# Rot. wt. 85 RPM, 8 to 12 K# WOB, TQ 6330 ft-Ib on btm, TQ 5500 ft-Ib off btm., 11.1 ECD, 110 SPM, 6.4 BPM, 271 GPM, 2000 psi on btm, 1750 psi off btm. 290 Units Max. Gas. 7.55 hrs ADT, 5.88 hrs ART, 1.67 hrs AST. 01/24/07 Scblumbel'gel' ~ ~ 3 () 'Lon? sc~MEO J~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth NO. 4121 .I/\N ~'. 9 ZOO] Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ¡¡,np~ t C)L( -- 18d. Field: Kuparuk Well Job # Log Description Date BL Color CD 1C-111 11415647 RST WFL 10/29/06 1 2B-01 11536780 PROD PROFILE 01/04/07 1 2H-11 11539477 PROD PROFILE 01/04/07 1 2B-02 11538781 PROD PROFILE 01/05/07 1 3N-19 11538782 PROD PROFILE 01/06/07 1 2W-06 11538784 PROD PROFILE 01/08/07 1 1C-28 L 1 N/A GLS 01/16/07 1 2M-06 11628958 INJECTION PROFILE 01/20/07 1 1 C-117 11628954 INJECTION PROFILE 01/18/07 1 2K-16 11638814 PRODUCTION PROFILE 01/22/07 1 1Y-22 11638815 PRODUCTION PROFILE 01/23/07 1 2N-337 A N/A SBHP SURVEY 01/21/07 1 2M-26 N/A SBHP SURVEY 01/21/07 1 2M-03 N/A INJECTION PROFILE 01/22/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. \1.-\ . . . . FRANK H. MURKOWSKI, GOVERNOR AIASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Guy Schwartz Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 \ O\ß ...- \ 'ì-' '"V Re: Kuparuk River Field, Tarn Oil Pool, 2N-337A Sundry Number: 306-365 SK' Þ~~U~~iI',' \2;1.,,)1'\\iJ \!, ;:I!.:~.:; o C' " " Ie' . ,~I Dear Mr. Schwartz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisU day of November, 2006 Encl. þ\\~ ' APPLICATION FOR SUNDRY APPROVAb;:~tl 20 MC 25 280 (A1.f (1-- U ' ðb STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION . E¡~ ,.,1f M"¡t' t~ IJ LULO .".+',u Ii',; 0 0 0 0 0 - 0 1. Type of Request: Abandon " Suspend Operational Shutdown Perforate Waiver Other Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 , Exploratory 0 198-122 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20262-01 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes 0 No 0 2N-337A 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 375074, ALK 4293 RKB 28' Kuparuk River Field I Tarn Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 1 0245' 5465' 9997' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" 108' 108' SURF CASING 2830' 7-5/8" 2858' 2311' PROD CASING 9566' 5-1/2" 9594' 5015' PROD CASING 637' 3-1/2" 1 0231 ' 5456' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9960'-1 0000' 5271'-5299' 3-1/2" L-80 9594' Packers and SSSV Type: Packers and SSSV MD (ft) no packer Cameo DS nipple @ 504' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: January 1, 2007 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Name Guv SCh:2 L1 Title: Wells Group Engineer Phone 265-6958 Date 11- R- óc, Signature ~'-'-I ç: ~-... I ...,,j Commission Use Onlv Conditions of approval: Notify Commission so that a representative may witness Sundry 30&;:- 3{¡;[) Plug Integrity ~ BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 - Other: :~HgDMS 8Ft 2 2006 Subsequent Form Required: APPROVED BY Date t¡,1I~ Approved by: THE COMMISSION Form 10-403 Revised 06/2006 '-""'" ~ '-oRIGINAL SuAuPlicate . It. f· or- ....01 ((/2, ~ ~ . . , P & A Procedure Outline 2N-337 A Pre-Rig Well Work: '~ "3 'Db \$ ç~ "".... "1-..0 1) Set retainer (w/ SL) and cement squeeze the existing perforations using Coil tubing. ~£?fv( 2) MIT the cement plug 'y;}. 3) Ensure well is dead in OA/IA/Tbg \ 4) Cut tubing at 9570' md 5) Prep wellhead for rig Sidetrack (Set BPVNR) Rig Work: 1. Move in and rig up Nordic 3. 2. Nipple down tree and tubing head adapter. 3. NU and test the 11" x 5K BOPE to 250 PSI /3500 PSI. 4. Pull and lay down the tubing hanger. Stand back 12 stands of 3-1/2" tubing and lay down the remainder. 5. Rig up E-Line. Make up 5-1/2" cast iron bridge plug and set inside 5-1/2" casing at 3400' MD. ,., 6. Jet cut 5-1/2" casing at 3058' MD which is 200' below the 7-5/8" surface casing shoe. 7. Pull and lay down 5-1/2" casing. 8. Make up 3-1/2" mule shoe, 1000' of 3-1/2" tubing stinger, 4" drill pipe and RIH to plug back total depth. 9. Spot an 850' balanced cement plug on top of cast iron bridge plug with the top of cement inside 7-5/8" casing shoe at approximately 2558' MD. - IA\ ~ ~ ;20bu s ~, - 10. Pull out of hole and lay down 3-1/2" tubing stinger. ,. ~?rtur).-( 11. Pick up drilling BHA, 4" drill pipe, and run in hole to top of cement and tag for cement hardness. Test 7-5/8" casing to 3000 PSI for 30 minutes and record on chart. ,¡ Note: Rig Sidetrack operations commence at this point. NIP (504-505, 00:3,500) TUBING (0-9594, 00:3,500, 10:2,992) PROO CASING (0-9594, 00:5,500, V>.t:15,50) SLEEVE-C (9488-9489, 00:3.500) Gas Lift andrelNalve 1 (9537-9538, NIP (9590-9591, 00:3,500) SEAL (9594-9595, 00:4,000) PROO CASING 9594-10231, 00:3,500, V>.t:9,30) Perf 9960-10000) FRAC 9960-10000) . ConocoPhillips Alaska, Inc. \ 1:: +- ~ ~ --?- ç --'- ~ , :=¡ -l- --{ r-->¡- ~ f--T ~ f---'- ~ Well Tvpe: PROD OriQ Completion: 6/19/1998 Last W/O: Ref Log Date: TD: 10245 ftKB Max Hole AnQle: 71 deg (â¡ 3584 Size Top Bottom TVD Wt Grade Thread 16,000 ° 108 108 62,58 H-40 WELDED 7,625 ° 2858 2311 29.70 L-80 BTC-MOD 5,500 0 9594 5015 15.50 L-80 BTC-MOD 3.500 9594 10231 5455 9,30 L-80 EUE Bottom 1 TVD I Wt I Grade 1 Thread 9594 I 5015 1 9.30 1 L-80 I 8RD EUE 1 Status I Ft I SPF 1 Date I Type 1 Comment I 140 14 17/30/1998 IPERF~'5" HC, BH, 180 deg orient Stimulations & Treatments Interval 1 Date I Type 1 Comment 9960 - 10000 I 8/3/1998 1 FRAC I Placed 213 Mlbs prop in formation, Gas Lift MandrellNalyes St I MD I TVD I r:,~~ Man Type I V Mfr V Type I V OD I Latch I Port 1 I 95371 49771 Camco I KBG-2-9 I Camco OV I 1,0 I BTM 10,313 Other II IUDs II 2uiD. etc.} - JEWELRY Depth TVD Tvpe Description 504 503 NIP Cameo DS Nipole 9488 4945 SLEEVE-C Sliding Sleeve, Baker CMU w/2.813 Cameo profile. SLEEVE CLOSED set 7/20/04 Camco D Nipple, Baker 5,5 CasinQ Seal Assemblv, size 80-40 Float Collar 2N-337 A API: 501032026201 SSSV Tvpe: NIPPLE Annular Fluid: Reference LOQ: Last TaQ: 9997 Last TaD Date: 6/23/2005 Casina Stñna . ALL Description CONDUCTOR SURF CASING PROD CASING PROD CASING TubinQ Strina . TUBING Size I Top 3,500 I 0 Perforations SummarY Interval I TVD 9960 - 10000 5271 - 5299 9590 9594 10231 5013 5015 5455 NIP SEAL COLLAR . KRU 2N-337A AnQle @. TS: deQ @. AnDie I1'ì> TD: 48 deD I1'ì> 10245 Rev Reason: TAG FILL Last Update: 7/26/2005 1 I Zone TRO Date I Vly Run Cmnt o 7/19/20041 ID 2,875 2,813 2,750 2.985 0,000 ,../- . . Review of Sundry Applications 306-365 ConocoPhillips Alaska, Inc. We1l2N-337A Kuparuk River Field, Tarn Oil Pool AOGCC Permit 185-109 Requested Action: ConocoPhillips Alaska, Inc. (CPAI) proposes to abandon the subject wellbore so that the well can be re-entered for a sidetrack. Recommendation: I recommend approval of CP AI's proposed action. Discussion: CPAI proposes to squeeze the existing perforations located at 9960' to 10000' MD, cut and pull the tubing and some ofthe 5-W' production casing, and set a cement plug across the 7-5/8" surface casing shoe. This will prepare the well for sidetracking, which will be discussed in a separate permit to drill application. Mr. Guys Schwartz informed me that the well will be sidetracked to another bottomhole location in the Tam Oil Pool. We1l2N-337A was completed in June 1998 and began production in August of the same year, the well has been shut in since July 2004. The well is located on the periphery of the Tam Oil Pool. Cumulative production from the well is 499 MBO, 470 MMCFG, and 286 MBW. Peak oil production was 910 BOPD in October 1999. The well has had a somewhat erratic production history, as can be seen by the production plot below, and has had a few periods of shut in production. The last period of sustained production, August 2002 through December 2003, showed production averaging approximately 200 BOPD through May of 2003 before declining rapidly and was producing at less than 20 BOPD during the last three full months of production. During the period of rapidly declining oil production the water production from the well remained relatively constant at about 80 to 100 BWPD. The Tam Oil Pool has an active gas and water injection program for enhanced recovery and the behavior exhibited by the subject well could be indicative of water breakthrough. A later attempt, June and July 2004, to resume production from the well was short lived an unable to establish production of more than 100 BOPD. In addition to the low production rates the well has also experienced other operational difficulties. In August 1999 the Operator submitted a sundry application, sundry number 399-146, to temporarily install and test a jet pump in the well in hopes of solving production problems associated with paraffin buildup in the tubing. The description of the propose activity stated, "[t]he production history for well 2N-337 A is characteristic of the 2N periphery producers, with intermittent production followed by periods of shut-in time." The application also stated, "[p]araffin accumulation has been a consistent . . impediment to production, and has resulted in a complete tubing obstruction. The high deviation ofW e1l2N-337 A is considered to be a contributing factor to wellbore cooling and consequent paraffin deposition." 'DID ~ . .......... .......... POCL:"""" GæR3e(I'D)(M:I'O) _.....,- 01 Ræ(1'D) ( twO) ..- R""(I'D)( twO) - "-CLI('IIo) 'II!) .m............... _.....H........ .. -.-............................. 1:1) .................................-. .............. .................................... ....................................... ....................................... a1 -. 001 'Œ6 93 Xli! 0'1 œ aa œ œ DAlE The report of sundry well operations that was submitted on October 27, 1999, for the work done under sundry approval 399-146 indicates that the jet pump was installed from July 17 to October 5, 1999, and that prior to installation ofthe pump the well produced 385 BOPD (with a note that production varied from 16 to 2200 BOPD depending on the amount of paraffin in the well) and produced at 678 BOPD during the test. Conclusion: Based on the rapid decline in oil production towards the end of this wells productive life, the documented history of production difficulties, and the fact that the well will be sidetracked to a new bottomhole location in the Tam Oil Pool I believe it is appropriate to approve this application. D.S. Roby Reservoir Engineer November 20, 2006 Re: Jet Pumped Wel1s Subject: Re: Jet Punlped Wells From: "NSK Problenl Well Sup\," <n 1617@'conocophillips.com> Date: Sat. 7 Dee 2002 14:07:01 -0900 To: Tonl :lvlaunder <tom_nlaunder@.admin.state.ak.us> CC: "n 1617" <n 1617@conocophilllps.com> Tom: I requested a list of surface powered jet pump wells from our PEls. The following should be the current total for the Kuparuk area: West Sak wells: 1C-123 (PTD 2010840) was recently SI for high watercut 1C-135 (PTD 2012200) is a huff and puff well and was recently put on water injection cycle CPF 2 are as follows: 2L-307 (PTD 1982560) 2 L - 3 1 3 (PTD 198 2 19 0 ) 2L-315 (PTD 1982180) 2 L - 3 2 1 (PTD 1 98 2 62 0 ) 2L-325 (PTD 1982090) 2 N - 3 0 3 ( PT 0 2 0 0 16 9 0 ) 2N-304 (PTD 2011300) 2N-305 (PTD 2001350) 2N-318 (PTD 2001000) 2N-319 (PTD 1981970) 2N-332 (PTD 2000790) ~ 2N-337 (PTD 1981220) 2N-339 tPTD 1981000) 2P-415 (PTD 2012260) There are no surface powered jet pump wells at CPF3. I hope this answers your question. Let me know if you need more information. Jerry Dethlefs ConocoPhillips Problem Well Supervisor Tom Maunder <tc'In ma1.lnde.r';,':'d.dmin.state.ak.us> 12/06/2002 09:00 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Jet Pumped Wells Pete and Dr Jerry, I have some emails f h'l b rom aWl e ack regarding the wells out there on jet pumps. Would you please provide an updated listing of the wells present l~l on jet pumps in greater KRU?? Thanks in advance. Tom __ well ComPliance Report File on Left side of folder 198-122-0 MD 10245 _ TVD 05465 KUPARUK RIV U TARN 2N-337A 50- 103-20262-01 Completion Dat~/19/98 Completed Status: 1-OIL ARCO Current: Name Interval Sent Received T/C/D D 8451 f_~2~j' SPERRY MPT/GR/EWR4/CNP/SLD OH 8/11/98 8/12/98 L DGR/CNP/SLD-MD t,~AL 2868-10245 OH 8/11/98 8/12/98 L DGR/CNP/SLD-TVD b~L 2315-5464 OH 8/11/98 8/12/98 L DGR/EWR4-MD -~e~AL 2868-10245 OH 8/11/98 8/12/98 L DGR/EWR4-TVD ,~AL 2315-5464 OH 8/11/98 8/12/98 R SRVY CALC ~967.74-12245. OH 9/21/98 9/24/98 Daily Well Opsi¢¢~//~o~ 3/24/?