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Home My WebLink About190-122 ? Pages NOT Scanned in this Well History File XHVZE 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. i ~ 0-"/~¢~- 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~ype OVERSIZED -El' Logs-of various kinds . El Other COMMENTS: Scanned by: Oianna Vincent Nathan Lowell -- TO RE-SCAN Notes: - Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ U ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 12, 2009 -, ~. _, r ~. u:. ,., ~~~~.^~,~ ~tAk t.,~ ~,~. Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • iq°~ 4a~" 3~~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped February 15th 2009. The corrosion inhibitor/sealant was pumped March 10th and 11 ~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, qq ' ` y~ M.J. Loveland /~ ~f ConocoPhillips Well Integrity Projects Supervisor U ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/12/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3G-02 190-137 SF NA 16" NA 1.7 3/11/2009 3G-03 196-122 SF NA 16" NA 1.7 3/11/2009 3G-05 190-075 12'6" 1.80 19" 2/15/2009 4.25 3/10/2009 3G-06 190-069 8'4" 1.20 18" 2/15/2009 3.5 3/10/2009 3G-07A 190-085 25'6" 3.40 18" 2/15/2009 3.4 3/10/2009 3G-11 190-076 22" NA 22" NA 4.25 3/10/2009 3G-14A 197-251 SF NA 17" NA 3.4 3/10/2009 3G-17 190-122 5' 0.80 16" 2/15/2009 2.55 3/10/2009 3G-18 190-125 18" NA 18" NA 4.25 3/10/2009 3G-19A 201-106 18" NA 18" NA 2.55 3/10/2009 3G-21A 198-052 21' 2.80 2'10" 2/15/2009 12.75 3/10/2009 3G-25X 196-136 SF NA 7" NA 2.55 3/10/2009 P ,..LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 October 2, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3G-17 (190-122) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforations on the KRU well 3G-17. If there are any questions, please contact me at 263-4574 or 659-7348. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 90 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 2536' FNL, 94' FEL, Sec. 23, T12N, R8E, UM (asp'$ 498285, 5988560) 3G-17 At top of productive interval 9. Permit number / approval number 1581' FNL, 235' FEL, Sec. 14, T12N, R8E, UM (asp's 498141, 5992681) 190-122 / At effective depth 10. APl number 50-103-20140 At total depth 11. Field / Pool 3457' FNL, 230' FEL, Sec. 14, T12N, R8E, UM (asp'$ 498147, 5992919) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7795 feet Plugs (measured) true vertical 6085 feet Effective depth: measured 7560 feet Junk (measured) true vertical 5907 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 1 1 5' 1 6" 219 sx AS I 1 1 5' 1 1 5' SURF CASING 3537' 9-5/8" 700 sx AS III & 480 sx Class G 3627' 3048' PROD CASING 7685' 7" 198 sxAS III & 160 sx Class G 7775' 6070' Perforation depth: m ..... ~, ?, ,. ........................................................................................................................................................................ . ....... . .......... ¢.~. - ./ Tubing (size grade and measured depth) i~;,~ii:~:~iiii~BB:!~ii~iii~iil~:iii:iii iii:iii:;;ii;iiiiiiiiiiiiii;iii:!i;!i!iii ;~:~:;~ ~ ~:: :~:::::;:: :: :~ ........... ~/rg 0i/~ .0 ~ / :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~: ?E-~:~:~ :::-:.:::::. ~-;-:-:-:.:-~. ~- ~ ~,(, / ~ Packers & SSSV (~pe & measured depth) :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~~.~ ..... , .... ' ':';':':':"~:~k :~::::~:~::::::;~; 13. Stimulation or ~ment squeeze summa~ Inte~als treated (measured) ..;... :~;...... ¢ ::::::::::::::::::::::::::::::::::::: ...... ================================================================================ Treatment description including volumes used and final pressure ................. ':' ......... ======================================== ::::::::::::::::::::::::::::::::::::::::::::: ...... 14. Representative Da y Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pre,ute Prior to well operation ~;; ~e:8 '; ;; ~ i~ :;: ..................................... :.:+:.:.: ....... :::::::::::::::::::::::::::::::::::::::::::::::: :: .::::-: ... :. ........ : ........................... . . :.. :. ........................................... , ........................ , ,- ....... ,.,.,., ....... , ..... 15. A~achments Copies of Logs and Su~eys run __ Daily Report of WelI Operations X ~:;S~:~:;::::::::::::::::::::::::::::: ~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: -; .:;:-:;: ;.; - ;:.:; ..;. ;- ;- ~.; -; -;.; -; ·; -: -:. :.:: :-; -:; :-; ~; · ;.: ·: · ;.: ;; -;.: ;.;.; - :.; ·: - :.: ·..: ·: -: · :. :-: - :.:.:. 17. I hereby certi~ that the foregoing is true and correct to the best of my knowledge. Questions? Carl Mike Mooney263-4574 Signed ~~/~ Title Wells Group Team Leader Date /~ ~ Michael Mooney , Prepared by Sharon AIIsu~Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 3G-17 Event History 09/07/01 PERFORMED 60' 2.25" GUNS, 2306 P J, 4SPF, 60/120 DEG. PHASING. ALL SHOTS FIRED FROM 7430- 7490' CORRECTED DEPTH TO SCHLUMBERGER PERFORATING LOG 1-NOV-2000. WELL ON PRODUCTION. [PERF] Page I of I 10/2/01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2538' FNL, 95' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1581' FNL, 235' FEL, Sec.14, T12N, RSE, UM At effective depth At total depth 1820' FSL, 236' FEL, Sec.14, T12N, R8E, UM 5. Type of Well: Development __X Exploratory__ Stratigraphic__ Service__ (asp's 498284, 5988562) (asp's 498141, 5992681) (asp's 498140, 5992920) 6. Datum elevation (DF or KB feet) RKB 90 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3G-17 9. Permit number / approval number 190-122 10. APl number 50-103-20140 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 115' SURF CASING 3537' PROD CASING 7685' 7795 feet Plugs (measured) 6085 feet 7514 feet Junk (measured) 5873 feet Size Cemented 16" 219 SxAS I 9-5/8" 700 Sx AS III & 480 G 7" 198 SxAS III & 160 G Tagged Fill (11/13/00) @ 7514' MD. Measured Depth 115' 3627' 7775' True verticalDepth 115' 3048' 6070' Perforation depth: measured 7564 - 7574' true vertical 5910 - 5917' rubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3.5", 9.3#, J-55, Tubing @ 7336' MD. Camco 'HRP-I-SP' Retry Packer @ 7250' MD. Otis 'FMX' Series '10' @ 1787' MD. RECEIVED Alaska Oil & Gas Cons. Commissior, Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiFBbl Prior to well operation 530 Subsequent to operation 126 Representative Daily AveraRe Productionorlnjection Data Gas-M~ Water-Bbl 230 4273 73 1051 Casing Pressure Tubing Pressure - 196 173 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service Signed 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Form 10-404 Rev 06/15/88 · Prepared by John Peirce 265-6471 SUBMIT IN DUPLICATE 3G-17 DESCRIPTION OF WORK COMPLETED CEMENT SQUEEZES, PERFORATING, & HYDRAULIC FRACTURE TREATMENT 10/16/00: RIH & tagged Fill at 7570' MD. 10/19/00: MIRU CTU. RIH w/CT & reversed out fill to 7583' MD, then pumped 56 bbls of Latex Acid Resistive Cement to attempt to squeeze off the open perforation intervals located at: 7430-7492' MD 7502- 7520' MD 7534- 7574' MD Attempted to hesitate a squeeze, but could not attain squeeze pressure. Contaminated cement w/biozan & jetted contaminated cement from wellbore to 7590' MD. RD. 10/20/00: RU CTU. RIH w/CT & Resqueezed the perforation intervals (listed above), Pumped 31 bbls of LARC and hesitated squeeze, but could not attain a sustainable squeeze pressure above 2250 whp. Placed another 25 bbls of cement behind pipe. Contaminated cement w/biozan & jetted contaminated cement from well to 7601' MD. RD. 10/28/00: MIRU CTU. RIH w/CT & Resqueezed the perforation intervals (listed above). Pumped 32 bbls of LARC and hesitated squeeze to place another 5.5 bbls of cement behind pipe. Held final 1600 whp for 1 hour. Contaminated cement & jetted contaminated cement from wellbore to 7600' MD. POOH w/CT. RD. Left well SI w/1875 whp for 3 days. 10/31/00: RIH & tagged PBTD at 7597' MD. 11/1/00: MIRU & PT equipment. Reperforated: 7564 - 7574' MD Used 2-1/8" carriers & shot the perfs at 4 