~ Are Dry Ditch Samples Required? yes ~nd Received.~-.~ Was the well cored? yes (~_~_~_. Analysis Description R~4,,,eO?-'y~ no 'Sample Set W" Comments: Tuesday, May 30, 2000 Page 1 of 1 STATE OF ALASKA ALASI~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 28' RKB · 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service .~. Kuparuk River Unit 4. Location of well at surface: 8. Well number: 117' FNL, 996' FEL, Sec 3, T9N, RTE, UM 2N-337A At top of productive interval' 9. Permit number/approval number: 1848' FSL, 2328' FEL, Sec 4, T9N, R7E, UM 98-122/399-146 At effective depth: 10. APl number: 1820' FSL, 2547' FEL, Sec 4, T9N, R7E, UM 50-029-20262-01 At total depth: 11. Field/Pool: 1806' FSL, 2607' FEL, Sec 4, T9N, R7E, UM Kuparuk River Field / Tarn Oil Pool 12. Present well condition summary Total Depth: measured 10245 feet Plugs (measured) None true vertical 5465 feet Effective Depfl measured 10074 feet Junk (measured) None true vertical 5349 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 9 cu yds High Early 108' 108' Surface 2830' 7.625" 274 Sx AS III & 2858' 2311' 240 Sx Class G w/60 Sx AS I top job Production 9568' 5,5" 210 Sx Class G 9594' 5015' Liner 638' 3,5" Included in above 10232' 5456' Perforation Depth measured 9960'-10000' true vertical 5271'-5299' Tubing (size, grade, and measured depth) 3.5"", g.3 Ib/ft, L-80 EUE @ 9617' Packers and SSSV (type and measured depth) Pkr: Baker CSR @ 9594'; SSSV: None, nipple @ 504' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) ~$~ N/A Treatment description including volumes used and final pressure Installed jet pump in production well from 7/17/99 to 10/5/99. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Oil rate varies from 16 to 2200 depending on amount of paraffin in wellbore Prior to well operation 385 509 0 944 313 Approximate average, water is power fluid used Subsequent to operation 678 421 1524 1594 378 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~/~~ Title: Production Engineering Supervisor Date ~/Z~/~ '\ Form 10-404 Rev 0~/~ 5f88 SUBMIT IN DUPLICATE \ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 15, 1999 .'Vis. Wendy Mahan Natural Resource Manager ,Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re' Kuparuk Area Annular Injection. Third Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the third quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 1999. Annular Injection during the third quarter of 1999: i Total for Previous New h(1) ! h(2) h(3) ~ Well Name Volume Volume Volume I Quarter Total Total q'~- ~1 -: 1C-25 i 520 i 100 -13-- --6-2-0- 34316 , 34936 hq-q4 -, CD1-40 i 20079 I 100 [ 0 20179 12171 32350 ~ 4905 [ 100 0 I~ 5005 0 5005 q~l- .~ ~ -, CDI-O1 j ~q- ~ ~ 1C-23 '~ 24865 I i00 0 24965 9605 34570 ! 17273 ~ 0 ~ 17273 qq-~W - CD1-37 17173 i . 4~- ~o -. CD1-39 3917 ~ 100 0 ] 4017 [ 0 4017 ~- g4 - 1D-12 4305 Total Volumes into Annuli for which Injection Authorization Expired during the quarter Well Name Total h(1) Volume 1D-09 ~ 32540 Total h(2) Volume , 100 Total h(3) Volume , 0 Total Volume Injected 32640 Status of Annulus Open. Freeze Protected 2N-337A 30539 100 ~ 0 30639 Open, Freeze Protected 2N-313 ! 32758 ' 100 ! 0 32858 Open, Freeze Protected 2N-321A ! 27507 100 , 0 , 27607 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC' Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Enget / Snodgrass Morrison and Winfree Sharon Allsup-Drake Well Files Ms. Wendy Mahan AOGCC Third Quarter 1999 Annular Injection Report Page Two STATE OF ALASKA '--~: . ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend __ Operation Shutdown __ Reenter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance X Perforate__ Other__ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB) ARCO Alaska, Inc. Development X. 28' RKB feet 3. Address: Exploratory~ 7. Unit or Property: P.O. Box 100360 SIratagrapic ~ Anchorage, AK 99510-0360 Service ~ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 117' FNL, 996' FEL, Sec 3, T9N, R7E, UM 2N-337A At top of productive interval: 9. Permit number: 1848' FSL, 2328' FEL, Sec 4, T9N, R7E, UM 98-122 At effective depth: 10. APl number: 1820' FSL, 2547' FEL, Sec 4, T9N, R7E, UM 50-103-20262-01 At total depth: 11. Field/Pool: 1806' FSL, 2607' FWL, Sec 4, T9N, R7E, UM Kuparuk River Field/Tarn Oil Pool 12. Present well condition summary Total Depth: measured 10245 feet Plugs (measured) none true vertical 5465 feet Effective Depth: measured 10074 feet Junk(measured) none ~ J true vertical 5349 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 9 cu yds High Early 108' 108' Surface 2830' 7-5/8" 274sx AS III, 240sx CG, 60sx ASI 2858' 2311' Production 9568' 5.5" 210 Sx Gas Blok 9594' 5015' Liner 638' 3.5" Included above 10232' 5456' Perforation Depth measured 9960'-10000' true vertical 5271 '-5299' Tubing (size, grade, and measured depth) - t~ f~,--~""J ' 3-1/2", 9.3#, L-80, EUE tubing @ 9617' MD. ~¢.C,~(~ 01[ '-; ¢~' ~ f':m'~R Ai3chor~ Packers and SSSV (type and measured depth) Pkr: Baker CSR @ 9594' MD; SSSV: None, nipple @ 504' MD. 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: Install jet pump in well - July, 1999 Oil _X Gas __ Suspended __ 16. If proposal was verbally approved Blair Wondzell 7/15/99 Name o! approver Date approved Service 17. I hereby certify that the forgoing is true and correct to the best of my knowledge. Signed (~~)----~ ~ Title: Production Engineering Supervisor Date FOR COMMISSION USE ONLY Conditions of approval: Notify Oomission so representitive may witnessI ~ ¢..~)~ Plug integrety __ BOP test__ Location clearance __ .-,fo~lp--' ,.t Mechanical integrety test__ Subsequent form required 10- rpl~ove ~ by order of the Commission Robert N. Chdstenson Commissioner ~,a,t~e ............. '~ 10-403 Rev 06/15/88 Attachment 1 Install Jet Pump Tarn Well 2N-337A Well 2N-337A is located in the periphery of drill site 2N. The production history for Well 2N- 337A is characteristic of the 2N periphery producers, with intermittent production followed by periods of shut-in time. Well 2N-337A has averaged ~ 7,000 bbls/month oil production since the well was brought on-line 9/98, which ranks 14th among the existing fourteen 2N producers. Paraffin accumulation has been a consistent impediment to production, and has resulted in a complete tubing obstruction. The high deviation of Well 2N-337A is considered a contributing factor to wellbore cooling and consequent paraffin deposition. Testing of Well 2N-337A with gas lift indicates that the proposed jet pump installation will result in sustained production. The water injection test at drill site 2N provides an opportunity to utilize injection water as a power fluid source for a jet pump installation in production Well 2N-337A. The jet pump is a reverse circulation pump, and "hard line" with a check valve will tie the injection header to the production annulus. The jet pump will be installed in the production tubing at an open sliding sleeve at 9488', which will result in tubing by annulus communication. A variance for Well 2N-337A is requested for the 90 day period from July 15, 1999 to October 15, 1999 to test the jet pump application. Due to the existing practice of chemical treating injected water, the short duration of the jet pump test (- 90 days), and the low annulus injection rate (- 2,000 bwpd), the existing schedule for chemical treating of injection water is expected to be sufficient for the 90 day jet pump test. Produced water used for injection is currently treated with RU 275 at the Kuparuk production wells. In general, pitting and wall loss corrosion in flow lines typically can not be detected by inspection until a coupon indicates a wall loss of greater than ~ 10 mils/year for at least 2 years. The 1999 coupon data for Kuparuk CPF2 injectors indicates that the average coupon wall loss or pitting corrosion is - 1-2 mils/year. Based on this information, wall loss and pitting in the production annulus is not anticipated for the duration of the 90 day test. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs August 12, 1998 2N-337A, :~-MM-80247 1 LDWG formatted Disc with verification listing. API#: 50-103-20262-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries. Inc. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs August 12, 1998 2N-337A, AK-MM-80247 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of~ Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2N-337A: 2"x 5"MD Resistivity & Gamma Ray Logs: 50-103-20262-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20262-01 2" x 5" MD Neutron & Densi~ Logs: 50-103-20262-01 2" x 5" TVD Neutron & Density Logs: 50-103-20262-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia ---_~ _-3..3. F: 3 '"' ' ',:i~ & Gas C. cns. Commission 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. 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 __ Annular Iniection 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 117' FNL, 996' FEL, Sec. 3, T9N, R7E, UM At top of productive interval 1857' FSL, 2426' FEL, Sec. 4, T9N, R7E, UM At effective depth At total depth 1827' FSL, 2645' FEL, Sec. 4, T9N, R7E, UM 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) 28' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2N-337A 9. Permit number 98-122 10. APl number 50-103-20262-01 11. Field/Pool Kuparuk River/Tarn Pool feet 12. Present well condition summary Total Depth: measured (approx) true vertical 12245' 5464' feet feet Plugs (measured) None Effective depth: measured (approx) true vertical Casing Length Structural Conductor 80' Surface 2830' Intermediate Production 10204' Liner 10O73' 5086' Size 16" 7.625" 5.5'x 3.5" feet feet Junk (measured) Cemented Measured depth True vertical depth 103 sx AS I 108' 108' 274 sx AS III LW 2858' 2310' & 240 sx Class G & 60 sx AS I 210 sx Class G 10232' 5200' Perforation depth: measured NONE true vertical 0RI61NAL Tubing (size, grade, and measured depth) RECEIVED JUL O9 1998 3.5', 9.3#, 9617' MD Packers and SSSV (type and measured depth) NONE L!uATF- Aiaska Oii & Gas 6o.s. Anchorage 13. Attachments Description summary of proposal Contact James Trantham at 265-6434 with any questions. Detailed operation program __ BOP sketch m LOT test, surface cement details and casing detail sheets _~X 14. Estimated date for commencing operation July 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas _ Service Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I ~ ~ ~ FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance __ Mechanical Integrity Test_ Subsequen~form require 10- '.~13.ff - ~,~w~,, drlglnal'~lCn~a ~,Y.~¢ ~ David W. Johnston IA pproval N~~) ..../p~ I Approved by the order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 . · Approved Copy SUBMIT ,F/~FRIFLI&ATE Operation Shutdown ~ Re-enter suspended well ~ Plugging ~ Time extension ~ Stimulate_ Pull tubing~ Variance~ Perforate~ Other X ,/ 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 _ Operation Shutdown __ Re-enter suspended well _ Plugging __ Time extension_ Stimulate _ Pull tubing __ Vadance _ Perforate_ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 117' FNL, 996' FEL, Sec. 3, T9N, R7E, UM At top of productive interval 1032' FSL, 2421' FEL, Sec. 4, T9N, R7E, UM At effective depth At total depth 937' FSL, 2587' FEL, Sec. 4, T9N, R7E, UM 5. Type of Well: Development Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) 28' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2N-337 9. Permit number 98-102 10. APl number 50-103-20262 11. Field/Pool Kuparuk River/Tarn Pool feet 12. Present well condition summary Total Depth: measured (approx) true vertical ~Effective depth: measured I "'~'-. Cas'~g Length I ~ctural Conductor 80' Surface 2830' Intermediate Production Liner 10655' 5497' 7O0O' 3800' Size 16" 7.625" feet feet feet feet Plugs (measured) None Junk (measured) Cemented 103 sx AS I 231 sx AS III LW & 60 sx Class G Measured depth 108' 2858' True vertical depth 108' 2310' Perforation depth: measured NONE true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal X Contact James Trantham at 265-6434 with any questions_. Detailed operation program X BOP sketch__ 14. Estimated date for commencing operation June 1998 16. If proposal was verbally approved Name of approver {~{ O,~ ~lo, ~ ~')~ Date approved I Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ~-_M ~/ (~.(¢ ¢. i?./[4,~,~(,;,,' Title Kuparuk Ddllinq Team Leader · -/ '~ FOR COMMISSION USE ONLY 15. Status of well classification as: Oil Gas _ Date Suspended X_~_ Conditions of approval: Notify Commission so re repzgse__ntative may witnE Plug integrity _-./" B est _ n cle~ Mechanical I ntegdt~--~~req~ Approved by the order of the Commission Form 10-403 Rev 06/15/88 S Commissioner Date SUBMIT tN/T~PLICATE ARCO Alaska, Inc. Cementing Details Well Name: 2N-337 Report Date: 06/07/98 Report Number:. 9 Ri~l Name: DOYEN 141 AFC No.: AK9493 Field: Tarn I I Casing Size Hole Diameter: I Angle thru KRU: Shoe Depth: I LC Depth: % washout: 7-5/8 9-7/8I n/a 2858J 2733 Centralizers State type used, intervals covered and spacing !Comments: Ran 31 Gemeco 7-5/8" x 9-7/8' bow spring centralizers. Placement on casing detail. Mud Weight: PV(prior cond): PV(after con(I): YP(prior cond): YP(after cond): Comments: 10.2 19 19 24 22 Gels before: Gels after: Total Volume Circulated: 10/14 9/13 680 bbls Wash 0 Type: Volume: Weight: Comments: Spacer 0 Type: Volume: Weight: Comments: ARCO 30 10.5 Lead Cement 0 Type: Mix wlr tamp: No. of Sacks: I Weight: Yield: I comments: AS III LW 70 43I 10.5 4.42 1st stage Additives: Additives: 1% Sl, 0.3% D65, 0.2% D46 : Displacement O Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 7.5 bpm '8.0 85 Reciprocation length: Reciprocation speed: Sir. Wt. Down: '15 90 fpm 63 Theoretical Displacement: Actual Displacement: Str. Wt. in mud:. 125.4 bbls 127.5 76 Calculated top of cement: CP: Bumped plug: Floats held: 1450 Date:06/06/98 Yes Yes Tim e:1520 hrs Remarks:Staged pumps up to 8.2 bpm and cond. mud, pretreated mud for cement contamination. Pumped 30 bbls of spacer, 34 bbls of lead and 50 bbls of tail cement. Displaced with 30 bbls fresh water, 22 bbls of mud, 35 bbls of spacer and 40 bbls of mud. Bumped plug to 1500psi, floats held. Pressured up to 3400 psi with rig pumps, no response, bled off pressure. Switched back to Dowell and tool opened on second attempt w/3280 psi. @ 1541 hrs. Displaced annulus above stage collar @ 6 bpm, circulated out cement contaminated mud and 8 bbls of cement. Increased rate to 8.5 bpm and conditioned mud for second stage. , Cement Company: I Rig Contractor: IApproved By: DS I DOYEN I D.Burley ARCO Alaska, Inc. Cementing Details Well Name: 2N-337 Report Date: 06/08/98 Report Number: 10 Ri~l Name: DOYON 141 AFC No.: AK9493 Field: Tarn i Casing Size HoPe Diameter: Angle thru KRU: Shoe Depth: I LC Depth: % washout: 7-5/8" 9-7/8" na 2858I 2733 Centralizers State type used, intervals covered and spacing Comments: Mud Weight: PV(prior cond}: PV(after cond): I YP(prior cond): YP(after cend): Comments: 10.1 19 19I 22 17 Gels before: Gels after:. Total Volume Circulated: 9113 7/10 780 Wash 0 Type: Volume: 'Weight: Comments: Spacer 0 Type: Volume: Weight:. Comments: ARCO 30 bbls 10.5 2nd Stage Lead Cement 0 Type: I Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: AS III LWI 70 231I 10.5 4.42 2nd Stage Additives: Comments:I I ! I 70 60 15.7 0.93 2nd stage ASI : Additives: Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 8 bprn 4 bpm na Reciprocation length: Reciprocation speed: Str. Wt. Down: Did not reciprocate 2nd stage, na Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 66.5 bbl 68.1 Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:6-8-98 yes Stage tool closed Time: Remarks:Pumped 30 bbls of spacer, Lead cement untill returns to surface(182 bbls) and 10 bbls of tail cement. Displaced with 30 bbls of fresh water followed by 38.1 bbls of mud, had 80 bbls of cement returns to surface. Bumped plug, stage tool closed @ 1480 psi, increased pump pressure to 2000 psi. Bled off casing, confirmed tool closed. Also, placed spacer across DY tool during dispacernent of 1st stage so when the DV tool was opened, there would not be a mud to cement Interface (clabbered mud has packed off at the wellhead/fiowline in the past). , CementDs Company: I RigDOYoNCOntractor: I D.BurleyJAppr°ved By: I Casing Detail 7-5/8" Surface Casing ^RCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL: TARN 2N-337 DATE: 6/08/98 1 OF I PAGES # ITEMS jts. 34-66 Lock B Lock A )ts. 3-33 jts 1-2 COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 141 RKB to Pad = 29.25' Above RKB 7 5/8" Landing Joint 34' OA. FMC GEN V- Prudhoe 7 5/8" Csg Hgr 7 5/8", 29.7#, L-80 BTC-MOD 7 5/8", 29.7#, L-80 BTC-MOD (Thread Locked Collar) JT. #79 Gemeco 7 5/8" Stage Collar (BAKERLOIC) 7 5/8", 29.7#, 1_-80 BTC-MOD (Thread Locked Collar) JT. #78 7 5/8",29.7#, L-80 BTC-MOD (shutoff baffle on top of~t #3, BAKE Gemeco Float Collar 7 5/8", 29.7#, L-80 BTC-MOD Gemeco Float Shoe 31 Gemeco Bow Spring CENTRAUZERS Run centralizers in center of Jts. 1, 2, 78, 79 over stop collars and over casing collars on Jts. 3 thru 12 and over collars of jts. 15,18,21,24,27,30,36,39,42,45,48,51,54,57,60, 63 and 65 Joints 67-77 (11 joints) will remain in the pipe shed. Remarks: String Weights with Blocks: 80K# Up, 65K# Dn, 20k# Blocks. Ran 68 LENGTH 29.25 2.70 1377.52 40.85 DEPTH TOPS 29.25 31.95 1409.47 2.70 1450.32 40.99 1453.02 1280.52 1494.01 1.32 81.05 1.49 2774.53 2775.85 2856.90 2858.39 oints of casing. Drifted casing with 6.750 plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is nan-coated. Doyon 141 Drilling Supervisor: D.P. BURLEY CASING TEST and FORMATION INTEGRITY TEST Well Name: TARN 2N-337 Date: 6/16/98 Supervisor: R.W. SPRINGER Casing Size and Description: Casing Setting Depth' Mud Weight: 10.1 ppg Hole Depth: 2,310' TVD 7 5/8", 29.7 ppf, L-80, BTC 2,858' TMD 2,310' TVD EMW = Leak-off Press. + MW 0.052 x TVD LOT DONE @6977' M.D.,3781' T.V.D. 310 psi + 10.1 ppg LOT = (0.052 x 2,310') = 12.7 ppg Fluid Pumped = 1.7 bbl Pump output = 0.1010 bps Shut Down pump after 17 strokes, total bled back at completion of test 1.5 bbls. 400 psi 350 psi 30O psi 250 psi i,M 150 psi 100 psi psi 0 psi 0 stks 1 stks 2 stks 3 stks 4 stks 5 stks 6 stks 7 stks 8 stks 9 stks LEAK-OFF TEST CASING TEST 10 11 12 13 14 15 16 17 18 19 20 stks stks stks stks stks stks stks stks stks si'ks stks STROKES CASING TEST and FORMATION INTEGRITY TEST Well Name: TARN 2N-337 Date: 6/10/98 Supervisor: R.W. SPRINGER Casing Size and Description: Casing Setting Depth: Mud Weight: 9.0 ppg Hole Depth' 2,322' TVD 7 5/8", 29.7 ppf, L-80, BTC 2,858' TMD 2,310' TVD EMW = Leak-off Press. + MW 0.052 x TVD 850 psi + 9.0 ppg LOT = (0.052 x 2,322') = 16.0 ppg Fluid Pumped = 1.2 bbl Pump output = 0.1010 bps Shut Down pump after 11 strokes, total bled back at completion of test 1.1 bbls. 2, 200 psi 2,000 psi 1,800 psi 1,600 psi 1,400 psi 1.1.1 1,200 psi ~ 1,000 psi 800 psi 600 psi 4O0 psi 200 psi 0 psi 0 stks --e-- LEAK-OFF TEST '-e--CASING TEST 1 stks 2 stks 3 stks 4 stks 5 stks 6 stks 7 stks 8 stks 9 stks 10 stks 11 stks 12 stks 13 stks 14 stks 15 stks STROKES ,-(,: Jet Pump Approval Request Subject: Re: Jet Pump Approval Request Date: Thu, 15 Jul 1999 15:58:48-0800 From: Blair Wondzell <Blair_Wondzell~admin.state.ak.us> To: Erickson&Versteeg <N 1177~mail.aai.arco.com> CC: Dobson&Sloan <N 1127@mail.aai.arco.com>, Beck&Zuspan <N1052~mail.aai.arco.com>, Ryan L Stramp <RSTRAMP~mail.aai.arco.com>, Goldmann&Hill <N 1297~mail.aai.arco.com> Hans, Thanks for visiting with me this afternoon on this situation. As I understand that you have only two pipelines to Tarn, one for production and the other for lift gas or injection. Since you will need the line for injection, if the for four subject wells are to be lifted during the test it will have to be with the jet pumps, powered by water. We agree this is a reasonable approach and that your efforts should reduce casing corrision to an acceptable level. Therefore testing jet pumps powered by injection water during the Tarn water injection test is acceptable. Blair Wondzell, 7/15/99 Erickson&Versteeg wrote: Blair, Per our phone conversation 7/12/99, verbal approval is requested to proceed with the planned jet pump installations at Tarn. Verbal approval is requested since the opportunity to test the jet pumps is limited to the duration of the Tarn water injection test,. Sundry requirements for the jet pump test were not anticipated, and the issues outlined in the sundry request were only recently recognized. Approval is requested to install jet pumps in wells 2N-319, 2N-335, 2N-33_~TA, and 2N-34.