spf. POOH w/guns. Rigged down. RIH w/perforating guns & shot 10' of perforations as follows: Alaska Oil & Gas Cons, Commission Anchorage 11/1/00: MIRU & PT equipment. Pumped 'A' Sand Hydraulic Fracture Treatment using 16/20 mesh proppant, through the open perforation interval (listed above). Pumped Breakdown stage w/200 bbls of 20# Gel, followed by Shutdown. ISIP @ 1980. Pumped 50 bbls of 40# Gelled Scour w/1 ppa proppant @ 30 bpm, followed by Shutdown. ISIP @ 1990. Pumped 100 bbls Crosslinked Gel Data Frac@ 15 bpm, followed by Shutdown. Pumped Frac w/50 bbls 40# Crosslinked Pad, followed by Crosslinked proppant stages from 1 to 12 ppa @ 15 bpm, followed by Flush, followed by Shutdown. Placed a total of 61,088 lbs of proppant into the formation. Rigged down. 11/4/00: RIH w/CT & performed proppant fill cleanout to hard tag at 7509' MD; could not go deeper. POOH & RD. 11/13/00: RIH w/bailer & tagged PBTD at 7514' MD. LIB indicated possible cement chunks at PBTD. Returned well to production w/gas lift & obtained a valid well test. Evaluating future fill cleanout. RE: Endic.o. tt Well 2-54/Q- 12 - - PTD #191-122 Subject: RE: Endicott Well 2-54/Q-12 - - PTD #191-122 Date: Tue, 30 May 2000 15:31:16 -0800 ~ From: Blair Wondzell <blair wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: 'Blair Wondzell' <blair_wondzell~admin.state.ak.us> CC: "Blosser, Bill R" <BlosseWR~BP.com>, "END, Delivery Team Leader" <ENDDeliveryTeamLeader~BP.com>, "END, Ops Team Leader" <ProdSupr~BP.com>, "Stewart, C Graham" <StewarCG~BP.com>, · Tom Maunder <tom maunder@admin.state.ak.us>, "END, Admin/Doc Specialist" <ENDAdminAssistant~BP.com>, "Sauve, Mark A (END)" <SauveMA2~BP.com>, Tom Maunder <tom maunder~admin.state.ak.us> Dan, We appreciate your efforts and can understand your frustrations in getting an interpretation. Certainly you should keep the well on injection. Why don't we just extend the time for developing a plan another 2 weeks, say until June 15, 2000. Sincerely, Blair Wondzell, 5/30/00. Blair, As we have exceeded the two week time period mentioned below, I wanted to give you an update on the status of Endicott Well 2-54/Q-12. On 5/19/00 a Kinley Caliper corrosion survey was run to determine the overall condition of the tubing in this well. Although a rush interpretation of the corrosion survey was requested, no results have been received to date. The corrosion information in anticipated to arrive any day so that we can finalize the repair plan and apply for regulatory approval. The well remains on water injection at present with daily monitoring of the tubing and annuli pressures. Please advise if you have any objection to continuing water injection at this point until the corrosion data is obtained and a repair plan formulated and submitted for approval. Dan Robertson Endicott Production and Wells Coordinator BP Exploration, Phone: (907) 659-6546 Fax: (907) 659-6533 Email: robertdb@BP.com From: Blair Wondzell [SMTP:blair wondzell@admin.state.ak.us] -- Sent: Tuesday, May 09, 2000 12:59 PM To: END, Production Coordinator Cc: Blosser, Bill R; END, Delivery Team Leader; END, Ops Team Leader; Stewart, C Graham; Tom Maunder Subject: Re: Endicott Well 2-54/Q-12 - - PTD #191-122 Mark, Thanks for the information. We certainly agree that you should keep the well on 1 of 2 5/30/00 3:31 PM RE: Endicott Well 2-54/Q-12 - - PTD #191-122 injection while you do diagnostic work. We expect that work to be pretty much completed and a plan formulated to repair the well or to apply for "Regulatory Approval" in about two weeks. Good luck. > Blair Wondzell, 5/9/00. > "END, Production Coordinator" wrote: > > Blair, > > As per our phone discussion this morning concerning water injection well integrity please accept this following synopsis of the recent activities associated with Endicott water injection well 2-54/Q-12. > > During routine daily well head pressure monitoring of Endicott water injection well 2-54/Q-12 it was recently observed that the tubing and inner annulus appeared to be in pressure communication. A successive series of diagnostic work was then initiated to determine the nature of this pressure communication. On 5/7/00 an e-line conveyed spinner/temperature/pressure log definitively identified a leak between the tubing and inner annulus at approximately 3700' MD. A caliper log has now been tentatively schedule to better define the extent of the tubing breach. Remediation options will be subsequently evaluated. > > It is the intent of the Endicott operator to continue water injection into well 2-54/Q-12 until the additional caliper information is collected and analyzed. The AOGCC will be kept informed of all new data as it becomes available. Your concurrence for this plan of action is sought. > > Mark Sauve > > Endicott Production & Wells Coordinator > > Ph: 907-659-6546 > > e-mail: sauvema2@bp, com 2 of 2 5/30/00 3:31 PM Re: Endicott Well 2-54/Q-12 - - PTD #191-122 /_ ~-- Subject: Re: Endicott Well 2-54/Q-12 - - PTD #191-122 Date: Tue, 09 May 2000 12:59:01 -0800 From: Blair Wondzell <blair wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "END, Production Coordinator" <ENDProductionCoordinator~BP.com> CC: "Blosser, Bill R" <BlosseWR@BP.com>, "END, Delivery Team Leader" <ENDDeliveryTeamLeader~BP.com>, "END, Ops Team Leader" <ProdSupr~BP.com>, "Stewart, C Graham" <StewarCG~BP.com>, Tom Maunder <tom maunder~admin.state.ak.us> Mark, Thanks for the information. We certainly agree that you should keep the well on injection while you do diagnostic work. We expect that work to be pretty much completed and a plan formulated to repair the well or to apply for "Regulatory Approval" in about two weeks. Good luck. Blair Wondzell, 5/9/00. "END, Production Coordinator" wrote: Blair, As per our phone discussion this morning concerning water injection well integrity please accept this following synopsis of the recent activities associated with Endicott water injection well 2-54/Q-12. During routine daily well head pressure monitoring of Endicott water injection well 2-54/Q-12 it was recently observed that the tubing and inner annulus appeared to be in pressure communication. A successive series of diagnostic work was then initiated to determine the nature of this pressure communication. On 5/7/00 an e-line conveyed spinner/temperature/pressure log definitively identified a leak between the tubing and inner annulus at approximately 3700' MD. A caliper log has now been tentatively schedule to better define the extent of the tubing breach. Remediation options will be subsequently evaluated. It is the intent of the Endicott operator to continue water injection into well 2-54/Q-12 until the additional caliper information is collected and analyzed. The AOGCC will be kept informed of all new data as it becomes available. Your concurrence for this plan of action is sought. Mark Sauve Endicott Production & Wells Coordinator Ph: 907-659-6546 e-mail: sauvema28bp, com 1 of 1 5/9/00 12:59 PM ALASKA OIL AND GAS CONSERVATION COM,,,,ISSION '~ ~.~7./ . WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~ GAS [~ SUSPENDED ["--J ABANDONED r~ SERVICE r~] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-122 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ~'~' ~ (7 O~,:l:i~-f~ 50-103-20140 4 Location of well at surface ~,-~ ~ ~ .... ;., L 9 Unitor LeaseName 2538' FNL, 95' FEL, SEC 23, T12N, R8E, UM ;'"'i~' ~"i ~',~ VE KUPARUK RIVER AtTop Producing Inten/al ; ~ ~ ~'~'~'~J:~.,,~'~z')..-~. ~~':~ ;'"' ~'';: :" ' ~~ 10 WellNumber 1581' FSL, 235' FEL, SEC 14, T12N, RSE, UM ~'.~ ~"-~ 3G-17 ,%' ~.~.(.Z/~,~0~S'~{~0;~3 · ' · 11 Field and Pool At Total Depth .;~ 1820' FSL, 236' FEL, SEC 14, T12N, R8E, UM ~,~,~)~,~,,,,, .~..',, KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 90' ADL 25547 ALK 2661~ 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Deplh, if offshore 116 No. of Completions 8/27/90. 8/31/90. 