__5 during the ~ 90 day period ending October 15, 1999. Water from the Tarn M.I header will be injected down the 5-1/2" X 3-1/2" production annulus as power fluid for the "reverse circulation" TRICO jet pump. The jet pump will be installed in the 3-1/2" tubing sliding sleeve, which will allow water entry from the annulus to the tubing. This will result in tubing by. annulus communication. A variance is requested for the duration of the test. Due to the existing practice of chemical treating injected water, the short duration of the jet pump test (- 90 days), and the iow annulus injection rate 2,000 bwpd), the existing schedule for chemical treating of injection water is expected to be sufficient for the 90 day jet pump test. Produced water used for injection is currently treated with RU 275 at the Kuparuk production wells. In general, pitting and wall loss corrosion in flow lines typically can not be detected by inspection until a coupon indicates a wall loss of greater than ~ 10 mils/year for at least 2 years. The 1999 coupon data for Kuparuk CPF2 injectors indicates that the average coupon wall loss or pitting corrosion is - 1-2 mils/year. Based on this information, wall loss and pitting in the production annulus is not anticipated for the duration of the 90 day test. Joe Versteeg (907) 659-7687 1 of I 7/15/99 4:00 PM Iet pUmp Approval Request Subject: Jet Pump Approval Request Date: Tue, 13 Jul 1999 16:27:19-0900 From: "Erickson&Versteeg" <N 1177@mail.aai.arco.com> To: blair_wondzell@admin.state.ak.us CC: "Dobson&Sloan" <N1127~mail.aai.arco.com>, "Beck&Zuspan" <N 1052@mail.aai.arco.com>, "Ryan L Stramp" <RSTRAMP@mail.aai.arco.com>, "Goldmann&Hill" <N 1297@mail.aai.arco.com> Blair, Per our phone conversation 7/12/99, verbal approval is requested to proceed with the planned jet pump installations at Tarn. Verbal approval is requested since the opportunity to test the jet pumps is limited to the duration of the Tarn water injection test,. Sundry requirements for the jet pump test were not anticipated, and the issues outlined in the sundry request were only recently recognized. Approval is requested to install jet pumps in wells 2N-319, 2N-335, 2N-337A, and 2N-345 during the ~ 90 day period ending October 15, 1999. Water from the Tarn MI header will be injected down the 5-1/2" X 3-1/2" production annulus as power fluid for the "reverse circulation" TRICO jet pump. The jet pump will be installed in the 3-1/2" tubing sliding sleeve, which will allow water entry from the annulus to the tubing. This will result in tubing by annulus communication. A variance is requested for the duration of the test. Due to the existing practice of chemical treating injected water, the short duration of the jet pump test (~ 90 days), and the low annulus injection rate (~ 2,000 bwpd), the existing schedule for chemical treating of injection water is expected to be sufficient for the 90 day jet pump test. Produced water used for injection is currently treated with RU 275 at the Kuparuk production wells. In general, pitting and wall loss corrosion in flow lines typically can not be detected by inspection until a coupon indicates a wall loss of greater than - 10 mils/year for at least 2 years. The 1999 coupon data for Kuparuk CPF2 injectors indicates that the average coupon wall loss or pitting corrosion is ~ 1-2 mils/year. Based on this information, wall loss and pitting in the production annulus is not anticipated for the duration of the 90 day test. Joe Versteeg (907) 659-7687 1 of I 7/13/99 4:52 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well o,, [] ~AS i--I SUSPENDED r-I ^B^NDONE© SERWCE I--I 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-122 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20262-01 4 Location of well at surface~i~~'"~'~"~m'"~e~i' -~ 9 Unit or Lease Name 117'FNL, 996'FEL, Sec. 3, T9N, R7E, UM ";-'"-':'~:;'~'~:'~u~; ;~ Kuparuk River Unit At Top Producing Interval_ .....~'}"-~i~"~' ....[1~,_¢~"~'1" ~ ' h~}~ ''-' !¢ i:~i 10 Well Number -; .,.~.~.}~:i~1848' FSL 2328'FEL Sec4 T9N R7E UM 2N-337A At Total Del:th ~ 11 Field and Pool 1806' FSL, 2607' FWL, Sec. 4, T9N, R7E, UM ............... KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. Tarn Pool RKB 28', Pad 121'I ADL 375074 ALK 4293 12 Date06.Jun.98Spudded 13 Date18-Jun-98T'D' Reached 14 Date19-Jun-98C°mp', Susp. or Aband. 15 WaterNADepth, if offshorefeet MSL 16 No.1 of Completions 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 10245' MD & 5465' TVD 10074' MD & 5349' TVD YES M NO U NA feet MD 1222' APPROX 22 Type Electric or Other Logs Run GR/Res, Neutron 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58# H-40 SURF. 108' 24' 9 cu. Yds High Eady 7.625" 29.7# L-80 SURF. 2858' 9.875' 274 sx AS III LW, 60 sx AS I, 240 sx Class G 5.5' x 15.5# L-80 SURF. 9594' 6.75' 210 sx Gas Blok 3.5' 9.3# L-80 9594' 10232' 6.75' (included above) 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9617' 9594'(CSR) 9960'-10,000' MD 5271'-5299' TVD 4 spT 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9960'-10,000' 213,406# proppant placed in formation with 15,389# proppant left in pipe 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 8/13/98I Flowing Date of Test Hours Tested PRODUCTION FOI OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 8/31/9E 13.00 TEST PERIOI: 87'1 889 '12 176I 1021 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBl. OIL GRAVITY-APl (corr) Press. 120 0 24-HOUR RATE: 472 482 12 0 28 CORE DATA Bdef description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL N/A Form 10-407 Submit in duplicate Rev. 7-'1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Total pump volumes for this event: Category 1. 13978 Category 2. 100 · Top of Reservoir (f3) 9766' 5135' Category 3. 0 Bose of Reservoir (T2) 10023' 5315' Total: 14078 Total to Date: 14078 Annulus left open - freeze protected with diesel. 31. LIST OF ATrACHMENTS Summary of Daily Drilling Reports, Directional Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~'~O.~ ~)4~3~.~,~ Title ~,~G T~'t~ ~""~"/~. DATE Prepored by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 8/4/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-337 WELL ID: AK9493 TYPE: _ STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:06/06/98 START COMP: RIG:RIG % 141 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20262-00 05/30/98 TD: 80' SUPV:DB D1) 8O) MW: 0.0 VISC: moving rig 0 PV/YP: 0/ 0 Move rig from 2N-339 to 2N-337. APIWL: 0.0 05/31/98 TD: 80' SUPV:DB D2 0) MW: 0.0 VISC: 0 PV/YP: 0/ 0 Road repair, rig maintenance APIWL: 0.0 Move rig over 2N-337. Accept rig @ 0800 hrs. 5/31/98. Delay spudding well due to road repair. Crews performing rig maintenance and cleaning. 06/01/98 TD: 80' SUPV:DB D3 MW: 0.0 rISC: 0 PV/YP: 0/ 0 Rig maintenance, road repair APIWL: 0.0 Proceed with rigs schedules summer maintenance, due to stand down for road repair 06/02/98 TD: 80' SUPV:DB D4 MW: 0.0 VISC: 0 PV/YP: 0/ 0 Rig down due to road maintenance Continue to wait on road repairs. APIWL: 0.0 06/03/98 (D5 TD: 80' SUPV:DB 0) MW: 0.0 rISC: 0 PV/YP: 0/ 0 Rig maintenance and road repair Rig on standby for road repair. APIWL: 0.0 06/04/98 TD: 80' SUPV:DB D6 MW: 0.0 VISC: 0 PV/YP: 0/ 0 Rig on standby for road repair APIWL: 0.0 Rig on standby for road repairs, performing summer maintenance and cleaning rig. 06/05/98 TD: 80' SUPV:DB D7 MW: 0.0 VISC: Mixing spud mud. 0 PV/YP: 0/ 0 APIWL: 0.0 Continued with rig maintenance. 06/06/98 TD: 1317' SUPV:DB DS) 1237) MW: 10.2 VlSC: 80 PV/YP: 10/53 Drill 9-7/8" hole from 1900' APIWL: 11.2 Spud @ 0930 hrs., drilled 9-7/8" hole from 108' to 294' Unable to obtain toolface while sliding. Reprogram tool. Drill 9-7/8" hole from 294' to 1317' Encountered hydrates @ 1220' 06/07/98 TD: 2868' SUPV:DB D9) 1551) MW: 10.3 VISC: 50 PV/YP: 19/26 RU to run 7-5/8" casing APIWL: 5.8 Drill 9-7/8" hole from 1317' to 2868'. Background gas reduced. 06/08/98 (D10) TD: 2868' 0) SUPV:DB NU BOPE MW: 10.1 VISC: 46 PV/YP: 19/17 Run 7-5/8" casing. Pump cement. ND diverter. APIWL: 5.4 06/09/98 TD: 2868' SUPV:RWS Dll) 0) MW: 9.1 VISC: 43 PV/YP: 19/13 Drilling float shoe N/U BOPE and test. RIH w/6.75" drill collar. APIWL: 7.2 06/10/98 TD: 3550' SUPV:RWS D12) 682 MW: 9.0 VISC: 49 PV/YP: 18/17 RIH w/new bit APIWL: 6.8 Drilled cement and stage tool. Wash and ream from 2679' to 2722' Drilled float equipment and 20' new hole. Perform FIT to 16.0 pg EMW. Drilled from 2888' to 3550' 06/11/98 TD: 5071' SUPV:RWS D13) 1521 MW: 9.1 VISC: 50 PV/YP: 15/18 Drilling @ 5615' Drilled from 3550' to 5071' APIWL: 6.0 06/12/98 TD: 7041' SUPV:RWS D14) 1970 MW: 9.1 VISC: 52 PV/YP: 15/20 Drilling @ 7650' APIWL: 6.2 Drilled from 5071' to 7041' No problems hole in good shape. 06/13/98 TD: 9228' SUPV:RWS D15) 2187 MW: 9.2 VISC: 50 PV/YP: 12/16 Drilling @ 9770' Drill from 7041' to 9228' Hole in good shape. APIWL: 6.0 06/14/98 TD:10655' SUPV:RWS 06/15/98 TD:10655' SUPV:RWS D16) 1427 D17) 0 MW: 10.0 VISC: 48 PV/YP: 13/17 Downloading LWD APIWL: 4.8 Drilled from 10136' to 10655' MW: 10.1 VISC: 52 PV/YP: 15/20 RIH w/drilling assy to tag cement APIWL: 4.8 POH to BHA. Spot hi-vis pill from 10650-10350'. Pump cement balanced plug from 10350-10050' 06/16/98 TD: 6977' SUPV:RWS D18) 0 MW: 9.7 VISC: 49 PV/YP: 13/23 Attempting to kickoff off sidetrack @ 7000' APIWL: 5.4 Pump balanced plug from 7250'-6950'. Wash from 6790'-6890' Drill cement from 6890'-6977'. Test BOPE to 250/3500 psi. Perform LOT to 12.7 ppg EMW. 06/17/98 TD: 8795' SUPV:RWS D19) 1818 MW: 9.2 rISC: 46 PV/YP: 15/15 Drilling Drilled from 6977'-8795' APIWL: 5.8 06/18/98 (D20) TD:12245' (3450 SUPV: RWS MW: 10.0 VISC: 49 PV/YP: 20/24 POH L/D Drillpipe Drilled from 8795' to 10245' APIWL: 4.0 06/19/98 TD:12245' SUPV:RWS D21) 0 MW: 8.5 VISC: 0 PV/YP: 0/ 0 Cementing 5.5" x 3.5" casing Run 3.5" tubing. Run 5.5" casing. APIWL: 0.0 06/20/98 TD:12245' SUPV:RWS D22) 0 MW: 0.0 VISC: N/U master flange 0 PV/YP: 0/ 0 APIWL: 0.0 Continue RIH w/5.5" casing. Pump cement. Install 9.625" x 5.5" packoff and test to 5000~. Run 3.5" tubing. Test casing to 3500 psi. 06/21/98 TD:12245' SUPV:RWS D23) 0 MW: 0.0 VISC: Rig moved and accepted 0 PV/YP: 0/ 0 APIWL: 0.0 N/D BOPE and freeze protect annulus. NU master valve. Secure well. Released rig @ 1500 hrs. 6/21/98, Move rig from 2N-337A to 2N-341. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~' Kl(2N-337A(W4-6)) WELL JOB SCOPE JOB NUMBER 2N-337A FRAC, FRAC SUPPORT 0730981452.2 DATE DAILY WORK UNIT NUMBER 08/03/98 TARN SAND FRACTURE STIMULATION DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES DS-GALLEGOS JORDAN FI ELD AFC# CC# Signed ESTIMATE K85114 180KNU2TN InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann , Initial Outer Ann I Final Outer Ann 568 PSI 0 PSI 46 PSl 500 PSII 1240 PSI 240 PSI DAILY SUMMARY TARN SAND FRACTURE STIMULATION SCREENED OUT EARLY WITH 7 PPA ON PERFS. 213,406 LB PROPPANT PLACED IN FORMATION WITH 15,389 LB PROPPANT LEFT IN PIPE. MAX TREATING PRESSURE 7596 PSl.[Frac-Refrac] TIME LOG ENTRY 07:00 MIRU DS FRAC UNIT - GALLAGOS; LRS; APC. TGSM WITH 17 ON LOCATION. PT LINES TO 9270 PSI OK. 09:27 PUMP HIGH RATE BD 7361 PSI / 25.6 BPM, 5754 PSI / 29.4 BPM. SD ISIP 582 PSI. 10:28 PUMP DATA FRAC WITH OVERFLUSH AT 15 BPM. SD ISIP 712 PSI. 12:06 PUMP BREAKDOWN, 1 PPA SCOUR STAGE. CANCEL 2 PPA SCOUR STAGE. SD ISIP 783 PSI. 14:04 PUMPED TARN SAND FRACTURE STIMULATION. SCREENED OUT EARLY WITH 7 PPA ON PERFS. 