12/29/90. NA feet MSLI 1 17 Total Depth (MD+'I'VD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost MD, 6085' TVD 7692' MD, 6007' TVD YES ~ NO r~ 1787, feet MD 1600' APPROX 7795' 22 Type Electric or Other Logs Run EWR, CN, SFD, DGR, CET, CBL, GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 219 SX AS I 9-5/8" 36~ J-55 SURF 3627, 12-1/4" 700 SX AS III, 480 SX CLASS G 7" 26# J-55 SURF 7775' 8-1/2" 198 SX AS III, 160 SX CLASS G 24 Perforations open to Production (MD+'I'VD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7336' 7250' 7534'-7574' W/4 1/2" CSG GUN @ 4SPF MD 5888'-5918' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED SEE ATTACHED ADDENDUM 27 PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) I DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ,,~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ,,~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 ~INUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATK;)N TESTS ~ Include interval tested, pressure data, all fluids recoverd and gravity, MEAS, DEPTH TRUE VERT, DEPTH GOR, and time of each phase, KUPARUK C TOP 7430' 5809' NA KUPARUK C BO'Fi'OM 7492' 5856' KUPARUK A TOP 7492' 5856' KUPARUK A Bo'FrOM 7630' 5959' 31. LIST OF ATTACHMENTS GYRO, FRAC 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 ADDENDUM WELL: 1/26/91 3G-17 Frac KRU "A" sand perfs from 7534"-7574' @ 4spf in 8 stages as follows: Stage 1. Pmp 129 bbls Gel/H20 w/YF240 Pre Pad @ 25 bpm 5750-4410 psi Pmp 45 bbls Gel/H20 w/Nou XL Pre Pad @ 25 bpm 4410-4450 psi Pmp 35 bbls Slick Diesel @ 25 bpm 4410-4450 psi ISIP 1946 Perf Fdc:304 Frac Grad: .73 Stage 2 Pmp 50 bbls YF240 Pad @ 5 bpm 2450-2890 psi Pmp 175 bbls YF240 Pad @ 25 bpm 5150-4250 psi Pmp 32 bbls YF240 w/2ppg 16/20 Carbolite @ 25 bpm 4250- 4120psi Pmp 30bbls YF240 w/4ppg 16/20 Carbolite @ 25 bpm 4120-3960psi Pmp 24bbls YF240 w/6ppg 16/20 Carbolite@ 25 bpm 3960-4110 psi Pmp 18 bbls YF240 w/8ppg 16/20 Carbolite @ 25 bpm 4110-4590 psi Pmp 14 bbls YF240 w/10ppg 12/18 Carbolite @ 25 bpm 4590-5170 psi Pmp 30 bbls YF240 Flush @ 25 bpm 5170 -7800 psi Pmp12 bbls Nou XL YF240 @25 bpm 5170-7800 psi Pmpl0 bbls Slick Diesel @25-0-2 bpm 7800-7520 psi Screen out @ 7400 psi Stage 3 Stage 4 Stage 5 Stage 6 Stage 7 Stage 8 Average Pressure: Fluid to recover: Sand in zone: Sand in casing: 4250 psi 559 (H20),45 Diesel 20,036~ 16/20 Carbolite & 580# 12/18 Carbolite 5938# 12/18 Date/ Addendum ARCTIC PACK REPORT WELL: 3G-17 FIELD: Ku.oartjk DATE' 9/21/90 CSG SIZES: (Annular Dimensions): 9 5/8" X 7" 8.921-7.0=1.~)21 TOTAL ACCUMULATED MUD VOLUME INJECTED' 70 Diesel bbls WATER WASH VOLUME INJECTED: 300 bbls - RATE **6 BPM; 1200 psi SURFACE CSG DEPTH: 3627 feet CEMENT TYPE: Arctic Set I WEIGHT: 15.7 ppg VOLUME' 2cj bbls 175 sx ARCTIC PACK: WEIGHT: ppg VOLUME: 55 bbls DEPTH OF ARCTIC PACK/CEMENT INTERFACE: 1800 FEET PUMP RATE: 6 pbm PUMP PRESSURE INITIAL: 1000 psi FINAL: 480 psi CIP TIME: 1510 ~)/21/~)~ PRESSURE TEST: DATE: ~)/24/90 PRESSURE RESULTS: to 590 ~ 1000 hrs PmD 10 (]al diesel to 1000 DSi ('~ 9:00 bled off -- REMARKS: No test - will retest later. Left 590 psi on a/p to observe bleed off. SIGNATURE' sumi~on ** Due to small ARCO Oil and Gas Company g>, Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field KUPARUK RIVER UNIT ICounty. parish or borough NORTH SLOPE Lease or Unit Title ADL:25547 ALK:2661 COMPLETION IState IWell no. Auth. or W.O. no. AK5130 Operator ~,RCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 12/26/90 ( TD: 0 PB: 7692 SUPV:GB 12/27/90 ( 9) TD: 0 PB: 7692 SUPV:DB 12/28/90 (10) TD: 0 PB: 7692 SUPV:DB 12/29/90 (11) TD: 0 PB: 7692 SUPV:DB/SK IDate Hour 08/27/90 02:30 Complete record for each day reported NORDIC 1 ^RCO W, 55.252072 Pr or status if a W.O. NU BOPE 9-5/8"@ 3627' MW:10.7 NaC1/Br MOVE RIG FROM 3G PAD TO 2K PAD, FIELD WIDE WHITE OUT CONDITIONS, SPOT RIG, ND TREE NU BOPE RIG ACCEPTED 12/26/90 @ 04:00 DAILY:SO CUM:~744,038 ETD:S744,038 EFC:$1,350,000 PREPARE TO PERF 9-5/8"@ 3627' MW:10.7 NaC1/Br NU BOPE, WATER BACK BRINE F/ll.0 TO 10.7PPG, TEST BOPE TO 3500 PSI, TALLY DRIFT & STRAP COMP STRING, WAIT ON HLS FOR PERFORATION, ROAD CLOSED FROM PBU DUE TO DRIFTING SNOW. DAILY:S28,147 CUM:$772,185 ETD:S772,185 EFC:$1,350,000 RUNNING 3-1/2" COMP 9-5/8"@ 3627' MW:10.7 NaCl/Br WAIT ON ROADS TO OPEN, RU HLS, PERFORATE 'A' SANDS FROM 7534'-7574' WLM W/4.5" CSG GUNS @ 4 SPF 180 DEG IN TWO RUNS, RD HLS, NU FLOW NIPPLE, RU TO RUN 3-1/2" COMP STRING, TEST CONTROL LINE AT SSSV, 208 JTS IN HOLE @ 0600. DAILY:S45,963 CUM:$818,148 ETD:S818,148 EFC:$1,350,000 NU TREE 9-5/8"@ 3627' MW:10.7 NaCl/Br SERVICE RIG & CROWN, FINISH RUNNING 3-1/2" COMPLETION, RETEST CONTROL LINE TO 5000 PSI WHEN MU TO HANGER-OK, DROPPED PACKER SETTING BALL, LAND HNGR & RILDS KICK ON PUMP TO SEAT PKR, BALL WILL NOT SEAT, REV CIRC, CYCLE SSSV, PU H~NG~R & WORK TBG TO DISLODGE BALL, ALL NO GO, TBG CIRC FREELY DROP 2ND BALL, AND CIRC DOWN, NO CHANGE, RU CAMCO, RIH W/SPINNER/CCL WHILE CIRCULATING, CIRC IS AROUND TAILPIPE, @ 7335', BALL SEAT FROM BAKER SOS IS GONE, VERIFY CIRC @ TAILPIPE & NO LEAKS IN BOTTOM 2 GLMS OR PKR ASSY, RD CAMCO, RU OTIS, RIH W/STANDING VALVE & SET IN D-NIPPLE @ 7323', VERIFY W/300 PSI ON TBG, SHEAR OFF & POH, RD OTIS, RU LINES, PRESS TBG TO 2500PSI & SET PKR, HOLD FOR 15 MIN, BLEED OFF PRESS, BOLDS, PRESS TBG TO 1200 PSI & PU & SHEARED PBR, BLEED OFF TBG & RELAND HNGR, RILDS, TEST ANNULUS, TBG & SSSV RU OTIS, RETRIEVE STANDING VALVE, RD OTIS, LDLJ SET BPV, ND BOPE, NU 3-1/8" WKM GEN IV 5KSI TREE DAILY:S161,218 CUM:$979~'~66 ,?.-ETD:~$.979,.366 EFC:$1,350,000 ~' -~' < 4 / ~.._' The above is correct For form prepar,~ an~ distribution, i~',t,e 1'3rillina SuDt. AR3B-459-1-D INumber all daily well history forms consecutively as they are prepared for each well. l~age no ARCO O,, and Gas Company Daily Well History-Final Report Inslruclions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the enlire operation if space is available. Accounting cost center code District County or Parish State ARCO ALASKA INC. NORTH SLOPE AK Field Lease or Unit ADL: 25547 ALK: 2661 I Titie I Well no. 3Gt17 KUPARUK RIVER UNIT Aufh. or W.O. no. AKS130 OperatorARCO A.R.Co. W.I. Spudded or W.O. begun Date sPuD 08/27/90 Date and depth as of 8:00 a.m. 12/30/90 (12) TD: 0 PB: 7692 SUPV:DB/SK Iotal number of wells (active or inactive) on fhisl DSt center prior to plugging and / bandonment of this well 55 ~252072 our I Prior status if a W.O. I 02:30 Complete record for each day reported NORDIC 1 RIG RELEASE 9-5/8"@ 3627' MW: 0.0 Diesel NU 3-1/8" WKM GEN 5KSI TREE, PULL BPV, SET TP, TEST TREE & PO TO 5000PSI, OPEN SSSV & TEST CONTROL LINE TO 5000 PSI, PULL TP, RU CIRC LINES, REV CIRC 12 BBL DIESEL CAP INTO ANNULUS, INJECT 4 BBL DIESEL CAP DOWN TBG, CV IN GLM @ 7185' HELD, MONITOR PRESS, SITP=IS00PSI, 10 MIN SITP=850PIS & FALLING, 3X7 PA=0PSI, 7X9 PC=400 PSI, SECURE WELL RELEASE RIG @ 12/29/90 09:30, MOVE TO 3G-16 DAILY:S23,476 CUM:$1,002,842 ETD:S1,002,842 EFC:$1,350,000 Old TD Released rig New TO II PB (Depth Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effec:ive ca~e corrected __ The above is correc, t AR3B-459-3-C INumberall daily well history forms consecutively o as they are prepared for each well Ii OlvlIJon of AllanticRichheldComparly 1 ___ I. ~A$16 OF /.O~ATiON ANO ~L~VA~ION I$ 0.$. MONUI~NTATION P~R LOUN$~IIIqY ~ SHOWN ~FtE ~,P.M.$.L.. OAYUM. $. COOROIN&TE$ SHOWN &RK A$.~. XONK g~ N~O 8;7. d. LOG~VKD WITHIN P$OOTR~¢T~O $K¢'$. ~$ · t$~ E I~ N.~ R. · ~.,U. M., AK. NO. 'Y X I0 $~ 9~8, aGO. 48 4 ~, ~R4. fl ~, DOO~ $60.49 4 gO~ 4 ~. ?0 NO. ~ X I~ ~,98e~0.~ 490~09.04 Iy b~900~ ~60.$0 4~0~ P04,?O I~ b~goO~ 6~0.84 400~ ~34.00 PI ~900~ $00.~ 400, VICINITY MIJP l.O 160 °00'$~,§$$" /60°00'"10. £68' 100m00'00,990" 160°00' 4 I. ? I $" I~0o00'4P.400~ I00°00'46. Iol" /~0o'~. t~ 4" /O0°O0' gO, 011, IO0°O0'40. I~~'~1,8 ? I" /~'~./~0 ~ I$ /0 b'.N.L.,/ F.W.L. 0.0. pAD P$30' g$9' 00,9 83.9 £§$$'"' P4b' 40.? 64.0 g~ $O'"" ,2PO' 40.4 $4.0 '~'' 196' 40,£ 84.0 P§SO""" I?0' 47,0 '`-.' 140' 4P.g 85.4 PESO'"'" I~°0' 46.8 53.0 g~30' ~ ~' 46.9 ~N.L. ~,~,L. 0.~. ~ ~0' 47.~ ~3.1 ~'~ 40' 4~.t '~ 70' 46.9 $3.1 '~ I RO' 46,6 '~ 14~' 4~.6 53.0 gO3O' ~ I?0' 4~.~ ~.9 SURV£¥OR'S C£R rlFI i HEREBY CERTIFY THAT I AM R~OtS~RgD ~ND LlCgNS~D ~ PRA~I~ ~ND $U~YIN~ IN THE STATF OF AND ~AT THIS PLAT ~PRffSgN~ { ~ T~T ALL OI~NM~$ AND ~TAtLS AR~ ~R~T AS OF ~PRIL R~ ID~O. Dorm Omt¢~ibtioo ~O¢O ALASKA,/NC. OWO. NO. ' cONOUcTOI9$ 8-22 Clt. by,'O,~.bl. / of / Oo~m.' 4 -R~.. No..'ySK ~$. 307d 8 ~REAT LAND DIRECTIONAL DRILLING, 21ient .... : ARCO ALASKA, INC. Field ..... : Kuparuk River Unit Well ...... : KRU 3G-17 (23-12-8) Section at: N,1.07,W Surveyor..: MIKE NAIRN MEAS INCLN DEPTH ANGLE 100 0.46 200 0.33 300 0.54 400 0.74 500 0.90 VERTICAL-DEPTHS BKB SUB-SEA INC. SECTION DISTNCE 100.0 10.0 0.1 200.0- 110.0 -0.5 300.0 210.0 -1.1 400.0 310.0 -1.9 500.0 410.0 -2.6 RECORD OF SURVEY Computation...: Survey Date...: RKB Elevation.'. Job Number .... : API Number · · ®I.e. lO/12/9o RADIUS OF CURVATURE 09/22/90 90.00 ft AK0990G244 50-103-20140 DIRECTION RELATIVE-COORDINATES CLOSURE BEARING FROM-WELL-HEAD DISTNCE BEARING DL /lOO S 46.49 W 0.1 N 0.3 W 0.3 N 66.76 W 0.46 S 7.12 W 0.5 S 0.6 W 0.8 S 51.23 W 0.13 S 41.45 W 1.2 S 0.9 W 1.5 S 37.91 W 0.21 S 56.59 W 1.9 S 1.7 W 2.6 S 42.69 W 0.20 S 62.09 W 2.6 S 3.0 W 4.0 S 48.63 W 0.16 7 600 0.99 600.0 510.0 -3.3 7 700 1.14 699.9 609.9 -4.3 7 800 1.30 799.9 ~ 709.9 -5.3 7 900 1.23 899.9 809.9 -6.2 7 1000 3.52 999.8 909.8 -4.1 S 59.01 W 3.4 S 4.4 W 5.6 S 52.12 W 0.'09 S 58.75 W 4.4 S 6.0 W 7.4 S 53.81 W 0.15 S 60.95 W 5.5 S 7.8 W 9.6 S 55.15 W 0.16 S 71.37 W 6.4 S 9.9 W 11.7 S 57.21 W 0.07 N 0.47 W 4.3 S 12.8 W 13.5 S 71.41 W 2.33 1100 10.77 1099.0 1009.0 8.3 1200 11.50 1197.1 1107.1 27.2 1300 12.16 1295.0 1205.0 47.1 1400 15.59 1392.0 1302.0 70.4 1500 18.04 1487.7 1397.7 98.5 N 10.91 E 8.1 N 11.6 W 14.2 N 55.24 W 7.26 N 10.96 E 27.0 N 8.0 W 28.2 N 16.42 W 0.73 N 13.30 E 47.1 N 3.7 W 47.2 N 4.44 W 0.67 N 13.41 E 70.4 N 1.9 E 70.4 N 1.53 E 3.43 N 11.47 E 98.6 N 8.1 E 99.0 N 4.70 E 2.46 7 1600 20.92 1582.0 1492.0 131.2 7 1700 26.48 1673.5 1583.5 171.0 7 1800 31.33 1761.1 1671.1 219.2 7 1850 34.60 1803.0 1713.0 246.3 7 1900 37.49 1843.4 1753.4 275.7 N 8.47 E 131.5 N 13.9 E 132.2 N 6.03 E 2.91 N 5.04 E 171.4 N 18.6 E 172.4 N 6.20 E 5.60 N 2.35 E 219.6 N 21.7 E 220.7 N 5.65 E 4.90 N 0.13 E 246.8 N 22.3 E 247.8 N 5.17 E 6.69 N 2.55 W 276.2 N 21.7 E 277.0 N 4.49 E 6.11 7 1950 39.43 1882.6 "1792.6 306.8 N 2.66 W 307.3 N 20.3 E 307.9 N 3.78 E 3.88 *Survey Codes: 7/GYRO (KRU3G17G) ~RU 3G-17 (23-12-8) MEAS INCLN DEPTH ANGLE 2000 40.63 2100 45.82 2200 51.10 2300 49.87 2400 49.43 7 2500 48.69 7 2600 48.47 7 2700 48.80 7 2800 48.16 7 2900 45.80 7 3000 45.68 7 3100 45.69 7 3200 43.22 7 3300 42.60 7 3400 42.24 3500 41.98 3600 41.60 3700 41.38 3800 41.48 3900 41.09 7 4000 40.96 7 4100 41.28 7 4200 41.65 7 4300 42.22 7 4400 42.81 7 4500 43.31 RECORD OF SURVEY VERTICAL-DEPTHS SECTION DIRECTION BKB SUB-SEA DISTNCE BEARING 1920.9 1830.9 1993.7 1903.7 2060.0 1970.0 2123.6 2033.6 2188.4 2098.4 2253.9 2163.9 2320.0 2230.0 2386.1 2296.1 2452.4 2362.4 2520.6 2430.6 2590.4 2500.4 2660.3 2570.3 2731.7 2641.7 2804.9 2714.9 2878.7 2788.7 2952.9 2862.9 3027.5 2937.5 3102.4 3012.4 3177.4 3087.4 3252.5 3162.5 3327.9 3237.9 3403.3 3313.3 3478.2 3388.2 3552.6 3462.6 3626.3 3536.3 3699.4 3609.4 339.0 407.4 482.2 559.3 635.4 710.8 785.8 860.8 935.6 1008.7 1080.3 1151.8 1221.9 1289.9 1357.4 1424.5 1491.1 1557.3 1623.5 1689.5 1755.1 1820.8 1887.0 1953.8 2021.3 2089.6 N 2.72 W N 0.50 W N 2.92 W N 4.77 W N 3.91 W N 3.47 W N 3.06 W N 2.48 W N 2.75 W N 2.22 W RELATIVE-COORDINATES FROM-WELL-HEAD 339.4 N 18.8 E 407.8 N 16.8 E 482.6 N 14.6 E 559.6 N 9.4 E 635.6 N 3.7 E 710.9 N 1.2 W 785.8 N 5.5 W 860.8,N 9.1 W 935.6 N 12.5 W 1008.6 N 15.7 W N 2.76 W 1080.2 N 18.8 W N 2.25 W 1151.6 N 21.9 W N 1.74 W 1221.6 N 24.3 W N 0.86 W 1289.7 N 25.9 W N 1.81 W 1357.1 N 27.5 W N 1.26 W N 0.99 W N 1.50 W N 1.89 W N 2.25 W 1424.2 N 29.3 W 1490.8 N 30.6 W 1557.0 N 32.0 W 1623.2 N 34.0 W 1689.1 N 36.3 W N 2.90 W 1754.7 N 39.3 W N 3.10 W 1820.3 N 42.7 W N 3.06 W 1886.5. N 46.3 W N 2.93 W 1953.2 N 49.8 W N 1.84 W 2020.7 N 52.6 W N 1.88 W 2089..0 N 54.8 W Page 2 10/12/90 CLOSURE DI STNCE BEARING 339.9 N 3.17 E 408.2 N 2.37 E 482.8 N 1.73 E 559.6 N 0.97 E 635.6 N 0.33 E 710.9 N 0.10 W 785.8 N 0.40 W 860.8 N 0.60 W 935.6 N 0.77 W 1008.7 N 0.89 W 1080.3 N 1.00 W 1151.8 N 1.09 W 1221.9 N 1.14 W 1289.9 N 1.15 W 1357.4 N 1.16 W 1424.5 N 1.18 W 1491.1 N 1.17 W 1557.3 N 1.18 W 1623.5 N 1.20 W 1689.5 N 1.23 W 1755.1 N 1.28 W 1820.8 N 1.34 W 1887.0 N 1.41 W 1953.8 N 1.46 W 2021.4 N 1.49 W 2089.7 N 1.50 W DL /lOO 2.40 5.31 5.48 1.64 0.66 0.78 0.32 0.47 0.66 2.38 0.30 0.26 2.48 0.74 0.56 0.36 0.40 0.31 0.20 0.42 0.31 0.33 0.37 0.57 0.78 0.50 ~Survey Codes: 7/GYRO KRU 3G-17 (23-12-8) S MEAS INCLN C DEPTH ANGLE 7 4600 43.83 7 4700 44.41 7 4800 45.02 7 4900 45.45 7 5000 46.00 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 3771.8 3681.8 2158.5 3843.6 3753.6 2228.1 3914.7 3824.7 2298.5 3985.1 3895.1 2369.5 4054.9 3964.9 2441.1 7 5100 43.13 4126.1 4036.1 7 5200 43.33 4199.0 4109.0 7 5300 43.49 4271.7 4181.7 7 5400 43.79 4344.0 4254.0 7 5500 44.10 4416.0 4326.0 7 5600 44.92 4487.3 4397.3 7 5700 42.61 4559.5 4469.5 7 5800 42.89 4633.0 4543.0 7 5900 43.22 4706.0 4616.0 7 6000 43.71 4778.6 4688.6 7 6100 44.41 4850.5 4760.5 7 6200 44.98 4921.6 4831.6 7 6300 45.62 4991.9 4901.9 7 6400 44.35 5062.6 4972.6 7 6500 43.46 5134.7 5044.7 7 6600 43.58 5207.2 5117.2 7 6700 43.92 5279.4 ' 5189.4 7 6800 44.32 5351.2 5261.2 7 6900 44.31 5422.8 5332.8 7 7000 44.01 5494.5 5404.5 7 7100 43.80 5566.6 5476.6 RECORD OF SURVEY 'Survey Codes: 7/GYR0 DIRECTION BEARING N 1.54 W N 1.76 W N 1.84 W N 1.95 W N 1.63 W 2511.2 N 1.35 W 2579.7 N 1.48 W 2648.5 N 1.56 W 2717.5 N 1.40 W 2786.9 N 1.43 W 2857.0 N 1.32 W 2926.1 N 2.96 W 2994.0 N 2.34 W 3062.2 N 2.36 W 3131.0 N 1.94 W 3200.5 N 2.31 W 3270.8 N 2.41 W 3341.9 N 2.45 W 3412.6 N 1.46 W 3481.9 N 2.57 W 3550.8 N 2.91 W 3619.9 N 2.75 W 3689.4 N 3.25 W 3759.2 N 3.60 W 3828.8 N 3.66 W 3898.1 N 4,80 W RELATIVE-COORDINATES FROM-WELL-HEAD Page 3 CLOSURE DISTNCE 2157.8 N 56.9 W 2158.6 2227.4 N 58.9 W 2228.2 2297.8 N 61.1 W 2298.6 2368.7 N 63.4 W 2369.6 2440.3 N 65.7 W 2441.2 2510.4 N 67.5 W 2511,3 2578.9 N 69.2 W 2579.8 2647.6 N 71.0 W 2648,5 2716.6 N 72.8 W 2717.6 2786.0 N 74.5 W 2787.0 2856.0 N 76.2 W 2857.1 2925.2 N 78.8 W 2926.2 2993.0 N 81.9 W 2994.1 3061.2 N 84.7 W 3062.3 3129.9 N 87.3 W 3131.1 3199.4 N 89.9 W 3200.7 3269.7 N 92.8 W 3271.0 3340.7 N 95.8 W 3342.1 3411.3 N 98.2 W 3412.8 3480.7 N 100.6 W 3482.1 3549.4 N 103.9 W 3551.0 3618.5 N 107.3 W 3620.1 3688.0 N 111.0 W 3689.7 3757.8 N 115.2 W 3759.5 3827.3 N 119.6 W 3829.1 3896.4 N 124.7 W 3898.4 10/12/90 BEARING DL /lOO N 1.51 W 0.54 N 1.51 W 0.59 N 1.52 W 0.61 N 1.53 W 0.43 N 1.54 W 0.57 N 1.54 W N 1.54 W N 1.54 W N 1.53 W N 1.53 W 2.87 0.21 0.16 0.31 0.31 N 1.68 W 0.20 N 1.70 W 0.35 N 1.72 W 0.47 N 1.76 W 0.17 N 1.79 W 0.30 N 1.83 W 0.59 N 1.61 W 0.72 N 1.63 W 0.57 N 1.64 W 0.64 N 1.65 W 1.36 N 1.66 W 1.03 N 1.53 W 0.82 N 1.54 W 2.43 N 1.57 W 0.40 N 1.59 W 0.33 N 1.60 W 0.53 KRU 3G-17 (23-12-8) S MEAS INCLN C DEPTH ANGLE 7 7200 42.93 7 7300 42.40 7 7400 41.65 7 7500 41.82 7 7600 41.02 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 5639.3 5549.3 3966.6 5712.8 5622.8 4034.2 5787.1 5697.1 4101.1 5861.7 5771.7 4167.6 5936.7 5846.7 4233.8 RECORD OF SURVEY 7 7650 40.31 597.4.6 5884.6 X 7795 40.31 6085.2 5995.2 4266.4 4360.2 DIRECTION BEARING N 5.22 W N 5.00 W N 0.85 W N 0.22 W N 0.39 W RELATIVE-COORDINATES FROM-WELL-HEAD 3964.8 N 130.7 W 4032.3 N, 136.7 W 4099.2 N 140.1 W 4165.7 N 140.7 W 4231.9 N 141.1 W N 0.09 E 4264.5 N 141.2 W, N 0.09 E 4358.3 N 141.0 W Page 4 10/12/90 CLOSURE DISTNCE BEARING 3967.0 N 1.89 W 4034.7 N 1.94 W 4101.6 N 1.96 W 4168.1 N 1.94 W 4234.3 N 1.91 W 4266.8 N 1.90 W 4360.6 N 1.85 W DL /lOO 0.89 0.54 1.98 0.33 0.80 1.48 0.00 ~Survey Codes: 7/GYRO X/EXTRAPOLATED ~RU 3G-17 (23-12-8) Page 5 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL lO/12/9o SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 0 90 0.41 90 0 0 S 46.49 W 0.10 N 0.24 W 100 190 0.34 190 0 0 S 11.06 W 0.42 