213,406 LB PROPPANT PLACED IN FORMATION WITH 15,389 LB PROPPANT LEFT IN PIPE. MAX TREATING PRESSURE 7596 PSI. 19:00 RDMO DS FRAC UNIT. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~' K1(2N-337A(W4-6)) WELL JOB SCOPE JOB NUMBER 2N-337A PERFORATE, PERF SUPPORT 0719981445.3 DATE DAILY WORK UNIT NUMBER 07/30/98 PERFORATE 8305 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 4 YESI YES SWS-ELMORE JONES FIELD AFC# CC# Signed ESTIMATE K85114 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 50 PSI 450 PSI 50 PSI 450 PSII 300 PSII 260 PSI DAILY SUMMARY ISWS PERFED FROM 9960' TO 10,000' IN 2 RUNS W/2.5" HC, BH, 4SPF, 180 DEG PHASED, 90 DEG ORIENT. HADTO PUMP GUNS DOWN @ 4 BPM FROM 2500' TO 9600'. PERFED USING 1000 PSI WHP.[Perf] LOG ENTRY TIME 08:00 SWS & LRS MIRU, HELD TGSM. ARMED GUN & PT LUB TO 3000#. 09:15 MIH W/20' - 2.5" HC, BH, 4 SPF, 180 DEG PHASED, 90 DEG ORIENT, MPD, SAFE, CCL. PUMPED DOWN GUNS W/DIESEL @ 2.5 BPM, 1000 PSI, UNABLE TO GET PAST 2650'. PULLED UP TO 2200'. 10:15 LRS RU HARD LINE & PT SAME TO 3200#. 10:45 CONT'D TO MIH W/GUN, PUMP W/DIESEL @ 4 BPM, 1500 PSI. SHUT DOWN PUMP @ 9600'. CORR TO SWS GR/CCL LOG 7-27-98. PERFED FROM 9980' TO 10,000' USING 950 PSI WHP. 13:00 POH & LD GUN, ALL SHOTS FIRED. 14:00 MU GUN & PT LUB TO 3000#. 14:15 MIH W/20'- 2.5" GUN AS ABOVE. PUMPED GUN DOWN W/DIESEL FROM 2500' TO 9600' @ 4 BPM, 1500 PSI. CORR TO ABOVE LOG & PERFED FROM 9960' TO 9980' USING 1000 PSI WHP. 16:00 POH & LD GUN, ALL SHOTS FIRED. 17:00 SWS & LRS RIG DOWN. 17:30 RELEASED SWS & LRS. rl ij j[ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-98287 Sidetrack No. 1 Page 1 of · _= [l[~ ~ I :~ Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #141 Field TARN DEVELOPMENT FIELD ,r~ Well Name & No. TARN DRILLSITE 2N/337 Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN ee ~ ~ ~,~ WELL DATA Target'l'VD (F'r) Target Coord. N/S Slot Coord. N/S -115.74 Grid Correction 0.000 Depths Measured From: RKB ~ MSL0 SS0 Target Description Target Coord, E/W Slot Coord, E/W -996.31 Magn, Declination 27.080 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: 100ft[~ 30m~ 10mi-'l Vert. Sec, Azim, 262.24 Magn, to Map Corr, 27.080 Map North to: OTHER ! SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Type Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL (FI') (DD) (DD) (FT) (F-D (F'r) (F'3) (Per 100 F~ Drop (-) Left (-) .._ MWD 6967.74 68.30 239,45 3778,24 4593.77 -2766,90 -4258,31 TIE IN POINT I 16-JUN-98 MWD 7000,00 68.19 239,42 32,26 3790,20 4620,53 -2782,14 -4284,11 0,35 -0,34 -0.09 KICKOFF POINT - INTERPOLATED i 17-JUN-98 MWD 7090,04 67.83 241.20 90,04 3823.91 4697,98 -2823,49 -4356,63 1,88 -0,40 1.98 4 3/4' MlXL 1,2 DEG AKO 17-J UN-98 MWD 7178,17 63,47 247,15 88,13 3860,27 4774,22' -2858,50 -4428,81 7,89 -4.95 6.75 17-JUN-98 MWD 7274.43 62.80 248.08 96.26 3903.77 4857.31 -2891.20 -4508.21 1.11 -0.70 0.97 17-JUN-SS aWE 7367,07 63,44 250.00 92,64 3945,66 4937.75 -2920,76 -4585,37 1,97 0.69 2,07__ ~__ ~' 17-JUN-98 MWD 7461.70 65.50 251.86 94.63 3986.44 5021.48 -2948.64 -4668.07 2.81 2.18 1.97 17-JUN-98 MWD 7556.57 66.94 254.78 94.87 4024.70 5107.23 -2973.54 -4749.22 3.20 1.52 3.08 .., UWD 0. S -0.0 17-JUN-98 MWD 7746.43 66.50 256.95 93.81 4099.49 5280.59 -3016.63 -4918.31 1.42 -0.41 1.48 ! · I V I J ~ ~ L,~ 17-J u N-98 MWD 7842.18 65.78 258.59 95.75 4138.23 5367.89 -3035.18 -5003.89 1.74 -0.75 1.71 17-J UN-98 MWD 7937.53 66.74 261.35 95.35 4176.62 5455.09 -3050.37 -5089.83 2.83 1.01 2.89 17-JUN-98 MWD 8027,53 67.86 260.75 90.00 4211,35 5538,10 -3063,29 -5171,84 1.39 1,24 -0,67 17-JUN-98 MWD 8122,70 66.72 259,09 95,17 4248.09 5625,81 -3078,65 -5258,27 2,01 -1,20 -1,74 17-JUN-98 MWD 8215,73 66,82 257,80 93,03 4284,79 5711,11 -3095,77 -5342,03 1,28 0,11 -1,39 17-JUN-98 MWD 8309,93 64,90 256,41 94,20 4323,31 5796,72 -3114,95 -5425,81 2,44 -2,04 -1,48 17-J U N-98 MWD 8404.73 65.41 257,39 94,80 4363,14 5882,37 -3134,45 -5509,60 1,08 0,54 1,03 17-JUN-98 MWD 8499,80 64,79 259,40 95.07 4403,18 5968,40 -3151,79 -5594,06 2.03 -0.65 2,11 17-JUN-98 MWD 8593,27 62,62 260,19 93,47 4444,58 6052.12 -3166,64 -5676,53 2,44 -2,32 0,85 17-JUN-98 MWD 8687,32 59.88 259,62 94,05 4489.81 6134.50 -3181,09 -5757,70 2.96 -2,91 -0,61 18-J UN-98 MWD 8779.53 59,64 259.20 92.21 4536,25 6214,06 -3195,73 -5836,01 0,47 -0.26 -0.46 18-JUN-98 MWD 8874,52 58,75 260,19 94.99 4584.90 6295,57 -3210.33 -5916,28 1.30 -0.94 1.04 18-JUN-98 MWD 8968,52 57,34 261.38 94,00 4634,65 6375.29 -3223.11 -5995,00 1.84 -1,50 1.27 18-JU N-98 MWD 9063,45 56,41 261,92 94.93 4686,52 6454,79 -3234,65 -6073.66 1,09 -0,98 0.57 i i I SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-98287 Sidetrack No. 1 Page 2 of _.2 ~ Company ARCO ALASKA, INC. Rig Contractor & No. Do~/on Drilling Co. - #141 Field TARN DEVELOPMENT FIELD _ Well Name & No. TARN DRILLSITE 2N/337 Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN ¢ i ~I~~~ WELL DATA , , Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -115.74 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/W -996.31 Magn. Declination 27.080 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: lOOftr~ 30m[-J 1om0 Vert. Sec. Azim. 262.24 Magn. to Map Corr. 27.080 Map North to: OTHER ,' S~RVEY DATA ' ' Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) (F'T) (F'r) (F'~ (FT) (Per lO0. FT)Drop (-) Left (-) ,, 18-JUN-98 MWD 9157.26 54.70 263.04 93.81 4739.58 6532.15 -3244.79 -6150.35 2.07 -1.82 1.19 18-J UN-98 MWD 9250.36 52.49 262.69 93.10 4794.83 6607.07 -3254.09 -6224.69 2.39 -2.37 -0.38 18-JUN-98 MWD 9345.78 50.96 263.40 95.42 4853.94 6681.97 -3263.16 -6299.05 1.71 -1.60 0.74 18-J UN-98 MWD 9440.07 50.29 261.75 94.29 4913.76 6754.85 -3272.58 -6371.32 1.53 -0.71 -1.75 18-JUN-98 MWD 9534.71 48.45 262.09 94.64 4975.38 6826.67 -3282.68 -6442.43 1.96 -1.94 0.36 18'JUN-98 MWD 9629.79 46.72 259.51 95.08 5039.52 6896.83 -3293.87 -6511.71 2.71 -1.82 -2.71 ...... 18-JUN-98 MWD 9720.74 44.97 262.09 90.95 5102.88 6962.05 -3304.33 -6576.11 2.80 -1.92 2.84 18-JUN-98 MWD 9814.71 45.02 262.92 93.97 5169.33 7028.49 -3312.99 -6641.98 0.63 0.05 0.88 18-J UN-98 MWD 9908.59 45.64 262.71 93.88 5235.33 7095.25 -3321.34 -6708.22 0.68 0.66 -0.22 18-JUN-98 MWD 10002.97 46.44 262.75 94.38 5300.84 7163.18 -3329.94 -6775.61 0.85 0.85 0.04 18-JUN-98 MWD 10096.83 47.22 263.24 93.86 5365.06 7231.63 -3338.29 -6843.55 0.91 0.83 0.52 18-JUN-98 MWD 10169.72 48.04 263.83 72.89 5414.18 7285.47 -3344.35 -6897.06 1.27 1.12 0.81 18-JUN-98 MWD 10245.00 48.04 263.83 75.28 5464.51 7341.42 -3350.37 -6952.71 0.00 0.00 0,00 Projected Data - NO SURVEY 'i'I ,,, ii iii Bi i ii TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION June 17. 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Paul Mazzolini. Tarn Drilling Tcam Supr. ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2N-337A ARCO Alaska. Inc. Permit No.: 98-122 Sur. Loc.: 117'FNL, 996'FEL, Sec. 3, T9N, R7E. UM Btmhole Loc: 1827'FSL, 2645'FEL. Sec. 4. T9N, R7E, UM Dear Mr. Mazzolini: Enclosed is the approvcd application for permit to drill the above rcfcrcnccd xvcll. The permit is approvcd subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingcnt upon issuance of a conservation order approving a spacing cxccption or approval of the pending Pool Rules. ARCO will assume the liability of any protest to thc spacing exception that may occur. The permit to drill docs not cxcmpt you from obtaining additional permits required by law from other governmcntal agcncics, and docs not authorize conducting drilling operations until all other requircd permitting dctcrminations arc made. Approval of annular disposal of drilling v,:astcs is contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Tcst (FIT). Ccmcnting records. FIT data. and any CQLs must be submittcd to thc Commission on form 10-403 to ensure the requirements of 20 AAC 25.080 arc met prior to initiating disposal operations. Blowout prevention cquiplncnt (BOPE) must be tcstcd in accordance with 20 AAC 25.035. Sufficicnt notice (approximatcly 24 hours) of thc BOPE test pcrformcd bcforc drilling below the surface casing shoc must bc given so that a representative of thc Commission may witness the test. Notice may be givcn by contacting the Commission petroleum field inspector on the North David W. Johnston X ~'% Chairman ~ ~ BY ORDER OF THE COMMISSION dlf/enclosurcs CC: Dcpartmcnt of Fish & Game, Habitat Section w/o cncl. Departmcnt of Environmental Conservation w/o cncl. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 June 16,1998 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Application for Permit to Drill KRU 2N-337A Surface Location: 117 ' FNL 996 ' FEL Sec 3 T9N R7E, UM Target Location: 1857 'FSL, 2426 'FEL Sec. 4, T9N, R7E, UM Bottom Hole Location: 1827 'FSL, 2645 'FEL Sec. 4, T9N, R7E, UM Dear Commissioner Johnston: Yesterday, ARCO submitted AOGCC Form 401 Application for Permit to Drill its KRU 2N-337A well. This well is a sidetrack from KRU 2N-337. The productive interval of the new well will be within 500' of a quarter section line and lies within the proposed Tarn Oil Pool. ARCO and partners own all of the adjacent properties. A request for spacing exception will be forthcoming. We request that the AOGCC proceed with processing and approval of Form 401 Application for Permit to Drill prior to the spacing exception being granted. This request is made to allow for continuous drilling rig operations. We intend to drill 2N 337A immediately. Estimated spud date for 2N 337A is June 16, 1998. The well would not be perforated or produced prior to the spacing exception being granted or approval of the pending Pool Rules. In making this request ARCO assumes the liability of any protest to the spacing exception that might be made. We appreciate your consideration of this request. If you have any questions or require additional information on this matter, please contact me at 263.4603. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 June 15, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-337A Surface Location: 117 ' FNL 996 ' FEL Sec 3 T9N R7E, UM Target Location: 1857 ' FSL, 2426 ' FEL Sec. 4, T9N, RTE, UM Bottom Hole Location: 1827 ' FSL, 2645 ' FEL Sec. 4, T9N, RTE, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files ~is ~Application for Permit to Drill development a well in the Tarn area, KRU 2N 3~ 1,~!ocated approximately seven miles southwest of the Kuparuk River Unit's 2M DrilTsite. This well is a sidetrack utilizing the surface hole from KRU 2N-337. Doyon Rig 141 is currently on the well. Present operations are plugging and abandoning the original production hole. Once cement plugs are set, we plan to drill to the new bottom hole location. We have discussed this plan with Blair Wondzell. All other pertinent information concerning the upper portion of this well, as well as requirements noted in the Permit to Drill for 2N-337 are still applicable. If you have questions or require additional information, please contact James Trantham at 265- 6434 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2N-337A Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill lb Type of Well Exploratory F~ Stratigraphic Test ~] Development Oil X Re-Entry Deepen Service F~ Development Gas E~ SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 121' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 375074, ALK 4293 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 117' FNL, 996' FEL, Sec. 3, T9N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1857' FSL, 2426' FEL, Sec. 4, T9N, R7E, UM 2N-337A #U-630610 At total depth 9. Approximate spud date Amount 1827' FSL, 2645' FEL, Sec. 4, T9N, R7E, UM 6/16/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2N-337 10228' MD 2645' @ TD feet 650' feet 2560 5454' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 7000' feet Maximum hole angle 65.24° Maximum surface 1357 psig At total depth 1610 psig (TVD) 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade CouplingI Length MD TVD MD TVD (include stage data) 20" 16" Weld 80' 28' 28' 108' 108' +_230 sx Permafrost cement 9.875" 7.625" 29.7# L-80 BTC MOE 2830' 28' 28' 2858' 2310' 1.50 Sx AS III L, 240 sx Cl. G 2. 250 Sx ASIIIL, 60 sx AS I 6.75" 5.5" 15.5# L-80 LTC-Mod 9572' 28' 28' 9600' 5010' 200 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 628' 9600' 5010' 10228' 5454' (included above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~. ~_~ i~, Conductor !? '~ V Surface ~ ~' ~ Intermediate Production , .,.~ LinerORIG!LI'' AL Perforation depth: measured ~ ~m,k~, 0ii ,:~ Gas ¢-.. ~ true vertical ....... knchorage- 20. Attachments Filing fee X Property plat [] BOP Sketch [] Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~-'~~, ~'~~ Title T arnDrillingTeamSupr. Date ~/1,,~/~:~ Commission Use Only 7 ~:>~ /.2 ~ 50- //O ~-- 2. C~ ~ ~ ~_. -- 4:2 / (_~ .--- / '~" ~' ~ other requirements conditions of approval Samples required E Yes ~ No Mud Icg required [-' Yes ,~ No Hydrogen sulfidemeasures E~Yes ,[~No Directional surveyrequired ~Yes BI No Required working pressure for BOPE ,r~2M ~O 5M 10M 15M Other: ,j, i.gi(181 Siglql~OlDy E] F'I by order of ~¢ --// ? ..- .Approved by David W. JohEIst0rl commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. '~J SIDETRACK DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N 337A 1. P&A well as per Application for Sundry. 2. Drill 63A'' hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools in record mode. Gamma Ray and Resistivity will be run in real time mode. 3. POH and LD BHA. Download LWD data. 4. Run and cement 5Y2" L-80 LTC Csg X 3½" L-80 8rd EUE Mod tapered production casing string with Baker casing seal receptacle at crossover point. 5. Pressure test casing to 3,500 psi. 6. Run 3Y2" L-80 8rd EUD Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 7. ND BOPE and install production tree. 8. Shut in and secure well. 9. Clean location, RD and move to next well on 2N pad. Well will be left ready for perforating. 2N 337A jt, 06/15/98 '-' ARCO Alaska, Inc. ~--J DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 337A Drillincl Fluid Properties: Drill from ST point to TD Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids 8.5 - 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillinq Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Degasser Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,350 psi (0.50 psi/E). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. 2N 337A jt, 06/15/98 ARCO Alaska, Inc. Well Proximity Risks: The nearest wells to 2N 337A are 2N337 and 2N 339. 2N337 has been abandoned and is approximately 650' to the south at TD. 2N339 is 1200' away at the sidetrack point of 2N337A and the wells diverge from there. Drillinq Area Risks: The primary risk in the 2N 337A drilling area is economic risk. 2N 337 was found to be unfavorable and 2N337A is hoped to be more economic. In respect to pressure data, a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into a nearby annulus or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2N 337A surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2N 337A be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AC)GCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure - 2,935 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: 2N 337A jt, 06/15/98 ARCO Alaska, Inc. Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5Y2" 15.5 L-80 3 LTC-M 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3Y2" 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). 2N 337A jt, 06/15/98 2N 337A WELLBORE SCHEMATIC and CEMENT DESIGN 16" Conductor Casing at 135' MD / RKB permafrost :::::;::::: 1,222'MD ........... Stage Oo,ar ......-.-.. ........-.- ........-.. -.-.....-.. ..........- ...... Top of :i:i:i:i:i: .....,..... West Sak ........... -...-...... Base o[ West Sak 2,101' ME) 7-5/8" Surface Casing at 2,858' MD Top of Cement at 9,100' MD 5-1/2' Production Casing at 9,600' MD 3-1/2' Production Casing at 10,228' MD i:i:i:!:!:' i:i:i:i:i: :::::::::: !i!i!i!ii! :::::::::: .......... .:.:.:.:.: i~i!iiii?' 7/8" Hole ........... :.:-;-;.;.; 6-3/4" Hole Conductor Casing Size / Hole Size 16' in 20" hole Depth: 135' MDRKB Top of Cement Surface Excess Calculated: 100% Volume Calculations: (135 l0 (0.7854 cf/If) (2.00) = 212 cf (212 cf) /(0.93 cl/sx) = 230 sx Slurry Volume: 212 cf or Arctic Set 1 230 sx Slurry Weight 15.7 ppg rounded Yield 0.93 cf/sx Slurr~ Surface Casing excess 7-5/8" in 9--7/8" hole! Stage 1: Volume (608 If) (0.2148 cf/10 (1.45) = 189 cf Lead (189 cO /(4.42 cf/sx) = 43 sx Tail (80010 (0.2148cf/10 (1.45)= 249cf shoe joint vol 21 cf + (249 cf) /(1.15 cf/sx) = 237 sx System: Lead (Arctic Set 3 Lite cement + 3.5% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCI2) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (Cl G cml + 1% SI(CaCI2) + 0.3% D65 (disp.) + 0.2% D46 (defoarn.) Lead Slurry Volume: 189 cf or 50 sx SlurryWeight 10.5 ppg Arctic Set3 Lite Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 249 cf or240 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.15 cf/sx Thickenin0 Time 3.5 - 4.5 hours Surface Casing excess Stage 2: Vol. Lead (1,222 If) (0.2148 cf/10 (4.00) = 1,050 cf (78 l0 (0.2148 cf/10 (1.45) = 24cf (1,074 cf) /(4.42 cf/sx) = 243 sx Tail (0If) (0.2148cf/10 (4.00)= 0cf (15010 (0.2148cf/10 (1.45)= 47cf (47 cf) /(0.93 cf/sx) = 50 sx System: Lead (Arctic Set 3 Lite cement + 3.5% D44 (NaCl) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCI2) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (Amt~c Set 1 cement ) Lead Slurry Volume: 1,074 cf or 250 sx Slurry Weight 10.5 ppg Arctic Set3 Lite Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 47 cf or 60 sx Slurry Weight 15.7 ppg Arctic Set 1 Slurry Yield 0.93 cf/sx Thickening Time 3.5 - 4.5 hours Production Casing Size / Hole Size 5-1/2' and 3-1/2' in 6-3/4' hole' Deplh: 10,228' Top oi 3-1/2" casing 9,600' Top of Cement 9,100' Excess Calculated: 50% BHT (Static): 160~ F 130~ F BHT (Circ): excess Volume around 5-1/2" (500 l0 (0.0835 cf/10 (1.50) = 63 cf Volume around 3-1/2" (628 If) (0.1817 cf/10 (1.50) = 171 cf 234 cf shoe joint vol 4 cf + (234 cf) /(1.20 cf/sx) = 198 sx System: (Class G cement + 2 gps D600 (latex) + 0.1 gps D135 (stabilizer) + 0.1 gps D47 (defoam.) + 3% D53 (Gyp) + 0.8% D65 (disp) + 0.12% D800 (ret.) Slurry Volume: 234 cf or 200 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.20 cf/sx Thickenin~l Time 3.5 - 4.5 hours 6/15/98 ARCO Alaska, Inc. Structure : Tarn Drill Site 2N Well : .337 Field : Tarn Development Field Location : North Slope, Alaska ICreoted by jones FOl': J Trantham] Dote plotted : 15-Jun-g8/ Plot Reference is 357A Vets}on ~1. Coordinates ore in feet reference slot ~557, True Vcd. ical Depths~e RK8 (Doyon 141).J TD LOCATION: 1827' FSL, 2645' FEL SEC. 4, TgN, RTE 3600 3900 ('- ¢200 -4,-- ¢500 .i ~ 4800 (D 5100 I 5400 57O0 ~' 66.38 DLS: 2.00 deg per 100 ft ~ 6~'8%5.4~ TANGENT ANGLE End D~op.&ffurn_ "-~ 65.24 DEG Becjin Final Drop 65.04 "--~...-~,...~ 61.04 "-.....~ DLS: 2.00 der per 100 ft 53.04 "'.,,.... ~ 49.04_ '",.,,,, End Angle Drop45.04 ",,,,. % T3 - Top Bermuda ",,% TARGET - Mid Bermuda "% "%. TARGET ANGLE 45 DEG i i i i i i i i i i i i i i i i i i i i i i <- West (feet) 7200 7000 6800 6600 6400 6200 6000 5800 5600 5400 5200 5000 4800 4600 4400 4200 4000 3800 TARGET LOCATION: ] ~ 2600 1857' FSL, 2426' FEL / SEC. 4, TgN, R7E ~_ ~,~, %. z6~_.3~.~_~, ....... J ......... ]?- ........... % ~,~ ~o % .................... o. / 262.24 AzimuLh 3600 7905' (To Target) ***Plane of Proposal*** 3800 4200 4500 4800 51 O0 5400 5700 6000 6300 6600 6900 7200 7500 7800 81 O0 Vertical Section (feet) -> Azimuth 262.24 with reference 0.00 N, 0.00 £ from slot #337 WELL PROFILE DATA 28O0 3000 I V ..... Paint .....MD Inc D~r TVD North East V. Sect DER/1 O0 KOP 7000.00 68.19 239.42 3790.20-2782.14-4284.11 4620.57 0.00 End of Drop/Turn 8057.29 65.24 262.24 4212.81-3100.32-5192.62 556~.72 2.00 End of Hold 8589.89 65.24 262.24 44.35.88 -3165.64-5671.82 6047..360.00 End of Drop/Turn 9601,85 45.00 262.24 5011.58-,3277.18 -6490.10 6873,20 2.00 Target 2N-337A ST 15-9914.99 45.00 262.24 5233.00-3307.06-6709.50 7094.63 0.00 End of Hold 10028,12 45,00 262,24 5313,00-5517.87-6788.76 7174,6~ 0.00 T.D. & End of Hold 10228.12 45,00 262.24 5454.42-.33`36.96 -6928.89 7316.04 O.O0 A~RC0 Alaska, Inc. Tarn Drill Site 2N 337 slot #337 Tarn Development Field North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 337A Version #1 Our ref : prop2972 License : Date printed : 15-Jun-98 Date created : 15-Jun-98 Last revised : 15-Jun-98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is nT0 10 12.816,w150 19 1.635 Slot Grid coordinates are N 5911892.648, E 460596.531 Slot local coordinates are 115.74 S 996.31 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Tarn Drill Site 2N,337 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S 7000.00 68.19 239.42 3790.20 2782.14 S 4284.11 W 7100.00 67.77 241.52 3827.69 2827.83 S 4364.76 W 7200.00 67.38 243.65 3865.83 2870.39 S 4446.81 W 7300.00 67.02 245.78 3904.59 2909.77 S 4530.16 W 7400.00 66.68 247.92 3943.90 2945.91 S 4614.70 W 7500.00 66.38 250.08 3983.73 2978.78 S 4700.33 W 7600.00 66.10 252.24 4024.02 3008.33 S 4786.94 W 7700.00 65.86 254.42 4064.73 3034.53 S 4874.44 W 7800.00 65.65 256.60 4105.80 3057.35 S 4962.71 W 7900.00 65.46 258.79 4147.19 3076.76 S 5051.64 W 8000.00 65.31 260.98 4188.85 3092.73 S 5141.14 W 8057.29 65.24 262.24 4212.81 3100.32 S 5192.62 W 8500.00 65.24 262.24 4398.23 3154.61 S 5590.94 W 8589.89 65.24 262.24 4435.88 3165.64 S 5671.82 W 8600.00 65.04 262.24 4440.13 3166.88 S 5680.91 W PROPOSAL LISTING Page 1 Your ref : 337A Version #1 Last revised : 15-Jun-98 Dogleg Vert Deg/100ft Sect 0.00 4620.57 KOP 2.00 4706.65 2.00 4793.70 2.00 4881.60 2.00 4970.25 2.00 5059.53 2.00 5149.34 2.00 5239.58 2.00 5330.12 2.00 5420.86 2.00 5511.69 2.00 5563.72 End Drop & Turn 0.00 5965.73 0.00 6047.36 Begin Final Drop 2.00 6056.53 8700.00 63.04 262.24 4483.91 3179.02 S 5769.99 W 2.00 6146.43 8800.00 61.04 262.24 4530.79 3190.95 S 5857.50 W 2.00 6234.75 8900.00 