S 0.59 W 200 290 0.52 290 0 0 S 38.02 W 1.09 S 0.85 W 300 390 0.72 390 0 0 S 55.08 W 1.82 S 1.64 W 400 490 0.88 490 0 0 S 61.54 W 2.55 S 2.84 W 500 590 0.98 590 0 0 S 59.32 W 3.34 S 4.26 W 600 690 1.13 690 0 0 S 58.78 W 4.29 S 5.83 W 700 790 1.28 7'90 0 0 S 60.73 W 5.35 S 7.65 W 800 890 1.24 890 0 0 S 70.34 W 6.28 S 9.66 W 900 990 3.30 990 0 0 N 11.10 W 4.77 S 12.58 W 1000 1091 10.11 1090 1 1 N 9.87 E 6.44 N 11.87 W 1100 1193 11.45 1190 3 2 N 10.96 E 25.62 N 8.24 W 1200 1295 12.13 1290 5 2 N 13.18 E 46.03 N 3.90 W 1300 1398 15.52 1390 8 3 N 13.41 E 69.85 N 1.75 E 1400 1502 18.11 1490 12 4 N 11.40 E 99.37 N 8.26 E 1500 1609 21.40 1590 19 6 N 8.18 E 134.54 N 1600 1718 27.38 1690 28 10 N 4.54 E 179.71 N 1700 1834 33.57 1790 44 16 N 0.83 E 237.99 N 1800 1960 39.66 1890 70 25 N 2.67 W 313.39 N 1900 2095 45.55 1990 105 35 N 0.62 W 404.03 N 2000 2247 50.52 2090 157 53 N 3.80 W 519.34 N 2100 2403 49.41 2190 213 55 N 3.90 W 637.47 N 2200 2555 48.57 2290 265 52 N 3.25 W 751.87 N 2300 2706 48.76 2390 316 51 N 2.50 W 865.18 N 2400 2856 46.85 2490 366 50 N 2.46 W 976.54 N 14.33 E 19.31 E 22.24 E 19.99 E 16.89 E 12.46 E 3.54 E 3.59 W 9.28 W 14.36 W 2500 2999 45,68 2590 409 44 N 2.76 W 1079.71 N 18.76 W KRU 3G-17 (23-12-8) DATA INTERPOLATED FOR 100 FT Page SUBSEA INTERVAL 6 lO/12/9o SUBSEA DEPTH 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 MEAS INCLN TVD MD-TVD VERT DEPTH ANGLE BKB DIFF CRRT 3142 44.65 2690 452 3280 42.73 2790 490 3415 42.20 2890 525 3550 41.79 2990 560 3683 41.42 3090 593 3817 41.41 3190 627 3950 41.03 3290 660 4082 41.22 3390 692 4216 41.74 3490 726 4351. 42.52 3590 761 4487 43.25 3690 797 4625 43.98 3790 835 4765 44.81 3890 875 4907 45.49 3990 917 5050 44.57 4090 960 4100 5188 43.31 4190 998 4200 5325 43.57 4290 1035 4300 5464 43.99 4390 1074 4400 5604 44.83 4490 1114 4500 5741 42.73 4590 1151 4600 5878 43.15 4690 1188 4700 6016 43.82 4790 1226 4800 6155 44.73 4890 1265 4900 6297 45.60 4990 1307 5000 6438 44.01 5090 1348 DIRECTION BEARING 43 N 2.04 W 38 N 1.04 W 35 N 1.73 W 35 N 1.13 W 34 N 1.42 W 33 N 1.95 W 33 N 2.57 W 33 N 3.06 W 33 N 3.04 W 35 N 2.38 W 37 N 1.87 W 38 N 1.60 W 40 N 1.81 W 42 N 1.93 W 43 N 1.49 W 38 N 1.46 W 38 N 1.52 W 38 N 1.42 W 40 N 1.38 W 38 N 2.70 W 37 N 2.36 W 38 N 2.00 W 40 N 2.37 W 42 N 2.45 W 41 N 1.88 W RELATIVE COORDINATES FROM WELL HEAD 1181.50 N 23.03 W 1275.95 N 25.67 W 1367.35 N 27.78 W 1457.41 N 29.95 W 1546.10 N 31.73 W 1634.32 N 34.34 W 1721.73 N 37.72 W 1808.71 N 42.11 W 1896.95 N 46.86 W 1987.27 N 51.37 W 2080.13 N 54.53 W 2175.33 N 57.35 W 2273.17 N 60.30 W 2373.70 N 63.60 W 2475.71 N 66.64 W 2570.41 N 68.97 W 2665.02 N 71.48 W 2760.80 N 73.88 W 2858.70 N 76.25 W 2953.19 N 80.16 W 3046.13 N 84.09 W 3140.80 N 87.67 W 3238.30 N 91.46 W 3338.75 N 95.70 W 3437.92 N 98.97 W 5100 6576 43.55 5190 1386 38 N 2.83 W 3533.09 N 103.10 W KRU 3G-17 (23-12-8) Page 7 10/12/90 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL .SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 5200 6715 43.98 5290 5300 6854 44.31 5390 5400 6994 44.03 5490 5500 7132 43.52 5590 5600 7269 42.56 5690 5700 7404 41.66 5790 5800 7538 41.52 5890 5900 7670 40.31 5990 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 1425 38 N 2.82 W 3628.67 N 107.83 W 1464 40 N 3.44 W 3725.81 N 113.19 W 1504 40 N 3.66 W 3822.92 N 119.28 W 1542 39 N 4.94 W 3918.72 N 126.58 W 1579 37 N 5.07 W 4011.54 N 134.88 W 1614 35 N 0.83 W 4101.78 N 140.16 W 1648 34 N 0.28 W 4190.93 N 140.86 W 1680 32 N 0.09 E 4277.53 N 141.16 W KRU 3G-17 (23-12-8) Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 10/12/90 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 1000 3.52 1000 910 -4 N 0.47 W 4 S 2000 40.63 1921 1831 339 N 2.72 W 339 N 3000 45.68 2590 2500 1080 N 2.76 W 1080 N 4000 40.96 3328 3238 1755 N 2.90 W 1755 N 5000 46.00 4055 3965 2441 N 1.63 W 2440 N DL/ 100 13 W 13 S 71.41 W 2.3 19 E 340 N 3.17 E 2.4 19 W 1080 N 1.00 W 0.3 39 W 1755 N 1.28 W 0.3 66 W 2441 N 1.54 W 0,6 6000 43.71 4779 4689 3131 N 1.94 W 3130 N 7000 44.01 5495 5405 3829 N 3.66 W 3827 N 87 W 3131 N 1.60 W 0.5 120 W 3829 N 1.79 W 0.3 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. 10/12/90 Client .... : ARCO ALASKA, INC. Field ..... : Kuparuk River Unit Well · KRU 3G-17 (23-12-8) Section at: N,1.07,W Surveyor..: MIKE NAIRN Computation...: RADIUS OF CURVATURE Survey Date.,.' 09/22/90 RKB Elevation.: 90.00 ft Job Number .... : AK0990G244 API Number .... : 50-103-20140 INTERPOLATED MARKERS REPORT Surface Location: 2538 SNL 95 WEL S23 T12N R8E MARKER IDENTIFICATION 9-5/8" CASING. TOP KUPARUK C TOP KUPARUK A BASE KUPARUK C 7" CASING TD MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD 0 0.00 0 -90 0 N 0.00 E 0 N 3627 41.54 3048 2958 1509 N 1.13 W 1509 N 7430 41.70 5809 5719 4121 N 0.66 W 4119 N 7492 41.81 5856 5766 4162 N 0.27 W 4160 N 7492 41.81 5856 5766 4162 N 0.27 W 4160 N 0E 31 W 140 W 141 W 141 W 7780 40.31 6074 5984 4350 N 0.09 E 4349 N 7795 40.31 6085 5995 4360 N 0.09 E 4358 N 141W 141W Great Land Dire£t/onal Drill/ng. Ins. <KB>O 400 800 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 56O0 6000 6400 6800 7200 400 VERTICAL SECTION VIEW ARCO ALASKA. INC. KRU 3G-17 (23-~2-8) Section at: N 1.07 W TVD Scale.' ! inch = 800 feet Dep Scale.' ! inch = BOO feet Drawn ' 10/12/90 Mirker IdenLification MD TVD SECTN A) KB 0 0 0 B) TD 7795 6085 4360 ,, . INCLN 0.00 .3! 0 400 600 ~200 ~600 2000 2400 2800 3200 3600 4000 Section Departure Great Land O~'re£tianal O?l'lling. Inc. Marker Identification A) KB B) TO MD N/S E/W 0 ON OE 7795 435B N t41 t~ PLAN VIEW ARCO ALASKA, INC. KRU 36-17 (23-12-B) CLOSURE .....: 4361 ft N 1.85 DECLINATION.: 0.00 E SCALE .......: ! inch = 700 feet DRAWN .......: 10/12/90 4550 42.00 3850 3500 3t50 2450 2t00 i750 t400 t050 700 350 " 0 ~, 350 2. t00 t750 t400 i050 700 350 0 350 <- NEST · EAST -> 700 t050 i400 i750 2t00 AOGCC GEOLOGICAL M/l. ! r'.H. lP, L~ g~,lVr__Pl I UH.T LiST PERMIT # /9 o - /~ 2- WELL NAME j~/~ (.4/ COMPLETION DATE /.,~ ! '~' ~' ~ ~o CO. CONTACT chc'~:k off or list data as it is receivcd.~list received date for 407. if cored intc~als ' I core analysis ~ 'dw ditch intcwais , J , not re~,uircd list as NR V/~ !' core descriptio~,~ j digital data j ' '""'~ '' '-' i r,,,..,,,, I;,ITERVALS SCALE j I J rll Iki ' I NO. Ilo thc nearest foot] [inchl! 00'1 , ..... ,,, ........................ i ! ,, !181 ! J - I Jill i i J STATE OF ALASKA ALA,SKA OIL AND GAS CONSERVATION COMMIS,51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown Pull tubing Alter casing Stimulate Plugging Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 95' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1581' FSL, 235' FEL, Sec. 14, T12N, R8E, UM At effective depth 1581' FSL, 235' FEL, Sec. 14, T12N, R8E, UM At total depth 1820' FSL, 236' FEL, Sec. 14, T12N~ R8E, UM 12. Present well condition summary Total Depth: measured 7795' feet true vertical 6085' feet Plugs (measured) None 6. Datum elevation (DF or KB) ~)0' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number ,3G-17 9. Permit number/approval number c,)Q-122 10. APl number 5o-10:~-20140 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 7430' feet Junk (measured) true vertical 5809' feet None Casing Le n gt h Size Structural Conductor 1 1 5' 1 6" Surface 3 62 7' 9 - 5 / 8" Intermediate Production 777 5' 7" Liner Perforation depth: measured 7502'-7520', true vertical 5863'-5877', Tubing (size, grade, and measured depth) Cemented Measured depth 219 Sx AS I 1 15' 700 SxAS III & 3627' 480 Sx Class G 198SxAS III & 7775' 160 Sx Class G 7462'-7492', 7430'-7462' 5833'-5856', 5810'-5833' 3-1/5" 9.3#, EUE, ABMOD, @7336' Packers and SSSV (type and measured depth) SSSV: Otis Series 10 (1787'), Packer: Camco HRP-I-SP (7250') 13. Stimulation or cement squeeze summary Perforate 7520'-7430' Intervals treated (measured) True vertical depth 115' 3045' 5917' RECEIVED JAN B 199 ~laska Oil & Gas Co~,~ Anchorage Treatment description including volumes used and final pressure 14. Prior to well operation Representative Daily Averaae Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure -536-/~' -237- -328- -40 - Tubing Pressure -192- Subsequent to operation -1210-¢'-615- -1527- -1100- -169- 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Title Operations Engineer Date SUBMIT IN DUPLICATE ARCO Alaska, Inc,'~ Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL 'TRACTOR REMARKS "PBDT7~' ~;~w I FIELD - DISTRICT- STATE OPERATION AT REPORT TIME DAYS DATE I--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather [Temp' Chill Fact°r VisibilitylWind Vel'Report OF OF miles Signed ARCO Alaska, Inc. Sul::)sicliary of Atlantic Ric~fielcl Corn WELL ~PBDT d __3G, -/7 /// ' -7 ~?z,' REMARKS / FIELD ' ~STRICT - STATE R. £./~ ~OPERAT..