59.04 262.24 4580.73 3202.64 S 5943.34 W 2.00 6321.38 9000.00 57.04 262.24 4633.67 3214.10 S 6027.39 W 2.00 6406.22 9100.00 55.04 262.24 4689.53 3225.30 S 6109.57 W 2.00 6489.15 9200.00 53.04 262.24 4748.26 3236.23 S 6189.76 W 2.00 6570.09 9300.00 51.04 262.24 4809.77 3246.88 S 6267.88 W 2.00 6648.93 9400.00 49.04 262.24 4873.99 3257.23 S 6343.82 W 2.00 6725.57 9500.00 47.04 262.24 4940.86 3267.27 S 6417.49 W 2.00 6799.92 9600.00 45.04 262.24 5010.27 3276.99 S 6488.81 W 2.00 6871.90 9601.85 45.00 262.24 5011.58 3277.16 S 6490.10 W 2.00 6873.20 End Angle Drop 9801.85 45.00 262.24 5153.00 3296.26 S 6630.23 W 0.00 7014.63 T3 - Top Bermuda 9914.97 45.00 262.24 5232.99 3307.06 S 6709.49 W 0.00 7094.62 TARGET - Mid Bermuda 9914.99 45.00 262.24 5233.00 3307.06 S 6709.50 W 0.00 7094.63 2N-337A ST 15-Jun-98 10000.00 45.00 262.24 5293.11 3315.18 S 6769.06 W 0.00 7154.74 10028.12 45.00 262.24 5313.00 3317.87 S 6788.76 W 10228.12 45.00 262.24 5454.42 3336.96 S 6928.89 W 0.00 7174.63 T2 - Base Bermuda 0.00 7316.04 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #337 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7690.56 on azimuth 244.28 degrees from wellhead. Total Dogleg for wellpath is 41.38 degrees. Vertical section is from wellhead on azimuth 262.24 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,337 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 337A Version #1 Last revised : 15-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 7000.00 3790.20 8057.29 4212.81 8589.89 4435.88 9601.85 5011.58 9801.85 5153.00 9914.97 5232.99 9914.99 5233.00 10028.12 5313.00 10228.12 5454.42 2782 14 S 3100 32 S 3165 64 S 3277 16 S 3296 26 S 3307 06 S 3307 06 S 3317 87 S 3336.96 S 4284.11 W KOP 5192.62 W End Drop & Turn 5671.82 W Begin Final Drop 6490.10 W End Angle Drop 6630.23 W T3 - Top Bermuda 6709.49 W TARGET - Mid Bermuda 6709.50 W 2N-337A ST 15-Jun-98 6788.76 W T2 - Base Bermuda 6928.89 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 3790.20 2782.14S 4284.11W n/a 3790.20 2782.14S 4284.11W 7 5/8" Casing n/a 3790.20 2782.14S 4284.11W 10228.10 5454.40 3336.96S 6928.87W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-337A ST 15-Jun-9 453871.000,5908620.000,0.0000 5233.00 3307.06S 6709.50W 15-Jun-98 ARCO Alaska, Inc. Tarn Drill Site 2N,337 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D i N A T E S 7000.00 68.19 239.42 3790.20 2897.88 S 5280.41 W 7100.00 67.77 241.52 3827.69 2943.57 S 5361.07 W 7200.00 67.38 243.65 3865.83 2986.13 S 5443.12 W 7300.00 67.02 245.78 3904.59 3025.51 S 5526.47 W 7400.00 66.68 247.92 3943.90 3061.65 S 5611.01 W 7500.00 66.38 250.08 3983.73 3094.52 S 5696.64 W 7600.00 66.10 252.24 4024.02 3124.08 S 5783.25 W 7700.00 65.86 254.42 4064.73 3150.28 S 5870.75 W 7800.00 65.65 256.60 4105.80 3173.09 S 5959.02 W 7900.00 65.46 258.79 4147.19 3192.50 S 6047.95 W 8000.00 65.31 260.98 4188.85 3208.47 S 6137.44 W 8057.29 65.24 262.24 4212.81 3216.07 S 6188.93 W 8500.00 65.24 262.24 4398.23 3270.36 S 6587.25 W 8589.89 65.24 262.24 4435.88 3281.38 S 6668.13 W 8600.00 65.04 262.24 4440.13 3282.62 S 6677.22 W PROPOSAL LISTING Page 1 Your ref : 337A Version #1 Last revised : 15-Jun-98 Dogleg Vert Deg/100ft Sect 0.00 4620.57 KOP 2.00 4706.65 2.00 4793.70 2.00 4881.60 2.00 4970.25 2.00 5059.53 2.00 5149.34 2.00 5239.58 2.00 5330.12 2.00 5420.86 2.00 5511.69 2.00 5563.72 End Drop & Turn 0.00 5965.73 0.00 6047.36 Begin Final Drop 2.00 6056.53 8700.00 63.04 262.24 4483.91 3294.76 S 6766.29 W 2.00 6146.43 8800.00 61.04 262.24 4530.79 3306.69 S 6853.81 W 2.00 6234.75 8900.00 59.04 262.24 4580.73 3318.39 S 6939.64 W 2.00 6321.38 9000.00 57.04 262.24 4633.67 3329.85 S 7023.70 W 2.00 6406.22 9100.00 55.04 262.24 4689.53 3341.05 S 7105.88 W 2.00 6489.15 9200.00 53.04 262.24 4748.26 3351.98 S 7186.07 W 2.00 6570.09 9300.00 51.04 262.24 4809.77 3362.62 S 7264.19 W 2.00 6648.93 9400.00 49.04 262.24 4873.99 3372.97 S 7340.13 W 2.00 6725.57 9500.00 47.04 262.24 4940.86 3383.01 S 7413.80 W 2.00 6799.92 9600.00 45.04 262.24 5010.27 3392.73 S 7485.11 W 2.00 6871.90 9601.85 45.00 262.24 5011.58 3392.91 S 7486.41 W 2.00 6873.20 End Angle Drop 9801.85 45.00 262.24 5153.00 3412.00 S 7626.54 W 0.00 7014.63 T3 - Top Bermuda 9914.97 45.00 262.24 5232.99 3422.81 S 7705.79 W 0.00 7094.62 TARGET - Mid Bermuda 9914.99 45.00 262.24 5233.00 3422.81 S 7705.80 W 0.00 7094.63 2N-337A ST 15-Jun-98 10000.00 45.00 262.24 5293.11 3430.92 S 7765.37 W 0.00 7154.74 10028.12 45.00 262.24 5313.00 3433.61 S 7785.07 W 10228.12 45.00 262.24 5454.42 3452.71 S 7925.19 W 0.00 7174.63 T2 - Base Bermuda 0.00 7316.04 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 34, T10N, RTE and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7690.56 on azimuth 244.28 degrees from wellhead. Total Dogleg for wellpath is 41.38 degrees. Vertical section is from wellhead on azimuth 262.24 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 337 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 337A Version #1 Last revised : 15-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 7000.00 3790.20 2897.88 S 5280.41 W KOP 8057.29 4212.81 3216.07 S 6188.93 W End Drop & Turn 8589.89 4435.88 3281.38 S 6668.13 W Begin Final Drop 9601.85 5011.58 3392.91 S 7486.41 W End Angle Drop 9801.85 5153.00 3412.00 S 7626.54 W T3 - Top Bermuda 9914.97 5232.99 3422.81 S 7705.79 W TARGET - Mid Bermuda 9914.99 5233.00 3422.81 S 7705.80 W 2N-337A ST 15-Jun-98 10028.12 5313.00 3433.61 S 7785.07 W T2 - Base Bermuda 10228.12 5454.42 3452.71 S 7925.19 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 3790.20 2897.88S 5280.41W n/a 3790.20 2897.88S 5280.41W 7 5/8" Casing n/a 3790.20 2897.88S 5280.41W 10228.10 5454.40 3452.70S 7925.18W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-337A ST 15-Jun-9 453871.000,5908620.000,0.0000 5233.00 3422.81S 7705.80W 15-Jun-98 ARCO Alaska, Inc. Tarn Drill Site 2N, 337 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G Depth Degrees Degrees Depth C 0 0 R D I N PROPOSAL LISTING Page 1 Your ref : 337A Version #1 Last revised : 15-Jun-98 ULAR ATES Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 7000.00 68.19 239.42 3790.20 2782.14 S 4284.11 W 4620.57 379.53 27.92 49.99 58.50 7100.00 67.77 241.52 3827.69 2827.83 S 4364.76 W 4706.65 386.85 28.32 50.92 58.56 7200.00 67.38 243.65 3865.83 2870.39 S 4446.81 W 4793.70 394.22 28.72 51.85 58.65 7300.00 67.02 245.78 3904.59 2909.77 S 4530.16 W 4881.60 401.63 29.13 52.77 58.79 7400.00 66.68 247.92 3943.90 2945.91 S 4614.70 W 4970.25 409.06 29.55 53.69 58.96 7500.00 66.38 250.08 3983.73 2978.78 S 4700.33 W 5059.53 416.51 29.96 54.60 59.16 7600.00 66.10 252.24 4024.02 3008.33 S 4786.94 W 5149.34 423.95 30.39 55.51 59.39 7700.00 65.86 254.42 4064.73 3034.53 S 4874.44 W 5239.58 431.37 30.81 56.41 59.66 7800.00 65.65 256.60 4105.80 3057.35 S 4962.71 W 5330.12 438.76 31.24 57.31 59.95 7900.00 65.46 258.79 4147.19 3076.76 S 5051.64 W 5420.86 446.10 31.67 58.21 60.27 8000.00 65.31 260.98 4188.85 3092.73 S 5141.14 W 5511.69 453.39 32.11 59.11 60.62 8057.29 65.24 262.24 4212.81 3100.32 S 5192.62 W 5563.72 457.54 32.35 59.63 60.83 8500.00 65.24 262.24 4398.23 3154.61 S 5590.94 W 5965.73 489.81 34.27 63.60 62.31 8589.89 65.24 262.24 4435.88 3165.64 S 5671.82 W 6047.36 496.40 34.66 64.40 62.58 8600.00 65.04 262.24 4440.13 3166.88 S 5680.91 W 6056.53 497.14 34.71 64.49 62.61 8700.00 63.04 262.24 4483.91 3179.02 S 5769.99 W 6146.43 504.25 35.16 65.36 62.90 8800.00 61.04 262.24 4530.79 3190.95 S 5857.50 W 6234.75 511.13 35.62 66.20 63.17 8900.00 59.04 262.24 4580.73 3202.64 S 5943.34 W 6321.38 517.78 36.09 67.00 63.43 9000.00 57.04 262.24 4633.67 3214.10 S 6027.39 W 6406.22 524.18 36.58 67.78 63.67 9100.00 55.04 262.24 4689.53 3225.30 S 6109.57 W 6489.15 530.32 37.07 68.52 63.89 9200.00 53.04 262.24 4748.26 3236.23 S 6189.76 W 6570.09 536.20 37.57 69.22 64.10 9300.00 51.04 262.24 4809.77 3246.88 S 6267.88 W 6648.93 541.80 38.08 69.90 64.29 9400.00 49.04 262.24 4873.99 3257.23 S 6343.82 W 6725.57 547.13 38.59 70.53 64.47 9500.00 47.04 262.24 4940.86 3267.27 S 6417.49 W 6799.92 552.17 39.10 71.14 64.64 9600.00 45.04 262.24 5010.27 3276.99 S 6488.81 W 6871.90 556.93 39.61 71.70 64.79 9601.85 45.00 262.24 5011.58 3277.16 S 6490.10 W 6873.20 557.02 39.62 71.71 64.80 9801.85 45.00 262.24 5153.00 3296.26 S 6630.23 W 7014.63 566.53 40.66 72.84 65.09 9914.97 45.00 262.24 5232.99 3307.06 S 6709.49 W 7094.62 571.91 41.25 73.48 65.26 9914.99 45.00 262.24 5233.00 3307.06 S 6709.50 W 7094.63 571.91 41.25 73.48 65.26 10000.00 45.00 262.24 5293.11 3315.18 S 6769.06 W 7154.74 575.96 41.69 73.96 65.39 10028.12 45.00 262.24 5313.00 3317.87 S 6788.76 W 7174.63 577.30 41.84 74.12 65.43 10228.12 45.00 262.24 5454.42 3336.96 S 6928.89 W 7316.04 586.85 42.89 75.25 65.71 All data is in feet unless otherwise stated. Coordinates from slot #337 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7690.56 on azimuth 244.28 degrees from wellhead. Vertical section is from wellhead on azimuth 262.24 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 337 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 337A Version #1 Last revised : 15-Jun-98 POSITION UNCERTAINTY SUM]4ARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 7000 ARCO (H.A. Mag) User specified 379.53 27.92 49.99 7000 10228 ARCO (H.A. Mag) User specified 586.85 42.89 75.25 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Comments in wellpath MD TVD Rectangular Coords. Comment 7000.00 3790.20 2782.14 S 4284.11 W KOP 8057.29 4212.81 3100.32 S 5192.62 W End Drop & Turn 8589.89 4435.88 3165.64 S 5671.82 W Begin Final Drop 9601.85 5011.58 3277.16 S 6490.10 W End Angle Drop 9801.85 5153.00 3296.26 S 6630.23 W T3 - Top Bermuda 9914.97 5232.99 3307.06 S 6709.49 W TARGET - Mid Bermuda 9914.99 5233.00 3307.06 S 6709.50 W 2N-337A ST 15-Jun-98 10028.12 5313.00 3317.87 S 6788.76 W T2 - Base Bermuda 10228.12 5454.42 3336.96 S 6928.89 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 3790.20 2782.14S 4284.11W n/a 3790.20 2782.14S 4284.11W 7 5/8" Casing n/a 3790.20 2782.14S ~284.11W 10228.10 545~.40 3336.96S 6928.87W 5 1/2" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-337A ST 15-Jun-9 453871.000,5908620.000,0.0000 5233.00 3307.06S 6709.50W 15-Ju~-98 ARCO Alaska, Inc. Tarn Drill Site 2N,337 Tarn Development Field,North Slope, Alaska PRODOSAL LISTING Dage 1 Your ref : 337A Version #1 Last revised : 15-Jun-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 7000.00 68.19 239.42 3790.20 2782.14S 4284.11W 0.00 4620.57 456298.78 5909132.56 7100.00 67.77 241.52 3827.69 2827.83S 4364.76W 2.00 4706.65 456217.90 5909087.28 7200.00 67.38 243.65 3865.83 2870.39S 4446.81W 2.00 4793.70 456135.65 5909045.14 7300.00 67.02 245.78 3904.59 2909.77S 4530.16W 2.00 4881.60 456052.11 5909006.19 7400.00 66.68 247.92 3943.90 2945.91S 4614.70W 2.00 4970.25 455967.40 5908970.48 7500.00 66.38 250.08 3983.73 2978.78S 4700.33W 2.00 5059.53 455881.61 5908938.05 7600.00 66.10 252.24 4024.02 3008.33S 4786.94W 2.00 5149.34 455794.85 5908908.94 7700.00 65.86 254.42 4064.73 3034.53S 4874.44W 2.00 5239.58 455707.24 5908883.19 7800.00 65.65 256.60 4105.80 3057.35S 4962.71W 