~.~, AT RE-PORT TIME [ WELL SERVICE REPORT iDAYS DATE j I ~)7oo o~3o ~>9oo · /lZ.o 1285" /8oo /5'/7- ,/200 /5'00 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ITemp. Chill Factor Visibility IWind Vel. I Signecl °F °F milesJ knots J Weather DIST: ORIG - NSK KOE FILES DSENG KOE FEES DS FOREMAN NSK CENT FILES KUPARUK OPERATIONS ENGINEERING PERFORATION RECORD WELl NAME: ~ ' I ? - G; ~ (~ . ENG REP: bj Nt. ~-~'g TIED IN wire: 5~ ~ATEO ~/~'/~& ,~ ~~ b~o COMPLETION ~AILS: ~,~'; ~/~~- P~f GUN INFO: ~ ¥" ~y~~,~ ' ORIENTATION: -ct/ DATE' ~/~ ~ - SERV. CO & ENG: PERI= INTERVAt: SAND A3 INT SAND ~ INT SPF: .. z~ , PHASING: GRAM WT: ~ o.f, HOLE SIZI~ GUN P~K)POSED Pk~-F'(~,E-D' GUN CCL RUN PERFORATIONS PERFC)RATI~S LENGTH TO TOP NO. (m d. DI~)., (m d-CET) ( tt ) SHOT CCL SETTING DEPTH COMMENTS SAND INT TIME GIJH SHOT ) 7 5'02 - 7S,~o ~soO.:; - ?yl~,~ /;~' ~. o' '7 ~.¢..~, 4. ~ ~ 24-~',.2 - -;q-q:~ -7 46o.,c- ?~-qo.$ 57.~' )q-55. o ' 7q6'z . '7 ~']7.. 7Hbo.5" 7~qo.>' ~o ~.~ v ,4C.C ARCO Alaska, Inc. Date: November 2, 1990 Transmittal #: 7940 RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. signed copy of this transmittal. / '/3G-14 Pulse Echo Cement Evaluation(PET) 9- /3'G-1 6 Pulse Echo Cement Evaluation(PET) 9- /,~G-17 G-18 ,,~G- 14 17 ~,R'G- 18 Please acknowledge receipt and return one 2 2 Pulse Echo Cement Evaluation(PET) 9- 2 Pulse Echo Cement Evaluation(PET) 9- 2 Acoustic Cement Bond Log 9 - 2 Acoustic Cement Bond Log 9 - 2 Acoustic Cement Bond Log 9 - 2 Acoustic Cement Bond Log 9 - 2 5-90 3308-6908 4-90 5820-9530 2-90 4668-7668 4-90 6500-9520 5-90 2992-6919 4-90 6500-9535 2-90 4668-7668 4-90 6500-9520 Date: DISTRIBUTION: Drilling NSK RECEIVED · ~-~Stat~'°[Alaska(+Sepia) 7: I'IOV ~u;b, l~J~(J ...................... :,~:~--" Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date' September 28, 1990 Transmittal #: 7904 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3G-17 3G-20 3G-18 LIS Tape and Listing LIS Tape and Listing LIS Tape and Listing Please acknowledge receipt and return 9-5-90 3500-7850~ ~-'~' 9-18-90 4550- 10150~' z~,.~ 9-24-90 6550-9700 ~~.--], Receipt Acknowledged: Date' DISTRIBUTION: Lynn Goettinger State of Alaska OC]' o; 1.990 Alaska Oil & Gas Cons. ~mmission Anchorage ARCO Alaska, Inc. Date: September 28, 1990 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 OCT 0 i 1.990 Alasl(a 011 & Gas C~ns. C~mmissmn Anchorage Transmitted herewith are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. ~ 3G-17 8-31 -90 3533-7795 3Go17 8-31 -90 3533-7795 3G-20 - 9o12-90 4640-10100 3G-20 9-1 2-90 4640-1 0100 3G-18 9-20-90 4566-9650 3G-18 9-20-90 4566-9650 Dual Gamma Ray Compensated Neutron Porosity Simultaneous Formation Density Dual Gamma Ray Electrmagnetic Wave Resistiyity Formation Exposure Time Dual Gamma Ray Compensated Neutron Porosity Simultaneous Formation Density Dual Gamma Ray Electrmagnetic Wave Resistivity Formation Exposure Time Dual Gamma Ray Compensated Neutron Porosity Simultaneous Formation Density Dual Gamma Ray Electrmagnetic Wave Resistivity Receipt Acknowledged- '~~----~ .... Date- ., DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK 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 X Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2538' FNL, 95' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1500' FSL, 170' FEL, Sec. 14, T12N, R8E, UM At effective depth NA At total depth 1730' FNL, 174' FEL, Sec. 14, T12N, R8E, UM (approx) (approx) 12. Present well condition summary Total Depth: measured 7795' feet (approx) true vertical 6098' feet Effective depth: measured NA feet (approx) true vertical NA feet Plugs (measured) None Junk (measured) None 6. Datum elevation (DF or KB) RKB 90' 7. Unit or Property name Kuparuk River Unit 8. Well Number 3G-17 9. Permit number 90-122 10. APl number 50-103-20140 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Size Structural Conductor 8 0' 1 6" Surface 3592' 9 5/8" Intermediate Production 7743' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented 219 SXAS III 770 Sx AS III & 480 Sx Class G 198 Sx AS III & 160 Sx Class G tail Measureddepth True ve~ical depth (approx) 115' 115' 3627' 3046' 7780' 6087' 13. Attachments Description summary of proposal Detailed operation program X BOP sketch 14. Estimated date for commencing operation November, 1990 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. Si~jned ~, ~/~, /¢'//~Y/,,~,-~ Tit,e Area Drilling Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission 10- 4 Commissioner IApproval No. Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SM!TH Approved Copy Fjeturr/ed SUBMIT IN TRIPLICATE /' feet ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Fill;OH" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to SDudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field KUPARUK County. parish or borough NORTH SLOPE JLease or Unit ADL: 25547 ALK: 2661 Title DRILLING Auth. or W.O. no. AK5130 IState AK I Well no. 3~-17 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 08/27/90 (1) TD: 530' ( 530) SUPV:JMM 08/28/90 ( 2) TD: 3650' ( 3120] SUPV: JMM 08/29/90 (3) TD: 3660'( SUPV:JMM 08/30/90 (4) TD: 5751'( 2091 SUPV:JMM 08/31/90 (5) TD: 7272' ( 1521 SUPV: JMM 09/01/90 (6) TD: 7795' ( 523 SUPV: Olv~M 08/27/90 IH°ur Complete record for each day reported DOYON 14 02:30 IARCO W I 55.2500 Prior status if a W.O. NAVIDRILL 12.25" MW: 8.7 VIS: 62 MOVE RIG FROM 3G-14 TO 3G-17. N/U DIVERTER AND TEST SAME. P/U AND M/U BHA. SPUD AT 55', DRILL.CMT TO 115'. P/U MWD AND ORIENT MOTOR. NAVIDRLG FROM 115' TO 530'. DAILY:S58,113 CUM:$58,113 ETD:S58,113 EFC:$1,350,000 POOH TO RUN 9-5/8" CASING MW: 9.6 VIS: 44 DRILL FROM 530' TO 3650'. WIPER TRIP TO 1030', CIRC BU, POOH TO RUN 9-5/8" SURFACE CASING. DAILY:S56,494 CUM:$114,607 ETD:S114,607 EFC:$1,350,000 PERFORMED EMW TEST 9-5/8"@ 3627' MW: 9.5 VIS: 38 POOH, RUN 93 JTS 9-5/8", 36#, J-55, BTC CASING. CEMENT WITH DOWELL: 80, BBLS WATER, 266 BBLS (770 SX) ASIII 12.1 PPG LEAD CEMENT, 99 BBLS (480 SX) CLASS G 15.8 PPG TAIL CEMENT. DISPLACE WITH 274 BBLS WATER, BUMP PLUG TO 2500 PSI, FLOATS HELD OK. ND DIVERTER, MU 9-5/8" CASING HEAD, NU BOPE, TEST BOPE. RIH WITH PDC BIT AND TURBINE, DRILL FLOAT COLLAR AT 3546', TEST CASING TO 2500 PSI, OK. DRILLOUT FLOAT SHOE AND 10' OF NEW FORMATION TO 3660'. PERFORM EMW TEST TO 12.2 PPG WITH 9.5 PPG MUD AND 431 PSI SURFACE PRESSURE AT TVD=3072' HELD OK. DAILY:S175,038 CUM:$289,645 ETD:S289,645 EFC:$1,350,000 DRILLING AT 5751 9-5/8"@ 3627' MW: 9.6 VIS: 38 /DRILL WITH TURBINE FROM 3660' TO 5751', ADT= 18.2 HRS, AST-1.6 HRS. DAILY:S116,107 CUM:$405,752 ETD:S405,752 EFC:$1,350,000 ORIENT RLL 9-5/8"@ 3627' MW: 9.7 VIS: 37 TURBODRLG 5751' TO 7272', CIRC BTTMS UP, POOH TO 9-5/8" SHOE. CIRC AND BALLANCE MUD 9.7. PERFORM EMW, UNABLE TO OBTAIN 11.0 PPG F_.MW. 386 PSI @ 5707 TVD. BLED OFF TO AND HELD AT 250 PSI = 10.5 EMW. POOH FOR BIT AND BHA. CHANGE OUT BHA AND BIT, RIH W/ ROTARY ASSY AND NEW BIT, ORIENT RLL. DAILY:S67,895 CUM:$473,647 ETD:S473,647 EFC:$1,350,000 WIPER TRIP FOR 7" CSG 9-5/8"@ 3627' MW:10.7 VIS: 40 REAM FROM 7223' TO 7272', LOG WITH RLL. ROTARY DRILL FROM 7272' TO 7297' WHILE MIXING LCM. PUMP 15 PPB LCM SLUG ACROSS OPEN HOLE, POOH TO SHOE. PERFORM LOT TO 11.0 PPG EMW WITH 10.5 PPG MUD. TEST GOOD, ROTARY DRILL FROM 7297' TO · 7795 TD. WIPER TRIP, PULLED 15 STANDS AND HOLE SWABBED. RIH AND CIRC, MUD WAS GAS CUT FROM 10.7 TO 9.1 PPG. WIPER TRIP TO 9-5/8' SHOE. DAILY:S67,426 CUM:$541,073 ETD:S541,073 EFC:$1,350,000 The above is correct For form preparation ~'~--distributio~ ~.-~ ~= ~'~ ~ ~41 ~:,.~ see Procedures Mar~al~l Section 10, ~'~. E ~ ~ OrilHng, Pages 86 a~7. ~ '~ ~--~ AR3B-459-1-D Title ,- INumber all daily well hlslorj/ forms consecutively as they are prepared for each well, iPage no. ARCO 0,, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Flrlel Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned. or Sold. "Final Report" should be submitted alaowhell operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report compleflOl3 and representative test data. in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District I Accounting cost center code IC°unty® I State ARCO ALASKA I~C. J NORTH SLOPE J AK Field ILease or Unit IWell no. KUPARUK [ ~G- 17 Auth. orW.O, no. Title ADL: 25547 ALK: 2661 I AK5130 J DRILLING Operator IA.R.Co. W.I. ARCO IDate 55. 2500 I Spudded or W.O. begun SPUD J 08/27/90 Date and depth as of 8:00 a.m. 09/02/90 ( 7) TD: 7795'( 0 SUPV:JMM Complete record for each day reported DOYON 14 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our l Prior status if a W.O. I 02:30 MOVING RIG 9-5/8"@ 3627' MW:10.7 VIS: 0 FINNISH SHORT TRIP TO SHOE. CIRC AND COND HOLE, DROP S.S. SURVEY, SPOT DIESEL PILL. POOH LDDP. RUN 177 JTS OF 7" CSG, LOST RETURNS WITH 60TH JT IN HOLE. PUMP CEMENT, BUMP PLUG W/ 3000 PSI, HELD OK. R/D CMT HD, N/D BOPS, SET SLIPS AND CUT CSG, N/U TREE, MOVE RIG. CONT WIPER TRIP TO 9-5/8" SHOE. CIRC, DROP SS SURVEY, SPOT DIESEL PILL. POOH, RUN 177 JTS 7" 26#, J-55, BTC AB MOD CASING. LOST RETURNS AT 60TH JT IN HOLE. RU DOWELL, ATTEMPT TO CIRC, NO LUCK. PUMP 10 BBL PRE-FLUSH, 35 BBL SPACER AT 11.7 PPG, 75 BBL (198 SX) ASIII LEAD CEMENT AT 12.1 PPG, 34 BBL (160 SX) CLASS G TAIL CEMENT @ 15.8 PPG. DISP WITH 295 BBL OF 10.7 PPG BRINE. BUMP PLUG TO 3000 PSI, FLOATS OK, CIP @ 0145 9/2/90. PUMP 50 BBLS OF 10.7 PPG MUD DOWN ANNULUS. ND BOPE, SET SLIPS, NU TREE, TEST TREE TO 3000 PSI. MOVE RIG OFF 3G-17 AT 06:00 HRS, 9/2/90. DAILY:S202,965 CUM:$744,038 ETD:S744,038 Old TD Released rig EFC: $1,350,000 New TO Date Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data ~Vell no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected e Correct SJgn~ ~ Date// J Tit, J.9 ~-or form prepa/'a.f~iJ:)n and distribution, 0 J I see Procedures~M'anual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well histow forms consecutively as they are prepared for each well. jPage no. Dlvlllon of AtlsntlcRIchfleldCofnpan¥ August 24, !990 Telecopy.. (907)276-7542 A. Wayne. McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box !00360 Anchorage, Alaska 99510-0360 P~e: Kuparuk River Unit 3G-17 ARCO Alaska, Inc. Pc?mit No. 90-122 Sur. Loc. 2538'FNL, Btmho!e Loc. 1730'FSL, 95'FEL, Sec. 23, T12N, RSE, UM. !74'F~, Sec. 14, T12N, RSE, UM. Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until ali. other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. ~,,- .-,, lb/ : Commissioner Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~4iSStON d!f Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA A~KA OIL AND GAS CONSERVATION COMMIf:~iON PERMIT TO DRILL 20 AAC 25.005 ! la. Type of Work Drill X Redrill __ I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil _X Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone 2_. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 90', Pad 53' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25547 ALK 2661 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25,025) 2538' FNL, 95' FEL, Sec. 23, T12N, RSE, UM Kuparuk River Unit At top of productive interval (TARGET) 8. Well number Number 1500' FSL, 170' FEL, Sec. 14 , T12N, RSE, UM 3G-17 #U630610 At total depth 9. Approximate spud date Amount 1730' FSL, 174' FEL, Sec 14, T12N, RSE, UM 28-AUG-90 $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 3G-16 7733' MD 1500'@ TD feet 25' AT surface feet 2560 6083' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 900' feet Maximum hole angle 44° Maximum sur~ac~ 1820 psig At total depth(TVD) 3100 psi~ @ 5845' 18. casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length IVD TVD IVD TVD (include stage data1 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' _+200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 3491 35' 35' 3526' 3060 1500 Cu. Ft. AS III & 550 Cu. Ft. Class G 8.5 7" 26.0# J-55 AB-MOl' 3791 35' 35' 3826' 3275' 190 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 3907' 3826' 3275' 7733' 6083' Top 500' above Kuparuk 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 verticaltrue vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Cu. Ft. RECEIVED Surface Cu. Ft. Intermediate Production AUG 2 1990 Liner Perforation depth: measured O./I.& Gas Cons. true vertical '"'}., ~lchorag~ .~ .... · . , 20. Attachments Filing fee ~ Property plat __ BOP Sketch X Diverter Sketch _~ Drilling program ~ Drilling fluid program X__ Time vs depth plot __ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _~~ ~,~~ Title Area Drilling Engineer Date I Commission Use Only I ~' ' Permit Number I AP, number I Approva, date ~ See cover letter for ~4:~-/ ~. ~ 50- //~),~-"' ~O//~4:~ 08/24/ 0 other rec{uiremenls Conditions of approval Samples required ~Y e s .~ N o Mud Icg required~ Ye s .,~ N o Hydrogen sulfide measures __ Yes ~ N o Directional survey required /~ Yes __ N o Required working pressure for DOPE __2M; ~ 3 M; __ 5 M' __ I 0M' __ 1 5 M Other: ~~ ~'~_~"'~-/ by order of ~ ~ Approved by Commissioner the commission Date "'Z Form 10-401 Rev. ~/' Submit in triplicate DRILLING FLUID PROGRAM (3G-17) Spud to 9-5/8" Drill out to Weight up surface casing weight up to TD Density 8.6-10.0 8.6-9.3 11.0 PV 1 5-35 5-1 5 1 0-1 8 YP 15-35 5-8 8-12 Viscosity 50-100' 30-40 35-50 Initial Gel 5-15 2-4 2-4 10 Minute Gel 15-40 4-8 4-8 APl Filtrate 10-1 2 8-1 0 4-5 pH 9- 1 0 8.5-9 9.0-9.5 % Solids 10 +/- 4-7 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: RECEIVED - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1820 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 3G-17 will be 3G-16. As designed, the minimum distance between the two wells would be 25' at surface. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. 2OO 150 100 5O 5O 100 2OO I - I I 2O0 150 100 I 5O 5O 100 I 150 200 ~ I 1700 I 150 I 100 I i I' 500 2 9oo I T 11 O0'~ 2,,500 szss ~,:: '."~ ,~ ~ ~ 0 0 700 0 1700 0 [ ~00 , ~0~ 50 0 50 100 1 50 20O _ 20O .150 100 5O 5O 100 HOR;. ..JNTAL PROJECTION SCALE 1 IN. = 1000 FEET TD LOCATION' 1730' FSL. I74' FEL SEC. 14, T12N, RSE Z 5000 4000 - 3000 - 2000 - 1000 _ ~ 1000 _ ARCO ALASKA, lnG. Pad 39, Well Not 17 Propoaad Kuparuk Field. North Slops. Alaska WEST-EAST 2000 1000 0 1000 I I ..I TARGET / TOP ZONE C TVD-$845 T,D=?403 DEP-4039 NORTH 4038 VEST 75 TARGET LOCATION, 1500' FSL. 170' FEL SEC. 14. T I2N, RSE SURFACE LOCATION' 2538' FNL, 95' FEL SEC. 23. T12N. R8E N 1 DEG 4 HI N W 4039' (TO TARGET) ARCO ALASKA, !ne. Pad 3G. Well No' 17 Kuparuk Field, Nor th Proposed Slope, Al asl<e 0 . RKB ELEVATION' 90' m i-I1 ---i i-I1 1 000 _ 2000 _ 5000 _ 4000 _ 5000 _ 6000 _ 7000 - KOP 9 15 21 27' ~gEOC TVD=2228 T/ 14 SAK SNDS TVD=900 THD=900 DEP=O BUILD 3 DEG PER ! O0 FT B/ PERHAFROST TVD=1605 THD=1622 DEP=135 T/ UONU SNDS TVD=1785 THD=1820 DEP=217 THD=2369 DEP=538 TVD=2400 THD=2608 DEP=704 B/ 14 SAK SNDS TVD=2860 THD=3248 DEP=1149 9 5/8" CSO PT TVD"'3060 THD"3526 DEP-1343 K-lO 'rVD'.'3340 '1'HD=3916 DEP-'1614 AVERAGE ANGLE 44 DEG 4 Hi N K-5 TVD=4840 THD=6004 DEP=3066 FAROET / TOP ZONE C TVD=5845 TIID=7403 DEP=4039 T/ ZONE A TVD=5850 THD=7410 DEP=4044 B/ KUP SNDS TVD=5939 THD=7533 DEP=4130 TD / LOG PT TVD=6083 THD=7733 DEP=4269 I I I 0 1 000 2000 3000 VERTICAL SEC:TI ON EC[IV[D · % AUG /~.la.s,ka Oil .& Gas Cons, I 4000 I 5000 GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 3G PAD 10. 11 12 13 14 15 16 17 18 19. 20. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. 