2.00 5330.12 455618.86 5908860.82 7900.00 65.46 258.79 4147.19 3076.76S 5051.64W 2.00 5420.86 455529.84 5908841.87 8000.00 65.31 260.98 4188.85 3092.73S 5141.14W 2.00 5511.69 455440.27 5908826.35 8057.29 65.24 262.24 4212.81 3100.32S 5192.62W 2.00 5563.72 455388.76 5908819.02 8500.00 65.24 262.24 4398.23 3154.61S 5590.94W 0.00 5965.73 454990.20 5908766.76 8589.89 65.24 262.24 4435.88 3165.64S 5671.82W 0.00 6047.36 454909.28 5908756.14 8600.00 65.04 262.24 4440.13 3166.88S 5680.91W 2.00 6056.53 454900.19 5908754.95 8700.00 63.04 262.24 4483.91 3179.02S 5769.99W 2.00 6146.43 454811.05 5908743.26 8800.00 61.04 262.24 4530.79 3190.95S 5857.50W 2.00 6234.75 454723.49 5908731.78 8900.00 59.04 262.24 4580.73 3202.64S 5943.34W 2.00 6321.38 454637.61 5908720.52 9000.00 57.04 262.24 4633.67 3214.108 6027.39W 2.00 6406.22 454553.50 5908709.49 9100.00 55.04 262.24 4689.53 3225.30S 6109.57W 2.00 6489.15 454471.28 5908698.71 9200.00 53.04 262.24 4748.26 3236.23S 6189.76W 2.00 6570.09 454391.03 5908688.19 9300.00 51.04 262.24 4809.77 3246.88S 6267.88W 2.00 6648.93 454312.87 5908677.94 9400.00 49.04 262.24 4873.99 3257.23S 6343.82W 2.00 6725.57 454236.89 5908667.97 9500.00 47.04 262.24 4940.86 3267.27S 6417.49W 2.00 6799.92 454163.17 5908658.31 9600.00 45.04 262.24 5010.27 3276.99S 6488.81W 2.00 6871.90 454091.82 5908648.95 9601.85 45.00 262.24 5011.58 3277.16S 6490.10W 2.00 6873.20 454090.52 5908648.78 9801.85 45.00 262.24 5153.00 3296.26S 6630.23W 0.00 7014.63 453950.31 5908630.40 9914.97 45.00 262.24 5232.99 3307.06S 6709.49W 0.00 7094.62 453871.01 5908620.00 9914.99 45.00 262.24 5233.00 3307.06S 6709.50W 0.00 7094.63 453871.00 5908620.00 10000.00 45.00 262.24 5293.11 3315.18S 6769.06W 0.00 7154.74 453811.40 5908612.19 10028.12 45.00 262.24 5313.00 3317.87S 6788.76W 0.00 7174.63 453791.69 5908609.60 10228.12 45.00 262.24 5454.42 3336.96S 6928.89W 0.00 7316.04 453651.48 5908591.22 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #337 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7690.56 on azimuth 244.28 degrees from wellhead. Total Dogleg for wellpath is 41.38 degrees. Vertical section is from wellhead on azimuth 262.24 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 337 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 337A Version #1 Last revised : 15-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 7000 00 8057 29 8589 89 9601 85 9801 85 9914 97 9914 99 10028 12 10228 12 3790 20 4212 81 4435 88 5011 58 5153 00 5232 99 5233 00 5313 00 5454 42 2782.14S 3100.32S 3165.64S 3277.16S 3296.26S 3307.06S 3307.06S 3317.87S 3336.96S 4284.11W KOP 5192.62W End Drop & Turn 5671.82W Begin Final Drop 6490.10W End Angle Drop 6630.23W T3 - Top Bermuda 6709.49W TARGET - Mid Bermuda 6709.50W 2N-337A ST 15-Jun-98 6788.76W T2 - Base Bermuda 6928.89W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 3790.20 2782.14S 4284.11W n/a 3790.20 2782.14S 4284.11W 7 5/8" Casing n/a 3790.20 2782.14S 4284.11W 10228.10 5454.40 3336.96S 6928.87W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-337A ST 15-Jun-9 453871.000,5908620.000,0.0000 5233.00 3307.06S 6709.50W 15-Jun-98 · WELL PERMIT CHECKLIST FIELD & POOL &'/~4~.,,,/_~',_~' COMPANY ,~/';¢_..<~ WELL NAME /'~_ ~..~ ~ -. ~,~'~/--~ PROGRAM: exp [] dev [] redrll [] serv [] wellbore seg [3 ann. disposal para req~ INIT CLASS h~_.,~b/ /~- O.,,',/ GEOL AREA ~:"~'~ ~ UNIT# ///~'~ ON/OFF SHORE · ~2~ ) ADMINISTRATION .~R DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY APPR N N N N N 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. ',,2f N 33. Seabed condition survey (if off-shore) ............. J Y N 34. Con, tact,nam, e/phon,e.for weekly progress reports ....... / Y N I exploratory omyj With proper cementing records, this plan 5~C (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. 4/, ANNULAR DISPOSAL 35. APPR DATE ~N GEOLOGY: ENGINEERING: UIC/Annul.ar-~ JDH / COMMISSION: DWJ ~ RNC ~ co/__~,1~ -- Comments/Instructions: M:cheklist rev 05/29/98 dlf:C:\msoffice\wordian\diana\checklist Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history_ file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu Aug 06 11:16:51 1998 Reel Header Service name ............. LISTPE Date ..................... 98/08/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/08/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT (TARN POOL) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) MWD RUN 2 AK-MM-80247 R. KRELL R. SPRINGER RECEIVED AUG 1 2 1998 Alaska 0il & Gas Cons. Commission Anchorage 2N-337A 501032026201 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 06-AUG- 98 MWD RUN 3 AK-MM-80247 R. KRELL R. SPRINGER MWD RUN 4 AK-MM-80247 R. KRELL R. SPRINGER 3 9N 7E 117 996 KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 148.80 147.30 120.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 135.0 9.875 7.625 2858.0 6.750 10245.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. ALL DEPTHS ARE DRILLER'S DEPTHS. DEPTH CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN D.HASTINGS AND A. TURKER ON 06/25/98. MWD IS PDC. 3. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED ON LOG. 4. MWD RUNS 2, 3, AND 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON (CTN), AND STABILIZED LITHO-DENSITY (SLD). 5. WELL WAS SIDETRACKED FROM WELL 2N-337 AT 7000'MD, 3790'TVD. 6. MWD RUNS 1 THROUGH 4 REPRESENT WELL 2N-337A WITH AN API# 50-103-20262-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10,245'MD, 5464'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (RESISTIVITY). SPSF = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY. SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBD2 = SMOOTHED BULK DENSITY -COMPENSATED (BEST BIN, RAPID SAMPLE METHOD). SCO2 = SMOOTHED STANDOFF CORRECTION (BEST BIN, RAPID SAMPLE METHOD). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (BEST BIN). COMPENSATED THERMAL NEUTRON POROSITY PROCESSING PARAMETERS: LITHOLOGY: SANDSTONE. FIXED HOLE SIZE: 6.75". MUD WEIGHT: 9.10 TO 10.0 PPG. MUD SALINITY: 500-800 CL- PPM. FORMATION WATER SALINITY: 19,149 CL- PPM. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH DRHO 2800.0 GR 2850.0 RPD 2850.5 RPM 2850.5 RPS 2850.5 RPX 2850.5 PEF 2858.5 RHOB 2858.5 FCNT 2860.0 NCNT 2860.0 NPHI 2860.0 ROP 2868.0 FET 2870.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: STOP DEPTH 10137.5 10150.5 10157.5 10157.5 10157.5 10157.5 10137.5 10137.5 10122.0 10122.0 10122.0 10245.0 10157.5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 2868.0 3550.0 3 3550.0 7000.0 4 7000.0 10245.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT GR RPD ROP RPX RPS RPM FET NPHI RHOB DRHO PEF FCNT NCNT Service Order Units Size Nsam Rep FT 4 1 68 MWD API 4 1 68 MWD OHMM 4 1 68 MWD FT/H 4 1 68 MWD OHMS4 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD HOUR 4 1 68 MWD P.U. 4 1 68 MWD G/CC 4 1 68 MWD G/CC 4 1 68 MWD BARN 4 1 68 MWD CNTS 4 1 68 MWD CNTS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DEPT GR RPD ROP RPX RPS RPM FET NPHI RHOB DRHO PEF FCNT NCNT Min 2800 5 58 1 31 0 O9 1 21 1 17 1 17 0 45 11 39 0 06 -0 14 -5 92 150 21 2.2 Max 10245 320.09 2000 3280.51 1184.15 1230.52 2000 99.96 52.07 7.09 4.24 73.65 22455.4 40492.1 Mean Nsam 6522.5 14891 120.704 14602 5.91411 14615 173.54 14755 4.85377 14615 5.05669 14615 6.21684 14615 1.26371 14576 38.5644 14525 2.33337 14559 0.0680187 14559 2.90026 14676 234.023 14545 25083 14545 First Reading 2800 2850 2850.5 2868 2850.5 2850.5 2850.5 2870 2860 2858.5 2858.5 2800 2833.5 2833.5 Last Reading 10245 10150.5 10157.5 10245 10157.5 10157.5 10157.5 10157.5 10122 10137.5 10137.5 10137.5 10122 10122 First Reading For Entire File .......... 2800 Last Reading For Entire File ........... 10245 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. 2 .5000 BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE PEF GR RPD RPM RPS RPX DRHO RHOB FCNT NCNT NPHI ROP FET $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 2850.0 2850 0 2850 5 2850 5 2850 5 2850 5 2858 5 2858.5 2860.0 2860.0 2860.0 2868.0 2870.0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: I~AXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) STOP DEPTH 3442.0 3455.0 3462.0 3462.0 3462.0 3462.0 3442.0 3442.0 3427.0 3427.0 3427.0 3549.5 3462.0 10-JUN-98 5.07 5.46 MEMORY 3550.0 2868.0 3550.0 69.3 71.2 VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER P1029RM4 P1029RM4 P1029RM4 P1029RM4 6.750 6.8 LSND 9.00 49.0 10.0 700 6.8 2.400 2.269 2.500 2.600 29.5 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 NPHI MWD 2 P.U. 4 1 68 NCNT MWD 2 CNTS 4 1 68 FCNT MWD 2 CNTS 4 1 68 RHOB MWD 2 G/CC 4 1 68 DRHO MWD 2 G/CC 4 1 68 PEF MWD 2 BARN 4 1 68 32 36 4O 44 48 52 9 10 11 12 13 14 Name Min Max Mean Nsam ' DEPT 2850 3549.5 3199.75 1400 ROP 0.47 3280.51 119.746 1364 GR 41.9 155.66 110.423 1211 RPX 2.01 1184.15 7.50278 1224 RPS 2.19 1230.52 8.17619 1224 RPM 1.68 2000 21.2353 1224 RPD 1.53 2000 14.7893 1224 FET 0.83 3.33 1.26284 1185 NPHI 27.81 50.94 43.8609 1135 NCNT 19795.8 27521.9 22626.9 1135 FCNT 151.11 315.25 178.814 1135 RHOB 1.69 2.91 2.20911 1168 DRHO -0.14 0.44 0.0764127 1168 PEF 1.22 12.2 2.51285 1185 First Reading 2850 2868 2850 2850.5 2850.5 2850.5 2850.5 '2870 2860 2860 2860 2858.5 2858.5 2850 Last Reading 3549.5 3549.5 3455 3462 3462 3462 3462 3462 3427 3427 3427 3442 3442 3442 First Reading For Entire File .......... 2850 Last Reading For Entire File ........... 3549.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI 3426 5 NCNT 3426 5 FCNT 3426 5 RHOB 3442 5 DRHO 3442 5 PEF 3442 5 GR 3455.5 RPX 3462.5 RPS 3462.5 RPM 3462.5 RPD 3462.5 FET 3462.5 ROP 3550.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) STOP DEPTH 6999.5 6999.5 6999.5 6999.5 ; 6999.5 6999.5 6999.5 6999.5 6999.5 6999.5 6999.5 6999.5 6999.5 14-JUN-98 5.07 5.46 MEMORY 7000.0 3550.0 7000.0 43.7 71.3 TOOL NUMBER P1029RM4 P1029RM4 P1029RM4 P1029RM4 6.750 6.8 LSND 10.00 48.0 9.8 6O0 4.8 MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset DEPT FT 4 1 68 ROP MWD 3 FT/H 4 1 68 GR MWD 3 API 4 1 68 RPX MWD 3 OHMM 4 1 68 RPS MWD 3 OHMM 4 1 68 RPM MWD 3 OHMM 4 1 68 RPD MWD 3 OHMM 4 1 68 FET MWD 3 HOUR 4 1 68 NPHI MWD 3 P.U. 4 1 68 NCNT MWD 3 CNTS 4 1 68 FCNT MWD 3 CNTS 4 1 68 RHOB MWD 3 G/CC 4 1 68 DRHO MWD 3 G/CC 4 1 68 PEF MWD 3 BARN 4 1 68 0 4 8 12 16 20 24 28 32 36 4O 44 48 52 3.000 1.962 2.250 4.500 .0 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 47.1 Name Min Max Mean Nsam DEPT 3426.5 6999.5 5213 7147 ROP 0.09 2587.03 207.011 6900 GR 35.5 202.01 113.497 7089 RPX 2.28 71.76 4.55566 7075 RPS 2.38 64 4.71958 7075 RPM 2.47 394.04 4.92932 7075 RPD 2.65 361.69 5.25678 7075 FET 0.45 12.45 1.28753 7075 First Reading 3426.5 3550 3455.5 3462.5 3462.5 3462.5 3462.5 3462.5 Last Reading 6999.5 6999.5 6999.5 6999.5 6999.5 6999.5 6999.5 6999.5 Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/08/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 N~xt Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Reel Trailer Service name ............. LISTPE Date ..................... 98/08/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Te chni cal Physical EOF Physical EOF End Of LIS File