21. Reperforate and add additional perfs. KJPARUK RIVER UNI~ 20" DIVERTER SCHEMATIC 5 6 4 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENAN(~E & OPERATION , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16"CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 13 5/8" 5000BOP STACK 7 , 6 ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TESTTO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSi HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO~-FOM PIPE RAMS. TEST BO~-FOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 CHECK LIST FOR NEW WELL PER}£1TS IT_nM APPROVE DATE (2 "~ .9 ~.r: ~'~" - lO. (lO a:d i3) ].2.. 13. (4) ~'- ,,',, , (.1.4,thru 2.~) (~ thz-= 28) (6) rev: 01/30/89 6.011. Company_ ~~"c-_r) Lease & Well No. v. ES NO Is the permit fee attached .......................................... ~ 2. Is well to' be located in a defined pool ............................. 3. Is we!! loca:ed proper distance from property line .................. 4. Is well located proper distance from other wells ........ ~ ........... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated amd is we!!bore pla: included ................ 7. Is opera:or the only affected parry. ......... : ....................... 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. is a conserve:ion order needed ...................................... Is administrative approval needed ................................... Is the lease number appropria:e ..................................... Does =he wa!! have a unique name and number ......................... 14. 15. 16. I7. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. 32. IS e. 6nductor string provided ........................................ Will surface casing pro=act all zones reasonably e.xp. ected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... W'~m!! cement :ia in surface and intarmedia:e or production strings . ..' Will cement cover ~ knom-n productive horizons ..................... Will al! casing give adequate safety in collapse, :ension and burs:. Is this well to be kicked off from an e.?-;s=ing wellbore ............. is old we!!bore abandonment procedure included on 10-403 ............ Is adequate we!!bore separation proposed ............................ Is a diver=er system req=ired ....................................... Is =he drilling fluid program schema=it and list of equipment adequate Are uecessary diagr~ and descriptions of diver~ar and BOPE ac=ached. Does BOPE have sufficient pressure rating - Test to ~ o psig .. Does =he choke manifold comply w/APl K?-53 (May 84) .................. Is the presence of H2S gas probable ............................. ~... exploratory and S=ratigraphic wells: Are data presen:ed on po=an:ia! overpressure zones? ................. Are seismic analysis data presen:ad on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. Addi:ional R-~arks: Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. T° 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 APPENDIXi No special 'effort has been made to chronologically organize this category of information. .,, - .. (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/09/05 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 90/09/05 ORIGIN OF DATA: 3G17 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** RECEIVED 01 iBBO 41aska Oil & Gas Cons. Commission Anchorage ** DATA VERIFICATION (every DEPT ROP NFO FXE EWR GRC 100 FT) NFl RHOB NN0 NPSC NN1 CAL 3500.000 -999.250 457.000 457.000 2344.000 2264.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3600.000 174.400 418.870 426.974 2440.000 2364.779 1.649 19.899 52.740 3.020 54.502 8.760 3700.000 276.416 503.166 541.667 2499.999 2454.668 .605 4.744 95.685 2.310 47.204 8.610 3800.000 239.590 513.293 510.678 2422.565 2343.013 4.986 4.633 88.986 2.260 48.350 9.310 3900.000 134.371 551.000 554.645 1.241 4.512 88.955 2.197 4000.000 116.356 511.000 497.000 .747 4.331 97.945 2.250 4100.000 171.763 542.600 518.450 .860 3.712 97.964 2.299 4200.000 153.442 543.000 583.000 .835 3.901 98.699 2.278 4300.000 160.190 540.604 .917 4.003 106.550 4400.000 .834 4500.000 .861 4600.000 .864 4700.000 .640 4800.000 .822 4900.000 .573 5OOO.OO0 1.117 129.576 535.000 3.377 100.205 160.760 575.000 4.251 101.656 150.586 593.152 3.159 107.740 180.703 583.000 3.131 106.310 181.055 519.000 3.078 84.384 194.192 567.000 2.397 75.074 136.719 663.000 5.554 91.177 144.773 615.000 3.302 78.871 175.698 649.026 3.130 118.710 126.502 583.000 2.131 123.777 163.171 559.000 1.893 133.465 5100.000 .800 535.812 2.294 559.000 2.244 527.000 2.385 574.948 2.359 615.000 2.242 559.000 2.380 567.000 2.422 639.000 2.511 551.000 2.353 632.982 2.431 551.000 2.431 607.000 2.415 5200.000 1.110 5300.000 .799 2433.501 45.381 2520.000 46.631 2528.400 45.845 2504.000 43.949 2552.000 44.714 2552.000 43.132 2600.000 42.640 2622.049 40.920 2664.000 40.199 2840.000 38.590 2680.000 40.033 3016.000 32.372 2792.000 36.557 2643.948 37.456 2648.000 44.152 2456.000 44.933 5400.000 .916 2558.499 8.680 2472.000 8.690 2489.600 8.720 2488.000 8.590 2516.831 8.750 2584.000 8.690 2616.000 8.700 2610.261 8.690 2600.000 8.640 2760.000 8.760 2664.000 8.910 2968.000 8.870 2792.000 8.520 2691.978 8.850 2440.000 8.900 2440.000 8.770 DRHO -999.250 .594 5.833 9.812 6.988 7.348 7.091 6.311 7.044 6.287 6.129 6. 157 6.160 6.099 6.124 5.603 5.263 5.878 6.200 6.071 5500.000 · .709~ 5600.000 1.250 5700.000 .729 5800.000 .752 5900.000 .791 6000.000 .651 6100.000 .769 6200.000 .673 6300.000 1.029 6400.000 .777 6500.000 .720 6600.000 .835 6700.000 .866 6800.000 .768 6900.000 .831 7000.000 .849 7100.000 1.129 7200.000 11.335 7300.000 1.352 7400.000 1.250 7500.000 .810 7600.000 1.176 7700.000 1.523 125.948 5.985 186.855 2.727 101.028 2.728 200.391 2.984 156.827 3.515 177.706 3.385 197.153 3.773 183.955 4.018 187.646 3.905 180.703 4.918 95.107 4.977 190.399 5.130 170.747 4.008 66.992 6.560 180.703 3.899 150.398 3.663 132.024 3.250 87.318 3.221 135.284 2.503 51.454 3.095 60.791 6.732 72.024 7.844 37.186 4.337 527.000 101.513 592.796 123.815 536.268 106.009 615.000 100.501 607.000 101.375 599.000 100.959 607.000 92.671 583.000 98.699 632.137 101.966 591.000 90.411 591.000 93.425 607.000 104.879 591.000 101.053 654.480 82.837 598.437 112.694 679. 000 139.974 681.915 207.776 511.580 145.423 503.637 110.018 528.922 77.110 600.064 80.786 607.289 80.508 576.278 94.649 559.000 2.517 590.539 2.204 597.146 2.495 551.000 2.418 599.000 2.327 599.000 2.486 631.000 2.387 631.000 2.405 587.182 2.343 559.000 2.463 607.000 2.528 607.000 2.507 591.000 2.512 604.736 2.448 576.915 2.498 695.000 2.432 647.034 2.442 511.000 2.234 531.665 2.349 514.668 2.391 599.714 2.412 584.770 2.367 560.349 2.422 2520.000 42.626 2661.530 40.229 2723.122 40.582 2680.000 41.536 2760.000 39.403 2600.000 38.440 2744.000 37.724 2760.000 38.306 2944.408 34.754 2696.000 37.674 2808.000 35.728 2760.000 36.516 2776.000 37.685 2885.919 34.338 2688.789 38.997 2568.000 38.695 2469.153 41.344 2273.280 52.145 2334.230 51.842 2376.284 53.369 2755.481 36.791 2769.502 37.558 2540.489 43.726 2552.000 8.840 2585.393 8.920 2612.292 8.800 2584.000 8.690 2552.000 8.560 2776.000 8.910 2744.000 8.530 2712.000 8.550 2910.091 8.580 2840.000 8.620 2984.000 8.750 2712.000 8.880 2760.000 8.800 2854.959 8.660 2716.958 8.770 2584.000 8.680 2511.254 8.760 2269.800 10.030 2399.406 8.750 2326.254 8.970 2776.000 8.970 2773.068 8.690 2529.262 8.720 5.105 8.042 5.313 5.489 5.928 5.494 5.245 4.982 6.284 4.654 4.436 5.017 5.475 5.104 5.051 5.564 5.691 10.266 6.361 6.236 5.923 5.701 5.257 ~800%0'00' -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .000 ** 458 DATA RECORDS ** FROM 3500.00 TO 7850.00 FT ** FILE TRAILER** FILE NAME: 3G17.MWD SERVICE NAME': RLL VERSION #: V2.0 DATE: 90/09/05 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 2) ********** ** TAPE TRAILER** SERVICE NAME: RLL DATE: 90/09/05 ORIGIN OF DATA: 3G17 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/09/05 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT